Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
190-116
TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 3G-10 50-103-20134-00 190084_3G-10_IPROF_08Jan2023 3G-13 50-103-20137-00 190116_3G-13_Puncher_03Oct2022 3G-20 50-103-20141-00 190123_3G-20_IPROF_28Apr2022 3H-35 50-103-20805-00 219064_3H-35_IPROF_03Aug2023 3I-11A 50-029-21932-01 210074_3I-11A_SBHPS-PLUG_25Jul2023 3M-05 50-029-21706-00 187025_3M-05_TBG_09Jan2022 3O-04 50-029-21826-00 188062_3O-04_CBL Post BiSN_24Aug2023 188062_3O-04_LDL_04Jan2022 3O-06 50-029-21824-00 188060_3O-06_CBL Pre-BiSN_24Aug23 3R-18 50-029-22249-00 192017_3R-18_LDL_21Feb2022 192017_3R-18_PressTemp_22Mar2022 3S-03 50-103-20458-00 203091_3S-03_IBC-CBL_04Sep2023 203091_3S-03_MechCut_14Jul2023 9of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38395 T38396 T38397 T38398 T38399 T38400 T38401 T38402 T38403 T38404 2/29/2024 3G-13 50-103-20137-00 190116_3G-13_Puncher_03Oct2022 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 12:12:37 -09'00' 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:17. Field / Pool(s): GL: 0.0 BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: GR/Res 23. BOTTOM 16" H-40 115' 9-5/8" J-55 3199' 7" J-55 6051' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate 9301' SIZE DEPTH SET (MD) 35' 62.58# 36# 115' 35' Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 8865-9095' MD 5 bbl 16.5# neat, 20 bbl 16.5# w/ 1.5 PPG Cement, 5 bbl 16.5# neat Water-Bbl: PRODUCTION TEST INJECTOR Date of Test: Oil-Bbl: Flow Tubing PLUGGED BACK All Perforations are cemented. 8966-9030' MD and 5841-5879' TVD (cemented) 9048-9088' MD and 5890-5915' TVD (cemented) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information 8862' MD/ 5779' TVD PACKER SET (MD/TVD) 24" 12-1/4" 200 sx AS I 35'920 sx AS III, 590 sx Class G 36' 4266'35' 36' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 26# WT. PER FT.GRADE 9/26/1990 CEMENTING RECORD 5983724 SETTING DEPTH TVD 5983509 TOP HOLE SIZE AMOUNT PULLED 494532 494363 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A 9. Ref Elevations: KB: 90' BOTTOM Kuparuk River Field/ Kuparuk River Oil Pool 1806' MD/1732' TVD 50-103-20137-00-00 KRU 3G-13 ADL0025548/ ADL0025547 2538' FNL, 5' FWL, Sec. 24, T12N, R8E, UM 2312' FNL, 1260' FWL, Sec. 26, T12N, R8E, UM ALK 2662 9/21/1990 9320' MD/ 6063' TVD 8865' MD/ 5781' TVD P.O. Box 100360, Anchorage, AK 99510-0360 498385 5988560 2097' FNL, 1429' FWL, Sec. 26, T12N, R8E, UM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 11/4/2022 190-116/ 322-265 ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 200 sx Class G8-1/2" 8875' MD/ 5787' TVD 8894' MD3-1/2" CASING Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment RECEIVED by James Brooks on 12/5/2022 at 1:20 PM Abandoned 11/4/2022 JSB RBDMS JSB 121422 xG 10/22/22 DSR WCB - 2023-07-14 Aband. DSR-1/3/23 Permit to Drill Number / Sundry: 190-116/ 322-265 KRU 3G-13 10/22/22 Abandoned Kuparuk River Field/ Kuparuk River Oil Pool Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1611' 1611' Top of Productive Interval N/A N/A N/A N/A N/A 31. List of Attachments: Schematics, Summary of Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Elliott Tuttle Digital Signature with Date:Contact Email: elliott.tuttle@conocophillips.com Contact Phone: (907) 263-4742 Senior RWO/CTD Engineer General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Authorized Title: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. TPI (Top of Producing Interval). Authorized Name and Formation Name at TD: INSTRUCTIONS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Elliott Tuttle DN: C=US, OU=CTD/ RWO Drilling Engineer, O="Conoco Phillips, Inc", CN=Elliott Tuttle, E= elliott.tuttle@conocophillips.com Reason: I am approving this document Location: Date: 2022.12.05 13:12:59-09'00' Foxit PDF Editor Version: 12.0.1 Elliott Tuttle 3G - 1 3 P r o p o s e d C T D S c h e m a t i c 9- 5 / 8 " 3 6 # J - 5 5 s h o e @ 4 2 6 6 ' M D 7" 2 6 # J - 5 5 s h o e @ 93 0 1 ' M D 16 " 6 2 # H - 4 0 sh o e @ 1 1 5 ' M D C- s a n d p e r f s 89 6 6 ' - 9 0 3 0 ' M D A- s a n d p e r f s 90 4 8 ' - 9 0 8 8 ' M D KO P @ 9 0 3 9 ' M D CP H D e p t h @ 9 1 0 6 ' 3- 1 / 2 " C a m c o S S S V a t 1 8 0 6 ' M D ( l o c k e d o u t - 9 / 1 9 / 9 8 ) 3- 1 / 2 " 9 . 3 # J - 5 5 E U E 8 r d T u b i n g t o s u r f a c e 3- 1 / 2 " M e r l a g a s l i f t m a n d r e l a t 2 6 6 8 ' , 4 7 8 1 ' , 5 8 5 4 ' , 7 0 1 7 ' , 79 3 1 ' 3- 1 / 2 " C a m c o g a s l i f t m a n d r e l a t 8 7 9 2 ' Ca m c o P B R a t 8 8 4 9 ' M D Ca m c o H R P - 1 - S P p a c k e r a t 8 8 6 2 ' M D D- n i p p l e a t 8 8 8 6 ' ' M D ( Mi l l e d t o 2 . 8 0 " ) 3- 1 / 2 " t u b i n g t a i l a t 8 8 9 4 ' M D NS A K L T P @ 8 8 7 5 ' R K B ( 1 . 7 8 " I D R N i p p l e ) 3G - 1 3 A w p 0 4 N o r t h TD @ 1 2 , 3 5 1 ' M D Li n e r B i l l e t @ 9 , 1 4 4 ' M D 3G - 1 3 A L 1 wp 0 3 TD @ 1 1 , 0 4 7 ' M D To p o f L i n e r 8 8 8 1 ' M D w / Sw e l l p a c k e r @ 9 1 1 8 ' Mo d i f i e d b y : E l l i o t t T u t t l e 11 / 2 9 / 2 0 2 2 - F I N A L Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 9,055.0 3G-13 4/22/2022 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Liner Top Packer 3G-13 11/10/2022 zembaej General Notes: Last 3 entries Com Date Last Mod By Tag @ 8992'' appears to be cement 9/21/1998 Admin 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 36.0 115.0 115.0 62.58 H-40 WELDED SURFACE 9 5/8 8.92 35.0 4,265.8 3,198.8 36.00 J-55 BTC PRODUCTION 7 6.28 35.0 9,301.2 6,051.3 26.00 J-55 BTC AB-MOD Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 31.4 Set Depth … 8,894.3 Set Depth … 5,798.0 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE-MOD 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) 31.4 31.4 0.08 HANGER 8.000 WKM GEN IV HANGER 3.500 1,805.8 1,732.2 39.14 SAFETY VLV 5.937 CAMCO TRDP-1A-SSA SAFETY VALVE locked out 9/19/98. Control line not shifted open, no control/tubing communication. 2.812 2,668.1 2,296.3 54.83 GAS LIFT 5.620 MERLA TMPD 2.875 4,780.5 3,499.9 54.68 GAS LIFT 5.620 MERLA TMPD 2.875 5,853.8 4,102.6 56.09 GAS LIFT 5.620 MERLA TMPD 2.875 7,016.8 4,747.3 57.77 GAS LIFT 5.620 MERLA TMPD 2.875 7,930.6 5,242.2 54.66 GAS LIFT 5.620 MERLA TMPD 2.875 8,792.0 5,739.0 55.50 GAS LIFT 5.750 CAMCO MMG-2 2.867 8,849.0 5,771.6 54.70 PBR 5.625 CAMCO 10' STROKE PBR 2.937 8,862.4 5,779.4 54.47 PACKER 5.937 CAMCO HRP-1-SP RETRIEVABLE PACKER 2.867 8,885.9 5,793.1 54.07 NIPPLE 4.540 CAMCO D NIPPLE NO GO/MILLED TO 2.80" 9/29/2022 2.800 8,893.6 5,797.6 53.94 SOS 4.500 BAKER SHEAR OUT SUB 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 8,875.0 5,786.7 54.26 PACKER Northern Solutions Liner Top Packer w/ 1.78" R-Nipple (10.92' OAL / 5.96' From top to R-nipple) Northern Solutions Mono- Pak LTP 11/10/2022 1.780 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,668.1 2,296.3 54.83 1 GAS LIFT DMY BK 1 0.0 1/15/1995 0.000 4,780.5 3,499.9 54.68 2 GAS LIFT DMY BK 1 0.0 1/6/1991 0.000 5,853.8 4,102.6 56.09 3 GAS LIFT DMY BK 1 0.0 1/15/1995 0.000 7,016.8 4,747.3 57.77 4 GAS LIFT DMY BK 1 0.0 1/15/1995 0.000 7,930.6 5,242.2 54.66 5 GAS LIFT DMY BK 1 0.0 1/15/1995 0.000 8,792.0 5,739.0 55.50 6 GAS LIFT DMY RK 1 1/2 0.0 1/15/1995 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,880.0 8,882.0 5,789.6 5,790.8 10/3/2022 CMT SQZ PUNCH IN 3-1/2" TUBING (PREP FOR CEMENT PILOT HOLE CTD SETUP) 8,966.0 9,000.0 5,840.7 5,861.1 C-4, 3G-13 8/12/1991 8.0 IPERF 2 1/8" Dyna Strip, 90 deg. phasing. Squeezed 8/19/98 9,000.0 9,030.0 5,861.1 5,879.3 C-4, A-3, 3G-13 8/12/1991 4.0 IPERF 2 1/8" Dyna Strip,0 deg. phasing. Squeezed 8/19/98 9,048.0 9,088.0 5,890.3 5,915.0 A-2, 3G-13 1/6/1991 4.0 IPERF 4 1/2" Expendable, 180 deg. phasing Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 8,865.0 9,095.0 5,780.9 5,919.3 Cement Squeeze 5 bbl 16.5# Neat 20 bbls 16.5# with 1.5 PPG Cemnet 5 bbls 16.5# Neat 10/4/2022 3G-13, 11/29/2022 11:52:03 AM Vertical schematic (actual) PRODUCTION; 35.0-9,301.2 AL1 Slotted Liner; 8,880.6- 11,047.0 IPERF; 9,048.0-9,088.0 IPERF; 9,000.0-9,030.0 IPERF; 8,966.0-9,000.0 Cement Squeeze; 8,865.0 ftKB CMT SQZ; 8,880.0-8,882.0 PACKER; 8,875.0 PACKER; 8,862.4 GAS LIFT; 8,792.0 GAS LIFT; 7,930.6 GAS LIFT; 7,016.8 GAS LIFT; 5,853.8 GAS LIFT; 4,780.5 SURFACE; 35.0-4,265.8 GAS LIFT; 2,668.1 SAFETY VLV; 1,805.7 CONDUCTOR; 36.0-115.0 Casing 1; 0.0 KUP INJ KB-Grd (ft) 36.78 RR Date 9/29/1990 Other Elev… 3G-13 ... TD Act Btm (ftKB) 9,320.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032013700 Wellbore Status INJ Max Angle & MD Incl (°) 58.82 MD (ftKB) 7,600.00 WELLNAME WELLBORE3G-13 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: LOCKED OUT General Notes: Last 3 entries Com Date Last Mod By Tag @ 8992'' appears to be cement 9/21/1998 Admin Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread A Lateral 2 3/8 1.99 9,150.5 12,351.0 4.60 L-80 STL 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) 90,838.0 WHIPSTOCK Baker WS tray over open hole anchors BOT na na 10/21/2022 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) 9,150.5 5,920.3 89.41 Aluminum Billet 2.630 Liner top billet BOT Billet 1.920 10,324.6 5,894.3 90.48 Deployment Sleeve 2.375 Shorty Deployment sleeve Baker 1.920 11,342.2 5,909.1 89.25 Deployment Sleeve 2.375 Shorty Deployment sleeve Baker 1.920 3G-13A, 11/29/2022 11:52:04 AM Vertical schematic (actual) A Lateral; 9,150.4-12,351.0 PRODUCTION; 35.0-9,301.2 AL1 Slotted Liner; 8,880.6- 11,047.0 IPERF; 9,048.0-9,088.0 IPERF; 9,000.0-9,030.0 IPERF; 8,966.0-9,000.0 Cement Squeeze; 8,865.0 ftKB CMT SQZ; 8,880.0-8,882.0 PACKER; 8,875.0 PACKER; 8,862.4 GAS LIFT; 8,792.0 GAS LIFT; 7,930.6 GAS LIFT; 7,016.8 GAS LIFT; 5,853.8 GAS LIFT; 4,780.5 SURFACE; 35.0-4,265.8 GAS LIFT; 2,668.1 SAFETY VLV; 1,805.7 CONDUCTOR; 36.0-115.0 Casing 1; 0.0 KUP SVC KB-Grd (ft) 36.78 RR Date 9/29/1990 Other Elev… 3G-13A ... TD Act Btm (ftKB) 12,351.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032013701 Wellbore Status SVC Max Angle & MD Incl (°) 94.18 MD (ftKB) 9,851.67 WELLNAME WELLBORE3G-13 Annotation End DateH2S (ppm) DateComment General Notes: Last 3 entries Com Date Last Mod By Tag @ 8992'' appears to be cement 9/21/1998 Admin Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread AL1 Slotted Liner 2 3/8 1.99 8,880.6 11,047.0 5,886.3 4.70 L-80 ST-L 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) 8,880.6 5,790.0 54.16 NS 225 Deployment Sleeve SBR 2.700 NS 225 Deployment Sleeve SBR 1.901 9,112.2 5,916.2 77.81 Swell Packer 2.700 Swell Packer (TBD) Halliburto n Swell Pkr. 1.686 10,041.7 5,892.3 89.72 Deployment Sleeve 2.375 NS 350-270, OH QCLL Liner Latch Northern Solutions 1.920 3G-13AL1, 11/29/2022 11:52:04 AM Vertical schematic (actual) AL1 Slotted Liner; 8,880.6- 11,047.0 PRODUCTION; 35.0-9,301.2 IPERF; 9,048.0-9,088.0 IPERF; 9,000.0-9,030.0 IPERF; 8,966.0-9,000.0 Cement Squeeze; 8,865.0 ftKB CMT SQZ; 8,880.0-8,882.0 PACKER; 8,875.0 PACKER; 8,862.4 GAS LIFT; 8,792.0 GAS LIFT; 7,930.6 GAS LIFT; 7,016.8 GAS LIFT; 5,853.8 GAS LIFT; 4,780.5 SURFACE; 35.0-4,265.8 GAS LIFT; 2,668.1 SAFETY VLV; 1,805.7 CONDUCTOR; 36.0-115.0 Casing 1; 0.0 KUP SVC KB-Grd (ft) 36.78 RR Date 9/29/1990 Other Elev… 3G-13AL1 ... TD Act Btm (ftKB) 11,040.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032013760 Wellbore Status SVC Max Angle & MD Incl (°) 96.59 MD (ftKB) 9,620.64 WELLNAME WELLBORE3G-13 Annotation End DateH2S (ppm) DateComment Page 1/19 3G-13 Report Printed: 11/29/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/18/2022 00:00 10/18/2022 06:00 6.00 MIRU, MOVE RURD P Suck out stack, freeze protect tree, dissconnect PUTZ/Interconnect, secure pipeshed and INJH cart, secure pits 0.0 0.0 10/18/2022 06:00 10/18/2022 09:00 3.00 MIRU, MOVE RURD P Continue to work Pre-move check list, securing all landings, perform walkaround, pull all matting around rig. 0.0 0.0 10/18/2022 09:00 10/18/2022 10:00 1.00 MIRU, MOVE DMOB P Trucks on location, pull service module off well row, stage on pad and jeep up 0.0 0.0 10/18/2022 10:00 10/18/2022 11:45 1.75 MIRU, MOVE DMOB P pull sub offwell row, stage on pad and jeep up 0.0 0.0 10/18/2022 11:45 10/18/2022 17:00 5.25 MIRU, MOVE MOB P Move rig from 2T pad to 1G wide spot. Wait for CPF3/STP change out 0.0 0.0 10/18/2022 17:00 10/18/2022 18:00 1.00 MIRU, MOVE MOB P Wait for CPF3/STP change out 0.0 0.0 10/18/2022 18:00 10/18/2022 19:30 1.50 MIRU, MOVE MOB P Move from 1Q wide spot to 3B pad 0.0 0.0 10/18/2022 19:30 10/18/2022 20:00 0.50 MIRU, MOVE MOB P Wait for rig move crew change out, 10 min and impromptue Nabors meeting, 20 min. 0.0 0.0 10/18/2022 20:00 10/18/2022 21:00 1.00 MIRU, MOVE MOB P Move from 3B to 3g pad. 0.0 0.0 10/18/2022 21:00 10/18/2022 22:00 1.00 MIRU, MOVE RURD P Drop jeeps from sub and service modules, spot mats around wellhead to cover hole, spot rig mats for sub. 0.0 0.0 10/18/2022 22:00 10/18/2022 22:45 0.75 MIRU, MOVE RURD P Spot sub over 3G-13 0.0 0.0 10/18/2022 22:45 10/19/2022 00:00 1.25 MIRU, MOVE RURD P Spot inner mats and service module. 0.0 0.0 10/19/2022 00:00 10/19/2022 03:00 3.00 MIRU, MOVE RURD P Safe out stairs and walk ways post rig move. Work rig up checklist. 