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192-084
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 2M-30 (PTD 192-084) Failed MITOA Date:Monday, August 25, 2025 10:27:36 AM Attachments:TIO and Bleed History (2).pdf 2M-30.pdf From: Bronga, Jaime <Jaime.Bronga@conocophillips.com> Sent: Monday, August 25, 2025 9:58 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Automation, AK Wells <akwellsautomation@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 2M-30 (PTD 192-084) Failed MITOA Well Name: 2M-30 Facility: CPF2 PTD: 192-034 Well Type: Inj AA Number (if applicable): AIO 2C.045 Internal Waiver (Yes/No if applicable): Yes Type of Issue: Failed MITOA Maximum Pressure (if applicable): Date of Occurrence (if applicable): Hi Chris, KRU 2M-30 (PTD 192-034) is an injection well operating under AIO 2C.045 for water only injection due to TxIA communication on gas injection. MIT-OA failed on 8/23/2025 and the subsequent surface casing leak detection on 8/24/2025 found a surface casing leak at 480 ft. As per the AA, the well will be shut in until the proper approvals have been received. CPAI intends to amend the waiver to include the surface casing leak. Please let me know if you have any questions or disagree with this plan. The TIO plot, schematic and bleed log are attached. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 AAnnnnuulaarr BBeehhaavviioorrss |TIO Pressures and Injection Rates Well Name 2M-30 Annular Pressures 0K 1K 2K Date Pressure (PSI)Jun 2025 Jul 2025 Aug 2025 Well is SI Tubing Pressure IA Pressure OA Pressure OOA Pressure Wellhead Temperature 0 50 100 Date Temperature (F)Jun 2025 Jul 2025 Aug 2025 Injection Rates 0K 2K 4K DateRateJun 2025 Jul 2025 Aug 2025 Gas Rate (MSCFD)Water Rate (STBD) INJ Date 90 5/28/2025 - 8/25/2025 Last Days AAnnnnuulaarr BBeehhaavviioorrss |Bleed History Date 90 5/28/2025 - 8/25/2025 Last Days Well Name Test Date IA Start Pressure IA End Pressure OA Start Pressure OA End Pressure OOA Pressure OOOA Pressure Well Name 2M-30 File Path (Copy and Place in File Explorer) \\nsknafs1\schematics$\Kuparuk and Satellites\Cpf2-Tarn-Tabasco-Meltwater\2m\2M-30.pdf Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 9,010.0 5/3/2021 2M-30 rogerba Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Tag & SBHP 5/3/2021 2M-30 rogerba Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 19.12 Top (ftKB) 40.0 Set Depth (ftKB) 119.0 Set Depth (TVD) … 119.0 Wt/Len (l… 94.00 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 40.2 Set Depth (ftKB) 3,487.0 Set Depth (TVD) … 2,763.0 Wt/Len (l… 45.50 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 39.3 Set Depth (ftKB) 9,331.6 Set Depth (TVD) … 6,371.9 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 39.1 Set Depth (ft… 8,865.9 Set Depth (TVD) (… 6,007.7 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE-ABM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 39.1 39.1 0.08 HANGER FMC GEN IV 3.500 1,824.1 1,721.1 39.45 SAFETY VLV CAMCO TRDP-4A MOD SSSV 2.812 8,826.8 5,977.3 38.85 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 2.985 8,829.8 5,979.6 38.85 PACKER BAKER F-1 PACKER w/XO SBE (0D=5", SEAL BORE ID=4" 4.000 8,853.3 5,997.9 38.87 NIPPLE CAMCO D NIPPLE w/NO GO PROFILE 2.750 8,865.0 6,007.0 38.87 SOS BAKER SHEAR OUT. TTL ELMD @ 8860' SWS PERF 12/2/1993 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 9,245.0 6,304.0 38.48 FISH 7 1/2" X 2" Bullnose Left in Hole 12/2/1993 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,936.0 8,968.0 6,062.3 6,087.2 C-4, A-4, 2M-30 12/2/1993 6.0 APERF 2 1/8" EnerJet; V' PhasE 8,978.0 8,996.0 6,095.0 6,109.0 A-4, A-3, 2M-30 12/22/1992 4.0 IPERF SWS 4.5" Csg Gun; 180 deg. ph; Orient 14.3 deg CCW F/ High Si 8,996.0 9,016.0 6,109.0 6,124.7 A-4, A-3, 2M-30 12/22/1992 4.0 IPERF SWS 4.5" Csg Gun; 180 deg. ph; Orient 3.3 deg. CCW F/ High S 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 8,775.1 5,937.0 38.76 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/8/2018 Notes: General & Safety End Date Annotation 11/17/2010 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 2M-30, 5/4/2021 7:11:02 AM Vertical schematic (actual) PRODUCTION; 39.3-9,331.6 FISH; 9,245.0 IPERF; 8,996.0-9,016.0 IPERF; 8,978.0-8,996.0 APERF; 8,936.0-8,968.0 SOS; 8,865.0 NIPPLE; 8,853.3 PACKER; 8,829.8 SEAL ASSY; 8,826.8 GAS LIFT; 8,775.1 SURFACE; 40.2-3,487.0 SAFETY VLV; 1,824.1 CONDUCTOR; 40.0-119.0 HANGER; 39.1 KUP INJ KB-Grd (ft) 45.02 Rig Release Date 8/28/1992 2M-30 ... TD Act Btm (ftKB) 9,350.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032018000 Wellbore Status INJ Max Angle & MD Incl (°) 56.09 MD (ftKB) 5,439.67 WELLNAME WELLBORE2M-30 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, December 19, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2M-30 KUPARUK RIV UNIT 2M-30 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/19/2024 2M-30 50-103-20180-00-00 192-084-0 W SPT 5979 1920840 3000 2650 2650 2650 2650 220 220 220 220 REQVAR P Austin McLeod 10/31/2024 Two year to MAIP. AIO 2C.045. 30 MinPretest Initial 15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name: KUPARUK RIV UNIT 2M-30 Inspection Date: Tubing OA Packer Depth 820 3300 3210 3210IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM241031180928 BBL Pumped:2.5 BBL Returned:2.4 Thursday, December 19, 2024 Page 1 of 1 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:Well Integrity Specialist CPF2 Subject:FW: CPAI 2M-03 (PTD #191-141) AA requirement discussion. Date:Tuesday, May 14, 2024 2:27:45 PM Attachments:image001.png CPAI_2M-03_SCMT_31Mar24_FieldPrint (2).Pdf 2M-03 Tubing and IA PT 4-10-24 (2).pdf 2M-03 Schematic.pdf 2M-03 Diagnostics OA-DDT 17 April 2024.xlsx 2M-03 Diagnostics MIT-IA 6 May 2024.xlsx Dusty, Thank you for following up on this with the call just now. As discussed, we are in agreement with the “normal” operation of the repaired well and believe in the passing MITIA and in general the CPAI surveillance/monitoring. As per AIO and regulation requirements, we can revisit this as changes in well conditions warrant. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Thursday, May 9, 2024 3:55 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: CPAI 2M-03 (PTD #191-141) AA requirement discussion. Chris- I just wanted to follow up with our discussion regarding the AA requirement for the 2M-03 (PTD #191-141) OA cement to surface situation. I am getting some internal feedback suggesting that this well should be operated without an AA due to the competent tubing string and production casing. I have collected all the information regarding the wells current barriers and have attached for your review. Attached is the tubing and IA pressure tests from on the on rig pressure test verification, a 10- 426 form for the passing diagnostic MIT-IA, a 10-426 form for the passing OA-DDT, the CBL that was performed to investigate the cement top behind the 7” casing, and the current well bore schematic. The theory behind returning the well to “normal” operations is that the well now has premium gas-tight HYD 563 threads in the newly installed tubing string and the top 1804’ of the replaced production casing. The CBL log shows competent cement into the surface casing with a cement top at ~1950’ which proved integrity from perforations to surface prior to the RWO with a passing MIT-OA in 2008 and recent pressure trends suggesting a competent shoe. The failing pressure test on the OA did not have a response within the conductor suggesting the failure of the SC was at least deeper than the set depth of the conductor. This leaves a small section of potential failure based on the assumption that the cement returns were lost at a calculated 240’. I will give you call tomorrow (10 May) to discuss this issue in depth but wanted to present the additional information that has been gathered to help paint a better picture of the current well bore condition. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Company:ConocoPhillips Alaska, Inc.Well:2M-03Field:Kuparuk RiverBorough:North SlopeState:AlaskaNorth Slope Kuparuk River 114' FSL & 36' FEL 2M-03 ConocoPhillips Alaska, Inc.Cement Bong LogGR / CCL / CBL / VDL / MAP31-March-2024Location:114' FSL & 36' FELElev.:K.B.41.01 ftAt SurfaceG.L.0.00 ftD.F.41.01 ftPermanent Datum:Ground LevelElev.:0.00 ftBorough: Field: Location: Well: Company:Log Measured From:Kelly Bushing41.01 ftabove Perm.DatumDrilling Measured From:Kelly BushingAPI Serial No.Section:Township:Range:501032016000002811N8ELogging Date31-Mar-2024Run NumberCBLDepth Driller7516.00 ftSLB DepthTD not taggedBottom Log Interval3000.00 ftTop Log Interval0.00 ftCasing Fluid TypeSea WaterSalinityDensity8.5 lbm/galFluid Level8.00 ftBIT/CASING/TUBING STRINGBit Size8.13 inFrom0.00 ftTo7516.00 ftCasing/Tubing Size7 inWeight26 lbm/ftGradeJ55From0.00 ftTo7516.00 ftMax Recorded TemperaturesLogger on Bottom Time31-Mar-2024 06:48:00Unit NumberLocation:2316Prudhoe BayRecorded ByMiles / PinonWitnessed ByBarrTHE USE OF AND RELIANCE UPON THIS RECORDED-DATA BY THE HEREIN NAMED COMPANY (AND ANY OF ITS AFFILIATES, PARTNERS, REPRESENTATIVES, AGENTS, CONSULTANTS AND EMPLOYEES) IS SUBJECT TO THE TERMS AND CONDITIONS AGREED UPON BETWEEN SLB AND THE COMPANY, INCLUDING: (a) RESTRICTIONS ON USE OF THE RECORDED-DATA; (b) DISCLAIMERS AND WAIVERS OF WARRANTIES AND REPRESENTATIONS REGARDING COMPANY'S USE AND RELIANCE UPON THE RECORDED-DATA; AND (c) CUSTOMER'S FULL AND SOLE RESPONSIBILITY FOR ANY INFERENCE DRAWN OR DECISION MADE IN CONNECTION WITH THE USE OF THIS RECORDED-DATA. 1.Header 2.Disclaimer 3.Contents 4.Remarks and Equipment Summary 5.Depth Summary 6.Wellbore Schematic 7.CBL Main Pass Up at 30 FPM 7.1 Integration Summary 7.2 Software Version 7.3 Composite Summary 7.4 Log ( SCMT_VDL_Image ) 7.5 Parameter Listing 8.CBL Repeat Pass Up at 30 FPM 8.1 Integration Summary 8.2 Software Version 8.3 Composite Summary 8.4 Log ( SCMT_VDL_Image ) 8.5 Parameter Listing 9.Calibration Report 10.Tail CBL: Remarks Equip name Length MP name Offset MH-22 40.9 AH-38 39.32 ERS-E:142 7 39.04 ERS-E Hou sing:1427 ERS-E Idle: 1427 EQF-46 37.68 PSTP-A:76 4 31.68 PSC-A:764 PSTC-A:89 2 PBMS-A:76 4 Sapphire 10 kPSI:764 PBMS 23.41 CCL 24.16 Sapphire Pressur e 24.78 Tempera ture 24.89 PSTC To ol String Bottom 0.00 PSTC 27.68 GR 27.97 SCMT-CB: 8155 23.41 SECH-CA:8 126 SCMC-CA: 8127 CMIR-AG:2 42 SCMS-CB:8 155 SCMX-CA:8 127 AH-278:074 TTG-C:832 SCMT 6.00 AUX 10.32 MAP 11.32 CBL3 11.82 DTSC 12.82 CBL5 12.82 DT 14.32 Objective: Log CBL from 3000' RKB to Surface Tool Zerod at rig floor Casing fluid 8.5 ppg Seawater Expected Free Pipe Parameters for 7" 26 lb/ft Casing CBL Amplititude: 60 mV CBL TT = 292 us Tool centralized with inline centralizers above and below sonde and TTG at bottom Main Pass logged up from 3000' to surface at 30 FPM Repeat Pass logged up from 3000' to 2700' at 30 FPM Field Pick Top of Cement at 1950' TD Not Tagged SLB Crew: Bell, Kennedy, Drover, Lee AFE: 10456192 SON: 1013597 TOOL_ZERO Lengths are in ft Maximum Outer Diameter = 2.125 in Line: Sensor Location, Value: Gating Offset All measurements are relative to TOOL_ZERO Type IDW-B Serial Number 777 Calibration Date 21-Dec-2023 Calibrator Serial Number 18 Calibration Cable Type 2-32 ZA-XXS-HPC Wheel Correction 1 -6 Wheel Correction 2 -4 Type CMTD-B/A Serial Number 3017 Calibration Date 09-Feb-2024 Calibrator Serial Number 265 Number of Calibration Points 10 Calibration Root Mean Square Error 5 Calibration Peak Error 9 Type 2-32ZA-XXS-HPC Serial Number F221093 Length 36000.00 ft Conveyance Type Wireline Rig Type SLB depth control procedures followedLog Sequence First Log In the Well IDW used as primary depth control systemRig Up Length At Surface Z-Chart used as secondary depth control systemRig Up Length At Bottom Rig Up Length Correction Stretch Correction Tool Zero Check At Surface Maxwell 2024.0 14.0.226717.3100 CBL Log[4]:Up Up 4.42 ft 3050.62 ft 31-Mar- 2024 6:46:22 AM 31-Mar- 2024 8:39:05 AM ON 0.00 ft No All depths are referenced to toolstring zero Company:ConocoPhillips Alaska, Inc. Well:2M-03 CBL: Log[4]:Up:S004 Description: SCMT VDL Image Format: Log ( SCMT_VDL_Image ) Index Scale: 5 in per 100 ft Index Unit: ft Index Type: Measured Depth Creation Date: 31-Mar-2024 08:54:16 Cable Tension (TENS) 0 1000lbf Gamma Ray (GR) PSTP-A 0 150gAPI Transit Time for CBL (TT) SCMT-CB 200 400us CCL Computed Amplitude (CCLC) PSTP-A -19 1V TIME_1900 - Time Marked every 60.00 (s) CBL Amplitude (CBL) SCMT-CB 0 10mV CBL Amplitude (CBL) SCMT-CB 0 100mV Good Bond (GOBO) 0 10mV Normalized Average MAP Amplitude (AVMA) SCMT-CB 0 100mV GoodBond From CBL to GOBO Min MaxAmplitude VDL VariableDensity (VDL) SCMT-CB 200 1200us Absent7.50017.50027.50037.50047.50057.50067.50077.50087.50097.500CBL Amplitude Mapping Image (0 - 100) SCMT-CB Relative Bearing (RB_SCMT) SCMT-CB 0 360deg -20 -10 10 20 30 0 GR CCLC CBL RB_SCMT 40 60 70 80 90 110 120 130 140 160 170 180 190 210 220 230 240 50 100 150 200 250 TENS GR TT CCLC CBL AVMA RB_SCMT 260 270 280 290 310 320 330 340 360 370 380 390 410 420 430 440 460 470 300 350 400 450 TENS GR TT CCLC CBL AVMA RB_SCMT 480 490 510 520 530 540 560 570 580 590 610 620 630 640 660 670 680 690 500 550 600 650 TENSCCLC AVMA 710 720 730 740 760 770 780 790 810 820 830 840 860 870 880 890 910 700 750 800 850 900 TENS GR TT CCLC CBL AVMA RB_SCMT 920 930 940 960 970 980 990 1010 1020 1030 1040 1060 1070 1080 1090 1110 1120 1130 950 1000 1050 1100 TENS GR TT CCLC CBL AVMA RB_SCMT 1140 1160 1170 1180 1190 1210 1220 1230 1240 1260 1270 1280 1290 1310 1320 1330 1340 1150 1200 1250 1300 1350 TENS GR TT CCLC CBL AVMA RB_SCMT 1360 1370 1380 1390 1410 1420 1430 1440 1460 1470 1480 1490 1510 1520 1530 1540 1560 1570 1400 1450 1500 1550 TENS GR TT CCLC CBL AVMA RB_SCMT 1580 1590 1610 1620 1630 1640 1660 1670 1680 1690 1710 1720 1730 1740 1760 1770 1780 1790 1600 1650 1700 1750 TENS GR TT CCLC CBL AVMA RB_SCMT 1810 1820 1830 1840 1860 1870 1880 1890 1910 1920 1930 1940 1960 1970 1980 1990 2010 1800 1850 1900 1950 2000 TENS Field Pick TOC GR TT CCLC CBL AVMA RB_SCMT 2020 2030 2040 2060 2070 2080 2090 2110 2120 2130 2140 2160 2170 2180 2190 2210 2220 2230 2050 2100 2150 2200 TENS GR TT CCLC CBL CBL AVMA RB_SCMT 2240 2260 2270 2280 2290 2310 2320 2330 2340 2360 2370 2380 2390 2410 2420 2430 2440 2250 2300 2350 2400 2450 TENS GR TT CCLC CBL CBL AVMA RB_SCMT 2460 2470 2480 2490 2510 2520 2530 2540 2560 2570 2580 2590 2610 2620 2630 2640 2660 2670 2500 2550 2600 2650 TENS GR TT CCLC CBL CBL AVMA RB_SCMT 2680 2690 2710 2720 2730 2740 2760 2770 2780 2790 2810 2820 2830 2840 2860 2870 2880 2890 2700 2750 2800 2850 TENS GR TT CCLC CBL CBL AVMA RB_SCMT 2910 2920 2930 2940 2960 2970 2980 2990 3010 3020 3030 3040 2900 2950 3000 3050 Description: SCMT VDL Image Format: Log ( SCMT_VDL_Image ) Index Scale: 5 in per 100 ft Index Unit: ft Index Type: Measured Depth Creation Date: 31-Mar-2024 08:54:16 Cable Tension (TENS) 0 1000lbf Gamma Ray (GR) PSTP-A 0 150gAPI Transit Time for CBL (TT) SCMT-CB 200 400us CCL Computed Amplitude (CCLC) PSTP-A -19 1V TIME_1900 - Time Marked every 60.00 (s) CBL Amplitude (CBL) SCMT-CB 0 10mV CBL Amplitude (CBL) SCMT-CB 0 100mV Good Bond (GOBO) 0 10mV Normalized Average MAP Amplitude (AVMA) SCMT-CB 0 100mV GoodBond From CBL to GOBO Min MaxAmplitude VDL VariableDensity (VDL) SCMT-CB 200 1200us Absent7.50017.50027.50037.50047.50057.50067.50077.50087.50097.500CBL Amplitude Mapping Image (0 - 100) SCMT-CB Relative Bearing (RB_SCMT) SCMT-CB 0 360deg CBL: Parameters Bottom Hole TemperatureBHT Borehole 212 degF SCMT CBL 3 ft