0.0 0.0 10/19/2022 03:00 10/19/2022 04:00 1.00 MIRU, WHDBOP NUND P PJSM. Nipple up BOP stack. **Rig accept @ 03:00 10-19-22 0.0 0.0 10/19/2022 04:00 10/19/2022 10:00 6.00 MIRU, WHDBOP RURD P Work through rig up check list. Ordered seawater and milling fluid trucks. Called out grease crew to service tree and tollhouse to RU tiger tank. Confirmed NSAK 2 3/8" motor and NOV 2.98" bi- center bit will be delivered this afternoon. 0.0 0.0 10/19/2022 10:00 10/19/2022 10:30 0.50 MIRU, WHDBOP CIRC P Greased valves, flood lines, and prep for BOP test. 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/4/2022 Page 2/19 3G-13 Report Printed: 11/29/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/19/2022 10:30 10/19/2022 18:30 8.00 MIRU, WHDBOP BOPE P BOP test. Witness waived by Brian Bixby - AOGCC. 250 / 4500 psi - 2500 psi for annular. Good shell test - 11:00. Test 1. Swab 2. Test 2. Blind/Shear, BOP TV2, Charlie 4, 5, 8, &12 Test 3. BOP TV 1, Charlie 3, 6, 7, & 11 Test 4. Manual choke D & Super choke C Test 5. Romeo 3, Bleeder 3, Tango 2, Charlie 2, & 10 Test 6. Charlie 1, 9, Tango 1 – install TIW test joint Test 7. Lower 2” pipe slip rams, upper, TIW #1, Romeo 1, Bleeder 1. Test 8. Annular BOP to 2,500 psi. Calibrated and tested gas detectors and alarms (H2S and LEL). Pass. Test 9. Upper 2” pipe slip rams, Bravo 6, & 8, lower TIW. Test 10. Bravo 7 &5, – swap out 2” test joint for 2 -3/8”. Test 11. 2-3/8” pipe slip rams, check N2 levels, swap to 2” test joint Test 12. Draw down accumulator. Koomy pressure, close all record stable pressure, time to increase 200 psi, entire recovery time Test 13. Stab injector and line up to reverse circulate coil, test inner reel valve and stripper. Verified flow alarms - PVT 0.0 0.0 10/19/2022 18:30 10/19/2022 20:00 1.50 MIRU, WHDBOP CTOP P Test PDL's and tiger tank line - good. Blow down test pump and well control choke. 0.0 0.0 10/19/2022 20:00 10/19/2022 20:45 0.75 SLOT, WELLPR CTOP P Prep and clean rig floor post BOPE test, valve check list, install night cap, pump open SSV and install fusible. Open swab and master, both grease locked - wellhead 0 psi. Pull nightcap and stab quick test sub. 0.0 0.0 10/19/2022 20:45 10/19/2022 22:30 1.75 SLOT, WELLPR PULD P PJSM, Pick up BHA #1, cement drilling / clean out assembly. straight motor with HYC 2.98 bi center bit. 0.0 76.5 10/19/2022 22:30 10/20/2022 00:00 1.50 SLOT, WELLPR TRIP P RIH with BHA #1, park shallow ~500 ' close EDC and shallow test motor, 967 psi free spin diff at 1.8 bpm. Continue in hole at min rate, park ~2000' open edc. Continue in hole 76.5 6,437.0 10/20/2022 00:00 10/20/2022 00:24 0.40 SLOT, WELLPR TRIP P Continue in hole 6,437.0 8,578.0 10/20/2022 00:24 10/20/2022 00:48 0.40 SLOT, WELLPR DLOG P Tie into the HRZ for a -6' correction 8,578.0 8,654.0 10/20/2022 00:48 10/20/2022 01:36 0.80 SLOT, WELLPR DISP P 8.5 ppg seawater in and out. Swap to power pro milling fluid and displace well bore at 2 bpm. Park and close EDC. 8,654.0 8,654.0 10/20/2022 01:36 10/20/2022 01:54 0.30 SLOT, WELLPR TRIP P PU Wt 45 k lbs, RIH @ min rate, tag cement at 8,778'. 8,654.0 8,778.0 10/20/2022 01:54 10/20/2022 05:30 3.60 SLOT, WELLPR MILL P PU and set rate, RIH and mill/drill cement in 3.5" tubing. WH 0 psi, IA 239 psi, OA 0 psi, CT 4,532 psi at 1.82 bpm in / out. Free spin diff 782 psi. BHP 3,254 psi. CT RIH wt 8.9 k lbs. Wash down to 8819' with little resistance - 60 + ft/hr, contaminated cement returns on the shaker. WOB increased after 8,820' to ~ 1 k and ROP 20-30 ft/hr, 8,840' WOB to 1.5 k @ 45 ft/min 950 psi differential. Milled down to D-nipple @ 8,886'. Saw PUW of 50K. 8,778.0 8,885.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/4/2022 Page 3/19 3G-13 Report Printed: 11/29/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/20/2022 05:30 10/20/2022 08:00 2.50 SLOT, WELLPR TRIP P PUH chasing sweeps. Park and open EDC, POOH @ 100 FPM pumping 2+ bpm. Jog coil from 500' to 1,000' to flush out cement debris. PUH to surface. Bump up. Perform no flow test. Pass. 8,885.0 0.0 10/20/2022 08:00 10/20/2022 08:30 0.50 SLOT, WELLPR PULD P LD BHA #1 over a dead well. Inspected Coil. Identified flat spot but nothing deep. 0.0 73.8 10/20/2022 08:30 10/20/2022 09:00 0.50 SLOT, WELLPR PULD P MU BHA #2, Baker 2 3/8" X-treme motor with 0.9 deg AKO and slick 2.80" D331 (2.80" go, 2.79" no-go) mill with up drill. Confirm HS scribe and measurement. MU and PT injector. Bump up. EDC open. * D331 mill go 2.80" no 2.79" 0.0 73.8 10/20/2022 09:00 10/20/2022 10:45 1.75 SLOT, WELLPR TRIP P RIH with BHA #2 to 600'. Close EDC to shallow test motor. 1.8 BPM, 3690 psi circ pressure, 469 psi differential pressure. Continue RIH pumping min rate @ 100 fpm slowing down when passing jewelry. 73.8 8,500.0 10/20/2022 10:45 10/20/2022 11:00 0.25 SLOT, WELLPR DLOG P Slow down to 5 FPM to tie into HRZ @ 8,575' for a -9.5' correction. Pumps online at 0.5 BPM and 1496 psi circ pressure. PUW 40K. 8,550.0 8,638.0 10/20/2022 11:00 10/20/2022 11:06 0.10 SLOT, WELLPR TRIP P RIH, dry tag TOC @ 8,886'. 1.9K WOB. BHP = 2467. WHP = 0 psi. IA = 262 psi. OA = 0 psi. PUW = 48K. 8,638.0 8,886.0 10/20/2022 11:06 10/20/2022 11:15 0.15 SLOT, WELLPR TRIP P PUH to 8864'. Pumps online @ 1.8 BPM. Circ pressure of 4,102 psi. 450 psi free spin differential pressure. 8,886.0 8,864.0 10/20/2022 11:15 10/20/2022 11:30 0.25 SLOT, WELLPR MILL P RIH to tag and begin milling @ 8,886'. Avg. ROP of 25 FPH. 811 psi differential pressure. 361 psi motor work. WHP = 0 psi, IA = 267 psi, OA = 0 psi. WOB = 1.97 Klbs. Mill oriented 20 deg ROHS. 8,886.0 8,891.0 10/20/2022 11:30 10/20/2022 11:50 0.34 SLOT, WELLPR MILL P Stalled motor @ 8,891'. PUW 44K. Back on bottom. 1.8 BPM/4068 psi. WOB = 1.8 Klbs. 310 psi motor work. Avg ROP of 20 FPH. 8,891.0 8,896.0 10/20/2022 11:50 10/20/2022 11:59 0.15 SLOT, WELLPR MILL P Stalled motor @ 8,896' . PUW 47K. BOB. 1.80 BPM / 4054 psi. 8,896.0 8,896.0 10/20/2022 11:59 10/20/2022 12:15 0.27 SLOT, WELLPR MILL P Stalled at same. PUW 50K. BOB. WHP = 0 psi, IA = 267 psi, OA = 0 psi. Stall at same. PUW 45K. BOB. Stall at same. PUW 46K. 8,896.0 8,896.0 10/20/2022 12:15 10/20/2022 12:30 0.25 SLOT, WELLPR MILL P Pump rate 1.8 BPM/4130 psi. Free spin differential 488 psi. BOB. Parked Coil at 8895.91' at first indications of motor work. Stalled motor @ 8896.3'. PUW 40K 8,896.0 8,896.0 10/20/2022 12:30 10/20/2022 12:45 0.25 SLOT, WELLPR MILL P BOB. Same pump rate. 725 psi differential pressure. Parked coil to mill off. Milled to 8896.4' and stalled again. Discussed with Town Engineer. Re- orient toolface 200 ROHS to attempt work past. 8,896.0 8,896.4 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/4/2022 Page 4/19 3G-13 Report Printed: 11/29/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/20/2022 12:45 10/20/2022 13:15 0.50 SLOT, WELLPR MILL P Discussed with Town Engineer. Re- orient mill 200 ROHS to work past stall depth. BOB. 1.81 BPM / 4153 psi. Slowly RIH to first indication of motor work. Park coil with 150 psi motor work to mill off. Slowly RIH at 5 FPH. Avg WOB of 1 K lbs. 310 psi motor work. Smoothed out. Mill to 8,900' and reorient back to 20 ROHS. 8,896.4 8,901.0 10/20/2022 13:15 10/20/2022 13:53 0.63 SLOT, WELLPR MILL P Re-orient mill back to 20 deg ROHS. Pump rate 1.8 BPM / 4383 psi. Avg WOB 1.7 K lbs. Avg ROP 19 FPH. 785 differential pressure. Milled to 8912' (26' of cement beyond D-nipple). 8,901.0 8,912.0 10/20/2022 13:53 10/20/2022 14:00 0.11 SLOT, WELLPR TRIP P PUW 41K. Wiper to 8,750' chasing gel sweep to lift cement debris from pilot hole. 8,912.0 8,750.0 10/20/2022 14:00 10/20/2022 14:06 0.10 SLOT, WELLPR TRIP P Wiper back down to 8,912' to continue milling pilot hole. 10K RIH weight. 8,750.0 8,912.0 10/20/2022 14:06 10/20/2022 15:30 1.40 SLOT, WELLPR MILL P BOB. WHP = 0 psi, IA = 308 psi, OA = 0 psi. Pump Rate 1.8 BPM / 4109 psi circ pressure. See motor work. 775 psi differential. Avg WOB = 1.2 Klbs. Avg ROP 20 FPH. Mill oriented 20 deg ROHS. WOB dropped to 1.0Klbs at 8,925'. Mill to 8,941' for next wiper. 8,912.0 8,941.0 10/20/2022 15:30 10/20/2022 15:45 0.25 SLOT, WELLPR TRIP P PUW 42K. Wiper to 8,750' chasing gel sweep to lift cement debris from pilot hole. Swap rig generators for oil change/maintenance schedule. 8,941.0 8,750.0 10/20/2022 15:45 10/20/2022 15:51 0.10 SLOT, WELLPR TRIP P Wiper back down to 8,941' to continue milling pilot hole. 10K RIH weight. Pump rate 1.85 BPM / 4275 psi. Free spin 511 psi. 8,750.0 8,941.0 10/20/2022 15:51 10/20/2022 17:36 1.75 SLOT, WELLPR MILL P BOB. WHP = 0 psi, IA = 321 psi, OA = 0 psi. See motor work. 303 psi differential. Avg WOB = 1.3 Klbs. Avg ROP 20 FPH. Mill oriented 20 deg ROHS. See higher vibrations at 8,943' (level 3 but short lived), reduced ROP, and increased differential. Wipe at 8,980'. Mill ahead, 9,055 stall, PU and restart. Mill ahead to 9,073' PU Wt 54 k lbs, RBIH and mill. 8,941.0 8,981.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/4/2022 Page 5/19 3G-13 Report Printed: 11/29/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/20/2022 17:36 10/21/2022 00:00 6.40 SLOT, WELLPR MILL P Pull short wiper, Mill ahead, 9,055 stall, PU and restart. Mill ahead to 9,073' PU Wt 54 k lbs, RBIH and mill. Wiper at 9,106 WOB bobbles at 8,986 and 8,893' both directions. Milll to 9,043, wipe, WOB bobbles again at 8,986 and 8,893' both directions. wipe at 9,072', same WOB bobles in both directions. 9,075' short void, 9,076' stall, PU Wt 55 k lbs. Void @ 9,077', ROP increased 60 ft/min with no to low WOB to stall at 9,089'. PU Wt 58 k lbs. Mill ahead, hard spot @ 9,093.5, WOB 2 k ROP 6 ft/hr. **Cement voids 9,074-9,076' and 9,077' - 9,089' 8,981.0 9,093.7 10/21/2022 00:00 10/21/2022 00:51 0.85 SLOT, WELLPR MILL P Continue to mill ahead, on hard spot @ 9,093.5, WOB 2 k ROP 5 ft/hr. WH 0 psi, IA 357 psi, OA 0 psi. 9,093.7 9,100.0 10/21/2022 00:51 10/21/2022 01:00 0.15 SLOT, WELLPR TRIP P PU Wt 60 k lbs, PUH 8,865.0 8,857.0 10/21/2022 01:00 10/21/2022 01:36 0.60 SLOT, WELLPR DLOG P Attempt to tie into the K1, missing ? PUH to 8,550' log HRZ for a +6' correction. 8,857.0 8,610.0 10/21/2022 01:36 10/21/2022 01:57 0.35 SLOT, WELLPR TRIP P Dry drift cement pilot hole. Clean with same WOB bobble that we have been seeing at 8,992'. 8,610.0 9,106.0 10/21/2022 01:57 10/21/2022 03:45 1.80 SLOT, WELLPR TRIP P PU Wt 60 k lbs, PUH above TOC, park and open EDC. POOH pumping 2 + bpm. 9,106.0 73.8 10/21/2022 03:45 10/21/2022 04:15 0.50 SLOT, WELLPR OWFF P Bump up, Flow check while holding PJSM, flow check - good. 73.8 73.8 10/21/2022 04:15 10/21/2022 05:15 1.00 SLOT, WELLPR PULD P LD BHA #2 over a dead well. ** Mill gauged out at 2.80" no , 2.79" go 73.8 0.0 10/21/2022 05:15 10/21/2022 05:45 0.50 SLOT, WELLPR CIRC P Install nozzle, stab injector, jet stack, MPD choke, and manifold 0.0 0.0 10/21/2022 05:45 10/21/2022 08:00 2.25 SLOT, WELLPR PULD P PU BHA#3, 24-arm caliper in memory mode below Coil Trak tools. PD required. Flow check post stack jetting indicated pressure build to 286 psi. Timer set to open caliper arms @ 12:15PM and close at 12:42PM. Bump up. EDC open. 0.0 58.9 10/21/2022 08:00 10/21/2022 10:00 2.00 SLOT, WELLPR TRIP P RIH with memory caliper to 8,546'. 58.9 8,546.0 10/21/2022 10:00 10/21/2022 10:20 0.34 SLOT, WELLPR DLOG P Tie into HRZ for a -8' correction. PU weight 44Klbs. CT down weight = 11K 8,546.0 8,627.0 10/21/2022 10:20 10/21/2022 10:38 0.30 SLOT, WELLPR TRIP P Continue to RIH to 9,100'. 8,627.0 9,100.0 10/21/2022 10:38 10/21/2022 12:15 1.62 SLOT, WELLPR WAIT P Park Coil and wait for caliper to open. 9,100.0 9,100.0 10/21/2022 12:15 10/21/2022 12:42 0.45 SLOT, WELLPR ELOG P Memory caliper arms open. Coil PU weight 52 K lbs. Pull caliper log at 50 fpm from 9,100 - 7815'. Calipers arms programmed to close at 12:42PM. Give BOT 2-hr callout for 3 1/2" XL whip stock. 9,100.0 7,815.0 10/21/2022 12:42 10/21/2022 14:15 1.54 SLOT, WELLPR TRIP P Arms closed. POOH with 24-arm caliper @ 100 fpm. At surface. Bump up. 250 psi WHP. 7,815.0 58.9 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/4/2022 Page 6/19 3G-13 Report Printed: 11/29/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/21/2022 14:15 10/21/2022 16:00 1.75 SLOT, WELLPR PULD P PUD BHA #3, 24-arm caliper. Download data. Confirmed good. Send to town for rush 3D processing. 58.9 0.0 10/21/2022 16:00 10/21/2022 17:12 1.20 PROD1, WHPST PULD P PU and PD BHA #4, Baker 3 1/2" whip stock tray with OH anchor (11.5'). 0.0 73.5 10/21/2022 17:12 10/21/2022 18:48 1.60 PROD1, WHPST WPST P RIH with WS 73.5 8,550.0 10/21/2022 18:48 10/21/2022 19:00 0.20 PROD1, WHPST DLOG P Tie into the HRZ for a -11' correction. 