Peak Detection T0_Delay and Noise GateCB3G SCMT-CB 268.7 us CBL Gate WidthCBLG SCMT-CB 44 us CBL LQC Reference Amplitude in Free PipeCBRA SCMT-CB 62 mV Nominal Casing Thickness - Zoned along logger depthsTHNO WLSESSION 0.362 in Drilling Fluid DensityDFD Borehole 8.5 lbm/gal Drilling Fluid TypeDFT_CATEGORY Borehole Water Borehole Fluid SlownessDTMD Borehole 206 us/ft Elevation of Derrick Floor Above Permanent DatumEDF WLSESSION 41.01 ft Elevation of Permanent Datum (PDAT) above Mean Sea LevelEPD WLSESSION 0 ft Geothermal GradientGGRD Borehole 1 0.01 degF/ft Generalized Temperature Selection, from Measured or Computed Temperature GTSE Borehole GTEM_LINEST(RT) SCMT MAP Peak Detection T0_Delay and Noise GateMAPG SCMT-CB 212.46 us MAP Minimum Sonic AmplitudeMMSA SCMT-CB 10.86 mV Minimum Sonic AmplitudeMSA SCMT-CB 1.84 mV Permanent DatumPDAT WLSESSION GL Run Sequence NumberRUN_SNUM WSDRUN 1 Surface Hole TemperatureSHT Borehole 68 degF CBL: Parameters SCMT Operating ModeCMTM SCMT-CB Log Toolstring Maximum Logging SpeedMAX_LOG_SPEED WLSESSION 1800 ft/h Maxwell 2024.0 14.0.226717.3100 CBL Log[3]:Up Up 2670.58 ft 3050.28 ft 31-Mar- 2024 6:14:14 AM 31-Mar- 2024 6:27:06 AM ON 0.00 ft No All depths are referenced to toolstring zero Company:ConocoPhillips Alaska, Inc. Well:2M-03 CBL: Log[3]:Up:S004 Description: SCMT VDL Image Format: Log ( SCMT_VDL_Image ) Index Scale: 5 in per 100 ft Index Unit: ft Index Type: Measured Depth Creation Date: 31-Mar-2024 08:54:24 Gamma Ray (GR) PSTP-A 0 150gAPI Transit Time for CBL (TT) TIME_1900 - Time Marked every 60.00 (s) CBL Amplitude (CBL) SCMT-CB 0 10mV CBL Amplitude (CBL) SCMT-CB 0 100mV Good Bond (GOBO)Absent7.50017.50027.50037.50047.50057.50067.50077.50087.50097.500 Cable Tension (TENS) 0 1000lbf Transit Time for CBL (TT) SCMT-CB 200 400us CCL Computed Amplitude (CCLC) PSTP-A -19 1V Good Bond (GOBO) 0 10mV Normalized Average MAP Amplitude (AVMA) SCMT-CB 0 100mV GoodBond From CBL to GOBO Min MaxAmplitude VDL VariableDensity (VDL) SCMT-CB 200 1200us Absent172737475767778797CBL Amplitude Mapping Image (0 - 100) SCMT-CB Relative Bearing (RB_SCMT) SCMT-CB 0 360deg 2660 2670 2680 2690 2710 2720 2730 2740 2760 2770 2780 2790 2810 2820 2830 2650 2700 2750 2800 2840 2860 2870 2880 2890 2910 2920 2930 2940 2960 2970 2980 2990 3010 3020 3030 3040 2850 2900 2950 3000 3050 TENS GR TT CCLC CBL CBL AVMA RB_SCMT CableGamma Ray (GR) PSTP-A CBL Amplitude (CBL) SCMT-CB Min MaxAmplitude Absent.500.500.500.500.500.500.500.500.500.500 Description: SCMT VDL Image Format: Log ( SCMT_VDL_Image ) Index Scale: 5 in per 100 ft Index Unit: ft Index Type: Measured Depth Creation Date: 31-Mar-2024 08:54:24 CableTension (TENS) 0 1000lbf Gamma Ray (GR) PSTP-A 0 150gAPI Transit Time for CBL (TT) SCMT-CB 200 400us CCL Computed Amplitude (CCLC) PSTP-A -19 1V TIME_1900 - Time Marked every 60.00 (s) CBL Amplitude (CBL) SCMT-CB 0 10mV CBL Amplitude (CBL) SCMT-CB 0 100mV Good Bond (GOBO) 0 10mV Normalized Average MAP Amplitude (AVMA) SCMT-CB 0 100mV GoodBond From CBL to GOBO Min MaxAmplitude VDL VariableDensity (VDL) SCMT-CB 200 1200us Absent7.50017.50027.50037.50047.50057.50067.50077.50087.50097.500CBL Amplitude Mapping Image (0 - 100) SCMT-CB Relative Bearing (RB_SCMT) SCMT-CB 0 360deg CBL: Parameters Bottom Hole TemperatureBHT Borehole 212 degF SCMT CBL 3 ft Peak Detection T0_Delay and Noise GateCB3G SCMT-CB 268.7 us CBL Gate WidthCBLG SCMT-CB 44 us CBL LQC Reference Amplitude in Free PipeCBRA SCMT-CB 62 mV Nominal Casing Thickness - Zoned along logger depthsTHNO WLSESSION 0.362 in Drilling Fluid DensityDFD Borehole 8.5 lbm/gal Drilling Fluid TypeDFT_CATEGORY Borehole Water Borehole Fluid SlownessDTMD Borehole 206 us/ft Elevation of Derrick Floor Above Permanent DatumEDF WLSESSION 41.01 ft Elevation of Permanent Datum (PDAT) above Mean Sea LevelEPD WLSESSION 0 ft Geothermal GradientGGRD Borehole 1 0.01 degF/ft Generalized Temperature Selection, from Measured or Computed Temperature GTSE Borehole GTEM_LINEST(RT) SCMT MAP Peak Detection T0_Delay and Noise GateMAPG SCMT-CB 212.46 us MAP Minimum Sonic AmplitudeMMSA SCMT-CB 10.86 mV Minimum Sonic AmplitudeMSA SCMT-CB 1.84 mV Permanent DatumPDAT WLSESSION GL Run Sequence NumberRUN_SNUM WSDRUN 1 Surface Hole TemperatureSHT Borehole 68 degF CBL: Parameters SCMT Operating ModeCMTM SCMT-CB Log Toolstring Maximum Logging SpeedMAX_LOG_SPEED WLSESSION 1800 ft/h Slim Cement Mapping Sonde SCMS-CB 8155 Master (Measured):17:31:42 25-Jul-2023 CBL 3 ft Temperature/Pressure Compensated Raw Amplitude (at 0 degree) (RC3A) mV Master 1350.000 1000.000 1511.551 1700.000 Raw Amplitude (at 0 degree) (RC3A) MAP 1 Temperature/Pressure Compensated Raw Amplitude (at 0 degree) (RM1A) mV Master 1075.000 500.000 1026.871 1650.000 MAP 2 Temperature/Pressure Compensated Raw Amplitude (at 0 degree) (RM2A) mV Master 1075.000 500.000 1010.342 1650.000 MAP 3 Temperature/Pressure Compensated Raw Amplitude (at 0 degree) (RM3A) mV Master 1075.000 500.000 816.677 1650.000 MAP 4 Temperature/Pressure Compensated Raw Amplitude (at 0 degree) (RM4A) mV Master 1075.000 500.000 1038.280 1650.000 MAP 5 Temperature/Pressure Compensated Raw Amplitude (at 0 degree) (RM5A) mV Master 1075.000 500.000 971.124 1650.000 MAP 6 Temperature/Pressure Compensated Raw Amplitude (at 0 degree) (RM6A) mV Master 1075.000 500.000 1022.094 1650.000 MAP 7 Temperature/Pressure Compensated Raw Amplitude (at 0 degree) (RM7A) mV Master 1075.000 500.000 1111.118 1650.000 MAP 8 Temperature/Pressure Compensated Raw Amplitude (at 0 degree) (RM8A) mV Master 1075.000 500.000 1088.758 1650.000 CBL 3 ft Temperature/Pressure Compensated Raw Amplitude (at 90 degree) (RC3A) mV Master 1350.000 1000.000 1508.483 1700.000 MAP 1 Temperature/Pressure Compensated Raw Amplitude (at 90 degree) (RM1A) mV Master 1075.000 500.000 895.421 1650.000 MAP 2 Temperature/Pressure Compensated Raw Amplitude (at 90 degree) (RM2A) mV Master 1075.000 500.000 896.117 1650.000 MAP 3 Temperature/Pressure Compensated Raw Amplitude (at 90 degree) (RM3A) mV Master 1075.000 500.000 811.133 1650.000 MAP 4 Temperature/Pressure Compensated Raw Amplitude (at 90 degree) (RM4A) mV Master 1075.000 500.000 1134.739 1650.000 MAP 5 Temperature/Pressure Compensated Raw Amplitude (at 90 degree) (RM5A) mV Master 1075.000 500.000 1116.163 1650.000 MAP 6 Temperature/Pressure Compensated Raw Amplitude (at 90 degree) (RM6A) mV Master 1075.000 500.000 1135.638 1650.000 MAP 7 Temperature/Pressure Compensated Raw Amplitude (at 90 degree) (RM7A) mV Master 1075.000 500.000 1121.395 1650.000 MAP 8 Temperature/Pressure Compensated Raw Amplitude (at 90 degree) (RM8A) mV Master 1075.000 500.000 1001.319 1650.000 CBL 3 ft Temperature/Pressure Compensated Raw Amplitude (at 180 degree) (RC3A) mV Master 1350.000 1000.000 1506.527 1700.000 MAP 1 Temperature/Pressure Compensated Raw Amplitude (at 180 degree) (RM1A) mV Master 1075.000 500.000 865.621 1650.000 MAP 2 Temperature/Pressure Compensated Raw Amplitude (at 180 degree) (RM2A) mV Master 1075.000 500.000 916.402 1650.000 MAP 3 Temperature/Pressure Compensated Raw Amplitude (at 180 degree) (RM3A) mV Master 1075.000 500.000 865.906 1650.000 MAP 4 Temperature/Pressure Compensated Raw Amplitude (at 180 degree) (RM4A) mV Master 1075.000 500.000 1187.346 1650.000 MAP 5 Temperature/Pressure Compensated Raw Amplitude (at 180 degree) (RM5A) mV Master 1075.000 500.000 1115.568 1650.000 MAP 6 Temperature/Pressure Compensated Raw Amplitude (at 180 degree) (RM6A) mV Master 1075.000 500.000 1095.522 1650.000 MAP 7 Temperature/Pressure Compensated Raw Amplitude (at 180 degree) (RM7A) mV Master 1075.000 500.000 1051.156 1650.000 MAP 8 Temperature/Pressure Compensated Raw Amplitude (at 180 degree) (RM8A) mV Master 1075.000 500.000 941.977 1650.000 CBL 3 ft Temperature/Pressure Compensated Raw Amplitude (at 270 degree) (RC3A) mV Master 1350.000 1000.000 1500.483 1700.000 MAP 1 Temperature/Pressure Compensated Raw Amplitude (at 270 degree) (RM1A) mV Master 1075.000 500.000 906.548 1650.000 MAP 2 Temperature/Pressure Compensated Raw Amplitude (at 270 degree) (RM2A) mV Master 1075.000 500.000 941.524 1650.000 MAP 3 Temperature/Pressure Compensated Raw Amplitude (at 270 degree) (RM3A) mV Master 1075.000 500.000 858.327 1650.000 MAP 4 Temperature/Pressure Compensated Raw Amplitude (at 270 degree) (RM4A) mV Master 1075.000 500.000 1148.295 1650.000 MAP 5 Temperature/Pressure Compensated Raw Amplitude (at 270 degree) (RM5A) mV Master 1075.000 500.000 1077.485 1650.000 MAP 6 Temperature/Pressure Compensated Raw Amplitude (at 270 degree) (RM6A) mV Master 1075.000 500.000 1063.477 1650.000 MAP 7 Temperature/Pressure Compensated Raw Amplitude (at 270 degree) (RM7A) mV Master 1075.000 500.000 1044.589 1650.000 MAP 8 Temperature/Pressure Compensated Raw Amplitude (at 270 degree) (RM8A) mV Master 1075.000 500.000 959.884 1650.000 Master (Measured):17:31:42 25-Jul-2023 Normalization Temperature in SFT Tube (CALI_NTEP) degF Master ----------54.50 ----- (CALI_NTEP) CBL Correction Factor (CBCF)Master ----------0.064 ----- MAP 1 Correction Factor (M1CF)Master ----------0.130 ----- MAP 2 Correction Factor (M2CF)Master ----------0.128 ----- MAP 3 Correction Factor (M3CF)Master ----------0.143 ----- MAP 4 Correction Factor (M4CF)Master ----------0.106 ----- MAP 5 Correction Factor (M5CF)Master ----------0.112 ----- MAP 6 Correction Factor (M6CF)Master ----------0.111 ----- MAP 7 Correction Factor (M7CF)Master ----------0.111 ----- MAP 8 Correction Factor (M8CF)Master ----------0.120 ----- Before (Measured):13:46:07 30-Mar-2024 CBL Amplitude (CBLF)mV Before ----------86.07 ----- Average MAP Amplitude (Fluid Compensated) (AMPF) mV Before ----------121.82 ----- Measurement Depth (DEPTH)ft Before ----------549.63 ----- Before (Measured):13:46:07 30-Mar-2024 CBL Adjustment Factor (CBL_ADJUST_FACTOR) Before ----------0.720 ----- CBL LQC Reference Amplitude in Free Pipe (CALI_CBRA) mV Before ----------62.00 ----- MAP Adjustment Factor (MAP_ADJUST_FACTOR) Before ----------0.821 ----- Depth of Before Calibration (BDEP)ft Before ----------549.63 ----- PBMS-A PBMS-A 764 JIG-BKGD Master (EEPROM):16:00:00 24-Nov-2014 RTD Coefficients -327.8335 106.2438 -5.833457 2.040335 -0.1657997 0 Master (EEPROM):16:00:00 12-Oct-2004 GR Coefficients 2000 3450 Master (EEPROM):16:00:00 24-Nov-2014 PBMS A Clock Coefficients -74.22706 -5.006179 -0.1046889 0.0007646669 1.897765E-06 0 Master (EEPROM):16:00:00 24-Nov-2014 Sapphire Pressure Model Coefficients -13291.43 3508.647 289.0231 -202.065 18.90847 0 18510.92 -11525.39 3430.524 -488.9738 27.38727 0 -220.8997 84.58038 -8.413407 0 0 0 4.751426 -1.09824 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Sapphire Temperature Model Coefficients 2305.546 -25.05117 5.70176 -1.348195 0.1238029 0 -1372.775 14.1012 -1.477443 0.3275643 -0.03044473 0 287.064 -2.988587 0.02645007 0 0 0 -21.14599 0.2477287 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Company:ConocoPhillips Alaska, Inc. Well:2M-03 Field:Kuparuk River Borough:North Slope State:Alaska State:Alaska Cement Bong Log GR / CCL / CBL / VDL / MAP 31-March-2024 0 6 Sd b 3 P Ij/ � dE00 e00 �\ as I 240 1. 1800{--� \ 1 8/ li 1200 600 It I rt� o CHAR7 NO. MC MPI _ T�gH�je y ofo 500,v IUI O kAqT � W W C C PVN 'OW H igKEN n ICCATryM \ 009-- � 00 092 — y / s� t 4 / OOPS---- _ 4 � 09 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:RKB (Est. 87' of Rathole) 7,365.0 2M-03 5/15/2020 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Swapped out SOV, pulled RHC, pulled plug 2M-03 5/6/2024 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: 11/10/2010 condijw 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 42.0 123.0 123.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 41.5 3,323.2 2,913.9 36.00 J-55 BTC Tie-Back String 7 6.28 40.6 1,804.4 1,733.3 26.00 L-80 HYD 563 Production 7 6.28 41.8 7,516.2 26.00 J-55 BTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth … 7,058.4 String Max No… 3 1/2 Set Depth … 5,934.4 Tubing Description Tubing – Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection HYD 563 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) 40.3 40.3 0.13 Hanger 6.982 3.5" FMC Gen 4 tubing hanger, H- BPV, EUE Lift threads FMC GEN IV 2.952 6,969.2 5,861.2 34.97 Mandrel – GAS LIFT 5.640 3.5" x 1.5" SLB MMG, GLM (SN#: 24384-09) SLB MMG 2.920 7,028.7 5,910.0 34.86 Nipple - X 4.506 3.5" HES 2.81" X-Nipple (SN#: 4792263702-01-001) HES 2.81" X 2.813 7,045.7 5,924.0 34.85 Locator 4.240 Baker Locator (4.24" No-Go) Baker 2.990 7,046.5 5,924.6 34.85 Seal Assembly 3.990 Baker GBH-22, 80-40 Seal Assembly (2' space out), (SN#: 453010065) Baker GBH-22, 80-40 2.990 Top (ftKB) 7,048.5 Set Depth … 7,089.8 String Max No… 5.41 Set Depth … 5,960.2 Tubing Description Tubing – Completion Lower Wt (lb/ft) Grade Top Connection ID (in) 2.97 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) 7,048.5 5,926.3 34.85 PBR 5.410 OTIS PBR w/ 10' STROKE & 4" SEAL BORE OTIS 2.970 7,064.4 5,939.3 34.84 PACKER 6.000 OTIS HVT RETRIEVABLE PACKER OTIS HVT 3.250 7,079.7 5,951.9 34.84 NIPPLE 4.540 CAMCO D NIPPLE CAMCO D 2.750 7,089.2 5,959.7 34.83 WLEG 4.500 OTIS RH BALL SEAT SUB/WIRELINE ENTRY GUIDE, NO ELMD LOG AVAILABLE OTIS 2.875 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) 40.6 40.6 0.13 EMERGENCY SLIPS 11" x 7" C-21 Emergency Slips 4/5/2024 7.000 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) 6,969.2 5,861.2 34.97 1 GAS LIFT DMY RK 1 1/2 0.0 4/28/2024 SLB MMG 0.000 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) 1,788.7 1,720.6 35.67 Collar - Stage 8.250 CMTR,TYPE H ES-II, HYD 563 L- 80, S/N#: 5031046-03 Halliburto n HES II CMTR 6.125 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,183.0 7,203.0 6,036.8 6,053.2 C-4, 2M-03 11/8/1992 4.0 IPERF 180 deg. phasing; Oriented 105 deg. CCW, 2 1/2" Titan 7,214.0 7,224.0 6,062.3 6,070.6 A-4, 2M-03 2/22/1992 4.0 IPERF 180 deg. phasing; Oriented 84.25 deg. CCW, 4 1/2" HJ II Csg Gun 7,238.0 7,258.0 6,082.1 6,098.6 A-3, 2M-03 2/21/1992 4.0 IPERF 180 deg. phasing; Oriented 172 deg. CCW, 4 1/2" HJ II Csg Gun 7,258.0 7,278.0 6,098.6 6,115.2 A-3, 2M-03 2/21/1992 4.0 IPERF 180 deg. phasing; Oriented 166 deg. CCW, 4 1/2" HJ II Csg Gun Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 49.5 1,804.4 49.5 1,733.3 Production String 1 Cement Pumped 123 bbls of 15.3# cement. Lost returns at 112 bbls cement pumped. Est. 7 bbls of Spacer left in OA. DHD tagged cement at 8' below SC spool. 4/5/2024 2M-03, 5/9/2024 2:15:14 PM Vertical schematic (actual) Production; 1,800.9-7,516.2 IPERF; 7,258.0-7,278.0 IPERF; 7,238.0-7,258.0 IPERF; 7,214.0-7,224.0 IPERF; 7,183.0-7,203.0 PACKER; 7,064.4 Nipple - X; 7,028.7 BALL & ROD; 7,021.0 Mandrel – GAS LIFT; 6,969.2 SURFACE; 41.5-3,323.2 Tie-Back String; 40.6-1,804.4 Production String 1 Cement; 49.5 ftKB CONDUCTOR; 42.0-123.0 EMERGENCY SLIPS; 40.6 Hanger; 40.3 KUP INJ KB-Grd (ft) 41.01 RR Date 1/3/1992 Other Elev… 2M-03 ... TD Act Btm (ftKB) 7,512.