8,550.0 8,776.0 10/21/2022 19:00 10/21/2022 21:12 2.20 PROD1, WHPST WAIT P Wait on caliper processing 8,776.0 8,776.0 10/21/2022 21:12 10/21/2022 21:30 0.30 PROD1, WHPST WPST P S/I pumps, RIH to ,896' PU Wt 44 k lbs, bleed pump pressure, close EDC, RIH to setting depth of 9,049.5 PU slack to 40 k lbs, CT Wt 36.05 k lbs, Tray oriented HS. WOB 0.02 k lbs, roll pumps bore pressure to 5,083, WOB to 3.8 k lbs during shear. RIH slowly and stack weight on tray to 3.2 k lbs. - Good set 8,776.0 9,049.5 10/21/2022 21:30 10/21/2022 23:24 1.90 PROD1, WHPST TRIP P PU Wt 44 k lbs, PUH above pilot hole, open EDC, POOH 9,049.5 73.5 10/21/2022 23:24 10/22/2022 00:00 0.60 PROD1, WHPST PULD P PUD BHA #4- WS setting assembly 73.5 0.0 10/22/2022 00:00 10/22/2022 00:36 0.60 PROD1, WHPST PULD P PUD BHA #4- WS setting assembly 0.0 0.0 10/22/2022 00:36 10/22/2022 01:54 1.30 PROD1, WHPST PULD P PD BHA #5, Window milling assembly, 0.6° AKO motor, reamer, and diamond speed mill. Inspect pack offs, replace , stab injector, bump up, set counters **DSM gauged in at 2.79 no go, 2.80 go 0.0 74.6 10/22/2022 01:54 10/22/2022 03:30 1.60 PROD1, WHPST TRIP P RIH with BHA #5, milling assembly. ** Note, targeting 11.8 ppg EMW 74.6 8,550.0 10/22/2022 03:30 10/22/2022 03:42 0.20 PROD1, WHPST DLOG P Tie into the HRZ for a -11' correction. 8,550.0 8,594.8 10/22/2022 03:42 10/22/2022 05:06 1.40 PROD1, WHPST TRIP P Continue in the hole, park, close EDC, PU Wt 43 k lbs Attempt to RIH for dry tag, stack weight at 8,973' PU Wt 50 k lbs, reattempt with same result. Pump min rate and attempt, stall, PU and reattempt at 1.5 bpm - free spin diff ~360 psi, mill in hole to 8980. Attempt to continue with out pumps, stack out at 8986. PU and set rate at 1.64 bpm mill down to 9010'. Cut pump to min rate, moist tag at 9,038'. PU Wt 45 k lbs. 8,594.8 9,038.0 10/22/2022 05:06 10/22/2022 11:42 6.60 PROD1, WHPST MILL P Pick up and set rate. WH= 194 psi IA 281, OA 0 psi CT 4565 psi at 1.92 in and out free spin 560 psi. CT RIH Wt 8.5, Tag WS and start milling at 9,038.1'. Milled to 9,039' at 1 fph. Auto-driller turned on. Stalled @ 9,039.9'. PUH. Pump back online @ 1.9 bpm. Free spin of 513 psi. Milled to 9,042' at Avg of 0.7 fph. WHP = 199 psi, IA = 349 psi. OA = 0 psi. Circ Press = 4655 psi. Differential = 736 psi. CT weight = 7.5 k lbs. Avg. WOB = 3k lbs. Pump rate = 1.83 bpm. Seeing fine metal shavings on ditch magnet. 9,038.0 9,042.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/4/2022 Page 7/19 3G-13 Report Printed: 11/29/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/22/2022 11:42 10/22/2022 13:36 1.90 PROD1, WHPST MILL P Continue milling exit window. WOB dropped from 2.5 to 2.1 K lbs @ 9,042.8' indicating the mill is begining to exit the casing. WOB fell off to 1.2 K lbs when reamer cleared the exit. BOW at 9,043.5' after reamer cleared. WHP = 175 psi, IA = 366 psi. OA = 0 psi. Circ Press = 4749 psi. Differential = 779 psi. CT weight = 5.6 k lbs. Avg. WOB = 2.8k lbs. Avg. ROP = 0.7 FPH. Pump rate = 1.83 bpm. 9,042.0 9,043.5 10/22/2022 13:36 10/22/2022 15:30 1.90 PROD1, WHPST MILL P Drill rat hole from 9043.5' to 9,059' (21' below TOW). WHP = 162 psi, IA = 370 psi. OA = 0 psi. Circ Press = 4686 psi. Differential = 726 psi. Avg CT weight = 7 k lbs. Avg. WOB = 0.7k lbs. Avg. ROP = 1.1 FPH. Pump rate = 1.85 bpm. Auto-Driller off. Increased milling parameters after string reamer cleared window. WHP = 159 psi, IA = 371 psi. OA = 0 psi. Circ Press = 4,617 psi. Differential = 845 psi. Avg CT weight = 6.8 k lbs. Avg. WOB = 2.0 k lbs. Avg. ROP = 10 FPH. Pump rate = 1.87 bpm. PUW 42K. 9,043.5 9,059.0 10/22/2022 15:30 10/22/2022 16:48 1.30 PROD1, WHPST REAM P Ream 30R, 30L, and HS at 1 FPM and 1.85 BPM pump rate. Dry drift and tag rat hole @ 9,059'. PU Wt 45 k lbs. Slight WOB bobble of approx. 0.15 K lbs. Ream HS once more prior to gathering static, Minimal formation solids noted in mud report. 9,059.0 9,059.0 10/22/2022 16:48 10/22/2022 18:42 1.90 PROD1, WHPST TRIP P PUH, park and open EDC. POOH pumping 2 bpm 8,850.0 74.0 10/22/2022 18:42 10/22/2022 20:12 1.50 PROD1, DRILL PULD P PUD BHA #5, window milling assembly. DSM gagued out 2.78 No, Reamer 2.80 no. Larg crackstarting in shank of string mill - taken out of service 74.0 0.0 10/22/2022 20:12 10/22/2022 21:00 0.80 PROD1, DRILL CIRC P Stab injector and jet stack 0.0 0.0 10/22/2022 21:00 10/22/2022 21:48 0.80 PROD1, DRILL CTOP P Pop off, pull upper quick, (hour'd out) install big nozzle, stab injector and pump slack back. Good audio indication of wire movement. Pop off. 0.0 0.0 10/22/2022 21:48 10/23/2022 00:00 2.20 PROD1, DRILL CTOP P Install air over/ hydraulic coil cutter, cut pipe. Find wire at 81'. Make hand cut for a total of 82' trimmed. Re-head ** New coil length 19,001' 0.0 0.0 10/23/2022 00:00 10/23/2022 01:12 1.20 PROD1, DRILL CTOP P Continue to re-head. Wire test good - 85 ohms and greater that 550 MOhms. Pull test coil connector to 35 k lbs - good. PT coil connector to 4,000 psi - good. Pump slack forward. 0.0 0.0 10/23/2022 01:12 10/23/2022 02:21 1.15 PROD1, DRILL PULD P PD BHA #6, build drilling assembly, 2.4+ °AKO motor with new style HCCC X33073 bit. 0.0 72.2 10/23/2022 02:21 10/23/2022 03:57 1.60 PROD1, DRILL TRIP P RIH W BHA #6, 72.2 8,550.0 10/23/2022 03:57 10/23/2022 04:09 0.20 PROD1, DRILL DLOG P Tie int othe HRZ for a -12' correction. 8,550.0 8,582.0 10/23/2022 04:09 10/23/2022 04:27 0.30 PROD1, DRILL TRIP P Continue in hole, park, close EDC, PU Wt 41 k lbs. One high WOB spike in the pilot hole, to 4 k lbs at 8,924' window clean. 8,582.0 9,059.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/4/2022 Page 8/19 3G-13 Report Printed: 11/29/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/23/2022 04:27 10/23/2022 07:12 2.75 PROD1, DRILL DRLG P Set rate, WH 207 psi, IA 296 psi, OA 0 psi. CT 4,486 psi at 1.73 bpm in and out, free spin unobtainable. CT Wt 7 k lbs, WOB 1.5 to 2.5 k lbs. Drilled build to 9363'. Started losing CT weight. Perform short wiper to 9,293'. PU 53K. 9,059.0 9,363.0 10/23/2022 07:12 10/23/2022 07:33 0.35 PROD1, DRILL DRLG P Continue drilling build section. WH 182 psi, IA 345 psi, OA 0 psi. CT 4,593 psi at 1.84 bpm in. 1.88 bpm out. CT Wt - 4k lbs. PU 55K. PUH to 9,346'. RBIH. BOB. WOB 0.7 k lbs. CT Wt 2 k lbs. Drilled to 9,369' and lost CT Wt. again. 9,363.0 9,369.0 10/23/2022 07:33 10/23/2022 07:48 0.25 PROD1, DRILL DRLG P PUH to 9,342'. PU 54K. RBIH. BOB to continue build section. WH 294 psi, IA 348 psi, OA 0 psi. CT 4,660 psi at 1.82 bpm in. 1.81 bpm out. CT Wt 1 lbs. Avg. WOB 1.1 k lbs. Avg. ROP 60 FPH. Lost CT Wt. again. Stacked -6 k lbs. PU 52 K. PU to 9,356'. 9,369.0 9,375.0 10/23/2022 07:48 10/23/2022 07:54 0.10 PROD1, DRILL DRLG P BOB. Sweep at nozzle. Sent another 5x5 sweep. Continue to drill build section. Lost CT Wt @ 9,386'. PU 58K. Total of 327' drilled below rat hole. PU weights increased 6K. Decide to make short wiper to just below window. 9,375.0 9,386.0 10/23/2022 07:54 10/23/2022 08:09 0.25 PROD1, DRILL WPRT P PU 58K. Chasing sweep. Perform wiper to 9,065'. 9,386.0 9,065.0 10/23/2022 08:09 10/23/2022 08:18 0.15 PROD1, DRILL WPRT P RBIH to continue drilling build section. Sweep to surface. BOB. 9,065.0 9,386.0 10/23/2022 08:18 10/23/2022 09:00 0.70 PROD1, DRILL DRLG P BOB drilling build @ 9,386'. Pump rate 1.81 bpm / 4,563 psi. Rate out 1.83 BPM. Density in 8.77 ppg. Density out 8.84 ppg. WHP 208 psi. IA 350 psi. OA 0 psi. BHP 4288 psi. Avg. WOB 1.6 K lbs. Avg CT Wt. -2 K lbs. Broke through. Gained CT Wt back. Continue to drill build section. WOB dropped to 0.4 k lbs stacking CT Wt. -4 k lbs. swap to new mud to improve weight transfer. 9,386.0 9,426.0 10/23/2022 09:00 10/23/2022 09:45 0.75 PROD1, DRILL WPRT P Swap to new mud. WOB dropped off. PUH to circ new mud around and regain weight transfer. PU 52K. New mud to bit @ 47 bbls away. 9,426.0 9,316.0 10/23/2022 09:45 10/23/2022 10:09 0.40 PROD1, DRILL WPRT P RBIH with new 8.6# mud. Pump rate 1.81 bpm / 4,235 psi. Rate out 1.83 BPM. Differential 498 psi. Density in 8.55 ppg. Density out 8.91 ppg. WHP 337 psi. IA 357 psi. OA 0 psi 9,316.0 9,426.0 10/23/2022 10:09 10/23/2022 12:51 2.70 PROD1, DRILL DRLG P BOB drilling. Continue to drill build section to 9,565'. New mud returns to surface @ 92 bbls away. Pump rate 1.81 bpm. Density in/out = 8.55 / 8.75 ppg. WHP 422 psi. IA 348 psi. OA 0 psi. Avg CT Wt. 3 k lbs. Avg. WOB 1.1 k lbs. Differential 609 psi. Avg ROP 50 FPH. Bumped ECD up to 12.2# to maintain 1:1. 9,426.0 9,565.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/4/2022 Page 9/19 3G-13 Report Printed: 11/29/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/23/2022 12:51 10/23/2022 13:06 0.25 PROD1, DRILL WPRT P Finished drilling build section. PUH chasing gel pill to the window. PU weight 57K. 9,565.0 9,060.0 10/23/2022 13:06 10/23/2022 13:15 0.15 PROD1, DRILL WPRT P Slow pumps to min rate and speed to 30 FPM across window. Pull through window @ 9,044'. Notice approx. 8K drag pulling 2.4 AKO motor through window/pilot hole at 9,036'. PUH to above TOC @ 8,850'. Open EDC. 9,060.0 8,850.0 10/23/2022 13:15 10/23/2022 15:30 2.25 PROD1, DRILL TRIP P POOH slowing to 40 FPM through jewelry. Bump up. 8,850.0 72.2 10/23/2022 15:30 10/23/2022 16:30 1.00 PROD1, DRILL PULD P PJSM. PUD BHA #6, build assembly. 2.4 AKO motor hung up briefly then popped through. 72.2 0.0 10/23/2022 16:30 10/23/2022 18:00 1.50 PROD1, DRILL PULD P PD BHA #7, lateral drilling assembly, strider agitator, 0.6° AKO motor, over a HCC new style 0.0 80.2 10/23/2022 18:00 10/23/2022 19:30 1.50 PROD1, DRILL TRIP P RIH W BHA #7, park shallow, close EDC and test agitatot / motor. 1.86 BPM and 830 psi diff. Continue in hole 80.2 8,543.0 10/23/2022 19:30 10/23/2022 19:54 0.40 PROD1, DRILL DLOG P Tie into he HRZ for a -13' correction, 8,543.0 8,590.0 10/23/2022 19:54 10/23/2022 20:18 0.40 PROD1, DRILL DLOG P Park and measure BHP - CTMD 8,750.76' and 5,625' TVD. off pump, choke closed, trap 3,625 psi and observe pressure climb to 3,650 psi and then fall to 3,639 psi for a calculated BHP of 12.3 ppg EMW. Note pressures were falling off and BHP is most likely lower. Appears as if we are charging up a relatively low per formation. 8,590.0 8,750.0 10/23/2022 20:18 10/23/2022 20:24 0.10 PROD1, DRILL TRIP P Continue in hole, slight WOB spike to 0.95 k lbs @ 8,898 in the pilot hole just below the TT where we had some stalls during milling operations. 8,750.0 9,063.0 10/23/2022 20:24 10/23/2022 20:30 0.10 PROD1, DRILL DLOG P Window clean Log the RA tag, 9,045' 9,063.0 9,081.0 10/23/2022 20:30 10/23/2022 20:36 0.10 PROD1, DRILL TRIP P Continue to RIH Set rate WH 420 IA 302, OA 6 psi, CT 4,760 psi @ 1.80 bpm in & out Free spin 820 psi, find bottom at 9,658' BHP 3,738 psi targeting 12.1 ppg EMW at the window - note 12.2 ppg at the bit. 9,081.0 9,565.0 10/23/2022 20:36 10/24/2022 00:00 3.40 PROD1, DRILL DRLG P OBD - Free spin 820 psi CT 4947 psi, CT Wt 2.3 k lbs, WOB 1.3 k lbs, ROP 126 ft/hr Horrible weight transfer even after adding additional 1% Lube 776. CT Wt fell to -6 k lbs rapidly after starting drilling. Added 2 ppb alpine beads to the hi-vis sweeps, PU and bypassed HP screens PU Wt 46 k lbs, Pump 5x5 sweep. String weight back to +5-9 k lbs, 2 k WOB, ROP up to ~300 + drill ahead with beads helping control CT Wt, effect short lived while beads on the back side. Build next batch of sweeps with active mud and 2 ppb beads. PU Wt 51 k lbs, @ 9,831'. drill ahead. 9,565.0 9,831.0 10/24/2022 00:00 10/24/2022 02:30 2.50 PROD1, DRILL DRLG P WH 211 psi, IA 368 psi, OA 7 psi, CT 5167 psi at 1.85 bpm in & out, Free spin 920 psi. BHP 3771 psi targeting 12.1 at the window - 12.3 ppg EMW at the bit. RIH CT Wt 6.6 k lbs, OBD, CT Wt -5 k lbs, WOB 2.4 k lbs, ROP 130 ft/ hr. 9,831.0 10,002.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/4/2022 Page 10/19 3G-13 Report Printed: 11/29/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/24/2022 02:30 10/24/2022 03:00 0.50 PROD1, DRILL WPRT P PU Wt 46 k lbs, PUH on wiper #1 to 9,207'. 10,002.0 9,207.0 10/24/2022 03:00 10/24/2022 03:24 0.40 PROD1, DRILL WPRT P RBIH from wiper #1, RIH Wt 6 k lbs 9,207.0 10,002.0 10/24/2022 03:24 10/24/2022 06:24 3.00 PROD1, DRILL DRLG P Tough time getting started, no weight transfer, snubbing - 8 k lbs, Pick up, restart. WH 359 psi, IA 382 psi, OA 7 psi, OBD CT 5000 psi @ 1.83 bpm in & out. Free spin 800 psi, BHP 3,760 targeting 12.1 ppg EMW, 12.3 ppg at the bit. CT Wt -7 k lbs, WOB 1.3 k lbs, ROP 120 ft/ hr. 10077' PU Wt 59 k lbs 10,002.0 10,229.0 10/24/2022 06:24 10/24/2022 08:09 1.75 PROD1, DRILL DRLG P WH 276 psi, IA 414 psi, OA 8 psi, OBD CT 5330 psi @ 1.88 bpm in & out. BHP 3,760 psi. Targeting 12.1 ppg EMW, 12.4 ppg at the bit. CT Wt --1 k lbs, WOB 1.2k lbs, ROP 110 ft/ hr. Differential 1214 psi. Stacked weight and lost WOB at 10,328'. PU Wt. 68K. PUH to 10,238'. RBIH and continue drilling. 10,229.0 10,400.0 10/24/2022 08:09 10/24/2022 08:39 0.50 PROD1, DRILL WPRT P PUH for wiper #2 to 9,550'. PU Wt 48K lbs. 10,400.0 9,550.0 10/24/2022 08:39 10/24/2022 09:03 0.40 PROD1, DRILL WPRT P RBIH from wiper #2. RIH Wt. 7 k lbs. Send another 10 bbls beaded active. 9,550.0 10,400.0 10/24/2022 09:03 10/24/2022 12:54 3.85 PROD1, DRILL DRLG P Back OBD. WH 268 psi, IA 430 psi, OA 8 psi, CT 5361 psi @ 1.85 bpm in & out. Holding 12.1 EMW. CT Wt. 5 k lbs. Avg WOB 1.2 k lbs. Avg ROP 110 FPH. Continue to pump 10 bbl beaded pills to improve weight transfer and WOB. Lost WOB @ 10,709'. PU Wt. 50 k lbs. 10,400.0 10,818.0 10/24/2022 12:54 10/24/2022 13:48 0.90 PROD1, DRILL WPRT P Sweep out nozzle. PUH @ 40 FPM chasing sweep for wiper #3 (long wiper) to 9,060'. PU 55 k lbs. PU to 9,060' to put GR sub above RA tag on WS but keep motor/mill below window. 10,818.0 9,060.0 10/24/2022 13:48 10/24/2022 14:06 0.30 PROD1, DRILL WPRT P RBIH from wiper #3 (long wiper). Tie into RA tag on WS for a +11' correction. RIH Wt. 7 k lbs. Send another 2#/bbl beaded pill. Noticed high pump pressures. Slow pump rate to 0.84 BPM. WHP 412 psi. IA 300 psi OA 11. Pump Press 6,050 psi. Differential 1391 psi. 9,060.0 9,840.0 10/24/2022 14:06 10/24/2022 17:06 3.00 PROD1, DRILL TRIP T PUH to troubleshoot. PU 45 k lbs. Checked choke and surface equipment for blockage. Not plugged at surface. BHA is plugged. Discuss with Town Engineer. Decision made to POOH with EDC closed. Bumped up. Spaced out. 9,840.0 80.2 10/24/2022 17:06 10/24/2022 19:00 1.90 PROD1, DRILL PULD T Crew change out. PJSM. PUD BHA #7, lateral drilling assembly. Inspect BHA for blockage. Break off bi-center. Attempt to blowdown motor + Strider ERD tool. No joy. Tools are plugged. Break off Baker motor. Found Strider ERD tool guts inside Baker motor. 80.2 0.0 10/24/2022 19:00 10/24/2022 20:30 1.50 PROD1, DRILL PULD T Reconfigure BHA to used NOV agitator (20 hrs runtime) and new 0.6 deg AKO Baker motor. PD BHA #8, lateral drilling assembly. 0.0 78.2 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/4/2022 Page 11/19 3G-13 Report Printed: 11/29/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/24/2022 20:30 10/24/2022 22:30 2.00 PROD1, DRILL TRIP T RIH with BHA #8, lateral drilling assembly, 0.6 AKO Baker motor and 3" HCC bi-center bit. Shallow test NOV agitator at 450'. Good test. 78.2 8,550.0 10/24/2022 22:30 10/24/2022 22:39 0.15 PROD1, DRILL DLOG T Tie into HRZ for a -8' correction. Orient motor HS, Set RIH speed to 30 FPM and min rate through pilot hole. 8,550.0 8,602.0 10/24/2022 22:39 10/24/2022 23:18 0.65 PROD1, DRILL TRIP T Orient motor HS, slow RIH speed to 30 FPM and slow pumps to min rate through pilot hole. Clean drift through pilot hole and window. RIH to trouble time depth where Strider tool failed at 9,840'. Pump 5 bbl beaded sweep (1#/bbl) to improve weight transfer during drilling. 8,602.0 9,840.0 10/24/2022 23:18 10/24/2022 23:48 0.50 PROD1, DRILL TRIP P RIH to last drilled depth of 10,818'. WHP 392 IA 319 OA 0. CT speed 40 FPM. Pump Rate 1 BPM. CT Press 3065 psi. CT Wt. 6 k lbs. BHP 4108 psi. Diff press 309 psi @ 10,131'. Pump 10 bbl beaded pill. CT PU Wt. 48K. 9,840.0 10,818.0 10/24/2022 23:48 10/25/2022 00:00 0.20 PROD1, DRILL DRLG P OBD. Increase pump rate to 1.87 BPM. WHP 164 psi, IA 328 psi, OA 0 psi, CT 5172 psi @ 1.87 bpm in & out. Diff Press.885 psi. Holding 12.1 EMW. Struggling with weight transfer. Beads not providing much relief. 10,818.0 10,848.0 10/25/2022 00:00 10/25/2022 04:12 4.20 PROD1, DRILL DRLG P WH 232 psi, IA 404 psi, OA 1 psi, CT 5280 psi at 1.85 bpm im & out. BHP 3853 psi, targeting 12.0 ppg at the window, currently 12.56 ppg at the bit. Extremly poor weight transfer, ROP 30- 40 ft/hr when in poor sand CT Wt -8 k lbs and 0.7 WOB, When in good sand, CT 0 k ls, WOB .3 k lbs, 140 ft/ hr. Start mud swap, New mud at the bit - 10,848.0 11,018.0 10/25/2022 04:12 10/25/2022 05:00 0.80 PROD1, DRILL DRLG P PU Wt 52 k lbs, Pick up as new mud exites the bit. Grab new parameters. WH 253 psi, IA 405 psi, OA 4 psi, Free spin 755 psi - unable to grab free spin on run in. OBD, CT 4827 psi @ 1.8 bpm in & out. Unable to drill, can't get started. PU Wt 64 k lbs ** New mud at the bit - 11,018' 11,018.0 11,029.0 10/25/2022 05:00 10/25/2022 05:54 0.90 PROD1, DRILL WPRT P PUH slowly waiting on beaded pill, RBIH as beads exit, RIH Wt -7 k lbs 11,029.0 11,029.0 10/25/2022 05:54 10/25/2022 10:42 4.80 PROD1, DRILL DRLG P BOBD, CT 4900 psi at 1.85 in and out, BHP 3850 psi, targeting 12.0 ppg at the window, getting 12.48 at the bit. ** Note add 1% Lube 776 and 1% low torque to system 11,029.0 11,200.0 10/25/2022 10:42 10/25/2022 11:00 0.30 PROD1, DRILL WPRT P PU Wt 54 k lbs - PUH on scheduled wiper #1 slight WOB tug and a little motor work at 10,580' 11,200.0 10,317.0 10/25/2022 11:00 10/25/2022 11:24 0.40 PROD1, DRILL WPRT P RBIH @ 40 ft/min and 1.85 bpm. carried ~ 6 k CT Wt to bottom 10,317.0 11,200.0 10/25/2022 11:24 10/25/2022 16:42 5.30 PROD1, DRILL DRLG P WH 248 psi, IA 429 psi, OA 5 psi. CT 5,068 psi at 1.85 bpm in & out. BHP 3,867 psi targeting 12.0 ppg at the window, currently 12.5 at the bit. Free spin diff 775 psi. 11,200.0 11,381.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/4/2022 Page 12/19 3G-13 Report Printed: 11/29/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/25/2022 16:42 10/26/2022 00:00 7.30 PROD1, DRILL DRLG P BHP 3,832 psi targeting 12.0 ppg at the window, currently at 13.0 at the bit. Free spin diff 767 psi. 11,381.0 11,581.0 10/26/2022 00:00 10/26/2022 00:12 0.20 PROD1, DRILL DRLG P BHP 3,832 psi targeting 12.0 ppg at the window, currently at 13.0 at the bit. Free spin diff 767 psi. ROP 30 fph before wiper trip. 11,581.0 11,591.0 10/26/2022 00:12 10/26/2022 01:12 1.00 PROD1, DRILL WPRT P Wiper trip #2 PU Wt 58 k lbs, POOH to 10,793' at 27 fph, pumping 1.86 bpm. RBIH at 27 fph pumping 1.86 bpm. 11,591.0 11,591.0 10/26/2022 01:12 10/26/2022 05:18 4.10 PROD1, DRILL DRLG P Targeting 12.0 ppg at the window, currently at 12.8 at the bit. Free spin diff 806 psi. ROP 90 fph after wiper trip. 11,591.0 11,737.0 10/26/2022 05:18 10/26/2022 05:36 0.30 PROD1, DRILL WPRT P PU Wt 56 k lbs, Pull unscheduled wiper 11,737.0 10,935.0 10/26/2022 05:36 10/26/2022 05:54 0.30 PROD1, DRILL WPRT P RHIH carry ~ 65-6 k CT weight to bottom - clean trip 10,935.0 11,737.0 10/26/2022 05:54 10/26/2022 13:30 7.60 PROD1, DRILL DRLG P WH 275 psi, IA 513 psi, OA 8 psi. CT 5,362 psi @ 1.84 bpm in & out. Free spin 765 psi. BHP 3902 psi, targeting 12.0 ppg EMW at the window, currently 12.7 ppg at the bit. CT Wt -4 k lbs, WOB 0.4 k lbs 11,929 53 k lbs 11,737.0 12,000.0 10/26/2022 13:30 10/26/2022 14:48 1.30 PROD1, DRILL WPRT P PU Wt 57 k lbs, PUH on third wiper - clean trip - 0.8 + bbls of cuttings returned 12,000.0 9,045.0 10/26/2022 14:48 10/26/2022 15:00 0.20 PROD1, DRILL DLOG P Tie int othe RA tag for a +19' correction 9,045.0 9,130.0 10/26/2022 15:00 10/26/2022 16:18 1.30 PROD1, DRILL WPRT P RBIH, CT Wt 6.6 k to4 k lbs to 11,800' cut pump rate breiflyto get to bottom - clean trip 9,130.0 12,000.0 10/26/2022 16:18 10/26/2022 19:06 2.80 PROD1, DRILL DRLG P WH 243 psi, IA 530 psi, OA 11 psi, CT 5513 psi @ 1.79 bpm in & out. Free spin diff 733 psi. BHP 3928 psi, holding 12.0 ppg EMW at the window is yeilding 12.8 ppg at the bit. ST Wt 2 k lbs, 12,000.0 12,089.0 10/26/2022 19:06 10/26/2022 19:18 0.20 PROD1, DRILL WPRT P BHA wiper PU WT 52 klbs 12,089.0 12,089.0 10/26/2022 19:18 10/27/2022 00:00 4.70 PROD1, DRILL DRLG P WH 307 psi, IA 510 psi, OA 4 psi. CT 4621 psi @ 1.65 bpm in & out. Free spin 774 psi. BHP 3918 psi, targeting 12.0 ppg EMW at the window, currently 12.7 ppg at the bit. CT Wt -5 k lbs, WOB 0.6 k lbs 12,089.0 12,193.0 10/27/2022 00:00 10/27/2022 07:00 7.00 PROD1, DRILL DRLG P WH 307 psi, IA 510 psi, OA 4 psi. CT 4621 psi @ 1.65 bpm in & out. Free spin 774 psi. BHP 3918 psi, targeting 12.0 ppg EMW at the window, currently 12.7 ppg at the bit. CT Wt -5 k lbs, WOB 0.6 k lbs 12,193.0 12,322.0 10/27/2022 07:00 10/27/2022 07:24 0.40 PROD1, DRILL WPRT P PU Wt 60 k lbs, PUH on wiper #1 12,322.0 11,475.0 10/27/2022 07:24 10/27/2022 07:54 0.50 PROD1, DRILL WPRT P RBIH, 11,475.0 12,322.0 10/27/2022 07:54 10/27/2022 08:39 0.75 PROD1, DRILL DRLG P WH 230 psi, IA 526 psi, OA 7 psi, CT 5314 @ 1.76 bpm in & out. BHP 3954 psi, targeting 12.0 ppg at the window runnng 12.93 ppg at the bit. Free spin 808 psi 12,322.0 12,346.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/4/2022 Page 13/19 3G-13 Report Printed: 11/29/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/27/2022 08:39 10/27/2022 10:18 1.65 PROD1, DRILL WPRT P PU Wt 52 k lbs PUH on swab wiper at 40 ft/ min, hole, build, window, and pilot hole clean. **Town called TD 12,346.0 8,800.0 10/27/2022 10:18 10/27/2022 12:06 1.80 PROD1, DRILL WPRT P Continue up hole on swab wiper. Increase target from 12.0 to 12.1 ppg EMW at the window to maintain 1 for 1. Lost charge on mud pump temporarily. 8,800.0 78.2 10/27/2022 12:06 10/27/2022 13:45 1.65 PROD1, DRILL TRIP P Bump up, set counters, RBIH 78.2 8,560.0 10/27/2022 13:45 10/27/2022 13:57 0.20 PROD1, DRILL DLOG P Tie into the HRZ for a -12' correction. 8,560.0 8,601.0 10/27/2022 13:57 10/27/2022 14:27 0.50 PROD1, DRILL DLOG P Park and measure BHP 8880.73 MD 5761.89 TVD Down on pump, close choke, trap 3596 psi and observe Pressure fall slowly to 3575 over 10 minutes. Bleed wellhead to 3540 psi observe pressure slowly climb and stabilize at 3546 psi - 11.85ppg EMW. 8,601.0 8,880.0 10/27/2022 14:27 10/27/2022 16:09 1.70 PROD1, DRILL TRIP P Continue in hole, pilot hole, window and build clean. Confirm TD of 12,351' 8,880.0 12,351.0 10/27/2022 16:09 10/27/2022 17:09 1.00 PROD1, DRILL TRIP P PU Wt 48 k lbs, PUH slowly waiting on Liner Runnning Pill and KW. Pump 12.1 ppg KWF. 12,351.0 12,351.0 10/27/2022 17:09 10/27/2022 19:57 2.80 PROD1, DRILL DISP P PU Wt 54 k lbs PUH laying in LRP and KWF. Paint yellow TD flag @ 11371' and white window flag @ 7976'. 12,351.0 108.2 10/27/2022 19:57 10/27/2022 20:09 0.20 PROD1, DRILL CTOP P Check coil for flat spot 30' above BHA. 108.2 78.2 10/27/2022 20:09 10/27/2022 20:27 0.30 PROD1, DRILL OWFF P At surface, check well for flow. 78.2 0.0 10/27/2022 20:27 10/27/2022 21:27 1.00 PROD1, DRILL PULD P LD drilling BHA #8 over dead well. 0.0 0.0 10/27/2022 21:27 10/27/2022 21:57 0.50 COMPZ1, CASING BOPE P Function check BOPE. 0.0 0.0 10/27/2022 21:57 10/27/2022 23:57 2.00 COMPZ1, CASING PUTB P PU lower liner segment, Non ported bull nose, 33 joints 2 3/8" lotted ST L liner, and shorty deployment sleeve 0.0 1,053.0 10/27/2022 23:57 10/28/2022 00:00 0.05 COMPZ1, CASING PULD P Make op Coiltrak to liner. Make up to coil and surface test. Stab on well. Tag up and set counters. 1,053.0 1,053.0 10/28/2022 00:00 10/28/2022 02:06 2.10 COMPZ1, CASING RUNL P RIH with BHA #9 lower liner segment. 1,053.0 9,039.0 10/28/2022 02:06 10/28/2022 02:12 0.10 COMPZ1, CASING DLOG P Tie into flag for a -20' correction. 9,039.0 9,039.0 10/28/2022 02:12 10/28/2022 04:18 2.10 COMPZ1, CASING RUNL P Continue in hole, slowed down to log RA tag and cement pilot hole was sticky, but at a little faster speed we had a clean pass through window. 9,039.0 12,351.0 10/28/2022 04:18 10/28/2022 04:30 0.20 COMPZ1, CASING RUNL P Land liner on depth, tag bottom twice with 2.4 k WOB. Bring pump on line at 1.5 bpm. Negative 14K string weight, liner left on bottom. Note: BOL = 12,351', TOL = 11,342' 12,351.0 11,342.0 10/28/2022 04:30 10/28/2022 05:30 1.00 COMPZ1, CASING TRIP P POOH painting flags White EOP at 10,318.78 11,342.0 9,030.0 10/28/2022 05:30 10/28/2022 05:36 0.10 COMPZ1, CASING DLOG P Tie into the RA tag for a +13.5' correction 9,030.0 9,058.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/4/2022 Page 14/19 3G-13 Report Printed: 11/29/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/28/2022 05:36 10/28/2022 07:24 1.80 COMPZ1, CASING TRIP P Continue to POOH Park and paint yellow window flag at 7944.2' Continue OOH 9,058.0 45.0 10/28/2022 07:24 10/28/2022 08:00 0.60 COMPZ1, CASING PULD P LD BHA # 9, Lower A lat completion. 45.0 0.0 10/28/2022 08:00 10/28/2022 08:24 0.40 COMPZ1, CASING CTOP P Prep floor for picking up liner 0.0 0.0 10/28/2022 08:24 10/28/2022 09:36 1.20 COMPZ1, CASING PUTB P Pick up middle A lateral completion, 33 joints of 2-3/8 STL 4.6 lb/ft R2 slotted liner under a shorty deployment sleeve and over a ported bull nose. LOA 1017.66' 0.0 1,017.7 10/28/2022 09:36 10/28/2022 10:15 0.65 COMPZ1, CASING PULD P Pick up BHA #10, stab injector, bump up, set counters 1,017.7 1,061.9 10/28/2022 10:15 10/28/2022 12:45 2.50 COMPZ1, CASING RUNL P RIH with A lateral middle completion Tie into yellow flag for -13.6' correction Continue in hole. 1,061.9 9,829.0 10/28/2022 12:45 10/28/2022 14:33 1.80 COMPZ1, CASING RUNL P 1st set down at 9830', PU 58 k, work pipe past. Continue to work pipe while RIH to 10,059'. Stick pipe, work pipe to 60 k lbs no movement. Work pipe to 70 k - pop free. PUH 200 feet, attempt to RBIH, stack out. 9,829.0 10,059.0 10/28/2022 14:33 10/28/2022 17:00 2.45 COMPZ1, CASING PULL T POOH for clean out assembly. 10,059.0 1,017.7 10/28/2022 17:00 10/28/2022 17:30 0.50 COMPZ1, CASING CTOP T Tagged up 82 K pulled coil connector out of coil, flow check. Left BHA and liner in hole. 0.0 0.0 10/28/2022 17:30 10/28/2022 23:30 6.00 COMPZ1, CASING CTOP T Cut 14' off coil length, installed new coil connector, inspected injector and MU UQC. PT CTC. 0.0 0.0 10/28/2022 23:30 10/29/2022 00:00 0.50 COMPZ1, CASING FISH T PJSM. PU overshot fishing BHA #11. Test MWD and PT QTS. 0.0 65.0 10/29/2022 00:00 10/29/2022 02:18 2.30 COMPZ1, CASING FISH T RIH with overshot fishing BHA to retrieve middle section of liner and BHA. At 8623 lightly tagged fish and started pushing 5K WOB. PU 2 K over. Continue in hole pushing 7 K WOB to 9000'. PU 4.5 K over. 65.0 9,000.0 10/29/2022 02:18 10/29/2022 04:48 2.50 COMPZ1, CASING PULL T POOH with overshot fishing BHA and middle section of liner. 