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032016000 Wellbore Status INJ Max Angle & MD Incl (°) 40.75 MD (ftKB) 2,400.00 WELLNAME WELLBORE2M-03 Annotation Last WO: End Date 4/11/2024 H2S (ppm) DateComment SSSV: TRDP Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 191-141 Type Inj N Tubing 0 0 0 0 Type Test P Packer TVD 5939 BBL Pump N/A IA 21 0 0 0 Interval O Test psi 1500 BBL Return N/A OA 1059 0 0 0 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: ConocoPhillips Alaska Kuparuk Galle 04/17/24 Notes:Diagnostics OA DDT, post OA pressure application Notes: Notes: Notes: 2M-03 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Form 10-426 (Revised 01/2017)2M-03 Diagnostics OA-DDT 17 April 2024 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 191-141 Type Inj N Tubing 860 860 860 860 Type Test P Packer TVD 5939 BBL Pump N/A IA 440 3300 3225 3210 Interval O Test psi 1500 BBL Return N/A OA 210 210 210 210 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: ConocoPhillips Alaska Kuparuk Rogers 05/06/24 Notes:Diagnostics MIT-IA to 3300 psi. Notes: Notes: Notes: 2M-03 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Form 10-426 (Revised 01/2017)2M-03 Diagnostics MIT-IA 6 May 2024 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 20, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2M-30 KUPARUK RIV UNIT 2M-30 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/20/2022 2M-30 50-103-20180-00-00 192-084-0 W SPT 5979 1920840 3000 2490 2500 2500 2500 210 220 210 210 REQVAR P Adam Earl 6/18/2022 MIT-IA tested as per AIO 2C.045 to max ant. Inj. Psi. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2M-30 Inspection Date: Tubing OA Packer Depth 520 3310 3235 3220IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220622095636 BBL Pumped:3 BBL Returned:3.3 Wednesday, July 20, 2022 Page 1 of 1 MEMORANDUM State of Alaska Depth Pretest Alaska Oil and Gas Conservation Commission To: JimRegg . �� ;P.I. DATE: Monday, August 24, 2020 Supervisor (6�('�% 131 SUBJECT: Mechanical Integrity Tests 2540 ConocoPhillips Alaska, Inc. �� 2540 " 2M-30 FROM: Matt Herrera KUPARUK RIV UNIT 2M-30 Petroleum Inspector ]A 1020 3350 3290 "I 3270 r - 200- 200 200' - - Src: Inspector 2.5 Reviewed By: I 190 P.I. Supry J f�l� NON -CONFIDENTIAL Comm IWell Name KUPARUK RIV UNIT 2M-30 Insp Num: mitMFH2O0822122002 Rel Insp Num: API Well Number 50-103-20180-00-00 Inspector Name: Matt Herrera Permit Number: 192-084-0 Inspection Date: 8/22/2020 Monday, August 24, 2020 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2M-30 � Type In w TVD - IIITyy� - 5979 j 'I'Ubing I 2540 2540 r 2540 �� 2540 " PTD 1920840 -- BBL ed: -- '- I, SPT I[ eSt Sl —_ 3000 _ ]A 1020 3350 3290 "I 3270 r - 200- 200 200' - - 25 BBL Returned: 2.5 OA I 190 Interval REQvAR- P/F P --I - Notes' MIT -IA performed to MAIP Per A10 2C.045 -- Monday, August 24, 2020 Page 1 of 1 Kett. w.- 3© Regg, James B (CED) P)b rlwl� o From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@cono1:ophillips.com> 1 ,< 6/45-t4r& Sent: Saturday, June 13, 2020 11:24 AM To: Regg, James B (CED); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (CED); Wallace, Chris D (CED) Subject: KRU 1M pad SW MITIA's 6-12-20 Attachments: MIT KRU 2M PAD pg 1 06-12-20.xlsx; MIT KRU 2M PAD SI WELLS 06-12-20.xlsx 0 Attached are the 10-426's for the SW MITIA's performed on 2M pad 6-12-20. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 WELLS TEAM Corwco►Ph�H�ps c STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to ii m.reood)alaska.00v: A0GCC.Insoectors20alaskaaov phoebe. brooks Malaska.cov OPERATOR: ConocoPhillips Alaska Inc, FIELD / UNIT / PAD: Kuparuk / KRU / 2M Pad DATE: 06/12/20 OPERATOR REP: Beck / Green AOGCC REP: 60 Min. ch ris.wallaceaalaska.00v Well 2M-30 INTERVAL Codes Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 4=Four Year Cyte F=Fail PTD 1920840 - Type Inj N Tubing 1500 - 1500 1500 ' 1500 N = Not Inletting Type Test P Packer TVD 5980 ' BBL Pump 3.0 IA 350 3300 3230 3210 Interval V Test psi 3000 BBL Return 3.0 OA 180 J 180, 180 180 Result P Notes: MITIA to maizimum anticipated injection pressure per AID 2C.045 Well 211 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1960800 Type Inj N Tubing 1225 1225 1225 1225 Type Test P Packer TVD 6192 BBLPumpJ 2.3 IA 550 2000 1960 1960 Interval 4 Test psi 1548 BBL Return 2.3 OA 400 430 430 430 Result P Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBLPump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Cotles INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G=Gas O= Other(describs in Notes) 4=Four Year Cyte F=Fail S=Slurry V= Required by Variance 1=Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Inletting Form 10-426 (Revised 01/2017) MIT KRU 2M PAD SI WELLS 0612-20 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED JAN 14 2020 1. Operations Abandon ❑ Plug Perforations Fracture Stimulate Pull Tubing ❑ hutdown ❑ ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program Performed: Suspend ❑ Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Conductor Extension Plug for Redrill Perforate New 4. Well Class Before Work: 5. Permit to Drill Number: 2. Operator Name:ConocoPhillips Development El Exploratory El192-084 Alaska, Inc. Stratigraphic El Service Q 6. API Number: 3. Address: 50-103-20180-00-00 P.O.Box 100360, Anchorage, Alaska 99510 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025586 KRU 2M-30 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Ku aruk River / Ku aruk River Oil 11. Present Well Condition Summary: Total Depth measured 9350' feet Plugs measured N/A feel true vertical 6380' feet Junk measured 9245' feet Effective Depth measured 9245' feet Packer measured 8830' feet true vertical 6304' feet true vertical 5980' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 119' 119 Surface 3447' 10.75" 3487' 2763' Intermediate Production 9293' 7" 9332' 6372' Liner Perforation depth Measured depth 8936' - 9016' feet True Vertical depth 6062' - 6125' feet Tubing (size, grade, measured and true vertical depth) 3.5" J-55 8866' MD 6008' TVD Packers and SSSV (type, measured and true vertical depth) Baker F-1 Packer 8830' MD 5998' TVD CAMCO TRDP-4A MOD SSSV 1824' MD 1721' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data 13 Oil -Bbl Gas-McfWater-Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A N/A N/A NIA N/A Subsequent to operation: N/A N/A N/A N/A N/A 14. Attachments (required per 20 AAC 25.070, 25.071, a 25.2es) 15. Well Class after work: ❑ Exploratory ❑ Development❑ Service E] Stratigraphic Daily Report of Well Operations F-116. Well Status after work: A Oil El Gas ElWDSPL❑ Copies of Logs and Surveys Run [I WIN,; WAG GINJ ❑ SUSP❑ SPLUG❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR Exempt: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. 319-562 Roger Winter Contact Name: Roger Mouser / Roger Winter Authorized Name: Well Integrity Field Supervisor Contact Email: N1927 Conoco hill) s.com Authorized Title: ��� r Guthnrivod Sinna}ure� iV91%/�/' Date: 0 / c� Contact Phone: 659-7506 917-4 Form 10-404 Revised 412017 141�piD riBUIVI' JAN 16 2020 Submit Original Only 2M-30 Description Of Work Completed Summary Date Event Summary 01105120 Cleaned landing ring on the existing conductor and welded 1T& 20" diameter 94# } a .q WW L" G "Copyright 2020. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other purpose or by other party is prohibited without the express consent of ConocoPhillips Alaska, Inc" 1V LL "Copyright 2020. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other purpose or by other party is prohibited without the express consent of ConocoPhillips Alaska, Inc:"' THE STATE IMMILISA GOGERNOR MIKE DUNLEAVY Roger Mouser Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2M-30 Permit to Drill Number: 192-084 Sundry Number: 319-562 Dear Mr. Mouser: AIaska Oil and Cas CGnsen7ation C€ omission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 vrww. a o g c c. o l a s k a. g o v Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Q` Price DATED this 1'l day of December, 2019. iBDMSL46'JDEC 19 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS DEC 12 2019 Drs tzl/7111 1. Type of Request: Abandon LJ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well E f•1 utdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑' Conductor Extension 2 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service 192-084- 3. Address: 6. API Number: P.O. Box 100360, Anchcorage, Alaska 99510 50-103-20180-00-00 . 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NIA Will planned perforations require a spacing exception? Yes ❑ No ❑� KRU 2M-30 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0025586 ' I Kuparuk River/Kuparuk River Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): `735 y r G'3 c6372 9245 �.s3 6304 Casing 2,/y./1 Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 119' 119' Surface 3447' 10.75" 3487' 2763' Intermediate Production 9293' 7" 9332' 6372' Liner Perforation Depth MD (a): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8936' to 8968 6062' to 6087' 3.5 J-55 8866' 8978' to 9016' 6095' to 6125' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): BAKER F-1 PACKER w/XO SBE (OD=5", SEAL BORE ID=4" 8830' MD, 5980' TVD CAMCO TRDP-4A MOD SSSV 1824' MD, 1721' TVD 12. Attachments: Proposal Summary 0 Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strati ra hic 9 p ❑ Development ❑ Service ❑� 14. Estimated Date for 1/15/2020 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑Y GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Roger Mouser Contact Name: Roger Mouser/Roger Winter Authorized Title: Well Integrity Field Supervisor Contact Email: N1927 Conoco hill) S.COM Contact Phone: 659-7506 Authorized Signature: Date: cOMMISSI N USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: I_ 1 •-1� �4 G!/I'Yr CYYJ /�rLo/o beG r'n ah d ec f t RBDMS DEC 19 2019 n Post Initial Injection MIT Req'd? Yes ❑ No Spacing caption Required? Yes ❑ No Subsequent Form Required: APPROVED BY Approved by: ` COMMISSIONER THE COMMISSION Date: 4 I u mi o m an Form 10-4 is 4/2017 Approved application is d n fr m h date of approval. Attachments in Duplicate "ll" KUP INJ ConocoPhillips JWLAttributes *11 Name Alaska, Inc.AKUPARUK RIVER UNIT ISSSV: TRDP I I how 2M-30 zaaO, a9Fmla Bza 45 AM Last Tag VatiuluMmetic leclwlf pnnlNation Entl pak peptM1 IRKBI last Mod By Lest Tag:RKB (12 of Fill, Leaving fi8'of Open Pegs) N]I2018 9,004.0 zembaej ----- ---- -- --�--- Last Rev Reason Annotation End Oah lae[Mod By Rev Reason: Tag B Replace DV@8,]]5.0' 6/8/2018 zembaej Casing Strings iMM'ERI3Ba CONRecripBon oO lln) ID lin) Top Ifil sH gent ILIKBg sH Depth OVD)... NRM1en n... GINe Top TM1kad CONDUCTOR 20 19.12 40.0 119.0 119.0 94.00 H-00 WELDED Cuing DoalPllon Do(in)IDfin) Top MOM) Sm Oel"m(new IS. Depm (NDI...--m ll_. Grade I I.P IT,. SURFACE 10314 9.95 402 3,487.0 2,763.0 45.50 J-55 BTC Culnp Cezcrlptkn OO an) IOlm Topn.) 1.!T- etaMM1Tubing TubingStrings TUHng Dncription TUBING SbinO Ma... U.IIn) Top lHKel SN OePa1(ft.. 5e[apm liVoj (... W[IIG%ry Grade TOP Connm[bn 3112 2.99 39.1 8.865.9 6,00]J 9.30 J-55 EUE-ABM c...UpTcg,dopn169 Completion Details Top OVD) Topincl Nominal Top Son (win (1) Item Des Cam IO0,d 39.1 39.1 0.08 HANGER FMC GENIV 3.500 1.824.1 1,721.1 39.45 SAFETYVLV CAMCO TRDP-OA MOD SSSV 2812 SAFETY IV, LBSp AK $8268 5,9]]3 38.85 SEALASSY BER GBH-22LOCATORSEALA58EMRLY 2.985 8,829.8 5,979.6 38.85 PACKER BARER F-1 PACKER w/XO SBE (0D=5', S L BORE ID=4' 4.000 B,853.3 5,99].8 38.8) NIPPLE CAMCOO NIPPIEwINO GO PROFILE 2.750 8.8650 6,00].0 38.87805 BAKER SHEAR OUT. TTL EWO@8869 SWS PERF 102/1993 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, Ott.) rop ITVDI Top mol 'P'gKB, BKB) Cas Cam V;06,304.0 Run Dah Ip lin) 9.245.0 38.48 FISH I ] 12' X 2' Bullnose Left in Hole 1001993 aURFACE Jn?3.eTp� Perforations B Slete an. Top(RKB) E.#Bn Top, ntl(BI B.OVID Me) Llnkedzona Dak Den (ehoum ) I. Com 3,9360106',��3 6,087.2 C:T, ,2MdO 1001993 6.0 APERF 2118" EnerJet; V' Ph.E un: a.na1Ilea 8,9]8.06,109A A-4Ad,2M-30 12/22/1992 4.0 IPERF SW54.5-Csg Gun; 180 Ph; Onem 14.3 tleg CCWF/HighSi 89960 6,124.7 A-0,Ad, 30 10201992 4.0 (PERF SW54.5 Cs9 Gun: 180 deg. Ph: Onent 3.3 deg. I CCW F/ High S Frac Summary Start Oak PmplaMOrslgol llb) PropWnt In Fmmatbn(AS GE LASSY;SAMO Stel SbROek Top Dem me, Btm Mel LlnktonuidSyekm Volcimm I Val Slvny(bdl Marginal Inserts PACKER, 9,aD,5 at Ni H Top5,T9V30) ln) = ekh TypeToplK) �P-6" 1RIOWR9un Run Oak Com 1 8,aT15B.1 0 12 GAS LIFT DMV RK 0.000 0.0 fi182016 NIPPLE; Ba53,3 Notes: General a Satety Em wee Annummm 1111]12010 NOTE: VIEW SCHEMATIC w/Alaska S[hematic9.0 a GS; Bmoe. P➢ERF;0,9MD8.9�.D- PERF.S.Sne6a,Wa,O IPERF,BleedGOno FISH; 9,M5a PRODUCTION; 39,39,3316 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Dec 10, 2019 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 2M-30, PTD# 192-084 conductor extension. Please contact Roger Mouser or Roger Winter at 659-7506 if you have any questions. Sincerely, Roger Mouser ConocoPhillips Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. Kuparuk Well 2M-30 (PTD 192-084) SUNDRY NOTICE 10-403 APPROVAL REQUEST 12-10-19 This application for Sundry approval for Kuparuk well 2M-30 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to the surface casing. At some point during normal operations the conductor subsided about 20". With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Extend the conductor to starter head. 3. File 10-404 with the AOGCC post repair • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,June 18,2018 TO: Jim Regg �, !Fj 1 i Supervisor SUBJECT: Mechanical Integrity Tests P.I.P /` ` CONOCOPHILLIPS ALASKA,INC. 2M-30 FROM: Matt Herrera KUPARUK RIV UNIT 2M-30 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry S512— NON-CONFIDENTIAL —NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2M-30API Well Number 50-103-20180-00-00 Inspector Name: Matt Herrera Permit Number: 192-084-0 Inspection Date: 6/14/2018 Insp Num: mitMFH180615104744 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2M-30 Type Inj W `TVD 5979 Tubing 2450 " 2440' 2440 • 2450 PTD 1920840 Type Test SPT Test psi 3000 IA 800 3300 3230 - 3220 ' BBL Pumped: 2.8 " BBL Returned: 2.7 OA 1025 1241 - 1253 • 1260 - Interval REQVAR IP/F P Notes' MITIA to MAIP per AIO 2C.045 IA Pressure tested to 3300 PSI per operator SCANNED JUN 2 2V* Monday,June 18,2018 Page 1 of 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Tuesday,June 20, 2017 6:51 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: Report of multiple IA bleeds KRU WAG injector 2M-30 (PTD 192-084) updated 6-20-17 Attachments: 2M-30 90 day SCADA 6-20-17.JPG Chris, During the monitor period,the well has continued to repeatedly build in IA pressure. An additional bleed by the drillsite operator was performed on 6-17-17. Patience was being practiced this last week due to the substantial increase in injection rate which began on 6-10-17 and I wanted to allow the thermal component of the well's reaction a chance to express itself. However, because the pressure build up is continuing, an IA fluid level was obtained this evening; it was found to be at 99'. The presence of this large gas cap, in combination with the continued increase in pressure leads me to suspect now that annular communication is present. DHD will be mobilized to perform the initial suite of diagnostics which will include packoff testing and an MITIA. If the MITIA passes, in anticipation of an AA submittal,the well will be WAG'ed to water injection for 30 days to confirm that this is in fact only a gas thread leak as is currently suspected. If the MIT fails,the well will be shut in and freeze protected as soon as possible with followup well intervention work with slickline/eline/coil as appropriate. Please let us know if you disagree with this plan forward. Attached is a copy of the updated 90 day SCADA plot which includes injection rates. Kelly Lyons/Brent Rogers ��1 Wil 2017 Well Integrity Supervisor SCOW ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Mobile Phone(907)943-0170 From: NSK Well Integrity Supv CPF1 and 2 Sent:Saturday,June 10,2017 10:12 AM To:Wallace, Chris D (DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject: Report of multiple IA bleeds KRU WAG injector 2M-30(PTD 192-084) 6-10-17 Chris, KRU WAG injector 2M-30(PTD 192-084) has had its IA bled multiple times since being WAG'ed to gas injection on 04/29/17. There have been localized temperature and injection rate changes which may be causing the IA repressurization. Therefore at this point,the IA repressurization is still believed to be thermally induced. However, because of the abnormally high number of bleeds,the well will be monitored under heightened scrutiny for the next 30 days. If the well becomes suspected of displaying TxIA annular communication, it will be reported at that time. A follow-up email will be provided at the conclusion of the monitor period. Please let me know if you disagree with the plan forward. Attached is a 90 day TIO plot. Kelly Lyons/Brent Rogers 1 • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Saturday, June 10, 2017 10:12 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: Report of multiple IA bleeds KRU WAG injector 2M-30 (PTD 1 ) 6-10-17 Attachments: 2M-30 90 day TIO plot 6-10-17.jpg - Chris, KRU WAG injector 2M-30 (PTD 192-084) has had its IA bled multiple times since being WAG'ed to gas injection on 04/29/17. There have been localized temperature and injection rate changes which may be causing the IA repressurization. Therefore at this point,the IA repressurization is still believed to be thermally induced. However, because of the abnormally high number of bleeds, the well will be monitored under heightened scrutiny for the next 30 days. If the well becomes suspected of displaying TxIA annular communication, it will be reported at that time. A follow-up email will be provided at the conclusion of the monitor period. Please let me know if you disagree with the plan forward. Attached is a 90 day TIO plot. Kelly Lyons/Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Mobile Phone (907) 943-0170 SNE® JUN 1 92017. • • duni4m04* 8 uct 8 1:1) 0 eNA co N I . — — vs _ rt1 r 1.6 0 at, a - . 11 .1Veirtf11% .1 / (*) 141 rsi I I ISd • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,June 09,2016 TO: Jim Regg P.I.Supervisor it 6 I Si((" SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2M-30 FROM: Jeff Jones KUPARUK RIV UNIT 2M-30 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2M-30 API Well Number 50-103-20180-00-00 Inspector Name: Jeff Jones Permit Number: 192-084-0 Inspection Date: 6/5/2016 Insp Num: mitJJ160608092211 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2M-30 Type Inj G 'TVD 5979 - Tubing 3850 . 3850 - 3850 - 3850 PTD 1920840 ' Type Test SPT Test psi l 1500 , 1 IA 1820 2810 2750 ' 2740 - Interval 4YRTST [P/F P / OA 1 280 • 280 . 280 . 280- Notes: I well inspected,no exceptions noted. CANNED DEC 2 92016 Thursday,June 09,2016 Page 1 of 1 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /~2" ~°¢/'/~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. Other, No/Type OVERSIZED · [] 'Logs-of vadous kinds . [] Other COMMENTS: Scanned by: Dianna Vincent Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: /si • • Nov ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 OCi April 13, 2011 1 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 ~. W P Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement 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 November 11, 2001. The corrosion inhibitor /sealant was pumped February 17 and 18, 2011. The attached spreadsheet presents the well name, top 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, Perry Klein ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 4113/11 2M & 2N PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor! Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 2M -05 50103201680000 1920470 Surface NA 16" NA 2.5 2/17/2011 ............ 2M -06 50103201760000 1920770 Surface NA 19" NA 2.5 2/18/2011 2M-30 50103201800000 1920840 Surface , NA 16" NA 4.25 2/17/2011 2N -303 50103203520000 2001690 26' 5.00 20" ` 11/8/2001 4.4 2/17/2011 2N -306 50103204900000 2040620 SF NA 24" NA 2 2/17/2011 2N -310 50103205490000 2070900 SF NA 28" NA 5.1 2/17/2011 2N -342 50103205470000 2070680 24" NA 24" NA 7 2/17/2011 • TO: Jim Regg r P.I. Supervisor ~~~ 6 ~ ~ ~ a~ FROM: Jeff Jones Petroleum Inspector State ®f Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 11, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC ZM-30 KUPARIIK RIV UNIT 2M-30 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~-- Comm Well Name• KUPARUK RN UNIT 2M-30 API Well Number 50-1 03-20 1 80-00-00 Inspector Name• Jeff Jones Insp Num: mitJJ080610130310 Permit Number: 192-084-0 :! Inspection Date: 6/2/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~ 2M-30 ~ ~ Well Type Inj. ~ W TVD i p T 1920840 TypeTes~sPT I Test psi j 5980 j IA Isoo~~OA 515 3~o / ~ 3020 i 3010 j 3000 3000 aso aao ~ soo ~ soo ~ Interval aYRTST p~ _ P ~ _ Tubing za7s i zags ~ zags ' _za~s ~I zags Notes• 6.5 BBLS diesel pumped; no exceptions noted. ~~~~ JUL ~. ~: 200$ Wednesday,.lune I f, 2008 Page I of I MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor Ð ,( I )t¿{1 '6 IbiD 7 DATE: Thursday, August 09, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2M-30 KUP ARUK RIV UNIT 2M-30 FROM: Bob Noble Petroleum Inspector Src: Inspector Reviewed By: ,-00 P.I. Suprv -.JJ:::'¡¿- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2M-30 API Well Number: 50-103-20180-00-00 Inspector Name: Bob Noble Insp Num: mitRCN07080613 1637 Permit Number: 192-084-0 Inspection Date: 8/5/2007 Rei Insp N urn: Packer Depth , Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2M-30 ¡Type Inj. ! w I TVD 5980 /j IA 1600 ¡ 2950 i 2930 I 2925 ¡ I ¡ i ¡ ¡ I vi' OA I I 1920840 ¡TypeTest I SPT i Test psi 520 i I 520 I P.T. I 2950 520 I i 520 i i I I \ 4YRTST ,/ P ,/ Tubing 2400 I 2400 I 2400 I 2400 i ! Interval P/F ¡ I Notes: SCANNED AUG 2 3 7007 Thursday, August 09, 2007 Page 1 of I THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 13, 2000 E P M A T E R IA 1~ U N D ER TH IS M ARK ER C:LORI~IFILM.DOC PERMIT DATA AOGCC Individual Well GeOlogical Materials Inventory T DATA_PLUS Page: 1 Date- 11/16/94 RUN DATE_RECVD 92-084 5431 92-084 SURVEY 92-084 SURVEY 92-084 407 92-084 CET T 3268-9350 OH/CDR/CDN R 0.00-9350 R 0.00-9350 R COMP DATE: 12/23/92 L 6300-9243 92-084 CDR/DC L 3507-9350 92-084 CDR L 3507-9350 92-084 CDN/DC A~507-9350 92-084 CDN L 3507-9350 92-084 CBT L 6300-9225 1 11/02/92 01/22/93 11/02/92 01/22/93 I 09/21/92 COMP 12/14/92 COMP 09/09/92 COMP 12/14/92 COMP 09/09/92 1 09/21/92 Was ~he well cored? ~~/Ana~s~& description received? Are well tests required~~s no Received? yes no Well is in compliance ~.%~ _ In~tial COMMENTS no yes no ARCO Alaska. Inc. · ,. Post Office EL. 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 7, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 'Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION ~'L- ~'~ 2M-02 Perforate , z ~¢: ~ 2M-04 Perforate '~z- '~? 2M-06 Perforate ¢) z._:/.,~ 2M-09 Perforate ¢}Z._3.~ 2M'- 30Perforate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering FC[!VFr JAN l i 1994 Alaska Oil & Gas C~)ns. Commission An~orage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALAbr¢, OIL AND GAS CONSERVATION COMMISo,..)N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing 2. Name of Operator ARCO Alaska, Inc. 3, Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 114' FSL, 66' FWL, SEC 28, T11N, RSE, UM At top of productive interval Stimulate __ Plugging Repair well 5. Type of Well: Development Exploratory Stratigraphic Service 981' FSL, 1028' FWL, SEC 33, T11N, R8E, UM At effective depth At total depth 789' FSL, 849' FWL, SEC 33, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 9350' feet Plugs (measured) 6386' feet Effective depth: measured true vertical 9 245' feet Junk (measured) 6 3 0 4' feet Casing Length Structural Conductor 1 21 ' Surface 3 4 8 7' Intermediate Production 9 3 2 9' Liner Perforation depth: Size Cemented 16" 176SXPFC 10 3/4" 811 SX PF E 685 SX CLASS G 7 " 201 SX CLASS G measured 8983'-9021', CDR dated 9/19/92 true vertical 6099'-6129', 6062'- Tubing (size, grade, and measured depth) 3 1/2", 9.3#. J-55 @ 8866' Packers and SSSV (type and measured depth) BAKER F-1 @ 8830' 8936'-8968' Perforate X Other feet 6. Datum elevation (DF or KB) RKB 146 7. Unit or Property name Kuparuk River Unit 6087' 13. Stimulation or cement squeeze summary Intervals treated (measured) Perforated 8936'-8968' Treatment description including volumes used and final pressure 14. Pressure Prior to well operation 8, Well number 2M-30 9. Permit number 92-84 10. APl number 50-103-20180 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Measured depth True vertical depth 121' 121' 3487' 2763' 9329' 6370' Subsequent to operation & ' , Gas C0¢Is. Commission Anchorage Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing 2129 809 psi 2013 psi 2203 530 psi 1910 psi Status of well classification as: Title Senior Engineer Suspended Service Date SUBMIT IN DUPLICATE 15. Attachments 16. Copies of Logs and Surveys run __ Daily Report of Well Operations X Oil Gas 17. I here%certify that the foregoing is true and correct to th-~ best of my kr~owledge. Signed' I ~d~,,'~/ ~ Form 10-404 Rev 06/15/88 ARCO Alaska, Inc. 0 Subsidiary of Atlantic Richfield Company WELL 2M-30 DATE 12/2/93 DAY 1 DESCRIPTION OF WORK PERFORATE A4 AND C4 SANDS CONTRACTOR / KEY PERSON SCHL~ERGER/JACK RATHERT PBTD (RKB) ILAST TAG (RKB) . DATE 9245 I 9245 - 11/27/93 ! TIME LOG ENTRY 1230 MIRU SCHLUMBERGER 1415 KUPARUK RIVER UNIT WELL SERVICE REPORT AFC/CC# - SCA# 997111 I FIELD COST EST. ACCUMULATED COST $8,350 $9,892 SSSV TYPE / STATUS CAMCO TRDP-4A MOD RIH W/1 11/16" TOOL STRING, I-IE~, 6' WT. BAR, CCL, MPD, 32' 2 1/8" ENERJET "V" PHASED GUN, 6 SPF, DP SHOTS DIRECTED TO LOW SIDE. 5' CCL TO TOP SHOT 1500 TIE IN TO CBL DATED 9/7/92, PULL UP TO 8931' W/CCL, SHOOT 8936' TO 8968'. POOH 1600 OOH, ALL SHOTS FIRED. 7.5" BY 2" BULLNOSE LEFT IN HOLE 1645 RDMO SUlvlMARY: PERFORATED 8936' TO 8968' NOTE: LEFI' BULLNOSE IN HOLE I ic~c~ ~ ~,,.oc~:~ st, MM~V~s co~~~ o~ BACK IXl C°M~m~ I ! INCOMPL~:[~ ARCO Alaska, Inc. Post Office [:_. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 10, 1 993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 'Dear Mr. Johnston' . . : Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10,404) notices in the Kuparuk,field. The wells are listed below. WELL ACTION qL- ~3~ 2M-02 Other (cony) qg..-q~ 2M-04 Other (cony) ff Z.-'T'7 2M-06 Other (conv) ff2.-.-7~I 2M-09 Other (conv) ~1'2..--¢~/ 2M-30 Other (conv) If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering RECEIVED At~Ska 0[1 & 6as Cons. Commiss~n Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA AI.A~,~' OIL AND G/~ ~SERVATION ~MI~.,,,.3N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Pull tubing Alter casing Stimulate __ Plugging Repair well 2. Name of Operator ARCO Alaska, Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 114 ' FSL, 66' FWL, SEC 28, T11N, R8E, UM At top of productive interval 981"' FSL, 1028' FWL, SEC 33, T11N, R8E, UM At effective depth 5. Type of Well: Development~ I Exploratory _ Stratigraphic Service At total depth 789' FSL, 849' FWL, SEC 33, T11N~ R8E, UM 12. Present well condition summary Total Depth: measured 93 5 0' true vertical 6 3 8 6' feet Plugs (measured) feet Perforate Other 6. Datum elevation (DF or KB) RKB 146 7. Unit or Property name Kuparuk River Unit 8. Well number feet 9. Permit number 92-84 10. APl number 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 9 2 4 5' true vertical 63 04' Length Size 121' 16" 3487' 10 3/4" 9329' 7" measured 8983'-9021' feet Junk (measured) feet Cemented 176 SX P F C 811 SX PF E 685 SX CLASS G 201 SX CLASS G Measured depth True vertical depth 121' 121' 3487' 2763' 9329' 6370' true vertical 6099'-6128' Tubing (size, grade, and measured depth) 3 1/2", 9.3#. J-55 @ 8866' Packers and SSSV (type and measured depth) BAKER F-1 @ 8830' Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED Anchorage 14. Pressure Representative Daily Averaae Production or Iniection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Prior to well operation N/A Subsequent to operation 21 35 737 1 875 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run m Daily Report of Well Operations X OilB Gas Suspended 17. I hereby/~rtify that ther~oregoing is true and correct to the best of my knowledge. Signed~~/{/~'~., ~'~ Title Senior Engineer Service IWAG INJ Form 10-404 Rev 06/15/88 Date /I ~ '"~,.~ SUBMIT IN DUPLICATE ARCO Alaska, Inc.' g~ WELL SERVICE REPORT Subltdtary of Atlantic Richfield Company WELL JPBDT FIELD-DISTRICT-STATE IDAYS DATE )NTRACTOR OPERATION AT RE~ TIME REMARKS ~: ~7111 ~Z'I~S ~l,-( ~/3" G5 TO ~=UU. car Sv Poll ,~/car t,~co P.~ . gnchorage I-'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK .w:.,_. _ 1ch"' ~'~'~_lvl''bI''ty .. Iwnd v,~. ALASKA OIL AND GAS CONSERVATION COMMISSION SEPTEMBER 8, 1993 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 PAUL WHITE ARCO ALASKA INC. P O BOX 100360 ANCHORAGE, ALASKA 99510-0360 DEAR MR. WHITE, OUR FILES INDICATE THAT ARCO ALASKA INC. IS THE OPERATOR OF THE FOLLOWING WELLS MENTIONED IN THIS LETTER. WE ARE REVEIWING OUR WELL PRODUCTION FILES AND FOUND SOME WELL STATUS ARE INCORRECT AND THAT 404 SUNDRY WELL OPERATION FORMS ARE MISSING FROM OUR WELL FILES. SOME 403 (SUNDRY APPROVALS) HAVE BEEN APPROVED FOR WORK ON THESE WELLS AND OUR FILES DO NOT REFLECT THAT THE WORK WAS ACCOMPLISHED. WOULD YOU PLEASE LOOK INTO THESE WELL SUNDRYS SO WE CAN CLOSE THEM OUT BY SUBMITTING THE APPROPRIATE 404 FORM WITH ATTACHMENTS FOR THE COMPLETED WORK. THESE WELLS CURRENTLY HAVE A STATUS OF, DEV 1-OIL, AND HAVE BEEN WATER INJECTORS OR WAGIN SINCE MAY 1993. WELLNAME PERMIT KUPARUK RIVER UNIT 2M-2 KUPARUK RIVER UNIT 2M-4 KUPARUK RIVER UNIT 2M-6 KUPARUK RIVER UNIT 2M-9 KUPARUK RIVER UNIT 2M-30 KUPARUK RIVER UNIT 31-13 92-0083 92-0093 92-0077 92-0079 92-0084 89-0025 I AM FORWARDING THIS LETTER AS A RECORD FOR YOU AND ME. THANKS FOR THE QUICK RESPONSE ON THESE REPORTS. SINCERELY, STEVE MCMAINS STATISTICAL TECHNICIAN ' ; STATE OF ALASKA £ ALAbr, A OIL AND GAS CONSERVATION COMMISo~ON .f: ~'~'~ APPLICATION FOR SUNDRY-APPROVALS Abandon_ Suspend _ Operation Shutdown _ Re-enter suspended well_ ' Alter casing _ Repair wel~(_ Plugging _ ~iamr~anecX;ension .~erfoS~iar~,late _ Other /~,~" 1. Type of Request: Change approved program 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Pull tubing _ 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 114' FSL, 66' FWL, SEC 28, TllN, RSE, UM At top of productive interval 6. Datum elevation (DF or KB) RKB 146 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2M-30 9. Permit number 981'' FSL, 1028' FWL, SEC 33, T11N, R8E, UM At effective depth At total depth 789' FSL, 849' FWL, SEC 33 , TllN, RSE, UM 12. Present well condition summary Total Depth: measured 9 3 5 0' true vertical 6 3 8 6' feet feet Plugs (measured) 92-84 10. APl number 50-103-2018O 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 9 2 4 5' true vertical 6 3 0 4' Length Size 121' 16" 3487' 10 3/4" 9329' measured 8983'-9021 ' feet feet Junk (measured) Cemented Measured depth True vertical depth 176 SX PFC 1 21 ' 1 21 ' 811 SXPFE 3487' 2763' 685 SX CLASS G 201 SX CLASS G 9329' 6370' E .E VED true vertical 6099'-6128' Tubing (size, grade, and measured depth) 3 1/2", 9.3#. J-55 @ 8866' Packers and SSSV (type and measured depth) BAKER F-1 @ 8830' APR 2 .Alaska 0il .