9,000.0 1,123.0 10/29/2022 04:48 10/29/2022 05:00 0.20 COMPZ1, CASING PULD T Park shallow, Flow check while PJSM - good check. LD BHA #11 fishing BHA 11,123.0 1,061.8 10/29/2022 05:00 10/29/2022 05:42 0.70 COMPZ1, CASING PULD T Lay down recovered coil trak from BHA #10. 1,061.8 1,016.0 10/29/2022 05:42 10/29/2022 06:00 0.30 COMPZ1, CASING CTOP T Crew change, PJSM, clean and prep floor for liner lay down 1,061.8 1,016.0 10/29/2022 06:00 10/29/2022 08:00 2.00 COMPZ1, CASING PULL T Lay down middle section of A lateral 1,016.0 0.0 10/29/2022 08:00 10/29/2022 09:42 1.70 COMPZ1, CASING PULD T PU BHA #12, clean out assembly, 0.6° AKO motor with D331 ridge set bit over a dead well. 0.0 63.3 10/29/2022 09:42 10/29/2022 11:15 1.55 COMPZ1, CASING TRIP T RIH w clean out assembly 63.3 8,545.0 10/29/2022 11:15 10/29/2022 11:27 0.20 COMPZ1, CASING DLOG T Tie into the HRZ for a +13' correction 8,545.0 8,582.1 10/29/2022 11:27 10/29/2022 12:27 1.00 COMPZ1, CASING TRIP T Continue to RIH w clean out assembly, Pilot hole, window and build clean. Continue in hole at ~50 ft/min and min rate 8,582.1 11,337.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/4/2022 Page 15/19 3G-13 Report Printed: 11/29/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/29/2022 12:27 10/29/2022 13:21 0.90 COMPZ1, CASING DISP T PU Wt 46 k lbs, Stage pump up slowly to 1.9 bpm, displace milling fluid to the bit while PUH slowly. 11,337.0 11,329.0 10/29/2022 13:21 10/29/2022 17:15 3.90 COMPZ1, CASING TRIP T PUH dragging low side at 1.90 bpm pumping 10 bbl hi vis sweeps at 11,329, 10150, and 9150' build and window clean. Time out two 10 bbl sweeps above the cement pilot hole, chase last sweep out of hole with 1.5 bottoms up. 11,329.0 9,045.0 10/29/2022 17:15 10/29/2022 17:21 0.10 COMPZ1, CASING DLOG T RA tie in for a +6' correction. 9,045.0 9,045.0 10/29/2022 17:21 10/29/2022 21:27 4.10 COMPZ1, CASING DLOG T RIH tag at 11336' and POOH laying in LRP. PU WT 48K. Paint white TD flag at 10337.64. Paint yellow window flag at 7962.36'. Continue POOH. 11,336.0 0.0 10/29/2022 21:27 10/29/2022 21:57 0.50 COMPZ1, CASING DLOG T Flow check and LD BHA #12. 0.0 0.0 10/29/2022 21:57 10/30/2022 00:00 2.05 COMPZ1, CASING DLOG T MU and RIH with liner. 0.0 300.0 10/30/2022 00:00 10/30/2022 01:36 1.60 COMPZ1, CASING PUTB T RIH with BHA #13 33 jts of 2-3/8" slotted liner. Did not stop at RA tag but it was right on depth at 9045'. 300.0 1,062.0 10/30/2022 01:36 10/30/2022 03:42 2.10 COMPZ1, CASING RUNL T RIH with liner on coil. Come off trouble time at 10,059'. 1,062.0 10,059.0 10/30/2022 03:42 10/30/2022 04:12 0.50 COMPZ1, CASING RUNL P Continue to RIH to the top of the first liner at 11,342. Set down 3K over and Increase flow rate to 1.5 bpm and good indication of release from liner. 10,059.0 11,336.0 10/30/2022 04:12 10/30/2022 07:12 3.00 COMPZ1, CASING TRIP P POOH with liner setting assembly 11,336.0 45.0 10/30/2022 07:12 10/30/2022 07:42 0.50 COMPZ1, CASING PULD P Park shallow, Flow check during PJSM, Check good. LD BHA 13, liner running assembly. 45.0 0.0 10/30/2022 07:42 10/30/2022 08:12 0.50 COMPZ1, CASING CTOP P Clear and prep rig floor for picking up liner 0.0 0.0 10/30/2022 08:12 10/30/2022 10:12 2.00 COMPZ1, CASING PUTB P PU upper section of A lateral completion, 37 joints 2-3/8" STL slotted liner 4.6 lb/ft over a ported bull nose and under a liner top billet. LOA ( 1,174.11') ** note knuckle run above GS as we dropping liner top off in the build section. 0.0 1,174.1 10/30/2022 10:12 10/30/2022 11:00 0.80 COMPZ1, CASING PULD P PU BHA #14, Upper A lateral l running assembly. 1,174.1 1,224.0 10/30/2022 11:00 10/30/2022 15:30 4.50 COMPZ1, CASING RUNL P RIH w upper A lateral completion. First set down at 9,780'. Work pipe slowly to 10,092' over 3.5 hrs of working pipe. 1,224.0 10,092.0 10/30/2022 15:30 10/30/2022 17:30 2.00 COMPZ1, CASING RUNL P Mix and pump 30 bbl Liner Running Pill down the coil. 1 bpm, CT 2746 psi, DP across the GS 777 psi. Work pipe slowly. Drive by the RA flag for a +3 foot correction. RIH to hard bottom ~5' past yellow td flag. Pump 1.5 bpm, diff 1000 psi, PU, CT Wt 41 k lbs, WOB 0.23. Reset depth to reflect dropped off liner. 10,092.0 10,315.0 10/30/2022 17:30 10/30/2022 20:00 2.50 COMPZ1, CASING TRIP P POOH with liner setting assembly. RA tag tie in +8' correction. 10,315.0 100.0 10/30/2022 20:00 10/30/2022 20:30 0.50 COMPZ1, CASING PULD P Park shallow, Flow check during PJSM, Check good. LD BHA 13, liner running assembly. 100.0 0.0 10/30/2022 20:30 10/31/2022 00:00 3.50 COMPZ1, CASING CIRC P Swap coil to fresh water. Remove floats from UQC and prep to test BOPE. 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/4/2022 Page 16/19 3G-13 Report Printed: 11/29/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/31/2022 00:00 10/31/2022 03:12 3.20 PROD2, WHDBOP BOPE P Start BOPE test. Witness waived by Lou Laubenstein- AOGCC. 250 / 4500 psi - 2500 psi for annular. Good shell test - 0:15. Test 1, Swab 2. Test 2. Blind/Shear, BOP TV2, Charlie 4, 5, 8, &12 Test 3. BOP TV 1, Charlie 3, 6, 7, & 11 Test 4. Manual choke D & Super choke C Test 5. Romeo 3, Bleeder 3, Tango 2, Charlie 2, & 10 Test 6. Charlie 1, 9, Tango 1 * install TIW test joint Test 7. Lower 2” pipe slip rams, Lower (relpaced upper with spare) , TIW #2, Romeo 1, Bleeder 1. Test 8. Annular BOP to 2,500 psi. Test 9. Upper 2” pipe slip rams, Bravo 6, & 8, Upper TIW. Test 10. Bravo 7 &5, – swap out 2” test joint for 2-3/8”. Test 11. 2-3/8” pipe slip rams, check N2 levels, swap to 2” test joint Test 12. Draw down accumulator. Koomy pressure, close all record stable pressure, time to increase 200 psi, entire recovery time Test 13. Stab injector and line up to reverse circulate coil, test inner reel valve and stripper. Verified flow alarms - PVT Calibrated and tested gas detectors and alarms (H2S and LEL). Pass. 0.0 0.0 10/31/2022 03:12 10/31/2022 03:36 0.40 PROD2, WHDBOP BOPE T Test 9. Upper 2” pipe slip rams, Bravo 6, & 8, Upper TIW. Grease B8 and retest - pass 0.0 0.0 10/31/2022 03:36 10/31/2022 06:00 2.40 PROD2, WHDBOP BOPE P Test 10. Bravo 7 &5, – swap out 2” test joint for 2-3/8”. Test 11. 2-3/8” pipe slip rams, check N2 levels, swap to 2” test joint Test 12. Draw down accumulator. Koomy pressure 3000 psi, close all record stable pressure, time to increase 200 psi 24 sec, entire recovery time 50 sec. Test 13. Stab injector and line up to reverse circulate coil, test inner reel valve and stripper. Verified flow alarms - PVT Calibrated and tested gas detectors and alarms (H2S and LEL). Pass. 0.0 0.0 10/31/2022 06:00 10/31/2022 07:00 1.00 PROD2, STK CTOP P Blow down, clean clear, crew change, valve check list 0.0 0.0 10/31/2022 07:00 10/31/2022 08:12 1.20 PROD2, STK PULD P PJSM, PU BHA #15, AL1 lateral drilling assembly 0.0 78.3 10/31/2022 08:12 10/31/2022 09:36 1.40 PROD2, STK DISP T Attempt to displace coil from fresh water to KW. Unable to pump through the coil. Trouble shoot Romeo valves inner reel valves. PJSM, un stab injector. Open double ball valves. stab coil. 78.3 78.3 10/31/2022 09:36 10/31/2022 10:36 1.00 PROD2, STK DISP P Displace well to 12.1 ppg KW. 78.3 78.3 10/31/2022 10:36 10/31/2022 12:15 1.65 PROD2, STK TRIP P RIH w BHA # 15, start mud down the coil. 78.3 8,550.0 10/31/2022 12:15 10/31/2022 12:27 0.20 PROD2, STK DLOG P Tie into HRZ for +5' correction 8,550.0 8,585.5 10/31/2022 12:27 10/31/2022 12:51 0.40 PROD2, STK TRIP P Park, close the EDC, PU Wt 40 k lbs, continue on in hole @ min rate, pass through window clean. Pump off, dry tag TOB @ 9,144', PU Wt 40 k, 8,585.5 9,144.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/4/2022 Page 17/19 3G-13 Report Printed: 11/29/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/31/2022 12:51 10/31/2022 13:45 0.90 PROD2, STK DISP P Chase mud from bit to surface displacing kill weight. 9,144.0 9,141.0 10/31/2022 13:45 10/31/2022 16:03 2.30 PROD2, STK KOST P Set TF to HS, See motor work at 9,141.3' Early. WH 0 psi , IA 302 psi, OA 0 psi. CT 5,563 psi @ 1.86 bpm in and out. Free spin 825 psi Engage auto driller. Billet not acting as a typical billet. PU Wt 36 k lbs. Dry tag TOB twice Start milling again KO at 1 ft/ hr new free spin 733 psi. 9,141.0 9,142.7 10/31/2022 16:03 10/31/2022 16:33 0.50 PROD2, STK KOST P Attempt to increase to 2 ft/hr struggling with auto drill. Drill manually taking bites. 9,142.7 9,144.3 10/31/2022 16:33 10/31/2022 16:45 0.20 PROD2, STK KOST P Increase ROP to 3 ft/ hr 9,144.3 9,145.4 10/31/2022 16:45 10/31/2022 17:36 0.85 PROD2, DRILL DRLG P Start to drill ahead, targetting 0.75 - 1 k lbs WOB Chase weight on bit of 1-1.5 k lbs. 9,145.4 9,170.0 10/31/2022 17:36 10/31/2022 17:54 0.30 PROD2, DRILL DLOG P PU Wt 43 k lbs, PUH and tie int othe RA tag for a +3' RBH Best guess TOB @ 9143' will confirm with resistivity once drilled past. Dry drift - Clean 9,170.0 9,170.0 10/31/2022 17:54 10/31/2022 22:42 4.80 PROD2, DRILL DRLG P WH 45 psi, IA 344 psi, OA 0 psi, CT 5386 psi @ 1.81 in and 1.81 out, free spin 761 psi, targeting 12.0 ppg EMW at the window. BHP 3709 psi.1.5 k WOB ROP ~66 ft/hr. 9,170.0 9,550.0 10/31/2022 22:42 10/31/2022 23:12 0.50 PROD2, DRILL WPRT P Wper trip #1, PU WT 48 Klbs. 9,550.0 9,550.0 10/31/2022 23:12 11/1/2022 00:00 0.80 PROD2, DRILL DRLG P Drilling with 3 Klbs WOB, flow rate 1.83, New mud at bit. 9,550.0 9,625.0 11/1/2022 00:00 11/1/2022 01:30 1.50 PROD2, DRILL DRLG P Drilling with 3 Klbs WOB, flow rate 1.83, New mud at bit. 9,625.0 9,729.0 11/1/2022 01:30 11/1/2022 04:18 2.80 PROD2, DRILL TRIP P Trip out of hole for a bigger bend 1.2 degree motor and a more common predictable bit. 9,729.0 0.0 11/1/2022 04:18 11/1/2022 06:18 2.00 PROD2, DRILL PULD P Pressure undeploy, Swap bit and motor, Pressure deploy. 0.0 0.0 11/1/2022 06:18 11/1/2022 07:00 0.70 PROD2, DRILL TRIP P RBIH w / 1.2° AKO motor w / a Dynamus bit 0.0 8,550.0 11/1/2022 07:00 11/1/2022 08:30 1.50 PROD2, DRILL TRIP P At 8550' Tie into the HSZ + 3.5' correction 8,550.0 9,729.0 11/1/2022 08:30 11/1/2022 09:54 1.40 PROD2, DRILL DRLG P Back on bottom @ 9728 drill ahead 9,729.0 9,852.7 11/1/2022 09:54 11/1/2022 12:24 2.50 PROD2, DRILL TRIP P At 9850' got the drop they needed POOH 9,852.7 64.6 11/1/2022 12:24 11/1/2022 13:54 1.50 PROD2, DRILL PULD P At surface, Tag up - Space out, PJSM, PUD BHA #16, Check valves not holding during PUD. Go to alt check list for failed check valves 64.6 0.0 11/1/2022 13:54 11/1/2022 15:12 1.30 PROD2, DRILL PULD P PD BHA #17 with .6° AKO motor, RR bit, and NOV agitator. Make up to coil and surface test tool. Stab injector on well, Tag up set counters 0.0 78.3 11/1/2022 15:12 11/1/2022 18:45 3.55 PROD2, DRILL TRIP P Trip in well, BHA #17. Shallow test @ 500', CT circ 4800 PSI, Diff=840 BSI @ 1.8 BPM. Continue in 78.3 10,167.0 11/1/2022 18:45 11/1/2022 19:00 0.25 PROD2, DRILL WPRT P Short trip 100' up WT 49 K 10,167.0 10,767.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/4/2022 Page 18/19 3G-13 Report Printed: 11/29/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/1/2022 19:00 11/1/2022 19:10 0.17 PROD2, DRILL DRLG P Back on bottom drilling at 10167' 10,767.0 10,250.0 11/1/2022 19:10 11/1/2022 19:45 0.59 PROD2, DRILL WPRT P Wiper to 9400' up WT 52 K 9,400.0 10,250.0 11/1/2022 19:45 11/1/2022 20:15 0.50 PROD2, DRILL DRLG P Back on bottom @ 10250' driling ahead 10,250.0 10,651.0 11/1/2022 20:15 11/2/2022 00:00 3.75 PROD2, DRILL WPRT Short trio to 9800' wiper # 2 p/u wt 52 K 10,651.0 10,651.0 11/2/2022 00:00 11/2/2022 00:30 0.50 PROD2, DRILL WPRT P Performing wiper trip form 10651.6 to 9800' up wt 52 K 10,651.6 10,651.6 11/2/2022 00:30 11/2/2022 04:18 3.80 PROD2, DRILL DRLG P Back on bottom drilling from 1`0651.6', Drilled to TD @ 11040' as per GEO and DD 10,651.6 11,040.0 11/2/2022 04:18 11/2/2022 07:06 2.80 PROD2, DRILL WPRT P Perform wiper trip to swab with sweeps, PUW=51K 11,040.0 78.2 11/2/2022 07:06 11/2/2022 08:48 1.70 PROD2, DRILL WPRT P Tag up at surface, Reset counters, RBIH 78.2 8,550.0 11/2/2022 08:48 11/2/2022 09:00 0.20 PROD2, DRILL DLOG P Log HRZ for tie in, +2.5' 8,550.0 8,585.0 11/2/2022 09:00 11/2/2022 09:06 0.10 PROD2, DRILL WPRT P Continue in on wiper trip 8,585.0 8,800.0 11/2/2022 09:06 11/2/2022 09:54 0.80 PROD2, DRILL PRTS P Obtain 30 min static BHP. Annular 3513 @ 5716' TVD for 11.83 PPG EMW. Call 12.1PPG for liner ops 8,800.0 8,800.0 11/2/2022 09:54 11/2/2022 11:00 1.10 PROD2, DRILL WPRT P Continue in well 8,800.0 11,047.0 11/2/2022 11:00 11/2/2022 12:00 1.00 PROD2, DRILL WPRT P Clean trip to bottom @ 11,047, Circ down LRP 11,047.0 11,047.0 11/2/2022 12:00 11/2/2022 14:42 2.70 PROD2, DRILL TRIP P POOH pumping 12.1 PPG LRP folled by 12.1 completion fluid, Paint EOP flags 9992 and 7900'. 