& Gas Cons. C0mmissi0r~ nchorage 13. Attachments Description summary of proposal ~X Detailed operation program _ BOP sketch _ CONVERT WELL FROM OIL PRODUCER TO WATER INJECTOR. 14. Estimated date for commencing operation 15. Status,j:~f well classification as' MAY 1,1993 Oil A Gas __ Suspended _ 16. if proposal was verbally approved Name of approver Date approved Service-W'~TOR ~/y~ 17. I hereby certify that the foregqing is true and correct to the best of my knowledge. Signed C-~ [,.,.) ~ ~ Title ENGINEER Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test __ Location clearance__ Mechanical Integrity Test ~. Subsequent form require IApproval No. Oriain~{.~ 5':~-'~ed,,,, By Approved by order of the Commission David V'¢. Joiqnston Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Drill Site 2M Procedure for Water Injection Conversions Well Nos. 2, 4, 6, 9, and 30 AFC #996572 Downhole Work: K84386 Surface Facilities: K84394 The following general slickline procedure should be utilized for the initial completions of the above wells for water injection service.. 1. Si well and MIRU slickline and hot oil pump truck. 2. RIH and set SV in the "D" nipple. Pressure test the tubing/DV's to 1500 psi. 3. RIH and pull the DV out of the'bottom 1-1/2" GLM. , Rig up hot oiler to the 3-1/2"x 7" annulus, and reverse circulate the annulus to diesel while taking returns from the tubing. Fill the annulus with diesel to the bottom GLM. Annular capacity is .0264 Bbls/Ft. 5. RIH and reset DV in bottom 1-i/2" GLM. 6. Pressure test the tubing to 2000 psi. 7. RIH and pull the SV. 8. RDMO slickline. Notify the State for witness of the Mechanical Integrity Test. . Conduct MIT test. Packer depths and 7" annular pressures required are shown below. Pressures must be held for 30 minutes with no more than a 10% decline. Bleed the annulus to 500 psi after completing each test, Well Packer TVD Depth Rea'd Casina Pressure for MIT 2M-02 6039' 1510 psi 2M-04 6057' 1515 psi 2M-06 5687' 1475 psi 2M-09 6033' 1510 psi 2M-30 5979' 1500 psi 10. Initiate water injection and gradually ramp up rates to maximum allocated water rates, or maximum header pressure available (if lower). RECEIVE APR 2 ~, 199;~ ^laska 0il & Gas 00ns. Anchorage Well 2M-30 Conversion to Water Injection ARCO Alaska requests approval to convert Well 2M-30 from an oil producer to a water injector. This well will be operated as a Class II UIC well in compliance with Area Injection Order No. 2. Water will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 8928' MDRKB and 9093' MDRKB 'This interval correlates with the strata found in ARCO's West Sak River State Well No. 1 between the depths of 6474' and 6880' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. Alaska Oil & Gas Cons. Anchorage OFJN_~oi~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well C.,lassir~..ation of Sewice Wel OIL ~ GAS [] SUSPENDED [] ABAN~D [] SERVICE 2 Name of Operator 7 Pem~ Number ARCO Naska, Inc 92-84 3 Address 8 AP! Number P.O. Box 100360, Anchora~le, AK 99510-0360 50-103-20180 4 Location of well at surface 9 Unit or Lease Name ~" ::.~,:r.:;,_:;:.-: ::: ....... " KUPARUK RIVER 114' FSL, 66' FWL, SEC 28, T11N, R8E, UM ~ ~-~,~?~.i:!;'~:~ At Top Producing Interval;' /~/'~'?'~.! ~" ~!!/_:;~; V~,~IFt~D ~ 10 Well Number ~'~/~.,rE__~ ....... '~- ~_, ' ' ~-' ~"'"'_. t~._~. ~ ~ 11 F'.~d and Pool 789' FSL, 849' F'WI., SEC 33, T11N, R8E, uM ~ ' ~ .... ~; : - ' ' ~ KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, ac.) I 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 146', PAD 105' GLI ADL 25586, ALK 2672 12 Dae Spudded 13 Date T.D. Reac~ed 14 Dale Comp., Susp. or Aband. 15 Water Deplh, i~ offshore I16 No. of ~ions 8/21/92. 08/26/92. 12722J92. NA feet MSLI 1 17 Total Del~h (MD+TVD) 18 Plug Back Deplh (MD+TVD) 19 D~ Su~ey 20 Del~h where SSSV sel 21 Thic~mss of permafrost 9350' MD, 6386' 'I'VD 9245' MD, 6304' TVD YES~X~ NO [--~ 1824' feet MD 1400' APPROX 22 Type Electric or Olher Logs Run CDR,CDN, GR,~ET,CBT,GYRO 23 CASING, UNER AND CEMENTING RECORD I SE'l-rING DEPTH MD CASING SIZE WT. PER Fr. GRADE TOP BoTro~ HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16' 62.5~ H-40 SURF 121' 24' 176 SX PFC 10-3/4' 45.5~ J-55 SURF 3487' 12-1/4' 811 SX PF E, 685 SX CLASS G 7' 26~ J-55 SURF 9329' 8-1/2' 201 SX CLASS 24 Perforations open to Prod~ (MD+TVD of Top and Bottom and 25 TUBING RECORD intewal, size and number) SIZE IDEPTH SET 3-1/2' 9.34f J-55/L-80 8866' 8830' 8983'-9021' W/4-1/2' CSG GUN ~ 4 SPF MD' 6099'-6128' T VD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL ~ID) AMOUNT & KIND Of= MATERIAL USED 27 PRODUCTION TEST Date First Production IMelhod of Operalioa (Flowing, gas lilt, etc.) I , Date of Test Houm Tested PRODUCTION FOR OIL-BI~. GAS-MCF WATER-BI~_ CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BI~. GAS-MCF WATER-BBL OiL GRAVITY-APl (car) Press. 24-HOUR RATE ~ CO,~ ~*~* C~ ,¥[~. d/ l'l ?_ 2 1993 Alaska 0ii & Gas Cons. ¢ommissiori Anchorage Form 10-407 Subrnil in duplicate Rev. 7-1-80 CONllNUED CN REVERSE SDE NAME Include interval tested, pressure data, all fluids recoverd and gravity, IVEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 8928' 6056' NA KUPARUK C BO-I-I'OM 8948' 6072' KUPARUK A TOP 8948' !607'Z KUPARUK A BOTTOM 9093' ;6185' 31. LIST OF ATTACHMENTS GYRO, REPORT OF OPERATIONS 32. I hereby certify that the f~egoing is true and correct to the bes~ of my knowledge 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' Classir~.ation 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 ARCO ALASKA INC. DAILY OPERATIOn_ PAGE: i WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 2M-30 NORTH SLOPE 50-103-20180 ACCEPT: 08/21/92 11:08 SPUD: 08/21/92 06:08 RET.~%SE: 12/22/92 08:30 OPERATION: DRLG RIG: PARKER 245 WO/C RIG: NORDIC i 08/22/92 (1) TD: 1590'( 0) 08/23/92 (2) TD: 3507'(1917) 08/24/92 (3) TD: 3507'( 0) 08/25/92 (4) TD: 4893'(1386) DRILL & SURVEY M~: 9.6 VIS: 64 WEIGH UTILITY MODULE & MVE F/2M-09 T/2M-30. ACCEPT RIG @ 11:00 HRS 08/21/92. SET IN & NU 20", 2M DIVERTER & FUNCTION TEST SAME. MU BHA, CHANGE STAB, BLADES TO 13-3/8" & 13.5". ORIENT & LOAD MWD. CLEAN OUT CONDUCTOR F/97'-121' SPUD @ 18:30 HRS 08/21/92. DRILL F/121'-1596'. SURVEY W/MWD. WIPE HOLE 10-3/4"@ 3486' MW: 9.7 VIS: 56 DRILL F/1590'-3507' SURVEY W/M~D. CIRC & COND FOR WIPER TRIP. WIPE HOLE F/~507'-1205'. 25-75K DRAG F/1671' T/1483', REMAINDER FREE. RIH F/1205'-2955'. WASH & REAM TIGHT HOLE @ 1730'-1750', 2040'-2140', 2600'-2700', 2900'-2955'. 3250' @ 0600 HRS. NIPPLE UP 10-3/4'@ 3486' MW: 9.6 VIS: 44 RIH. REAM & REAM F/3250'-3507'. NO FILL. CIRC & COND MUD. DROP SURVEY. POOH. TIGHT HOLE 2976'-2850'. REAM & WASH THROUGH SAME. DOWN LOAD MWD. LD MOTOR & BREAK BIT. BLUE TIP INSERT F/CONDUCTOR AUGER STUCK BETWEEN CONE & JET HOUSING. RU WEATHERFORD CSG TONGS. RAN 10.75" CSG. HIT BRIDGE @ 2160'. WORK & WASH CSG TO 2313'. RU HOWCO. CIRC PRIOR TO CMT JOB. CMT CSG. CSG SHOE SET @ 3487'. CMT W/811 SX PF "E" & 685 SX CLASS "G". PERFORM TOP JOB W/165 SX PF "C". SET 20" X 10.75 CSG SLIP W/100K. LD LANDING JT. SET OUT DIVERTER. DRILL, SURVEY, & LOG 10-3/4"@ 3486' MW: 8.7 VIS: 30 REPLACE 3 SWITCHES IN CONTROL BOX ON SHAW CRANE. SET DIVERTER ON STUMP. MU SPEED HEAD W/14K FOOT POUNDS. NU 13-5/8' BOPE STACK. LOU GRIMALDI W/AOGCC WAIVED WITNESS OF BOP TEST. TEST ALL LINES, VALVES, RAMS & HYDRIL TO 300 & 3000 PSI. NO FAILURES. SET WEAR BUSHING. SLIP & CUT DRLG LINE. MU BHA, ORIENT & LOAD RA SOURCES. RIH TO 3407' DRILL PLUGS, FLOAT COLLAR, & CMT TO 3467'. CIRC BU. ~EST CSG TO 2000 PSI. DRILL CMT FLOAT SHOE @ 3487'. C/O TO 3507'. DRILL 10' NEW HOLE TO 3517'. CIRC CLEAN. PERFORM PIT TO 12.5 PPG. EMW. DRILL 8.5" HOLE F/3517'-4219'. SURVEY W/MWD, LOG W/LND. FLOW LINE PLUGGED W/DISPLACEMENT RUBBERS F/CMT JOB-RESULTING IN SPILL. 'REMOVE FLOW LINE & FISH RUBBER PLUGS OUT. INSTALL FLOW LINE. DRILL 8.5" HOLE F/4219'-4893'. SURVEY W/MWD, LOG W/LWD. WELL : 2M-30 OPERATION: RIG : PARKER 245 PAGE: 2 08/26/92 (5) TD: 8945'(4052) DRILL, SURVEY LOG 10-3/4"@ 3486' MW:10.0 VIS: 36 DRILL TO 8945', LOG & SURVEY 08/27/92 (6) TD: 9350'( 405) 08/28/92 (7) TD: 9350'( 0) 08/29/92 (8) TD: 9350' ( 0) 09/07/92 (9) TD: 0 PB: 0 RUNNING 7 CSG 7"@ 9329' MW:10.0 VIS: 43 DRILL, LOG, & SURVEY. CBU @ 9350'. SHORT TRIP TO 6579', HOLE NOT TAKING PROPER MUD, RIH TO 9350', NO FILL. CIRC @ 9350', @ 6.5 BPM RATE, CHECK MUD OFTEN FOR GAS OR OIL, NO LIGHT SPOTS. MIX & SPOT 35 BBLS 15% DIESEL PILL WEIGHTED TO 10.5 PPG. POH, LD DP. DOWNLOAD ANADRIL DNR TOOL, REMVE SOURCE. LD TURBINE, BREAK OFF BIT. PULL WEAR RING, RIG TO RUN 7" CSG. RUNNING 7" CSG. BREAK CIRC @ 10-3/4" SHOE. RUNNING 7" CSG. NIPPLE DOWN BOP 7"@ 9329' MW:10.0 VIS: 41 FIN RUNNING 7" CSG, WASH THROUGH BRIDGE @ 6000', WITH SHOE @ 9329' & FLOAT COLLAR @ 9245'. MU HALLIBURTON CMT HEAD. BREAK CIRC, RECIP CSG, CIRC, STARTED PACKING OFF AFTER ATER PUMPING 32 BBS. CONT TO CIRC & RECIP PIPE,WELL PACKING OFF & STICKING. PMP A TOTAL OF 1250 BBLS BEFORE ABLE TO CIRC @ 6 BPM. TEST LINES TO 4000 PSI, PMP 20 BBLS ARCO PREFLUSH, DROP %1 BTM PLUG, PMP 50 BBLS ARCO SPACER, DROP 92 BTM PLUG, BATCH MIX & PMP 201 SX CLASS G CMT. DISPLACE W/347 BBLS 10 PPG BRINE. BUMPED PLUG W/3500 PSI, TEST CSG 1/4 HR. BLED OFF, FLOATS HELD. WELL FLOWING @ 7 GPM, CLOSE WELL IN 1 HR. HAD 65 PSI BUILD, OPEN WELL. BLEED WELL DOWN. FINAL FLOW 5 GAL. IN 1-1/2 MIN. RIG DN CMT HEAD, RAISE STACK, SET SLIPS W/154,000 NET, BLOW DOWN LANDING JT, MAKE ROUGH CUT ON 7", LD LANDING JT. RIG DOWN CSG, ELEV, SET DOWN STACK. ND BOP. RIG RELEASED 7"@ 9329' MW:10.0 VIS: 41 FIN ND OF BOP. MAKE FINAL, NU TREE & TEST TO 3800 PSI. INJECT 200 BBLS WATER & 100 BBLS DIESEL INTO 10-3/4" X 7" ANN. INITIAL PRESS 150 PSI, FINAL PRESS 650 PSI. RD LINE RAN GR/CLL/CET/CBT/GBT/GCT 7"@ 9329' MW: 0.0 RAN GR/CCL/CET/CBT/GBT F/9225'-6300' RAN GYRO F/9200'-SURFACE. BOND LOOKS GOOD. ~ST COST- $31,602 12/22/92 (11) TD: 9350 PB: 9245 SWS POH W/SETTING TOOL 7"@ 9329' MW: 0.0 MVE RIG F/2M-12 TO 2M-30. ND TREE-LEVEL RIG. NU BOPE-HEAT BOP W/STEAM. COMPLETE BOP TEST @ 3000 PSI. TEST WAIVED BY AOGCC REP, JERRY HERRING. PULL TEST PLUG. RU SWS, TEST LUB TO 1000 PSI. TEST CSG @ 3500 PSI F/30 MIN-25 PSI LOSS. RIH & PERF W/4-1/2" SWS GUN @ 4SPF F/8983'-9021'. POOH. _LOAD PIPE SHED W/3-1/2" TBG, DRIFT, TALLY WHILE PERF'N. MAKE 6" GUAGE RING RUN. MU BAKER SETTING TOOL & PKR. RIH. SET PKR @ 8823' W/TP @ 8859'. POH. WELL : 2M-30 OPERATION: RIG : NORDIC I PAGE: 3 12/23/92 (12) TD: 9350 PB: 9245 RIG RELEASED 7"@ 9329' MW: 0.0 POOH W/WL, RD SWS, MU COMP STRING & RIH PER TBG DETAIL, TEST SSSV CTRL LINE TO 5000PSI WHILE RIH & BEFORE LANDING HANGER-OK, RAN 31 SS BANDS. 59K UP WT, 34K DN WT. BALL RUN IS SOS. STING INTO & LOCATE PERM PACKER @ 8630', SPACE OUT & LAND HGR, RILDS. PU ANN & TBG TO 1000PSI, CLOSE SSSV, BLEED TBG TO 500 PSI & TEST SSSV F/10MIN-OK, EQUALIZE & OPEN SSSV. PU ANN & TBG TO 2500 PSIF/15 MIN, LOST 30 PSI, OK. HOLD ANN PRESS & SHEAR OUT BALL W/4000PSI, BLEED OFF PRESS & CLOSE SSSV. PULL LNDG JT, INSTALL BPV, ND BOP, NU FMC GEN IV TREE, PULL BPV, INSTALL TP & PT TREE TO 250 PSI & 5000 PSI, PACKOFF TO 5000 PSI, PULL TP, OPEN SSSV. RU PUMP LINES & DISPLACE ANN W/12 BBLS DIESEL, BULLHEAD 4 BBL DIESEL DOWN TBG, SI WELL, SICP & SITP @ O, SET BPV, RELEASE RIG @ 20:30 ON 12/22/92. MOVE RIG TO 2M-02 S I GNATURE: (dril~r~ DATE: //~/~ SUB - S URFA CE DIRECTIONAL SURVEY ~-'J UIDANCE ~'J ONTINUOUS ~ OOL I ICI OFILNE Il?a/bo_. -- Company Well Name Field/Location ARCO ALASKA, INC. 21q-30 (114' FSL, 66' FEL, SEC 28, T11N, R8E, Uti) KUPARUK RIVER, NORTH SLOPE, ALASKA Job Reference No. 92546 Locjcjed BV: G. SCitWARTZ Date 7-SEP-92 Computed B¥- R. KRUWELL · SCHLUMBERGER · GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA INC. 2M-30 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA SURVEY DATE' 7-SEP-1992 ENGINEER' SCHWARTZ METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- Averaged deviation and azimuth INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 44 DEG 13 MIN WEST COMPUTATION DATE' 29-SEP-92 PAGE i ARCO ALASKA INC. 2M-30 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 O0 100 O0 200 O0 3O0 O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 DATE OF SURVEY' 7-SEP-1992 KELLY BUSHING ELEVATION' 146.00 FT ENGINEER' SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 -146 O0 100 O0 -46 200 O0 54 300 O0 154 399 93 253 499 49 353 598 59 452 696 75 55O 794 26 648 891 24 745 0 0 N 0 0 E 0.00 O0 0 5 N 48 45 E -0.05 O0 0 3 N 14 47 E -0.18 O0 0 23 S 72 33 W -0.01 93 3 43 S 59 2 W 3.06 49 6 25 S 55 9 W I2.15 59 9 16 S 53 29 W 25.22 75 12 8 S 50 51W 44.07 26 13 28 S 51 3 W 66.08 24 I4 51 S 51 5 W 90.29 0 O0 0 37 0 O0 1 48 4 45 1 25 4 18 0 96 1 45 1 17 0 O0 N 0 05 N 0 16 N 0 13 N 1 33 S 6 52 S 14 26 S 25 97 S 39 96 S 55 23 S 0 O0 E 0 02 E 0 09 E 0 12 W 3 02 W 10 72 W 21 51 W 36 51 W 53 70 W 72 71 W 0 O0 N 0 0 E 0 0 0 3 12 25 44 66 91 06 N 17 43 E 18 N 30 4 E 17 N 42 14 W 30 S 66 9 W 55 S 58 40 W 81 S 56 28 W 80 S 54 34 W 93 S 53 21W 31 S 52 47 W 1000.00 1100.00 1082 1200.00 1176 1300.00 1269 1400.00 1360 1500.00 1450 1600.00 1537 1700.00 1622 1800.00 1702 1900.00 1778 987 38 841.38 17 3 57 936.57 18 39 73 1030.73 20 41 58 1123.58 22 51 89 1214.89 25 24 28 1304.28 27 51 71 1391.71 30 14 19 1476.19 34 35 40 1556.40 38 38 55 1632.55 42 11 S 49 34 W S 48 43 W S 47 27 W S 46 5 W S 46 4 W S 46 33 W S 47 11W S 48 14 W S 47 7 W S 47 9 W 117 62 148 14 181 71 218 80 259 53 304 29 352 76 406 10 465 65 530 35 2 27 1 74 2 34 2 11 2 79 2 48 3 25 4 64 3 40 3 83 72 80 S 92 115 140 169 200 233 269 309 353 93 84 W 118 77 S 52 12 W 85 S 117 33 S 142 81S 169 12 S 198 06 S 230 28 S 266 15 S 305 26 S 349 42 S 397 01W 149 04 W 182 04 W 220 35 W 260 74 W 305 10 W 353 72 W 407 89 W 466 28 W 531 37 S 51 34 W 97 S 50 55 W O0 S 50 12 W 66 S 49 33 W 39 S 49 4 W 88 S 48 46 W 32 S 48 38 W 97 S 48 32 W 73 S 48 21W 2000 O0 1850 80 1704 80 45 0 2100 2200 230O 2400 2500 2600 2700 2800 2900 O0 1920 O0 1985 O0 2047 O0 2108 O0 2169 O0 2230 O0 2290 O0 2351 O0 2411 02 1774 75 1839 74 1901 53 1962 50 2023 33 2084 64 2144 05 2205 17 2265 S 46 20 W 02 47 31 S 46 12 W 671 75 50 24 S 47 57 W 746 74 52 34 S 48 35 W 825 53 52 28 S 47 13 W 904 50 52 25 S 47 8 W 983 33 52 43 S 47 7 W 1062 64 52 55 S 47 6 W 1142 05 52 54 S 46 33 W 1221 17 53 6 S 45 47 W 1301 599 40 51 77 O1 25 41 68 34 94 81 2 21 2 80 3 19 1 58 0 54 0 09 0 65 0 50 1 27 0 15 400 74 S 447 67 W 600 83 S 48 10 W 450 73 S 499 502 07 S 554 554 17 S 613 607 40 S 672 661 34 S 730 715 34 S 788 769 66 S 847 824.08 S 905 879.55 S 962 70 W 672 84 W 748 49 W 826 41W 9O6 49 W 985 66 W 1064 08 W 1144 28 W 1224 81W 1304 94 S 47 57 W 28 S 47 51W 73 S 47 54 W 13 S 47 54 W 39 S 47 51W 75 S 47 47 W 51 S 47 44 W 19 S 47 41W 07 S 47 35 W 3000 O0 2471.14 2325 14 53 24 3100 3200 3300 3400 3500 3600 3700 3800 3900 O0 2530.38 2384 O0 2589.67 2443 O0 2649.51 2503 O0 2710 O1 2564 O0 2771 03 2625 O0 2832 83 2686 O0 2894 34 2748 O0 2955 06 2809 O0 3013 86 2867 38 53 45 67 53 31 51 52 56 O1 52 43 03 51 58 83 51 52 34 52 13 06 53 14 86 54 30 S 44 30 W 1381 82 S 42 50 W 1462 S 42 48 W 1542 S 42 38 W 1622 S 42 46 W 1702 S 42 39 W 1781 S 42 23 W 1860 S 42 9 W 1939 S 42 35 W 2018 S 42 59 W 2099 37 87 96 55 75 34 14 54 40 2 61 0 42 0 39 0 78 0 47 1 12 0 41 0 26 2 16 0 27 935 80 S 1019 73 W 1384 04 S 47 27 W 994 1053 1112 1170 1228 1286 1345 1404 1463 26 S 1075 34 S 1129 19 S 1184 77 S 1238 91S 1291 87 S 1345 24 S 1398 02 S 1451 31S 1506 16 W 1464 87 W 1544 24 W 1624 17 W 1704 98 W 1783 10 W 1861 10 W 1940 55 W 2019 57 W 2100 41 S 47 14 W 71 S 47 0 W 62 S 46 48 W 04 S 46 36 W 10 S 46 26 W 54 S 46 16 W 20 S 46 6 W 47 S 45 57 W 25 S 45 50 W COMPUTATION DATE' 29-SEP-92 PAGE 2 ARCO ALASKA INC. 2M-30 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA DATE OF SURVEY' 7-SEP-1992 KELLY BUSHING ELEVATION- 146.00 FT ENGINEER' SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORZZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MZN 4000 O0 3071 86 2925 86 54 33 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 3129 O0 3188 O0 3246 O0 3304 O0 3361 O0 3419 O0 3476 O0 3534 O0 3591 93 2983 12 3042 21 3100 13 3158 93 3215 54 3273 91 3330 06 3388 93 54 25 12 54 26 21 54 33 13 54 38 93 54 45 54 54 54 91 55 5 06 55 9 20 3445.20 55 11 S 42 53 W 2180 84 S 42 37 W 2262 S 42 30 W 2343 S 42 25 W 2424 S 42 9 W 2506 S 42 7 W 2587 S 42 8 W 2669 S 42 6 W 2751 S 41 51W 2833 S 42 0 W 2915 23 52 88 35 9O 59 43 44 43 0.18 0 25 0 05 0 28 0 17 0 16 0 13 0 O0 0 33 1 3O 1522 95 S 1562 05 W 2181 60 S 45 44 W 1582 1642 1702 1763 1823 1884 1944 2005 2067 75 S 1617 67 S 1672 70 S 1727 02 S 1782 55 S 1836 19 S 1891 95 S 1946 95 S 2001 13 S 2056 31W 2262 29 W 2344 26 W 2425 10 W 2506 82 W 2588 64 W 2669 55 W 2751 45 W 2833 15 W 2915 91 S 45 37 W 12 S 45 31W 41 S 45 25 W 81 S 45 18 W 29 S 45 12 W 92 S 45 7 W 71 S 45 1W 66 S 44 56 W 61 S 44 51W 5000 O0 3648 39 3502.39 55 5 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 3705 O0 3762 O0 3818 O0 3874 O0 3930 O0 3986 O0 4043 O0 4103 O0 4164 48 3559.48 55 18 24 3616.24 55 33 62 3672.62 55 49 64 3728.64 56 4 46 3784.46 56 1 46 3840.46 55 55 72 3897.72 53 45 83 3957.83 52 47 41 4018.41 52 38 S 44 18 W 2997 44 S 44 22 W 3079 S 44 11W 3161 S 43 57 W 3244 S 43 43 W 3327 S 43 19 W 3410 S 43 5 W 3493 S 43 55 W 3575 S 44 15 W 3654 S 44 2 W 3734 55 87 46 30 26 10 06 97 53 0 44 0 2O 0 30 0 36 0 27 0 37 0 19 3 68 0 26 0 29 2126 85 S 2112 38 W 2997 60 S 44 48 W 2185 2244 2303 2363 2423 2484 2543 2601 2658 57 S 2169 50 S 2227 85 S 2284 61S 2342 79 S 2399 21S 2455 81S 2512 08 S 2567 18 S 2623 76 W 3079 25 W 3162 69 W 3244 05 W 3327 16 W 3410 86 W 3493 13 W 3575 86 W 3655 27 W 3734 70 S 44 48 W 03 S 44 47 W 61 S 44 46 W 44 S 44 44 W 39 S 44 42 W 21 S 44 40 W 16 S 44 38 W 07 S 44 38 W 63 S 44 37 W 6000 O0 4225.12 4079 12 52 38 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 4285.84 4139 O0 4346.59 4200 O0 4407.40 4261 O0 4468 26 4322 O0 4529 08 4383 O0 4589 94 4443 O0 4650 65 4504 O0 4710 63 4564 O0 4768 89 4622 84 52 36 59 52 35 40 52 30 26 52 31 08 52 34 94 52 31 65 52 46 63 53 47 89 54 39 S 43 56 W 3813 99 S 43 53 W 3893 S 43 50 W 3972 S 43 47 W 4052 S 43 49 W 4131 S 43 50 W 4210 S 43 50 W 4290 S 43 51W 4369 S 42 47 W 4449 S 41 21W 4531 45 88 26 61 99 33 8O 80 O1 0 22 0 O6 0 23 0 22 0 O7 0 14 0 14 0 39 3 22 0 34 2715 39 S 2678 42 W 3814 09 S 44 36 W 2772 2829 2887 2944 3001 3059 3116 3174 3234 63 S 2733 91S 2788 20 S 2843 48 S 2898 76 S 2953 O0 S 3008 32 S 3063 34 S 3118 89 S 3172 53 W 3893 56 W 3972 51W 4052 42 W 4131 38 W 4211 33 W 4290 36 W 4369 46 W 4449 67 W 4531 54 S 44 36 W 97 S 44 35 W 34 S 44 34 W 68 S 44 33 W 06 S 44 32 W 40 S 44 31W 86 S 44 31W 85 S 44 29 W 04 S 44 27 W 7000 O0 4826 94 4680 94 54 20 7100 7200 7300 7400 7500 7600 7700 7800 7900 O0 4885 O0 4943 O0 5002 O0 5061 O0 5119 O0 5176 O0 5232 O0 5288 O0 5345 34 4739 79 4797 42 4856 22 4915 39 4973 20 5030 68 5086 92 5142 73 5199 34 54 17 79 54 10 42 54 1 22 53 56 39 55 3 20 55 34 68 55 39 92 55 51 73 54 38 S 40 58 W 4612 32 S 40.44 W 4693 S 40 24 W 4774 S 4O 16 W 4855 S 4O 8 W 4935 S 40 50 W 5016 S 40 53 W 5099 S 40 45 W 5181 S 40 33 W 5264 S 40 30 W 5346 35 33 15 83 99 15 53 O5 18 0 61 0 35 0 10 0 21 0 32 1 33 0 15 0 25 0 32 0 86 3296 16 S 3226 30 W 4612 34 S 44 23 W 3357 3419 3481 3542 3604 3666 3729 3792 3854 58 S 3279 24 S 3332 O0 S 3384 77 S 3436 72 S 3489 90 S 3543 37 S 3597 10 S 3651 69 S 3704 37 W 4693 12 W 4774 53 W 4855 75 W 4935 47 W 5017 38 W 5099 29 W 5181 17 W 5264 59 W 5346 36 S 44 19 W 33 S 44 16 W 15 S 44 12 W 84 S 44 8 W O1 S 44 4 W 18 S 44 1W 58 S 43 58 W 12 S 43 55 W 27 S 43 52 W COMPUTATZON DATE: 29-SEP-92 PAGE 3 ARCO ALASKA INC. 2M-30 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA DATE OF SURVEY: 7-SEP-1992 KELLY BUSHING ELEVATION: 146.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IOO FEET FEET FEET DEG MIN 8000 O0 5403 97 5257 97 54 2 8100 8200 8300 8400 8500 8600 8700 8800 8900 O0 5464 O0 5528 O0 5594 O0 5662 O0 5732 O0 5804 O0 5878 O0 5956 O0 6034 30 5318 13 5382 93 5448 57 5516 42 5586 23 5658 89 5732 47 5810 34 5888 30 51 38 13 49 8 93 47 31 57 46 52 42 44 51 23 43 4 89 40 8 47 38 48 34 38 55 S 40 18 W 5427 29 S 39 40 W 5506 81 S 39 40 W 5583 53 S 39 44 W 5657 71 S 39 45 W 5731 13 S 41 0 W 5802 52 S 41 11W 5872 O1 S 41 54 W 5938.43 S 43 10 W 6001.50 S 42 54 W 6064.23 1 63 1 92 2 91 0 37 3 1 3 5 0 0 45 69 29 O2 40 30 3916.58 S 3757 30 W 5427 42 S 43 49 W 3977.67 S 3808 4036.95 S 3857 4094.17 S 3905 4150.87 S 3952 4205.42 S 3998 4257.72 S 4044 4307.76 S 4088 4354.02 S 4131 4399.88 S 4173 55 W 5506 63 W 5583 19 W 5657 21W 5731 51W 5802 41W 5872 21W 5938 12 W 6001 94 W 6064 98 S 43 45 W 75 S 43 42 W 98 S 43 39 W 46 S 43 36 W 90 S 43 33 W 43 S 43 32 W 88 S 43 30 W 97 S 43 30 W 71 S 43 29 W 9000.00 6112.22 5966.22 38 42 9100.00 6190.44 6044.44 38 25 9200.00 6268.86 6122.86 38 28 9300.00 6347.14 6201.14 38 29 9350.00 6386.28 6240.28 38 29 S 42 58 W 6126.93 S 43 0 W 6189.22 S 43 7 W 6251.26 S 43 7 W 6313.46 S 43 7 W 6344.56 0.48 0.26 0.10 0.00 0.00 4445.79 S 4216.66 W 6127.42 S 43 29 W 4491.37 S 4259.13 W 6189.72 S 43 29 W 4536.78 S 4301,43 W 6251.77 S 43 28 W 4582.17 S 4343.98 W 6313.98 S 43 28 W 4604.88 S 4365.24 W 6345.09 S 43 28 W COMPUTATION DATE: 29-SEP-92 PAGE 4 ARCO ALASKA INC. 2M-30 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA DATE OF SURVEY: 7-SEP-1992 KELLY BUSHING ELEVATION: 146.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 1000 2000 3000 4000 5000 6000 7000 8000 9000 0 O0 -146 O0 O0 987 O0 1850 O0 2471 O0 3071 O0 3648 O0 4225 O0 4826 O0 5403 O0 6112 0 0 38 841 80 1704 14 2325 86 2925 39 3502 12 4079 94 4680 97 5257 22 5966 N 0 0 E 38 17 3' S 49 34 W 117 80 45 0 S 46 20 W 599 14 53 24 S 44 30 W 1381 86 54 33 S 42 53 W 2180 39 55 5 S 44 18 W 2997 12 52 38 S 43 56 W 3813 94 54 20 S 40 58 W 4612 97 54 2 S 40 18 W 5427 22 38 42 S 42 58 W 6126 0 O0 62 4O 82 84 44 99 32 29 93 0 O0 2 27 2 21 2 61 0 18 0 44 0 22 0 61 1 63 0 48 0 O0 N 72 4OO 935 1522 2126 2715 3296 3916 4445 0 O0 E 80 S 93 74 S 447 80 S 1019 95 S 1562 85 S 2112 39 S 2678 16 S 3226 58 S 3757 79 S 4216 0.00 N 0 0 E 84 W 118 77 S 52 12 W 67 W 600 73 W 1384 05 W 2181 38 W 2997 42 W 3814 30 W 4612 30 W 5427 66 W 6127 83 S 48 10 W 04 S 47 27 W 60 S 45 44 W 60 S 44 48 W 09 S 44 36 W 34 S 44 23 W 42 S 43 49 W 42 S 43 29 W 9350.00 6386.28 6240.28 38 29 S 43 7 W 6344.56 0.00 4604.88 S 4365.24 W 6345.09 S 43 28 W ARCO ALASKA INC. 2M-30 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA COMPUTATION DATE- 29-SEP-92 TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEg MIN PAGE 5 DATE OF SURVEY' 7-SEP-1992 KELLY BUSHINg ELEVATION' 146.00 FT ENGINEER' SCHWARTZ 0 O0 146 O0 246 O0 346 O1 446 22 546 84 648 17 750 43 853 27 956 81 INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH VERTICAL DOgLEg RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH 0 0 N 0 0 E O0 0 5 N 34 57 E O0 0 5 S 89 7 W O0 1 40 S 65 31W O0 5 24 S 55 43 W O0 7 25 S 54 38 W O0 11 3 S 52 4 W O0 12 51 S 50 55 W O0 14 6 S 51 20 W O0 16 11 S 50 5 W 0 O0 -146 O0 146 O0 0 246 O0 100 346 O0 200 446 O0 300 546 O0 400 646 O0 500 746 O0 600 846 O0 700 946 O0 800 FEET DEG/IO0 FEET FEET FEET DEg MIN 0 O0 -0 12 -0 18 0 69 6 70 17 63 33 64 54 88 78 67 105 33 0 O0 0 O0 0 36 3 49 2 19 3 83 3 62 1 63 1 79 2 17 0 O0 N 0 11 N 0 18 N 0 17 S 3 37 S 9 73 S 19 40 S 32 85 S 47 90 S 64 83 S 0 O0 E 0 07 E 0 07 E 0 81 W 6 14 W 15 28 W 28 30 W 44 93 W 63 59 W 84 0 O0 N 0 0 E 0 0 0 7 18 34 55 79 41 W 106 13 N 31 43 E 19 N 21 52 E 83 S 78 27 W O1 S 61 15 W 11 S 57 30 W 32 S 55 34 W 66 S 53 50 W 61 S 53 1W 44 S 52 28 W 1061 48 1046 O0 1167 1274 1383 1495 1609 1729 1856 1993 2138 900 O0 18 3 23 1146 44 1246 57 1346 17 1446 62 1546 13 1646 62 1746 21 1846 89 1946 O0 1000 O0 1100 O0 1200 O0 1300 O0 1400 O0 1500 O0 1600 O0 1700 O0 1800 S 49 3 W O0 19 58 S 47 56 W O0 22 19 S 46 15 W O0 24 56 S 46 1W O0 27 45 S 46 32 W O0 30 34 S 47 20 W O0 35 54 S 48 5 W O0 40 35 S 46 58 W O0 44 52 S 46 24 W O0 48 35 S 46 50 W 136 08 170 37 208 93 252 57 302 06 357 64 422 83 501 71 594 60 700 42 1 41 2' 19 2 02 2 84 2 48 3 67 4 31 3 60 2 27 3 30 84 89 S 107 89 W 137 28 S 51 48 W 107 133 164 198 236 280 333 397 470 68 S 133 97 S 161 28 S 193 51S 229 59 S 269 35 S 318 88 S 376 43 S 444 63 S 520 64 W 171 92 W 210 34 W 253 12 W 303 70 W 358 21W 424 30 W 503 19 W 596 70 W 701 63 S 51 8 W 15 S 50 24 W 71 S 49 39 W 16 S 49 6 W 77 S 48 44 W 09 S 48 37 W 07 S 48 25 W 03 S 48 ll W 87 S 47 53 W 2297 13 2046 O0 1900 O0 52 33 2461 2625 2791 2957 3126 3294 3459 3621 3784 46 2146 90 2246 64 2346 99 2446 39 2546 17 2646 19 2746 35 2846 85 2946 O0 2000 O0 2100 O0 2200 O0 2300 O0 2400 O0 2500 O0 2600 O0 2700 O0 2800 O0 52 25 O0 52 53 O0 52 52 O0 53 6 O0 53 41 O0 52 58 O0 52 22 O0 51 56 O0 52 56 S 48 37 W S 47 6 W 952 S 47 5 W 1083 S 46 38 W 1215 S 45 25 W 1348 S 42 48 W 1483 S 42 39 W 1618 S 42 50 W 1749 S 42 19 W 1877 S 42 25 W 2006 822 74 90 27 28 16 63 31 53 13 41 1 57 0 13 0 71 1 11 1 23 0 21 0 74 1 13 0 46 1 93 552 66 S 611 79 W 824 45 S 47 54 W 640 729 819 911 1009 1108 1205 1299 1395 55 S 708 38 S 803 52 S 900 97 S 995 86 S 1089 76 S 1181 24 S 1270 29 S 1356 O9 S 1443 12 W 954 77 W 1085 43 W 1217 95 W 1350 61W 1485 08 W 1619 11W 1750 41W 1878 33 W 2007 85 S 47 52 W 37 S 47 47 W 53 S 47 42 W 41 S 47 31W 62 S 47 11W 97 S 46 49 W 93 S 46 30 W 30 S 46 14 W 36 S 45 58 W 3955 40 3046 O0 2900.00 54 34 4127 4299 4472 4646 4820 4995 5171 5348 5527 62 3146 64 3246 41 3346 07 3446 90 3546 82 3646 33 3746 80 3846 78 3946 O0 3000 O0 54 24 O0 3100 O0 3200 O0 3300 O0 3400 O0 3500 O0 3600 O0 3700 O0 3800 O0 54 33 O0 54 43 O0 54 59 O0 55 7 O0 55 4 O0 55 28 O0 55 56 O0 55 58 S 42 56 W 2144 51 S 42 33 W 2284 S 42 25 W 2424 S 42 7 W 2565 S 42 7 W 2707 S 41 47 W 2850 S 44 17 W 2994 S 44 15 W 3138 S 43 49 W 3284 S 43 13 W 3433 68 58 39 27 58 O1 25 86 29 0 03 0 14 0 28 o 13 0 26 0 29 0 49 0 35 0 31 0 38 1496 34 S 1537 32 W 2145 31 S 45 46 W 1599 1702 1806 1912 2018 2124 2227 2332 2440 29 S 1632 48 S 1727 84 S 1821 16 S 1916 73 S 2012 39 S 2109 57 S 2210 96 S 2312 56 S 2414 51W 2285 06 W 2425 71W 2565 92 W 2707 90 W 2850 99 W 2994 77 W 3138 69 W 3285 95 W 3433 34 S 45 35 W 11 S 45 25 W 80 S 45 14 W 58 S 45 4 W 79 S 44 55 W 18 S 44 48 W 41 S 44 47 W O0 S 44 45 W 41 S 44 42 W ARCO ALASKA INC. 2M-30 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA COMPUTATION DATE: 29-SEP-92 PAGE 6 DATE OF SURVEY: 7-5EP-1992 KELLY BUSHING ELEVATION: 146.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HoRIz. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 5703 85 4046 O0 3900 O0 53 38 5869 6034 6199 6363 6527 6692 6860 7032 7203 64 4146 39 4246 03 4346 42 4446 82 4546 32 4646 49 4746 66 4846 78 4946 O0 4000 O0 4100 O0 4200 O0 4300 O0 4400 O0 4500 O0 4600 O0 4700 O0 4800 O0 52 41 O0 52 37 O0 52 35 O0 52 31 O0 52 31 O0 52 44 O0 54 34 O0 54 15 O0 54 10 S 43 59 W 3578 16 S 44 6 W 3710 40 S 43 57 W 3841 33 S 43 50 W 3972 11 S 43 48 W 4102 58 S 43 50 W 4233 08 S 43 51W 4363 68 S 41 34 W 4498 83 S 40 52 W 4638.79 S 40 23 W 4777.38 3 26 0 27 0 O7 0 23 0 O9 0 34 0 34 0 98 0 25 0 O9 2546 04 S 2514 28 W 3578 26 S 44 38 W 2640 2735 2829 2923 3017 3111 3210 3316 3421 84 S 2606 08 S 2697 36 S 2788 53 S 2878 69 S 2968 91S 3059 75 S 3151 20 S 3243 57 S 3334 49 W 3710 38 W 3841 03 W 3972 33 W 4102 68 W 4233 12 W 4363 35 W 4498 66 W 4638 10 W 4777 5O S 44 37 W 42 S 44 36 W 20 S 44 35 W 66 S 44 33 W 14 S 44 32 W 74 S 44 31W 88 S 44 28 W 81 S 44 22 W 39 S 44 15 W 7374 12 5046 O0 4900 O0 53 58 7546 7723 7900 8070 8227 8375 8519 8656 8786 68 5146 63 5246 47 5346 23 5446 11 5546 64 5646 15 5746 47 5846 57 5946 O0 5000 O0 5100 O0 5200 O0 5300 O0 5400 O0 5500 O0 5600 O0 5700 O0 5800 O0 55 26 O0 55 43 O0 54 38 O0 52 20 O0 48 25 O0 47 24 O0 44 36 O0 41 37 O0 38 46 S 40 11W 4914.96 S 40 59 W 5055 28 S 40 43 W 5201 S 4O 3O W 5346 S 39 51W 5483 S 39 44 W 5603 S 39 39 W 5713 S 41 18 W 5816 S 41 1W 5909 S 43 13 W 5993 O1 56 40 85 33 O0 95 09 0 23 0 57 0 36 0 84 2 56 3 08 1 16 1 78 2 71 0 54 3526 78 S 3423 25 W 4914 96 S 44 9 W 3633 3744 3854 3959 4052 4137 4215 4286 4347 70 S 3514 16 S 3610 98 S 3704 62 S 3793 64 S 3870 12 S 3940 62 S 4007 38 S 4069 87 S 4125 59 W 5055 03 W 5201 84 W 5346 53 W 5483 66 W 5604 81W 5713 37 W 5816 36 W 5910 37 W 5993 30 S 44 3 W 07 S 43 57 W 66 S 43 52 W 56 S 43 46 W 09 S 43 41W 64 S 43 36 W 39 S 43 33 W 39 S 43 31W 55 S 43 30 W 8914.99 6046.00 5900.00 38 54 9043.23 6146.00 6000.00 38 32 9170.86 6246.00 6100.00 38 19 9298.55 6346.00 6200.00 38 29 9350.00 6386.28 6240.28 38 29 S 42 55 W 6073.64 S 42 59 W 6153.91 S 42 57 W 6233.20 S 43 7 W 6312.56 S 43 7 W 6344.56 0 . 34 0.30 0.31 0.00 0. O0 4406.77 S 4180.35 W 6074.12 S 43 29 W 4465.54 S 4235.06 W 6154.41 S 43 29 W 4523.57 S 4289.11 W 6233.71 S 43 29 W 4581.51 S 4343.36 W 6313.08 S 43 28 W 4604.88 S 4365.24 W 6345.09 S 43 28 W COMPUTATION DATE: 29-SEP-92' PaGE 7 ARCO ALASKA INC. 2M-30 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA MARKER 10 3/4" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK a BASE KUPARUK a LAST READING GCT PB1-D 7" CASING DATE OF SURVEY: 7-SEP-1992 KELLY BUSHING ELEVATION: 146.00 PT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 144' FSL A 66' FEL, SEC28 TllN R8E UM MEASURED DEPTH BELOW KB TVD FROM' KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 3487.00 8928.00 8948.00 8948.00 9093.00 9200.39 9245.00 9329.00 9350.00 2763.01 6056 I2 6071 69 6071 69 6184 96 6269 17 6304 08 6369 84 6386 28 2617 O1 5910 12 5925 69 5925 69 6038 96 6123 17 6158 08 6223 84 6240 28 1221 38 S 4412 76 S 4421 95 S 4421 95 S 4488 19 S 4536 96 S 4557 18 S 4595 34 S 4604 88 S 1285 05 W 4185 91W 4194 46 W 4194 46 W 4256 17 W 4301 60 W 4320 59 W 4356 31W 4365 24 W COMPUTATION DATE: 29-SEP-92 PAGE 8 ARCO ALASKA INC. 2M-30 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA MARKER 10 3/4" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK a BASE KUPARUK A LAST READING GCT PBTD 7" CASING DATE OF SURVEY: 7-SEP-1992 KELLY BUSHING ELEVATION: 146.00 FT ENGINEER: SCHWARTZ ************ STRATIGRAPHIC SUMMARY ************ SURFACE LOCATION = 144' FSL ~ 66' FEL, SEC28 T11N R8E UM MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 3487 O0 8928 O0 8948 O0 8948 O0 9093 O0 9200 39 9245 O0 9329 O0 9350 O0 2763 01 6056 12 6071 69 6071 69 6184 96 6269 17 6304 08 6369 84 6386 28 2617 01 5910 12 5925 69 5925 69 6038 96 6123 17 6158 08 6223 84 6240 28 1221 38 S 4412 76 S 4421 95 S 4421 95 S 4488 19 S 4536 96 S 4557 18 S 4595 34 S 4604 88 S 1285 05 W 4185 91W 4194 46 W 4194 46 W 4256 17 W 4301 60 W 4320 59 W 4356 31W 4365 24 W FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 9350.00 6386.28 6240.28 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 6345.09 S 43 28 W I DIRECTIONAL SURVEY COMPANY FIELD WELL COUNTRY RUN ARCO ALASKA INC. KUPARUK RIVER UNIT 2M-30 USA ONE DATE LOGGED 07 - SEP - 92 DEPTH UNIT ~'EET REFERENCE 92~46 WELL' 2R-30 (114' FSL, 66' FEL, SEC 28, T11N, R8E, UN) HORIZONTAL PROJECTION IOO0 ,. ....... . ..... WELL: 21~-30 (114' FSL, 66' FEL, SEC 28, T11N, R8E, tiM) VERTICAL PROJECTION · : : : · : ' : . ' · : ' - "'F- i'": '-~ ..... :' 'F ':'"' - : ~ ": .....l ]' : ......... , .4 .......... :"-:"':'":'"t .......................... :"': ............... .... ? :' ........ !'"7"E" :'"~ · : ' ' .