11,047.0 100.0 11/2/2022 14:42 11/2/2022 16:00 1.30 PROD2, DRILL OWFF P At surface, flow check well. Good test. Static losses 1 BPH, Lay down BHA #17 100.0 0.0 11/2/2022 16:00 11/2/2022 17:30 1.50 COMPZ2, CASING RURD P Prep floor for liner ops, PJSM to make up liner 0.0 0.0 11/2/2022 17:30 11/2/2022 18:30 1.00 COMPZ2, CASING PUTB P PJSM M/U AL1 lower liner segment m/u BHA 0.0 0.0 11/2/2022 18:30 11/2/2022 20:30 2.00 COMPZ2, CASING TRIP P M/U QC stab injector on well RIH w / lower liner 1,049.1 8,949.0 11/2/2022 20:30 11/2/2022 22:15 1.75 COMPZ2, CASING TRIP P Stop at flag @ 7896.30 EOP + 5' correction continue in hole 8949' having trouble getting past 9959' to 10192' 8,949.0 10,680.0 11/2/2022 22:15 11/3/2022 00:00 1.75 COMPZ2, CASING Continue in hole w/ lower liner 10,680.0 11/3/2022 00:00 11/3/2022 00:12 0.20 COMPZ2, CASING TRIP P Continue running in hole w / lower liner 10,680.0 11,043.5 11/3/2022 00:12 11/3/2022 00:42 0.50 COMPZ2, CASING TRIP P Tagged TD @ 11043.5 'wt ck 50 K pump off liner POOH up wt 38 K, Remove liner length left in hole from counters. Continue out of hole 11,043.5 9,030.0 11/3/2022 00:42 11/3/2022 00:48 0.10 COMPZ2, CASING DLOG P At 9030' tie into RA TAG + 10' correction repaint flags yellow 7743.86' EOP & white 8876.89 EOP ' continue OOH 9,030.0 9,045.0 11/3/2022 00:48 11/3/2022 02:30 1.70 COMPZ2, CASING TRIP P Continue out of well, repaint flags yellow 7743.86' EOP & white 8876.89 EOP ' continue OOH 9,045.0 0.0 11/3/2022 02:30 11/3/2022 03:00 0.50 COMPZ2, CASING PULD P At surface flow check well, L/D BHA prep for upper liner 0.0 0.0 11/3/2022 03:00 11/3/2022 05:36 2.60 COMPZ2, CASING PUTB P Start picking up upper liner 30 joimts of slotted liner swell packer & pup 7 joints of solid liner 0.0 1,205.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/4/2022 Page 19/19 3G-13 Report Printed: 11/29/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/3/2022 05:36 11/3/2022 06:24 0.80 COMPZ2, CASING PULD P M/U QC stab injector PUH tag up and correct depths 1205' RIH 1,205.0 1,205.0 11/3/2022 06:24 11/3/2022 08:12 1.80 COMPZ2, CASING TRIP P RIH, BHA #19, AL1 upper liner segment 1,205.0 8,906.0 11/3/2022 08:12 11/3/2022 08:18 0.10 COMPZ2, CASING DLOG P Correct to flag for +8.7' 8,906.0 8,914.0 11/3/2022 08:18 11/3/2022 08:48 0.50 COMPZ2, CASING TRIP P Continue in hole, Clean down to top of lower segment @ 10045 8,914.0 10,045.0 11/3/2022 08:48 11/3/2022 08:54 0.10 COMPZ2, CASING TRIP P Latch up to lower liner PUW=51K, Set down pump online 1.5 BPM Release from Liner. Remove liner length left in holr 10,045.0 8,870.0 11/3/2022 08:54 11/3/2022 10:00 1.10 DEMOB, WHDBOP CIRC P Check tree bolts, BHP=3627 PSI, Sensor TVD=5686, Displace well to seawater 8,870.0 8,870.0 11/3/2022 10:00 11/3/2022 13:30 3.50 DEMOB, WHDBOP TRIP P Trip out of well, Freeze protect from 2500' 8,870.0 49.0 11/3/2022 13:30 11/3/2022 14:54 1.40 DEMOB, WHDBOP PULD P Tag up - Space out PUD BHA #19 and lay down, Pull checks in UQC in preperation for nexr BOPE test 49.0 0.0 11/3/2022 14:54 11/3/2022 16:00 1.10 DEMOB, WHDBOP CTOP P Stab back on Jet stack Flush rig 0.0 0.0 11/3/2022 16:00 11/3/2022 23:30 7.50 DEMOB, WHDBOP DMOB P Work RDMO check list 0.0 0.0 11/3/2022 23:30 11/4/2022 00:00 0.50 DEMOB, WHDBOP DMOB P Nipple down BOP"S / RIG RELESE 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 11/4/2022 DTTMSTART JOBTYP SUMMARYOPS 4/22/2022 SUPPORT OTHER OPERATIONS DRIFT TBG TO 2.79, TAG D NIPPLE FOR 37' CORRECTION. RIH W/ GAUGES, LIGHTLY TAG @ 9055' RKB. MEASURED BHP @ 9050 'RKB (3848 PSI) UNABLE TO DRIFT DMY WHIPSTOCK DRIFT PAST SSSV @ 1806' RKB. BRUSH TBG TO 3222' SLM WHERE TOOLS WERE TEMPORARILY STUCK & PACKED OFF WITH SCALE. ABLE TO FREE UP TOOLS. RDMO FOR PLAN FORWARD. NOTE: TAG DEPTH CONFIRMS THE NEED FOR AN FCO. ALSO CONSIDER SCALE BLAST FOR THE TBG WALLS. 4/23/2022 SUPPORT OTHER OPERATIONS (PRE CTD) DDT-SV, MV, SSV (PASSED), PPT-SV, MV, SSV (PASSED) 5/25/2022 SUPPORT OTHER OPERATIONS RUN IN HOLE WITH MOTOR AND MILL. DRY TAG AT 9033' CTMD. CLEANOUT TO HARD TAG AT 9188'CTMD 9212' RKB WITH SLICK SEAWATER. MAINTAIN GOOD 1:1 RETURNS THROUGHOUT. DRIFT WITH 2.65" DUMMY WHIPSTOCK DRIFT TO 9040' CTMD. WELL READY FOR ELINE. 5/27/2022 SUPPORT OTHER OPERATIONS DRIFT W/ 8' X 2 1/8" STEM & 2.25" BAILER & TAG FILL @ 9039' RKB; MAKE SEVERAL BAILER RUNS DOWN TO 9039' RKB (RECOVERING FORMATION SAND, FRAC SAND, AND LARGE CHUNKS OF SCALE (SEE ATTACHMENTS). TARGET DEPTH OF CALIPER IS 9100' RKB. JOB SUSPENDED FOR PLAN FORWARD. 9/1/2022 SUPPORT OTHER OPERATIONS RIH W / ABRADO NZ SCALE BLAST FROM 1700' TO 1900' DRIFT TO TAG AT 9004' CTMD, PERFORM FILL CLEANOUT FROM 9000' CTMD TO 9111' USING SLICK SEAWATER AND GEL SWEEPS AT 2 BPM, MAINTAINED 1:1 RETURNS, LIGHT SAND CONCENTRATIONS OBSERVED, PERFORM INJECTIVITY TEST FROM .25 BPM TO 2 BPM, RIH WITH DUMMY WS DRIFT, JOB IN PROGRESS. 9/2/2022 SUPPORT OTHER OPERATIONS RIH WITH 2.625" DUMMY WS DRIFT TO 9100' CTMD, F/P TBG TO 3500', READY FOR S/L CALIPER LOG, IN PROGRESS. 9/18/2022 SUPPORT OTHER OPERATIONS RIH W/ READ CALIPER. WHP PRESSURE RAPIDLY INCREASING WHILE RIH. TAG UP AT ~1700' AND UNABLE TO WORK TOOLSTRING PAST TAG DEPTH. CONFER W/ CWG AND DECISION MADE TO POOH AND ATTEMPT TO PUMP DIESEL DOWN TBG. WHP DECREASING WHILE POOH. PRESSURE UP TBG WITH TRIPLEX TO 2500 PSI. LOST 50 PSI IN 15 MIN. ICE PLUG SUSPECTED AT ~1700'. BLEED TUBING BACK TO STARTING PRESSURES. JOB SUSPENDED FOR A PLAN FORWARD. 9/28/2022 SUPPORT OTHER OPERATIONS Re-dress unit and spool 2" coil string #8690 in deadhorse. Leave deadhorse at 19:00 hrs. Arrive on 3G-13 at 22:00 hrs. Rig up Coil unit and prepare to test BOP's. 9/29/2022 SUPPORT OTHER OPERATIONS Fill Coil, BOP test 250/4000 psi. P/U Left hand thread 2.80" mill/motor assembly. TAG ICE AT 1696' CTMD, BREAK THROUGH ICE AT 2300' CTMD, CONTINUE TO RIH TO TAG D NIPPLE, MILL NPL FROM 8886' TO 8888' RKB, DRIFT DOWN TO 9097' RKB, F/P TBG TO 2500', READY FOR E- LINE. KRU 3G-13A Summary of Operations CLEANOUT TO HARD TAG AT 9188'CTMD 9212 DRIFT WITH 2.65" DUMMY WHIPSTOCK DRIFT TO 9040' CTMD RUN IN HOLE WITH MOTOR AND MILL. DRY TAG AT 9033' CTMD y CTMD, CONTINUE TO RIH TO TAG D NIPPLE, MILL NPL FROM 8886' TO 8888' RKB 10/3/2022 SUPPORT OTHER OPERATIONS PERFORMED SBHP AND TEMP AT 9050' AND 8884' LOG CALIPER ON 7" CASING AND 3.5" TUBING, FROM 9100' TO 7931' PUNCH 3.5" TUBING AT MIDDLE OF 15FT JOINT PUNCHER PERFORATED INTERVAL = 8880'-8882', CCL TO TOP SHOT = 6.29', CCL STOP DEPTH = 8873.71' 10/4/2022 SUPPORT OTHER OPERATIONS RIH TO DRY TAG PBTD AT 9100' RKB, PUMP 2 WELLBORE VOLUMES OF SLICK SEAWATER, PERFORM INJECTIVITY TEST. PUMP 16.5# CEMENT JOB AS PER PROCEDURE. PRESSURE UP AND HOLD CEMENT SQUEEZE FOR 30 MINS @ 1500 PSI. WASH DOWN WITH POWERVISC DOWN TO 8860' CTMD. CHASE POWERVISC WITH SSW, POOH FREEZE PROTECTING WELL WHILE MAINTING 1400 PSI ON WHP WHILE POOH. 10/5/2022 SUPPORT OTHER OPERATIONS POOH FROM 7000'. FREEZE PROTECT WELL FROM 3000' TO SURFACE WITH SD, MAINTAINING 1400 PSI ON WHP. AT SURFACE HOLD 1700 PSI ON WELL FOR 15 MINS, NO LEAK OFF. CLOSE SWAB VALVE. JET CT STACK, STAND BACK COIL AND RDMO. JOB COMPLETE. 10/8/2022 SUPPORT OTHER OPERATIONS TAG TOC @ 8780' SLM. DRIFT TBG W/ DMY WHIP STOCK DRIFT TO 8780' SLM, NOTE TIGHT SPOT @ 6594' SLM, JOB COMPLETE. 10/18/2022 DRILLING SIDETRACK Complete rig down from 2T-30. Move from 2T-30 to 3G-13. Spot sub and service module over well. 10/19/2022 DRILLING SIDETRACK Rig up CDR3 to 3G-13, accept @ 03:00. Complete RU checklist. Test BOPE, witness waived by Brian Bixby AOGCC. PD BHA #1, straight motor and 2.98" HYC bi center bit. RIH to midnight depth of 6,437'. 10/20/2022 DRILLING SIDETRACK Continue in hole, tie into HRZ and displace well bore to milling fluid. Milled cement from 8,778' to D-nipple at 8,886'. POOH. LD BHA #1 over a dead well. PU BHA #2, 0.9° AKO motor and slick 2.80" D331 mill. Dry tag @ 8886'. Mill 2.80" pilot hole to a midnight depth of 9,093'. 10/21/2022 DRILLING SIDETRACK Continue to mill ahead from 9,093' to 9,100'. Tie into HRZ for +6' correction. Dry drift and tag at 9,106'. POOH and LD BHA #2, pilot hole milling assembly. PD BHA #3, 24-arm memory caliper, RIH & log caliper from 9,100' to 8,500'. POOH,& PUD. PD BHA #4, BOT whip stock. RIH and set TOWS @ 9,038' with tray oriented HS. POOH and PUD BHA #4. 10/22/2022 DRILLING SIDETRACK Continue to PUD BHA #4 WS setting assembly. PD BHA #5, Window milling assembly. RIH and tag TOWS @ 9,038'. Mill exit window and rat hole from 9,038'-9,058'. POOH and PUD BHA #5. Pump slack and trim pipe. New CT length 19,001'. 10/23/2022 DRILLING SIDETRACK Continue to re-head coiled tubing. Pressure and pull test new connector to 4kpsi and 35 k lbs respectively. PD BHA #6, build/turn drilling assembly with 2.4° AKO motor and new style HCC X33073 bit. RIH and drill build from 9,059' to 9,565'. POOH, PUD BHA #6 and PD BHA #7, A lateral ERD drilling assembly, Strider agitator, 0.6°AKO motor over new style HCC X33073 bit. RIH, measure BHP at 12.3 ppg EMW, log RA tag @ 9,045'. Drill build from 9,565' to midnight depth of 9,831'. TAG TOC @ 8780' SLM PUNCH 3.5" TUBING AT MIDDLE OF 15FT JOINT PUNCHER PERFORATED INTERVAL = 8880'-8882 g RIH and set TOWS @ 9,038' Above red line is the plug/abandonment of the primary wellbore. Below the red line is the ST operation. -WCB DRIFT TBG W/ DMY WHIP STOCK DRIFT TO 8780' SLM, NOTE TIGHT SPOT @ 6594' SLM @ Milled p cement from 8,778' to D-nipple at 8,886 PUMP 16.5# CEMENT JOB AS PER PROCEDURE. PRESSURE UP AND HOLD CEMENT SQUEEZE FOR 30 MINS @ 1500 PSI 10/24/2022 DRILLING SIDETRACK Continue to drill ahead using Alpine beads to mitigate extremely poor weight transfer from 9,831' to scheduled, long wiper at 10,818' Pull wiper back to window, tie into RA tag for depth control and RBIH. While RIH, experienced BHA failure, spike in bore pressure and reduction in pump rate. POOH, PUD BHA #8. Found internals of Strider agitator on top of mud motor. Replaced agitator with NOV agitator and fresh 0.6 ° AKO motor, PD BHA #8. RIH and drill ahead to midnight depth of 10,848. Struggle to get drilling, extremely poor weight transfer. 10/25/2022 DRILLING SIDETRACK Continue to drill ahead slowly with poor weight transfer from 10,848' to 11,200'. Perform a wiper trip at 11,200'. Drill ahead to midnight depth of 11,581'. 10/26/2022 DRILLING SIDETRACK Continue to drill ahead slowly with poor weight transfer from 11,581' to 11,591'. Perform a wiper trip at 11,591'. BOBD from 11,591' to 12,193'. 10/27/2022 DRILLING SIDETRACK Drill ahead from 12,193 to 12,351' where TD was called. Pull swab wiper, RBIH, measure BHP of 11.85 ppg EMW. Confirm TD, lay in LRP, displace well to 12.1 ppg KWF, LD drilling assembly over a dead well, MU lower liner segment w/33 jts slotted LNR. 10/28/2022 DRILLING SIDETRACK RIH and release liner on depth. Bottom at 12,351'. MU and RIH with middle section of liner. Could not get it down and POOH for CO BHA. At surface pulled coil connector out of coil. Inspect injector, rehead coil and MU overshot fishing BHA #11. 10/29/2022 DRILLING SIDETRACK POOH with middle section of liner and BHA. Made a clean out run. 10/30/2022 DRILLING SIDETRACK RIH with middle section of liner and BHA. Release liner on depth. POOH. RIH with upper section of liner. Release liner on depth. POOH. 10/31/2022 DRILLING SIDETRACK BOPE test 11/1/2022 DRILLING SIDETRACK Drill AL1 lateral 11/2/2022 DRILLING SIDETRACK Drill AL1 lateral finished drilling TD @ 11048' condition well laid in LRP & KWF p/u lower liner 32 joints of slotted liner RIH to TD 11043' 11/3/2022 DRILLING SIDETRACK Drill AL1 lateral 11/10/2022 SUPPORT OTHER OPERATIONS DRIFT W/ MAG STEM & 2.60" MAGNET DOWN LINER TOP @ 8880' RKB; MEASURED BHP (3541 PSI) @ 8870' RKB; BRUSH n' FLUSH TBG & 4' INTO LINER TOP; SET 2.72" NORTHERN SOLUTION LTP W/ R-PLUG & RSG SEAL GUIDE @ 8875' RKB (OBTAIN GOOD TBG TEST); PULLED 1.78" R-PLUG & SEAL GUIDE @ 8883' RKB. JOB COMPLETE Pa g e 1 / 1 Ce m e n t S q u e e z e 3G - 1 3 Ce m e n t De s T y p e C e m e n t e d S t r i n g S t a r t D a t e E n d D a t e J o b C e m e n t C o m p C e m e n t S u p O b j E v a l M e t h o d E v a l R e s C o m Ce m e n t S q u e e z e S q u e e z e P R O D U C T I O N , 9, 3 0 1 . 2 f t K B 10 / 4 / 2 0 2 2 1 0 / 5 / 2 0 2 2 S U P P O R T OT H E R OP E R A T I O N S - AB A N D O N M E N T 5/ 2 7 / 2 0 2 2 0 5 : 3 0 Ha l l i b u r t o n En e r g y S e r v i c e s su c c e s s Ce m e n t S t a g e s St g # D e s O b j C o m T o p ( f t K B ) B t m ( f t K B ) T o p M e a s M e t h P u m p S t a r t D a t e P u m p E n d D a t e To p Pl u g ? Bt m Pl u g ? Q P u m p I n i t (b b l / m i n ) Q P u m p Fi n a l (b b l / m i n ) Q P u m p A v g (b b l / m i n ) P P u m p Fi n a l ( p s i ) P P l u g Bu m p ( p s i ) P H e l d ( p s i ) P R e l D a t e T y p e 1 C e m e n t S q u e e z e S u c c e s s 5 b b l 1 6 . 5 # N e a t 20 b b l s 1 6 . 5 # w i t h 1 . 5 P P G C e m n e t 5 b b l s 1 6 . 5 # N e a t 8, 8 6 5 . 0 9 , 0 9 5 . 0 1 0 / 4 / 2 0 2 2 1 0 / 5 / 2 0 2 2 N o N o Sq u e e z e Ce m e n t F l u i d s Fl u i d Es t T o p (f t K B ) Es t B t m (f t K B ) M i x e d D a t e P u m p S t a r t D a t e P u m p E n d D a t e O b j C l a s s Am o u n t (s a c k s ) Mi x H 2 0 Ra t i o (g a l / s a c k ) Wa t e r S o u r c e Yi e l d (f t ³ / s a c k ) Vo l Pu m p e d (b b l ) Ex c e s s (% ) Fi l t r a t e (m L / 3 0 m i n ) De n s (l b / g a l ) F l u i d D e s C o m Sq u e e z e Pe r f o r a t i o n s 8, 8 6 5 . 0 9 , 0 9 5 . 