-'"'~ ' ' '': ~ ~ I-~. : I.. :. i .... T:. ............... I ..... :'": ...... I ...... :'":***:'*'l ....... : ................... ,~_.j ..!_.i...!...:...! ..... ;...i ...... !--~ : -:---! - -~ -I I .......... ~ ..... - I ............ I ...r..~ ~. "-!---i'--:."'r'""-?-~"~"'~ 'i-"~ .......... : .......... ~. .... 1 ...... 1...~ ........ 1...: ........... ~ ............ ~ ~:: : i . . : Ld ..... :...~ ..!..:...: .................... : .~, ...... ~ ........ ~ · i I ~ '--: ...... :---: ..... :---:'- :---: ..... : .... : .......... ~ ............. : : . ' i · ~ _ ! ...... i" i---i ........................... i ....... ! ................ : ...... t-- -J- :::: . ] ~ ~ ~ I : : : i : : ,. :J-,~e,oo~ I"'!"! ......... 1 ...... ! ..... :"i";'~'":": .... :":":'"'-1" ........ J'i ................ :, I--~ ....... ...... :--~-t-- ....... 'i ............................................................. ---F--:---:---: ..... ~---:---~ ....... J ....... i---F--: .......... : ....... : ..... I-..!---~.-.! ...... ! ...... ~...i...! ..................... : .......... J' .............. J ......... !---: ...... ;--'! -~'-i--i ....... ~ ...... !-i- ......... [ ................. ... .................... , .................. , ...... ?'-!"-:--'I ...... fj ti:i J J J' ..... ~'': .... ~"~' ...... '"'~": .............. : ~ , .:~ ........... , ~ ',i-- ......... .-"--~ -~"' .... / J ;;I ; ! ~;;/~-.-'~.. r'T'T"F': ...... FT":"'?i':'":":'T'i" I.~-;~-;-I---;-~ ~-~1--~---~---;- -~----I -t- I I/;-: -;---~ .... ,:- A06CC 6EOLO61CAL MATERIALS INYENTORY LiST PERMIT ~ ~ - ~ WELL N~ME ~ ~ ~ ~-- ~ COMPLETION DATE ~ t ~ I.~ CO. CONTACT ~0 ~ i check off or list data as it is reCe!ved.*list received date for 407. if not re~luire,d list as NFl 407 I* } I~-~q3 drillin9 histo~ ~" survey! t ! well tests~1 core dcscrirtio~ cored,, inte~al~,,core anal~i~ ~ d~ ditch inte~al~ , digital data ' LOG 'I~PE R~N INTERVALS SCALE 11~"']~"h~'/~ .... ~-~, ~) (~', ..~"~\N"O~ ~ ~~~- ~ "~:q~:~"~)(t° thc nearest footJ ,,, [inchll.~,.. ~00'] 13I 1~1 ! II II1,1 II I I I I I I I ARCO Alaska, Inc. Date: December 11, 1992 Transmittal #' 8619 RETURN TO: ARCO Alaska, Inc. Attn: Nikki Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. and return one signed copy of this transmittal. I2M_27 '''' ~ ~'"9/ 2M 27/ ~ I 2 M- 26---" CDR ~2-''',~''¢ 2M 26-'- CEAI f2M -09 / CDR ?'~-¢~ 2M 09/ CE:Al 2M-30 ~' CDR ~/.--/,:¢ 2M- 17 '/ C.,DR ~Z"~¢ M 06 ~- CE:N Receipt Acknowledged' DISTRIBUTION: Please acknowledge receipt 09-19-92 09- 1,9"L 92 07-28-92 07-28-92 09-18-92 09-18-92 09-19-92 09-19-92 1 1 -1 8-92 09-17-92 09-17-92 Date' 3117-7855 3117-7855 2859-6765 2859-6765 4359-12177 4326-12177 35O7-935O 35O7-935O 3212-7947 3790-5732 3790-5732 RECEIVED DEC 1,4-' 992 Alaska Oil & Gas Cons. Commission Anchorage D&M Drilling Vendor Package(Johnston) NSK State of Alaska(+Sepia) ARCO Alaska, Inc. Date: October 30, 1992 Transmittal #: 8586 RETURN TO: ARCO Alaska, Inc. Attn: Nikki Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. one signed copy of this transmittal. Please acknowledge receipt and return 2M-12 ~: 5~'/'~ LIS Tape and Listing 2M 30~ ~/ LIS T~ and Usting 2 M- 2 7~ ~~lS T~ and Usting 2 M 0 6 ~ ~, LIS T~ a~ Usting 2M 09~~ LIS T~ and Usting 2M 02~~LIS T~ and Usting Receipt Acknowledged: 1 0-1 0-92 92545 09-1 9-92 92528 09-1 9-92 92471 09-1 8-92 92486 09-1 8-92 92511 10-06-92 92539 a t e' P.,.ECEIV ED NOV 0 2_ 1992. DISTRIBUTION: Alaska 0il & Gas Cons. Commission Anchorage Lynn Goettinger State of Alaska ARCO Alaska, Inc. Date: October 30, 1992 Transmittal #: 8585 RETURN TO: ARCO Alaska, Inc. Attn: Nikki Stiller Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Sub-Surface Directional 1 0- 0 6 - 9 2 Survey Sub-Surface Directional 0 9- 0 7 - 9 2 Survey Sub-Surface Directional Survey Sub-Surface Directional Survey Sub-Surface Directional Survey Sub-Surface Directional 0 8 - 2 4- 9 2 Survey 09-26-92 10-07-92 08-25-92 Receipt Acknowledged:-- / DISTRIBUTION; D&M State of Alaska (2 copies) 92610 92546 92585 92547 92518 92519 Da,e E D NOV 0 £ 1992. AJaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: September18, 1992 Transmittal #: 8552 RETURNTO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. return one signed copy of this transmittal. M O2 Receipt Cement Evaluating Log Cement Bond Log ~ Cement Evaluating L~og Cement Bond Log ~" Acknowledge' 9-7-92 9-7-92 9-7-92 9-7-92 Drilling State of Alaska(+sepia) Please acknowledge receipt and Date' 6300-9243 6300-9225 0-10843 8000-10890 D NSK SEP 2 '~ 1992 Alaska 0ti & Gas Cons. C, ommission Anchorage ARCO Alaska, Inc. Date: September 4, 1992 Transmittal #: 8538 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. and return one signed copy of this transmittal. Please acknowledge receipt 2M-30 CZ~ 2M 30 CDR Receipt Acknowledged: 8-24-26-92 3487-9350 8-24-26-92 3487-9350 Date: DISTRIBUTION: D&M Drilling Vendor Package(Johnston) NSK State of Alaska(+Sepia) RECEIVED SEP 09 1992 011 & Gas Cons. Commission Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501.3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 August 17, 1992 A. W. 'McBride Area Drilling Enginer ARCO Alaska, Inc. P O Box 10360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2M-30 ARCO Alaska, Inc. Permit No: 92-84 Sur. Loc. ll4'FSL, 66'FEL, Sec. 28, TllN, R8E, UM Btmhole Loc. 815'FSL, 760'FWL, Sec. 33, TllN, R8E, UM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test'performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Si __ ~ Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. " STATE OF ALASKA ALAbr,,A OIL AND GAS CONSERVATION COMMISS~,..)N PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill [] lb Type of Well Exploratory [] Stratigraphic Test E] Development Oil X Re-Entry [~ Deepen E] Service ~] Development Gas [] Single Zone X MullipleZone [~] 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 146', Pad 105' GL feet Kuparuk River Field 3. Address 6. Property Designalion Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25586, ALK 2672 4. Location of well at sudace 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.025) 114' FSL, 66' FEL, Sec. 28, T11N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 4291' FNL, 929' FWL, Sec. 33, T11N, R8E, UM 2M-30 #UG630610 At total depth 9. Approximate spud date Amount 815' FSL, 760' FWL, Sec. 33, T11N, R8E, UM 9/2/92 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in properly 15. Proposed depth (MD and TVD) properly line 2M-31 Proposed 9,338' MD 760'@ TD feet 15' @ 400' MD feet 2560 6,345' TV• teet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.O35(e)(2)) Kickoff depth 400 feet Maximum hole angle 5 3° Maximumsudace 1 632 ~,,~o At total depth fTVD) 3149 18. Casing program Setting Depth size Specifications Top Bottom Quantily of cemenl Hole Casing Weight Grade Coupling Length MD TV• MD TVD (include slage data) 24" 20" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 13.5" 10.75" 45.5# J-55 BTC 3518' 41' 41' 3,559' 2,756' 381 Sx Permafrost E & HF-ERW 685 Sx Class G 8.5" 7" 26.0# J-55 BTCMOE 4389' 41' 41' 4430' 3275' HF-ERW 8.5" 7" 26.0# J-55 BTC 4908' 4430' 3275' 9,338' 6,345' 159 Sx Class G HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry. and Deepen Operalions. Present well condition summary Total depth: measured feet Plugs (measured) true vedical feet Effeclive depth: measured feet Junk (measured) true vedical feet Casing Length Size Cemented Measured depth True Verfical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vedical 20. Attachments Filing fee X Property plat r-] BoP Sketch X Diveder Sketch X Drilling program X Drilling fluid program X Time vs depth plot Fi Refraclion analysis [] Seabed repod ~--] 20 AAO 25.050 requirements X 21, I hereby cerlify that lhe foregoing is true and correcl to the best of my knowledge /ftJ~///;~ .~ ~ ,-,.=L Title Area Drillin~l En,ineer Date Signed ..... t Commission Use Only/ Perm, Number ¢ I/ 50- /_C).~ ,-~. ~//~)(~ ~)~'/ ¢~'~'--' ~othe, requirements Conditions of approval Samples required(,._/ [] Yes 5J~,' No Mud Icg required [] Yes ~ No Hydrogen sulfide l-1 measures Yes /,[~ No Direclional survey required .~ Yes ~ No Required working pressure forBOPE ~ 2M ,J~ SM Bi 5M r-] 1OM ~ 15M Other: Original Signed By David W. Johnston by order of Approved by Commissioner lhe commission Dale m I Rev, 7-24-89 Submil in IriDlicate ARCO ALASKA, Structure : Pad 2M Well : .30 Field : Kuparuk River Unit Location : North Slope, Alaska CREATED BY : JONES For: Bill Mathews i0ATE PLOI-rED : 29-JUL-92 PLOT REFERENCE IS 30 VERSION #4. ~COORDINATES ARE IN FEET REFERENCE SLOT #30. iTRUE VERTICAL DEPTHS ARE REFERENCE WELLHEAD. <-- West 5000 4-500 4OO0 3500 3000 2500 2000 15OO I O00 I I I I I I I I i I I I I I I I I I I V EASTMAN TARGET ANGLE 40 DE(; 52.50 4-9.50 4-6.50 4-3.50 J SURFACE LOCATION: J S 44 21 DEG W I sEc. 28, T11N, RBE I 6145' '~T0 TARGET) . 350 KOP TVD=400 TMD=4-O0 DEP=O ' ' ' ' _ 3,00 yoo_ 9.00 15.00 BUILD 3 DEG / 100' mso_ 21.00 TARGET LOCATION - 27.00 B/ PERMAFROST .~ I TARGET LOCATION: I I ~oo_ 33.00 T/ UGNU SNDS I SEC. 33, tl 1N, RSE I - 39.00 TVD=1431 TMD=1489 DEP=302 1750_ 4.~.00 TARGET ,51 .OO EOC TVD=6056 - TVD=I 933 TMD=21 79 DEP=771 TMD=8961 2~oo_ T/ W SAK SND$ DEP=6145 TVD=2001 TMD=2294- DEP=862 SOUTH 44-05 - WEST 4-285 24-50_ W S~K~ SNDS TVD=2556 TMD=3224 DEP=1609 ' SG PT TVD=2756 TMD=3559 DEP=IB7B 28oo_ K-1 0 TVD=2B21 TMD=B66B DEP= 1966 3150- AB MODIFIED CSG PT - T'v'D=3275 TMD--44-30 DEP=2577 3500.. - 385o_ MAXIMUM ANGLE - 53.38 DEG ,~2oo_ K-5 -I-VD=4316 TMD=6175 DEP=3978 - 4550- - 4-900- - 5250_ - BEGIN ANGLE DROP TVD=544-5 TMD=8060 DEP=54-90 5600_ - DROP1.5BEG/ 100' 5950_ - 6300_ 665O TARGET - T/ ICOP SNDS (EOD) TVD=6056 TMD=8961 DEP=6145 T/ ZONE A TVD=6067 TMD=8975 DEP=61 B/ KUP SND$ TVD=6192 TMD=9138 DEP=6259 3~)/LO~G~GI~ T~])=6345TMD=9338 DF, P=6388 SCALE 1 : 250.00 500 0 500 I I I I 500 0 500 - _1000 - _1500 -2000 . .2500 _3000 - _3500 *ODD ~500 5000 ....... 101501111.5111:111.11150135100 ..... ; I ;0 I 15 I 10 159150 350 0 350 700 1400 17 0 2100 2 50 2800 3850 &200 4 50 4 0 52 0 56 0 SCALE 1 : 175.00 yerticol SecHon on 224.21 ozimuih with reference 0.00 N, 0.00 E from slot #30 40.50 63100 I 66150 I I V Casing Design / Cement Calculations 12-Aug-92 INP. UT WELL INFOBM.ATION Well Number: Surface Csg MD: Surface Csg TVD: !MD; TVD: TOp of West gak~ TMD= Top of Target~ TMD: iTop of ?arget, TVD: Estimated Mud Weight: Surface Casing Choice {1, 2, 3, or 4): Production Casing Choice (1 or 2)-- Proc~jctlon Casing Fi'ac, Pressure 3,559 II 2,766 ft 9,338 ft 6,345 ft 2~294 ft 8,961 ft B,056 [t 10,0 ppg a,500 psi .,, PRESgURE INFORMATION Maximum anticipated surfuoe pressure Estimated BH pressure at top of target zone _~EUE~T CALCULATiC)N.q Surface Casing Cement: Surface lead: TVD sul[~(;e shoe {(13.5'0.052)-0.11}'TVDShOe A~l[i~lp~tecl MU0 Weight = Top of Target Zone, TVD = 100 pal Overbalance = --! Top We~t Bak, TMD .-- Design I~ad L~uttom 500 ft above the Top Of west Sak = Annular area - Lead length * Annulus area = Ex,ess factor = Cement volume required = Yield fu~ Permafros! (:;mt: Cement volume required 2,756 ft .1&$2 osii 10.0 ppg 6,056 ff 3,249 psi 3149 psi] . · 2,294 fl 1,794 0.3637' of/if 052 cf 750 cf 1.97 381 Surface Iai J: RECEIVED AUG I ~; lB"" TMD shoe (surface TD - 500' above West Sak) * (Annulus area) !. ength of omt Inside esg Internal osg volume Cmt required In casing Total cmt Excess factor Cement volume required Yield for Class G cmt Cement volume required A,~$k¢.~ .,, Oil & Gas Cons. Commission Anchorage 642 cf 80 ff 0.5398 ct/if 43 cf 685 cf 15% 788 of 1.15 / U; I,~,~V/L, I / I",IV UI'~ J. LL ! I'11_1 ~.-.~. , ,/ Casing Design / Cement Calculations 12-Aug-92 Production Casing Cement: ProdlJctiorl tail: CASING DESIGN TMD = Top of Target, TMD = Want TOC 500' above top of target = Annulus area (9" Hole) -- (TD-TOC)*Annulus area = Length of cmt wanted In osg --- Internal csg volume = Grot require0 In casing = TOtal cmt = Excess factor = Cement volume required = Yield for Class (3 cmt = cement volume required =J , 9,338 fl; 8,g61 ff 8,461 ft 0,174$ 153d 80 fl 0,2148 17 Cf 170 cf 15% 196 ef 1,23 Surface (Pipe Body): TP.n,~inn (Pipe Rody) = Dead Wt in Air - Buoyant Force Dead Wt In Air = Length * (Wt/ft) Buoyancy = O.t~ppg*.052*TVD Surf. Oa$.*X-$ect, Area TENSION - Minimum Deslg_n Factors are: 'r(obl=l,5 and T(Js) .--..,.t,.t~ Casing Rated For: MD ~urfaoe ehoe - Casing Wt (lb/E) = Dead WI in AI~ = Buoyancy = Tension (Pipe Body) '-- Design Factor 715000 lb 3,559 ft 45.50 Ib/ft 161934,5 ID 17893,9 lb 144O40.6 lb .... Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air- Buoyant Force Dead Wt In Air --- Length * (WfJft) Buoyancy--9.$ppg*,052'TVD Surf. Cas,'X-sect. Area Casing Rated For: MD surface shoe = Casing Wt (lb/f0 = Dead Wt In Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 931000 lb 3,559 ft 45.50 Ib/ft 161934,5 lb 17893,9 lb 144040,6 lb Production (Pipe Body): Ten.~tan (Pipe Body) .-. Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WVft) Buoyancy =Mud Gradlent*.O52*TVD Proci.*X-sect. Area Casing Rated For: TMD -- Casing Wt (lb/fO = Dead Wt In Air = Buoyancy = Tension (Pipe Body) = Design Factor =I 415000 lb 9,838 ft 26,00 Ib/ft 242788,0 ID 24907,5 lb 217860.5 lb Production (Joint Strength); Tension (Pipe Body) = Dead Wt in Air- Buoyant Force Dead Wt in Air = Length * (WVft) Buoyancy =Mud Gradlent*.052*TVD ProcJ.*X-sect, Area RECEIVED AUG I ~ !~2 ~ ~, ~. ~' Al~sn~ u~l & Gas Cons. Commission Anchorage Casing Rated For; TMD -- Casing Wt (lb/f0 = Dead Wt In Air = Buoyancy = Tension (Joint Strength) = Design Factor 4900001b 9,338ft 26.O01D/[t 242788,01b 24907,51b 217880.51b .: ..... Casing Design 1 Cement Calculations BURST -M!nimum.Des_[gp~actor = 1,1 Surface Casing: uurst = Maximum sar!ace pressure Casing Rated For= Max Shut-in Pres = Design Factor =1 12-Aug.g2 "1~1.6 @6I ..~ ProductiOn Casing: 1, Design Case ~ Tubing leak while well is SI Inside pres=Csg Fmc pres(3500 psi)~-Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.gppg *0.052*TVD) Net Pressure = Pressure lnslcle-Pressure outside Design Factor = Hating I Net Pressure Caaing Rated For: Inside pressure Outside Pressure Net Pressure Design Factor 4980 psi 6799 psi 2936 psi 3863 psi ...... , , , COLLAPRE. Minimum Design Factor.=_1_ .~ Surface Ca~;Ing i, Worst Case ,. Lo~t c~rculation and casing pres?,ure ---. 0 2. External pressure =Mud Wt * 0.052 ' TVD Production Casing 1, Worst Case - Full eva~:uution of casing 2, Mucl weight On outside = Mu0 WI * 0.052 ' TVD CaGing Reted For= Mud Gradient -- Ext, Pres, ;~ Botlo;'r, = Interrlat Pressure = Design Fac!or =[ Casing Ratecl For: MU;I Graolent [] Ext. Pres, ~ Bottom = Internal Pressure = Design Factor =1 2090 p$1 0.520 Ib/ft 1433 psi 0 psi 1,sJ 432O pal 0.520 lO/It 3299 psi ..... _0 RECEIVED A~.~ska. Oil & Gas Cons. Commission Anchorage Casing Design / Cement Calculations 12-Aug-92 Surface Casing Choices OD ID Ib/ft Grade Metal X-Section g.{~2S 8.6Ol 47 L-e0 13,5724 ~q, if]. 9.625 8.835 40 L-~t0 I1,4538 sq,in, §.62.~ ~.r~?l 36 J-6~; !0,2545 sq.in, 10,750 9,950 45,5 J-55 13,0062 sq,in, Jt Strength Body Strength Coilapaa Buret l l~1000 lb 1006000 l0 4/'50 psi 6870 psi 979000 lb ~t~O~h Ih 3099 psi 5750 639000 lb 564000 lb ~020 psi 3520 psi Production Casing Choices (30 ID lb/It Gratis Metal X-Section Jt Strength 7.000 6.276 28 L-80 7.549t sq. in. 687000 lb 7,000 6.27~ 2B J-55 7.5491 Sq, i~,. 4YUUO~J lb Body Strength C~lap,e Bur~ 604000 lb 6410 psi 7240 415000 lb 4320 ps1 4980 AUG .