0 1 0 / 4 / 2 0 2 2 1 0 / 5 / 2 0 2 2 M e t G Originated: Delivered to:31-Oct-22Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 1B-09 50-029-20655-00 N/A Kuparuk River Multi Finger Caliper Field & Processed 29-Sep-22 0 12 1J-102 50-029-23317-00 N/A Kuparuk River Injection Profile Field- Final 9-Oct-22 0 13 1J-102 50-029-23317-00 N/A Kuparuk River Injection Profile Field- Final 10-Oct-22 0 14 3G-13 50-103-20137-00 N/A Kuparuk River Multi Finger Caliper Field & Processed 21-Oct-22 0 15678910PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:1B-09 PTD: 181134 T372121J-102 PTD: 206110 T372133G-13 PTD: 190116 T372143G-1350-103-20137-00 N/AKuparuk RiverMulti Finger CaliperField & Processed21-Oct-2201Kayla JunkeDigitally signed by Kayla Junke Date: 2022.11.02 08:48:27 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-10-03_22055_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22055 KRU 3G-13 50-103-20137-00 Caliper Survey w/ Log Data 03-Oct-221 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:190-116 T37163 Kayla Junke Digitally signed by Kayla Junke Date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y Samantha Carlisle at 3:20 pm, May 03, 2022 'LJLWDOO\VLJQHGE\-DPHV-2KOLQJHU '1 & 8628 &RQRFR3KLOOLSV2 :HOOV&RLOHG7XELQJ 'UOOLQJ&1 -DPHV-2KOLQJHU ( -DPHV-2KOLQJHU#FRSFRP 5HDVRQ ,DPWKHDXWKRURIWKLVGRFXPHQW /RFDWLRQ \RXUVLJQLQJORFDWLRQKHUH 'DWH )R[LW3')(GLWRU9HUVLRQ -DPHV- 2KOLQJHU ;; 97/ 97/ ; ; %23 WHVW WR SVLJ $QQXODU SUHYHQWHU WHVW WR SVLJ 12 ; ; 97/ '65'/% 97/ -/& Jeremy Price Digitally signed by Jeremy Price Date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tate of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg.1-% DATE: Tuesday, August 6, 2019 P.I. Supervisor 1\ / i 81ci (I q SUBJECT: Mechanical Integrity Tests l ConocoPhillips Alaska, Inc. 3G-13 FROM: Adam Earl KUPARIJK RIV UNIT 3G -I3 Petroleum Inspector Ste: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3G-13 IInsp Num: mitAGE190805110724 Rel Insp Num: API Well Number 50-103-20137-00-00 Inspector Name: Adam Earl Permit Number: 190-116-0 Inspection Date: 8/3/2019 i Packer Depth Well 1 3G-13 Type Inj w 'TVD 5771 - Tubing PTD 9m160 Type Test srT Test psi 1500 IA BBL Pumped: 2.i BBL Returned: z -� OA Interval? _--4vRTST P/F Notes: MIT/IA Pretest Initial 15 Min 30 Min 45 Min 60 Min 2720 2720 2720 27220 520 1800 1740 1720 ' 350 450 - 460 460 Tuesday, August 6, 2019 Page I of I 441 MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Friday,August 21,2015 Jim Regg c P.I.Supervisor �el? 1 131 i 5 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3G-13 FROM: John Crisp KUPARUK RIV UNIT 3G-13 Petroleum Inspector Src: Inspector Reviewed By P.I.Supry J 6/2— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3G-13API Well Number 50-103-20137-00-00 Inspector Name: John Crisp Permit Number: 190-116-0 Inspection Date: 8/15/2015 Insp Num: mitJCr150821101102 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well r 30-13 Type Inj C' 'TVD 5779 Tubing 3311 i 3313 "T 3312 3312 PTD 190H6° (Type Test,SPT Test psi 1500 " IA 1240 2000 - 1950 - 1 1935 - Interval 4YRTST P/F ! P ✓ OA 10 ' 10 10 10 - Notes: 1.5 bbls pumped for test. - SCANNED . a '; f. ,: Friday,August 21,2015 Page 1 of 1 Pages NOT Scanned in this Well History File XHVZE 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. /¢(~)-//~' 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 various kinds Other COMMENTS: Scanned by: Bevedy Bm~han Lowell Date:,.,.,~ Is/~ [] T° RE-SCAN Notes: Re-Scanned by: Beverly Bren Vincent Nathan Lowell Date: ~si NOTScanned.wpd 0 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, September 08, 2011 TO: Jim Regg p� P.I. Supervisor I �'"y l t �l (t SUBJECT: Mechanical Integrity Tests l CONOCOPHILLIPS ALASKA INC 3G -13 FROM: Jeff Jones KUPARUK RIV UNIT 3G -13 Petroleum Inspector Src: Inspector Reviewed By: r P.I. Supry J0 NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3G - 13 API Well Number: 50 - 103 - 20137 - 00 - 00 Inspector Name: Jeff Jones Insp Num: mitJJ110906082044 Permit Number: 190 - 116 - Inspection Date: 8/30/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I __ 3G -13 Type Inj. w I TVD 5779 IA — 1550 3229 ' 3131 3116 ' P.T.D 1901160' TypeTest Test psi I — 1500 " I OA 360 530 530 530 Interval 4YRTST P/F P • Tubing 2665 2667 2665 2665 Notes: 4 BBLS diesel pumped. I well inspected; no exceptions noted. Thursday, September 08, 2011 Page 1 of 1 ~ ~ COr1 / . . ocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 11, 2009 . Mr. Tom Maunder ~ ~ ~ ~ Alaska Qil & Gas Commission 3~ 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 f~~~;~, Ft a~~: . . .. . ~t ~ ~ ~ * ~ J ~. • ,,. Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 30~' 2009 and the corrosion inhibitor/sealant was pumped August 8~', 9~' and 10~` 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please ca11 Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ~~~~ MJ Lov land ~i~ ~ ConocoPhillips Well Integrity Projects Supervisor ~ ~ ConocoPhillips Alaska inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 08/11/09 ~~ ~~ ~~ o ~., o.,,, elt Name PI # TD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date .,.K Corrosion inhibitor . Corrosion inhibitor/ sealant date bbis a~ 3G-12 50103201310000 1900730 24' 4.00 20" 7/30/2009 4.25 8/10/2009 3G-13 50103201370000 1901160 17" n/a 17" n/a 2.97 8/10l2009 3G-15 50103201390000 1901210 18" n/a 18" n/a 2.97 8/10/2009 3G-23 50103201440000 1901320 17" n/a 17" n/a 1.27 8/10/2009 3H-02 50103200830000 1871070 21" n/a 21" n/a 3.82 8/8/2009 3H-06 50103200780000 1870780 8'5" 2.00 18" 7/30/2009 5.52 8/8/2009 3H-07 50103200790000 1870790 17" n!a 17" n/a 2.97 8/8/2009 3H-09 50103200860000 1871120 17" n/a 17" n/a 5.52 8/8/2009 3H-10B 50103200870200 2031600 16" n/a 16" n/a 2.55 8/8/2009 3H-12 50103200880000 1871290 2'7" n/a 2'7" n/a 8.92 8/9/2009 3H-15 50103200820000 1871030 19" n/a 19" _ n/a 3.4 8/9/2009 3H-16A 50103200960100 2000220 15' 2.75 17" 7/30/2009 1.7 8/9/2009 3H-18 50103200950000 1880090 SF n/a 17" n/a 5.52 8/9/2009 3H-20 50103200930000 1871340 16' 3.75 16" 7/30/2009 2.25 8/9/2009 3H-22 50103200970000 1880110 27'6" 4.25 21" 7/30/2009 8.5 8!9/2009 3H-25 50103202030000 1990400 30" n/a 30" n/a 7.65 8/9/2009 3H-26 50103202080000 1940290 SF n/a 9" n/a 2.12 8/9/2009 3H-28A 50103202360100 1960370 SF Na 18" n/a 5.1 8/9/2009 3H-32 50103203220000 2000010 10" n/a 10" n/a 1.27 8/9@009 3K-102 50029233786000 2071650 ~/a n/a 5" Na 1.27 8/8/2009 3Q-01 50029222200000 1911250 15'7" 2.00 17" 7/30/2009 4.25 8/8/2009 3Q-02 50029216880000 1870040 41' 4.75 21" 7/30/2009 5.52 8/8/2009 3Q-04 50029222190000 1911240 4'10" 1.50 16" 7/30/2009 4.25 8/8/2009 3Q-07 50029216820000 1861940 6" n/a 6" n/a 1.7 8!9/2009 3Q-12 50029216770000 1861890 7" n/a 7" Na 2.97 8/8/2009 3Q-13 50029216640000 1861760 44'6" 5.00 21" 7/30/2009 8.92 8!8/2009 3Q-15 500292f6660000 1861780 49'S" 4.50 20" 7/30/2009 9.35 8/8/2009 3Q-16 50029216670000 1861790 46' 5.25 30" 7/30/2009 8.5 8/8/2009 05/12/09 --~ t~ fit Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~~ ~~~ ~; AY ~ ~ 2009 ~I~s~~ tail C~~s ~rarls. ~~rr-~liss~e~r~ ~I~ChOT3~~ Log Description NO. 5228 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 3A-18 AYS4-00069 PERF/SBHP SURVEY - 6 04/26/09 1 1 3C-08 6146-00033 GLS $ = / - OM21/09 1 1 2M-25 B14B-00034 GR/TEMP LOG /9 /- 04/22/09 1 1 1 R-19A AYS4-00065 SBHP SURVEY -r (~ ~' 3~0 ~ 04/23/09 1 1 3G-13 AYS4-00067 SBHP SURVEY - ( 04/24/09 1 1 3G-05 AYS4-00066 SBHP SURVEY 04/24/09 1 1 3F-07 6148-00038 SBHP SURVEY - ~ 04/24/09 1 1 3F-08 6148-00037 SBHP SURVEY 04/24/09 1 1 3M-25A 614B-00040 SBHP SURVEY 04/25/09 1 1 3K-08 B14B-00039 SBHP SURVEY C~ 04/25/09 1 1 2N-318A AWJI-00026 MEM BHP SURVEY -d 04/27/09 1 1 2Z-07 8146-00045 SBHP SURVEY L 04/29/09 1 1 2Z-O1A B14B-00044 SBHP SURVEY ~-_ 4 04/29/09 1 1 3K-102 ANHY-00080 GLS 04/30/09 1 1 2W-06 604C-00036 PRODUCTION PROFILE 05/02/09 1 1 2W-12 604C-00037 PRODUCTION PROFILE - p~ j 05/03/09 1 1 3C-02 B04C-00045 POWERCUTTER W/SBHP SURVEY 05/09/09 1 1 1 J-120 604C-00043 GLS ~ 0 0 05/08/09 1 1 31-11 B04C-00044 SMALL TBG PUNCH W/SBHP 05/08/09 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • ~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # s ' r~ ~r;.'c. ~ wLr.. Log Description NO. 5203 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 3F-03 ANHY-00070 INJECTI 2D-03 ANHY•00075 ON PROFILE - ~ ~ PRODUCTIO 04/04/09 1 1 E-29 G-13 3F-18 B04C-00030 ANHY-00079 B04C-00031 N PROFILE _ - PRODUCTION PROFILE l 9 INJECTION PROFILE c/ PRODUCT 04/10/09 04/14/09 04/15/09 1 1 1 iD-117 B14B-00027 ION PROFILE / - INJECTION P 04/15/09 1 iD-128 AYS4-00057 ROFILE '}- INJECTION PROFILE 04/16/09 04/16/09 1 1 1 H-21 1 D-120 B14B-00028 AYS4-00058 PRODUCTION PROFILE _ L INJECTION PROFI 04/17/09 1 21(-22 1 E-15 AYS4-00059 AYS4-00061 LE IBP/SBHP - INJECTION PROFILE 04/17/09 04/18/09 1 1 1Y-04 3F-02 AYS4-00071 AYS4-00063 ~. - INJECTION PROFILE PRODUCTION PROFILE ~'- - 04/20/09 04/28/09 04/22/09 1 1 1 1 G-04 1R-03A 8146-00036 AYS4-00063 SBHP SURVEY `~. L° L~ SBHP SURVEY i } -L ~• ~dtb _d~ /( M ~ L 04/23/09 04/23/09 1 1 G-06 ~ ~ . 1 B14B-00035 SBHP SURVEY ~ •g~ l ~~ ~- ~~-~ Q ~~~ 04/23/09 1 1R-10 2F-02 i R-15 6146-00031 AYS4-00060 8148-00032 SBHP SURVEY - ~~ c INJECTION PROFILE ~} L+ -- /~ I c.~ SBHP SURVEY ~ ' - ~ 04/20/09 04/19/09 1 1 . - } L 04/20/09 1 04/30/09 L_J Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor l<r2rr BI3D! D7 DATE: Wednesday, August 22, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA fNC 3G-13 KUPARUK RlV UNIT 3G-13 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ",Ø- Comm NON-CONFIDENTIAL Well Name: KUPARUK RN UNIT 30-13 API Well Number: 50-103-20137-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070820 I 7 I 739 Permit Number: I 90-116-0 Inspection Date: 8/20/2007 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3G-13 Type Inj. G TVD 5779 IA 1650 2470 2440 2440 IP.T. l~lIOU TypeTest ;>rl Test psi 1500 OA 300 360 360 360 Interval 4YRTST P/F P / Tubing 3660 3660 3660 3660 Notes: Pretest pressures observed for 30+ minutes and found stable. ../ SCANNED S E P 1 0 2007 Wednesday, August 22, 2007 Page I of I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test DATE: OPERATOR REP: AOGCC REP: Email to: Tom_Maunder@admin.state.ak.us and Bob_Fleckenstein@admin.state.ak.us OPERATOR: ConocoPhillips Alaska Inc. FIELD / UNIT / PAD: Kuparuk/KRU/3G 08/04/03 Arend/Brake- APC Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. P'T'D'I1900840IITypeTestP I TestpsiI 1500 I Casing I 13501 24601 24201 24201 P/F Notes: 2 Yr MIT required by internal Waiver Well J3G-12 J Typelnj P.T.D. J 1900730 Type Test Notes: T.V.D. I 5686 I Tubingl 23501 23501 23501 23501 Interval Test psiI 1500 I Casing I 125O1 235O1 23OO1 228O1 P/F P.T.D. I1901160 TypeTest Test psiI 1500 I Casing I 11401 24001 23801 23801 P/F Notes: P.T.D. I1901210IITypeTestP I Test psil 1500 I Casing I 12401 24501 24251 24251 P/F Notes: A header pressure anonomile occurred right before the start of the test Well 136-16 I Type Inj P.T.D. I1901040 Type Test Notes: T.V.D. I 5764 ITubin! TestpsiI 1500 I Casin! 31001 31001 31001 31001IntervalI i~ 13001 24001 24001 24001 P/F Well 13G-24 P.T.D. 11901340 Notes: Type Test Test psiI 1500 I Casing I 12001 21001 21001 21001 P/F Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R - Internal Radioactive Tracer Survey A -- Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover O = Other (describe in notes) MIT Report Form Revised: 05/19/02 S(;ANN~D SEP ~. ~i ?_0[~3 MIT KRU 3G 08-04-03.xls 8/5/2OO3 MEMORANDUM TO: Randy Ruedrich Commissioner THRU: Jim Regg "'~ P.I. Supervisor State of Alaska Alaska 0il and Gas Conservation Commission FROM: Well[ 3G-10 I P.T.D. I 19o-o~ I DATE: August 4, 2003 SUBJECT: Mechanical Integrity Test Conoco Phillips 3G Pad KRU Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. I Type Inj.I S I T.V.D. I 5789 I Tubing I 2000 [2000 I 2000 12000 I TypetestI P ITestpsil 1447 I Casingl 1350I 2460I 2420I 2420I P/F I P I Notes: WellI 3G-12 P.T.D.I 190-073 Notes: Welll 3G-13 P.T.D.I 190-116 Notes: WellI 3G-15 P.T.D.I 190-121 Notes: WellI 3G-16 P.T.D.I 190-104 Notes: WellI 3G-24 P.T.D.I 190-134 Notes: I Type testI P I Testpsil 1422 I CasingI 1250I 2350I 2300I 2280I P/F I P I Typelnj.I e I T.V.D. 15779 I Tubing 13850 13850 13850 13850 I'nterYa'l 4 I Type testI P I Testpsil 1445 I CasingI 1140I 2400I 2380I 2380I P/F I --P I Type,nj.I C I T.V.D. 15727 I T.bing 14000 14000 14000 14000 I lntervall 4 I Type testI P I Testpsil 1432 I Casingl 1240I 2450I 2425I 2425I P/F I-P ITypelnj.I e I T.V.D. I 5764 I Tubingl 3100 I 3100 I 3100 I 3100 I lntervall 4 TypetestI P ITestpsil 1441 I Casingl 1300 I 2400 I 2400 I 2400I P/FI P I Type,.j.I s I T.V.D. 15716 IT.bing 12350 12350 12350 12350 I,nterYa, I 4 Type testI P I Testpsil 1429 ICasingI 1200I 2100I 2100I 2100I P/F I P Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to Conoco Phillips 3G Pad in the Kupamk field and witnessed the routine 4 year MIT's on the above listed 6 wells. The pretest pressures were observed and found to be stable. The standard annulus pressure tests were then performed with all wells demonstrating good mechanical integrity. M.I.T.'s performed: _6 Number of Failures: O Attachments: Total Time during tests: 4 hours CC: MIT report form 5/12/00 L.G. SO~NiEE~:' ,~U~ ?, _1 2_003 2003-0804 MIT KRU 3G-24 cs.xls 8/15/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: . Abandor) . I-'1' i Suspend I-'] OperatiOn Shutdown. I~1 · Perforate [--I Variance I~1 Annular Disp. [--'1 · · . · .. . . '.. .. . . · .. · AIt~'r.C~sing ....El ..... RePai~?el!...,..C · .Plug Perf0rat~ns. .... "':r-'~. '.'