~r,~ 0[~ & ~as Oons. Commissio~ Anchorage Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids DRILLING Well Io5/¥" Spud surface casin~l 9.0-10.0 15-25 15-35 50-120' 5-15 15-40 10-12 9-10 10% + FLUID PROGRAM 2M-30 Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 8.5-9 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD 10.0 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 <10-12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1632 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 2M-30 is proposed well 2M-31. As designed, the minimum distance between the two wells would be 15' @ 400' MD. The wells would diverge from that point. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds. Adjust FV to 50-80 sec/qt below gravel beds. , , 7 6 5 4 I I L_ 13 5/8" 5000 BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2_ ASSURE THAT ACCUMULATOR PRESSURE IS 3(X:X) PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. ;~ OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2_ CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE UNE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE UNES. 7. TEST TO 250 PSI AND 3(:X)O PSI AS IN STEP 4. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY & CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTFOM 9. RAMS TO 250 PSI AND 3000 PSI. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. 10 CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD 11. AND 12_ LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE 13. DRILLING POSITION. TEST STANDPIPE VALVES TO 3(:X:)O PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16' -2000 PSI STARTING HEAD 2- 11' - 3000 PSI CASING HEAD 3. 11' - 3000 PSI X 13-5/8' - 5(:X:)0 PSI SPACER SPOOL 4. 13-,5/8' - 5000 PSI PIPE RAMS 5. 13-5/8' -5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8' - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8' - 5000 PSI ANNULAR K PARUK RIVER UNI1 20" DIVERTER SCHEMATIC i I J 5 f DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE 4. 20" - 2000 PSi DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 20" - 2000 PSI ANNULAR PREVENTER EDF 3/10/92 CASING A~O TUBING 0E$iGN WELL CASING STRING 80ROLGH STATE DATE )frO GR. I .,.~j~osi/rt. MUD WT. Ii 0/a. HYO. GR. II osi/ft. CASi)~ SiZE INTF. RVAL Bottom Too C~CIIIPTION LENGTH Wt. Graae Thread WEI~gT TENSION M INIHJM BF -too o~ STRE~NGTH BF..~ secC£on TENSION lbs COLLAPSE I. Z5' PP~.SS. ~ bottom T0F osi ,, 7.:' Z3'~- , e7 $¥ CO. LAPSE INTERNAL RESIST. 1.1~,5' BURST MINIMUM I.~ tension F~F_SSURE YIELD osl COF os! osi BOF Iq,3& ~.'-/4, 7 ~. / ~' i, 7 · .. ,i ** CHECK LIST FOR NEW WELL PERMITS ** ]:TEN APPROVE DATE (2) Loc'[~'2%l~A~/e/hru 8] (3) Admin 7/~(_ (4) Cas9 (5) BOPE [9 thru 13] [10 & 13] [14 thru 22] [23 thru 28] · 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Company /~'~ ~,2, , , Lease & Well NO YES Is permit fee attached ............................................... Is well to be located in a defined pool .............................. Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... Is sufficient undedicated acreage available in this pool ............. Is well to be deviated & is wellbore plat included ................... Is operator the only affected party .................................. L Can permit be approved before 15-day wait ............................ Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease ncrnber appropriate .......................................... Does well have a unique name & n~mber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface $ intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. ~-~ Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... ~. Are necessary diagrams & descriptions of diverter & BOPE at~ached .... Does BOPE have sufficient pressure rating -- test to ~O~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... REMARKS (6) Other '[29 thru 31'] (7) Contact ~32] ~.' (8) Add__.!.l ,,~', ~ ~'/~'~.' 29. 30. 31. 32. 33. FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone nLrnber of contact to supply weekly progress data ...... Additional requirements ............................................. n, / / geology' engineering: .... BEW JDH '/_~ INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE Additional remarks' rev 08/03/92 jo/6.011 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. ****************************** ****************************** I~LD 'iNAnE ~ ~UPAR.~ RIVE~R UNiT STATE : Ab~S~A REFERENC~ NU ~ 92528 RECEIVED ~OV 0 Z 199Z 'N~,II~ OIt & G~s ODDS. CommissiQn Anchorage ,~s T~e Ver~lC~tto~ List~n~ .cblu~ber~er Alaska Co~Duti..~ Center 19-$EP-19q2 12:17 SERVICE ~E : ~EE!., ~AME : 9~528 CONTINUATION # : P~vIOUS ~EEL COMMENT : ARC!3 ALASKA, INC,,KUPAR[JK RIVER UN!T,2M-30,50-i03-20180-O0 **$* TAPE HE,DER **** SERVICE NA~ : DaT~ : 92/0qt19 O~!ClN : FLIC TAP~ NA~E : ~2598 CONTINUATION # : PREVIOUS TAPE : CO~ENT TAP~ HEADER KUPARUK RIVER UNIT # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: T&P~ CREATION DATE: JOB DATA JOB LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION ~ECTIUN:. TOWNSHIP: ~ANGE: FNL: FEb: FWL: ~LEVATION(FT FROM ~$5 O) KELLY BUSHING: D~RRIf~ FLOOR: WELL CASING RECORD BIT RU~ 925~ PERRY ~ORPiSON ~ST STRING ~ND STRING 50~032018000 ARCO AbASK. A liNC. SCHbu~.~:BEDG~R WELL SERVICES 19-8EP-99 BiT RUN 2 BIT RU~ 3 2~ 114 66 !46.00 146,00 105.00 !.2,250 9.625 34~7.0 PAGE: ,~i[S Tape verif~.cati, om Listlnc~ ;chlumber~er AlasKa Co~putin~ Cemter )o-SEp-! 9q2 ~2:17 STRING P~ODUCTION STRING ~!T TO RES. 65 3' BIT TO GR 75 7: ~IT TO ~EN, ~,3~'5~ git TO NEUT:x3~ 7 ~ATRIX DENSITY ~,65 (G/CC) SAwD, FLUID DENSITY ~.0 (G.CC), RES SA~PI..E RATE : 20.SEC, DEN, /~EUT. sa~gPbM REATE : lO:SEC, ROT~TIONAL BULK DENSITY PROCESSING USED, BARITE ADDED TO ~UD SYSTE~, DUWNHOLM SOFTW~RE: V4.0C S PAGE: **** FILE HEADER **** FILM NAUE : EDIT ,001 SERVICE : FLIC VERSION ~ O0~A06 DAT~ : 9~/09/~.9 ~.aX REC SIZE : 10~4 FILE TYPE : LO L~ST FILE t FIL~ HEADER DeDthsh!fted add C,l~DPed curves~ all bit rubs merged, DEPTH INCRE,ENT 0.5000 FIL~ 8[)~MA. RY PBU TOOL CODE START DEPTH STOP DEPTH ~49~,0 9350,0 BASMLIN~ CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) ----------EQUIVALENT UNSHIFTED DEPTH---------- BASELINE DEPTH MWD ;;;;;T;'""" ~!740 9014.5 9019.5 9oo .s 8997,0 900~.0 8~9~,0 8986.0 !M Tar~. Verif!c~tJ. on Llst:inQ ch!umberqer AlasKa Co.m. put:ino Cemter 93~i0 ~8~9'0 ~7~.4 5 ~72! 5 ~657~0 8~45 0 8625.0 8588.5 8569,0 8562°0 8545,0 8514,5 8476 0 8387 0 ~343i5 8306 0 8267,5 229,0 204~5 8135o0 ~079'5 ~069,0 8051,~ 8026. 7967.. 7945.5 7932'5 7894 5 777.., 7653 0 7583 5 7446:0 7260 5 7139 5 7I!6 0 7O50 5 685P,0 6778,5 6739.5 6722,0 6666,S ~043,0 8886.5 8867.0 8822,0 8n03,5 8787.5 8727,5 8724,5 8669,5 8648,0 8637.5 8628.5 8592.0 857~.5 8565.0 8549.0 85!6,0 8479.5 8421.0 8390.5 8347.0 ~31~,0 ~27..5 8230.5 ~206.0 8136.5 8079.5 8073.5 8068.0 ~054.5 8029.5 8012.5 7970,0 7948.5 7937.0 7899.5 7867.0 7821 0 7775:0 7657~0 7633.0 7587,0 7449,0 7345,5 7279.5 726~.0 7142,5 71~8.0 7053.0 6860,0 6780,5 6742.0 6726.0 6690.5 6666,5 !,2:!7 Tame Verificat!on Llst:ino ~chlumberqer alaska ComputtnO Center 19-S~,:P-.!, 992 12:1.7 6610.5 6581.0 6520.0 6495,0 6423.5 6384.0 6352.5 63t2.5 6~97,0 1.00,0 MER~ED DATA SOURCE PBU TOO[., CODE $ 6610.5 6580.5 6520.0 6494.0 64~2.0 63~3.0 6349.5 6311.0 6294.0 97.0 ..... T TO CASE[) HOLE GR THE DEPTH SHIFTS ABOVE REFLEC. ~D G~.~ . FPOM CET/CBT RAN OM 26-A~G-92, ALL OTHER CURVES $ # LIS FORMAT .~ATA PAGE: ** DATA FORMAT SPECIF!CAT'IOM ~ECORo ** ** oE'.. TYPE - 64~5B ** TYPE 1 66 0 2 66 0 3 73 40 4 66 5 66 6 73 7 65 8 6~ 0,5 11 66 25 1~ 68 13 66 0 I4 65 FT 15 66 68 ~6 66 0 66 0 ~,IS Tame veriflcat!on ;ch u~b~raer A1 k.. Co .... C t 1 ....... ,, as a mputina en er 19-$EP-1992 12117 ** SET TYPE - CH~N ** .:................. .... ...........,........,,-..,,. .... ...... ....... ... .... ............ AH~ S~RV IIN!T SER¥ICF AP1 A.P~~A~API a FI Ntlg~ NUmB $IZ~ ~P~ PROCESS ID O~DE~ ~ bOG TYPE CLASS MOD NUMB SA~P gbEg CODE CHEX) D~D? FT 548241 O0 000 O0 0 I 1 ! 4 68 0000000000 R~OB MWD G/C3 548241 O0 000 O0 0 ~ I 1 4 6~ 0000000000 D~HO MWD G/C3 5482~1 O0 000 O0 0 1 ! l 4 68 0000000000 P~? ,WP BN/E 548~4! O0 000 O0 0 1 1 ! 4 68 O000000000 CaLM ~WD IN 54~24~ O0 000 O0 0 ! 1 I 4 6~ 0000000000 NON! ~WD PU-S 548241 O0 000 O0 0 1 ! ! 4 68 0000000000 Ra ~WD OHMM 548241 O0 000 O0 0 1 1 ! 4 68 0000000000 ~P ~WD DH~ 5~241 O0 000 O0 0 1 1 1 4 6~ 0000000000 ~OP ~WD F/H~ 548241 OO 000 O0 0 ! 1 ! 4 68 0000000000 GR ~WD GAPI 54~24! O0 000 O0 0 ! 1 1 4 6~ 0000000000 ** DaTa ** DEPT. 9350.000 CALN.MWD -999.250 ~nP.,WD 151.269 DEPT. 9000'000 CALN.MwD 8.908 ROP.MWD 75.950 DEPT. 8500.000 DEPT. 8000.000 ROP.MWD 277.594 DEPT. 7500.000 ROP.aWD 335.i. 47 DE~T. 7000.:000 CaLN.~WD ~.663 ROP.MWD 589.793 DMPT, 6500,000 C.aLN, ~w[> 8.504 P{)P i ~WD 486.051 DMPT. 6000.000 CALN.MWD 8.569 ~OP,MWD 172.677 RHOB.MWD -999,950 DRHO. ~'4WD -999'250 PEF,MWD MPHI.~WD ~999.~250 RA.MWD -999.~50 RP ~R, MWD 999,... 50 HOB. I~WD 2.30~ DRHO.MWD 0 053 DEF.~WD GR.~WD 37.8 0 DHO.B.~4WD '2 582 DRH[] MWD 0.012 PEF.~WD 2.400 , ~W[) 85.596 NPH!.~wD 3~1 0 RA.'MWD 4.0~6 RP.MWD ' CR', wD lo NPHI.~wD 38.800 RA:~WD 3~483 RP,MWD GR. MWD 74. 129 RHOB.~WD 2.126 DRH ~!D:H'I ~WD 51.800 RA'MWD 1 452 RP.~WD ' G~'NWD ~20.414 ~ ..... . -999.250 -999.250 3.279 26.745 4.091 3,700 2,228 3,~20 3, 97 2,660 3,252 2:,52~ 1,096 2,564 2.684 Verification Listlno ~cblumber~er Alaska Computing Center DE;PT. 5500,000 PHOS,~WD CAI,,M.MWD 8.500 NPNI.MWQ ~OP.~WD 554,573 GR,~WD D~PT, 5000.000 CALN.MWD S,5~9 NP~I.~WD POP,~WD 435,4~4 CaLN.~WD 8.542 NPHI,~WD ~O~.MWD 27],0~5 GR,MWD D~PT. 4000.000 RNOB.~WD C&LN,~WD 8.500 NPHI,MWD ~OD,MWD 549,47! GR.MWO DEPT. 3500,000 RgO%.MWD C~&LN,~D 9.575 NPHI.~WD ~OP,~WD -999,250 GR,~WD DEPT, 349~,000 C.~LN,~WD 9,655 NPHI,MWD ROP,~WD -999,250 END OF D~TA 19-SEP-199P 12:17 34:000 2.27P 36,900 2,207 DRHO,NWD 42,000 P~,M~D 92,!64 2,089 DRHO,MwD 47,699 RA,MWD 7A.656 1.989 DRMO.MWD 52 600 ~A.,4WO 70:564 2, I, 50 DRHO, 4:~o400 R~,!qwD 71,8!6 -0.007 3.609 -0.008 3,611 -0.014 2.670 -0,024 3,089 -0.032 4,588 0.008 4.579 PEF.MWD ~P.~WD PEF.MWD RP.~WD PEE.MWD PEF.~WD ~P.NWD PEF.~WD ~P.~WD PAGE: 2,801 3,559 2,937 3,342 2,R64 2.805 2,382 2,939 2.238 4,083 3,06~ 4,091 **** FILE TRAILER **~* FILE NAME ~ EDIT ,001 SERVICE : FhIC VERSION : O0iA06 DAT~ : 9~/09/~9 ~AX RFC SIZE ~ 10~4 ' FIL~ TYPE : LO **** F~LE HEADER **** FILE NAME I EDIT ,002 SERVICE ~ FL!C V~RSION : O0~A06 DAT~ : 9~/09/!9 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER 2 Curves amd Io~ header data for each bit run ~,n seDaratel fileS, .~'[S Ta~e Veri. flcatlon Ll, stino ;chlUmLeroer Alaska Comuutlno Center PAGE: DEPTH IUC~EME~T: # CD~ LOG HEADER DATA DATE LOGGED: ~OFTWA~E 1 0.5OOO TOO STADT DEPTH ~26a.o 3268.0 SURFACE $OFTWAR~ VERSION: DOWNHOL~ SOFTWARE VERSION~ DATA TYPF (~ODY OR PEAL-TI~E): TD DRILLER (FT): ~D LOGGE~(FT): TOP ~OTTOM bOG INTERVAL (FT)' ~IT ~OTATIONAI, SPE~D ~OLE INCLINATION (DFC) STRING (TOP TO EVDO~ TOOL CODF ............. L ¥ C $ ENO OPE TOOL TYPE R:~SI'STIVI,.:Y NE[.IT~ON DENSITY STOP ";';7"", . 92!8.0 AND CASING DATA MOLE BIT SIZE (IN)~T( I,I,,~RS CASING DEPTH ~ .... ): CONDITIONS EN$!TY (LB/G): !SCOSITY rS): b!LOR l bOSS ( C U~ RECO~ TIVITY ( AT MEA AT MAX FILT~A CAKE A NEUTRON MATmI 3.: DED TEMPERATURE OH~) aT TEmPErATURE (DEGF): SU~E[) TEmPErATURE (~T) CIRCULATING T~PERATU~E: TE AT T (~T): TOOL X DENSITY{ CORRECTION 26-.~{JG-92 FAST V4.OC M~TMO~Y 9350.0 9350 0 9350,0 TOOL RGS022 NOS014 1, 2,25 '34 ,~ 7.0 BRINE 1o.10 139.0 3,980 1,890 68.0 68,0 SANDSTONE 2.65 8,500 ,IS Tame Verification Listinq ~chlumherqer AlasKa Computlno Center 19-$E~-!992 12:17 PEMARKS: FIELD ENGINEER'S REMARKS: BIT TO RES. 65 3' BIT TO GR 75,7' ~T TO O~N 1~ 5~ ~TT TO NE.~. ~ 7 ~AT~!× DENSITY 2.65 (G/CC) SA~D. FLI)!D DUNSITY 1.0 (G.CC). DEN. /.~,~!.JT. ~A~PLE ~E~T = 30 ~C ~OT~TIO~AL ~gb~ DENSITY PPOCE$$ING USFD BARI~ A6OE~ ~0 ~UD sYSTE~. S LIS FORMAT DATA PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 645B ** ~YPE REP~ CODE VALIIE I 66 0 2 66 0 3 73 44 4 66 5 66 6 73 7 65 8 68 0,5 9 65 FI !~ 66 0 14 ~5 MT 15 66 68 I6 66 0 66 ** SET WYPE - C~AM ** ID ORDER # LOG TYPE CbhSS ~OD NUMB $.h~P ELE~ CODE (HEX) DFPT PT ~4824! O0 000 O0 0 2 1 ! 4 68 RMOB bWO G/C3 54~24! O0 000 O0 0 2 !. 1 4 68 D~MO LWD G/C3 54~41 O0 000 O0 0 ~ ! 1 4 68 PE? LWD 548241 O0 000 O0 0 2 ~.. I 4 68 DCAL bWD IN 549241 O0 000 O0 0 2 1 1 .4 68 D~HI LWD PU 548241 O0 000 O0 0 ~ I ! 4 68 TMPM LWD PU 5'!~,!l O0 000 O0 0 2 1 1. 4 6~ 0000000000 0000000000 0000000000 0000000000 0000000o00 0000000000 .,IS Ta~e Veriftcatlon LtstinO ;chlumber~er Alaska Computing Center 19'-SgP-! 992 12:!,7 ID ORDER ~ LOG TYPE CLASS MOD MUiR $~P ELE~ CODE (HEX) .... ...... ' .... " ........ ' ........... :"'"";"'"'"'"""""""""""" PS~ LWD UNM~ S4824! O0 000 O0 0 2 I 1 4 68 0000000000 ~Op~ b~ F/~R ~4824! O0 000 O0 0 2 ! ! 4 68 0000000000 G~ bWP GAP! 5¢~24~ 00 000 00 0 2 ~ 1 4 68 0~00000000 D~PT. ~350.500 PHOB LWD 2999 ~50 DRHO.L~D -999 250 PEF.LWD DCAL. LWD 1999'250 DPHI~LWD 999~ ..50 T~.~PH. bWD -999~250 ATR.LWD ~S~.L~D -99~.~50 ~OPE. I..WD J48.765 ~.LWD -999.250 DFPT 90OO.000 R~OB LWD ~ 278 DRHO,LWD 0.O31 PKF.LWD DCAL~LWD 0.394 DpHI:LWD 0~226 TNPH.LWD 30,300 ATR.LWD DS~.LWD ~7.873 ~OPE.LWD 84.906 GR.LWD 40.703 DEPT ~500.0OO RHnB.[.WD 2 583 D~O I, WD 0,023 PEF.LWD DCAT :LWD 0,46~ DP~I' !~WD 0:040 TNPH:LWD 33.600 ATR.LWD PS~.LWD ],5~7 ROPE.LWD 49.315 GR.GwD 90.04! DC~.~.:LWD 0,064 DPNI.LWD 0,2:'18 T~PH,LWD ~, I00 ATR,bWD DFPT 7500,000 R~{OB.LWD ~.500 DRHO,LWD 0.008 PEF.L. WD DCALiLWD 0.3!8 DPHI,LWD 0,09i T~4PH, LWD 35'500 ATR.LWD PBR LWD ~979 ~OPK bWO 3!9 ]57 GR ~WO !11,544 DEPT. 7000 000 RNOB.LWD 2 438 ~RHO bWD 0.054 PEF.LWD D~.AL.LWD '0:328 OPHI,LWD 0:128 ..~PH:LWD 40.600 ~TRiI,,WD .. ~ , ~ : ~ '~ · * . .. PSR LWD 3 874 RCPE,LWD 580 004 GR,LwD 69.559 DFPT. 6500,000 R~OB.LWD 2,~63 DRHO BWD 0.003 PEF.LWD DCAL,LWD 0.059 DPHI.LWD 0.295 TMPH: [,W~D 5!.800 ATR"LWD PSR.LWD i.117 ~OPE.LWD 484.908 GR.bWO 1!8'047 DKPT' 6000.000 R~{Og. LWD :2.468 DRM(], LWD ~ 05! PEF'LWD DCAL. LWD 0.!53 DPHI,LWD 0.~10 TNPH. LWD 3:600 ATR. LW'D PSP.LWD 2,458 ROPE.LWD 500,765 GR,LWD 52'158 DEPT, 5500.000 ~}{OB,LWD 2.2~6 DRH'O. bWO 0.00.] PEF:. L~D bCAL.LWD 0,0OO DPMI.LWD 0.~.~1 TNPg,LWD 36.~00 ATRiLWD PS~.LWD 3,709 ROPE. LWD 585.559 DFPT, 5000.000 ~{~:B, LWD 2,269 D~HO.LWD -0 011 PEF.LWD DCAL,L~D 0,073 DP~ I, !.~Wl:~ 0.231 T~P~,LWD 37:800 AT~,LWD ~S~.LWD 3,253 ROPE.LWD 406.~60 GR,LWD 84,610 -999 250 2.934 19.796 :298 2642 3.',261 4,194 I, 09 4.374 2,055 2,887 3,850 2.900 ~.496 ,lq Taoe Verification L!sti.o ,chlUmberoer AlasKa Comeuti,~ Center D~PT, 4500. 000 DC.a!.,.[~O 0 O49 O~PT. 4000.000 R,nS.~w~ OCAL.t, wD 0.2~0 DP~I ~'S~.bwD ~.4-72 D~PT. 3500.000 RHOB.LWD DCAL.LWD !.1]4 DP~I,LWD PS~.L~'D a.!55 ROPE.LWD DCAL,LWD -999 ~50 DPHI,LWD PSR,LWD -999:~50 ~OpE.LWD END OF DATA ** ] q-Sf:P-1992 12:!7 2.235 D~HO.LWD -0.006 0.252 TNPH.GWD 477.600 G~.LWD 96.821 2.230 D~HO.LwQ 0.009 0.254 T~P~{.LWD 47.800 529,593 G~.LWD 82.006 1.994 DRMO.LWD -0.042 0.404 TNPg. LWD 53.500 -999.250 G~.LWD 68.793 -999.250 DRWO.LWO -999.250 -999.250 TNP~.LW~ -999 250 -999.~50 GR.LWD -999~250 PEF.I.,~D ~TR.LWD PEF.LWD ATR.LWD PEF.LWD ATR.LWD PEF.LWD ATR.LWD PAGE: 2.875 2.738 2.759 3,135 2.241 4.479 -999,250 -999,250 **** FILE TRAILER **** FIL~ MA~E : EDIT .002 S~VICE : VERSION : O0!A06 DAT~ : 92/09/19 ~X REC SIZ~ : 1024 F!L~ TYP~ : LO LAST FILE **** TAPE TRAILER **** SERVICE NA~ : EDIT DATE : 92/09/19 O~IGIN ~ wLIC T~P~ NAME · : 92528 CONTINUATIO~ ~ : ! PREVIOUS TAPE COMMENT : ARCO' ALASKA, INC,,KUPARUK RIVER **** REEL TRAILER **** SERVICE NAMM : EDIT DATE : 92/09/19 ORIGIN : FLIC R~EL NAME : 92528 CONTINUATION ~ ~ CO~ENT : ARCO ALASKA, INC.,KUPARU~ RIVER UNIT,2~-30,50-!03'~O180'O0