. .... Stimulate 'El' ....':Time'Ex[~hsi0~ ' E] ' Other 'i'.", Ch~nge':A."~P!6v~'rr~gmm' ':ir'-I:":'...'PQi!Tu~i,g'..El "P~dorate'NewP001":"'i.~'.::;':.~'I' .." "" Re-enterS'u~pen~J~';~ll .....r-'l .:i4:'Curren't Well stattisi.~...~.!~. '..:. :'.. :, · ......... · "'. 5. Permit to Drill Number: 2. Operator Name: ":' '.'; ~e~,; ~n~;~; ' ": ': ': i~ "."". '" ~ ~i~/':" ConocoPhillips Alaska, Inc. . id ............ ~ ...... El.. 190-116/ · St'r~iig~a'~iC'' BI i'"'.' ."$~/i~e.' ..r'~'l· 6. APl Number: 3. Address: · · P. O. Box 100360 ,i." '':': '" . ...... = ...... ',.....:... 50-103-20137-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 90' 3G-13 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9320' feet true vertical 6063' feet Plugs (measured) Effective Depth measured 9212 feet Junk (measured) true vertical 5994 feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 115' 16" 115' 115' SUR. CASING 4176' 9-5/8" 4266' 3199' PROD, CASING 9211' 7" 9301' 6051' . Perforation depth: Measured depth: 8966 - 9088 RE CE ~./E,D true vertical depth: 5841- 5915 JUL 0 t~ ,003 Tubing (size, grade, and measured depth) 3-1/2", J-55, 8894' MD. ~SS~(S gi~ ~ ~?i~S" Packers & SSSV (type & measured depth) pkr= CAMCO 'HRP-I-SP' RETR. pkr= 8862' SSSV= SSSV SSSV= 1806' · :12. stimulation Or cement Squeeze summary:: . .. ,. ...' .. . · '.' .. ' : . · . . . "Intervalstr~ated.(meas~red) "N/A '." ' ..' · · . . · . ::,.. Treatment descriptions including volumes used and'final.pressure: . . .. .... .' ......... · . 13.' '. " .... "· · .... .. RepreSentative Da!ly Average'Ptoducti0n o'r Injection'Da~ta ". .. .. :. . .... ' ..... .' , 'OiI-Bbl .' ..... .. Gas-Mcf ' ' '..." ". · :', ' 'wa'te~Bbl" Casin,q' Pressure. ' Th'bin,q Pressure " .Pdor t~ We"i0Pera[i0r~ ..... .. ' .' '. ".' 2:.i. 100.. ' ' '50 ...... ' 2i73 .' . Subsequentto'operation ... ' · · .11871 . · .... "'.... .. 50. '":" ... 3683. :14~.:Attachments · · ~ .15. Well Class after proposed work: : : ' .... · · . . · . · .: 'C~pies of L~)gs and Si~rveys'tun __. Exploratory .[-'~ Devel0pme~t r-] Service r'~ .., · ... . · .. . . DailY/' RepOrt of .Well Operations _X .t 6. Weli StatUs after pr~p0sed w(~rki · O!ll--'l '" G~s r'-I ' wAG[~'i GINJr--] WINJ'I--I ' WDSpLr-i 17. I hereby certify that the foregoing i.s true and correct to the best of my knowledge. I Sundry Number or N/A if C.C. Exempt: I Contact Jeff spencer @ 659-7226 · Printed Name //3 I:~be~l't D. C~is..teRsa~'~ Title Production Engineering Technician ....... Signature /~,~~,~/~~" Phone .... ,. ~ ,,,-.,,~ 659-7535 Date ~////~.ii:!'!'i.i ii!~, iCAi NED JUL I $ 2003 Form 10-404 Revised 2/2003 · RBDMS BFL JUl_ 0 8 2003 ORi$tNAL SUBMIT IN DUPLICATE 3G-13 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary o61291o31commenb~,'d:WAG:.;EOB Injection .:~.":"'.i.'.:: '"' "' .. ' ' I I i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: Operation Shutdown __ Pull tubing Alter casing Stimulate Plugging Repair well Perforate Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. ©. Box 100360, Anchorage, AK 99510 5, Type of Well: Development _ Exploratory _ Stratigraphic _ Service X 4. Location of well at surface 2538' FNL, 5' FWL, Sec. 24, T12N, R8E, UM At top of productive interval 2097' FNL, 1429' FWL, Sec. 26, T12N, R8E, UM At effective depth 2248' FNL, 1313' FWL, Sec. 26, T12N, R8E, UM At total depth 2312' FNL, 1260' FWL, Sec. 26, T12N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 9320 feet 6063 feet Plugs (measured) 6. Datum elevation (DF or KB) 90'., RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3G-13 9. Permit number/approval number 90-116 10, APl number 50' 103-201,37/94-320 11, Field/Pool Kuparuk River Oil Field/Pool None Effective depth: measured 9 21 2 true vertical 5993 feet feet Junk (measured) None 13. Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 220 SX AS I 900 SX AS III & 590 SX CLASS G 200 SX CLASS G 80' 1 6" 4231' 9-5/8" 9266' 9-5/8" measured 8966' - 9030', 9048' - 9088' true vertical 5841' - 5880', 5890' - 5915' Tubing (size, grade, and measUred depth) 3.5", 9.3#, J-55 @ 8894' Packers and SSSV (type and measured depth) PKR: Camco HRPI-SP @ 8862' SSSV: CAMCO TRDP-1A-SSA @ 1806' Stimulation or cement squeeze summary ~/~/ CONVERT WELL FROM OIL PRODUCER TO WATER INJECTOR Intervals treated (measured) Measured depth 115' 4266' 9301' True vertical depth 115' 3200' 6051' RECEIVED APR - 6 995 ~,!~s~,a 0it & Gas Cons. Commission ~,nr, hnr; Treatment description including volumes used and final pressure 14. Representative D~ily Average Production or In!ection Data OiI-Bbi Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation -519- -1273- -228- -1295- -178- Subsequent to operation -0- -0- -3400- -825- -1400- 15. Attachments CoDies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 09/12/90 Title Wells Superintendent SUBMIT IN DUPLICATE STATE OF ALASKA ALAGKA OIL AND GA8 COI~ERVATION COMMISSION Mechanice. J ln'tegri~. Test OPERA[OR: FIELD t UHtl' I PAD: PRETES] PACKER I]ECI I Tt~G -'- ~ CAS, lNG TBG TEST. J ::CSG ............. L_ g ..... GOOD ~S T 30 MIN TIME TBG cS(; 750 740 -] START 'TINE COMUENTS COMMENI'$. OOMMENI8 'IUBING INJECTiO# R_UlD: P = PRC'~IJ~D WATER INJ S ~ ~LT WATER INJ ~ ~ MISCIBLE INJ ]= I~ECTIOH ~,~ = NOT [P~JECTIHG ANNULAR FLUID: DIESEL GLYCOL SAL1 VVA fFR DRILLING Mt ~D OTHER r~; ~ P.P.G. Grad. z;'/5.? AOGCC REP ' OP~i;~,TOR REP JCg&AQCD.XI_S WE~. TEST: Instal 4. Year W(~-knver Other Edc [u span FI-051 (R~v. WcJ3) ! i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well Change approved program _ Operation Shutdown __ Re-enter suspended well __ _ Plugging_ Time extension _ Stimulate __ Pull tubing __ Variance __ Perforate __ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development . X.. Exploratory _ Stratigraphic _ Service 4. Location of well at surface 2538' FNL, 5' FWL, Sec. 24, T12N, RSE, UM At top of productive interval 2097' FNL, 1429' FWL, Sec. 26, T12N, At effective depth 2248' FNL, 1313' FWL, Sec. 26, T12N, At total depth 2312' FNL, 1260' FWL, Sec. 26, T12N, R8E, UM R8E, UM R8E, UM 12. Present well condition summary Total Depth: measured 9 3 2 0 true vertical 6063 feet feet 6. Datum elevation (DF or KB) RKB 90 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3G-13 9. Permit number 90-116 10. APl number 50-1 03-201 37 11. Field/Pool Kuparuk River Oil Field/Pool Plugs (measured) None ORIGINAL Effective depth: measured 9 21 2 true vertical 5993 feet feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 80' 1 6" 4231' 9-5/8" 9266' 9-5/8" 220 SX AS I 90O SX AS III & 590 SX CLASS G 2OO SX CLASS G measured 8966'- 9030', 9048' 9088' true vertical 5841' - 5880', 5890' - 5915' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 8894' Packers and SSSV (type and measured depth) PKR: Camco HRPI-SP @ 8862' SSSV: CAMCO TRDP-1A-SSA @ 1806' Measured depth 115' 4266' True vertical depth 115' 3200' 9301' 6051 ' RECEIVED DEC - 1 1994- Aiaska 0il & Gas Cons. Commission Anch0r;, '~ 13. 14. 16. Attachments Description summary of proposal ~ CONVERT WELL FROM OIL PRODUCER TO WATER INJECTOR Detailed operation program BOP sketch Estimated date for commencing operation 12/1/95 If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas Suspended Se,vice X ~_WATER INJECTOR ) 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~ f ~ Title Wells Superintendent FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity .. BOP Test _ Location clearance Mechanical Integrity Test ~ Subsequent form require 10- Approved Copy Original Signed By Returne(~ 2- Approved by order of the Commission David W. Johnston cb~missioner oate Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE IApproval ~1o. _~, Attachment 1 ~,onversion to Water Injection Kuparuk Well 3G-13 ARCO Alaska requests approval to convert Well 3G-13 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 8966' and 9088'. 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. STATE OF ALASKA AL~;~r~A OIL AND GAS CONSERVATION CON, .... SSION .... WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [~ GAS r'-] SUSPENDED r"-] ABANDONED r-'] SERVICE r'"] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90-116 3 Address j~ ~ C F~~.~ 8 APl Numbe~ P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20137 4 Location of well at surface --4 .......... - ..... ~"'~"~ 9 Unit or Lease Name At Top Producing Interval 'Sur~ """) ~! ~!t~O~j 10 Well Number At Tota Depth '· " Anchorage 11 Field and Pool 2312' FNL, 1260' FWL, SEC 26, T12N, R8E, UM KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 90'I ADL 25548 ALK 2662 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 116 No. of Completions 9/21/90. 9/26/90. 1/06/91. NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 9320' MD, 6063' TVD 9212' MD, 5993' TVD YES X[~.J NO U 1806, feet MD 1600' APPROX 22 Type Electric or Other Logs Run EWR/C N/SF D/DGR/CET/CBL/GYRO 23 CASING, LINER AND CEMENTING RECORD SE]rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'[TONI HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 220 SX AS I 9-5/8" 36~ J-55 SURF 4266' 12-1/4" 920 SX AS II1~ 590 SX CLASS G 7" 26# J-55 SURF 9301' 8-1/2' 200 SX CLASS G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) pACKER SET (MD) 3-1/2' 8894' 8862' 9048'-9088' W/4-1/2" CSG GUN @ 4SPF MD 5890'-5915' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR DIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~- 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ~0. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 8968' 5842' NA KUPARUK C BOTTOM 9016' 5871' KUPARUK A TOP 9016' 5871' KUPARUK A BOTTOM 9170' 5966' . ., 31. LIST OF ATTACHMENTS GYRO 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed //~/~ ~~ Title /ail~EA DRILLING ENGINEER Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion repeal and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pedinent 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 O,'~ .,nd~Ga~ '-" ~:I? ~1~ Well History- Initial Report - Dali; lestm=tlene: Prepare and ~~;~ Wedneldly a~er a well Is spudded or workout o~retlonl are lt~. p~or ~ on the form giving inclusive dates only. Dally wo. District ICoun~,parish or borough i stel, ARCO A~S~ INC. '~' ~ NORTH SLOPE I AK ~.,.~ IL.. or Unit IWell no. KUPARUK I ~L:25548 ALK: 2662 3G-1p Auth. or W.O. no.~ ITitle AK5172 I CO~LETION Operator IARCO W.I. ARCO J 55. 250721 Spudded or W.O. begUnsPUD IDele 09/21/90 IH°ur 23: 30 IPr'°r status if a w'O' Date and depth as of 8:00 a.m. 01/06/91 ( TD: 0 PB: 9212 SUPV:DB/LA 8) Complete record for each day reported NORDIC 1 PERFORATING 9-5/8"@ 4266' MW:10.6 NaCl/Br MOVE RIG F/3G-22 TO 3G-13, ACCEPT RIG 1/5/91 @ 23:30, ND M. ASTER VALVE & THA, SET TP, NU BOPE & TEST,.RU HLS, PERF F/9088'-9068' W/4.5" CSG @ 4SPF 180 DEG PHASE, ALTERNATING BH CHARGES. DAILY:S21,882 CUM:$849,745 ETD:S849,745 EFC:$1~370,000 The above Is correct t see Procedums~ Section 10, ~ Drilling, Pages 86 an~87. Der.. / ITItle AR3B~5~I-D Number ell dally well history forllll coneecutlvely as they are prepared for each well. no. ARCO C.. and Gas Company ~r~ Daily Well History-Final Report - .- , ~ ~.,~-~__~;~ .... Instructions: Prepare and subm~ ~.~ Wednesday after allowable has been assigned or well ia Plugged, Abandoned, or Sold. "Final Report" should be sub '~"..~~'euspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, re~j~t~ltlVe test data in blocks provided. The "Final Repert" form may be used for reporting the entire operation if space is availebl Accounting cost center code District ~'". ICounty or Parish State Fie~dARCO ALASKA INC. I NORTH SLOPE AK I tease or Unit no. KUPARUK I ADL: 25548 ALK: 2662 3G~13 Auth. W.O. or no. ITM AK5172 I COMPLETION cost center prior to plugging and on this ARCO abandonment of this well 5 5.2 5 2 0 Spudded or W.O. begun iDate Hour Prior status if a W.O. SPUD 9/21/90 23:30 Date and depth Complete record for each day reported as of 8:00 a.m. 01/07/91 ( 9) TD: 0 PB: 9212 SUPV:DB/LA NORDIC 1 RIG RELEASE 9-5/8"@ 4266' MW:10.6 Diesel RIH W/GUN #2, PERF F/9068'-9048' W/4.5" CSG GUNS @ 4SPF 180 DEG PHASE WITH ALTERNATING BH CHARGES, RD HLS, RU & RUN 3-1/2" COMP ASSY W/CAMCO 'HRP-1-SP' PKR @ 8862' AND CAMCO 'TRDP-1A-SSA' SSSV @ 1806', TT @ 8894', TEST CL TO 5K WHEN MU TO SSSV & HANGER, DROPPED BALL BEFORE HANGER MU, LAND HANGER, RILDS, PRESS TBG, TO 2500 PSI & SET PKR, HELD 10 MIN HOLD TBG & PRESS ANN TO 1000 PSI, HOLD 10 MIN, BLEED OFF ANN, BOLDS, HOLD 1300 PSI ON TBG, PU & SHEARED PBR BLEED OFF TBG RELAND HANGER, RILDS, TEST SSSV W/700PSI DIFF FOR 15 MIN OK, SET BPV, ND BOP NU 3-1/8" WKM GEN IV 5KSI TREE, TEST PO PULL BPV, SET TP,TEST TREE TO 5000 PSI, TEST CL TO 5000 PSI & OPEN SSSV, TEST CSG & PKR TO 2500 PSI PRESS TBG & SHEAR SOS, REV CIRC 12 BBL DIESEL CAP INTO ANN, INJECT 4 BBL DSL CAP INTO TBG, SITP=450 PSI & FALLING, SICP=0 PSI, 7X9 PA=600 PSI, CHECK VALVE HELD, ND LINES, SECURE WELL RELEASE RIG 1/6/91 @ 23:00 DAILY:S187,546 5~: .,i~. ¢~' "~ ~.~ ~"~ ..... .~; Alaska Oil & Gas Cons. I?~'' Anchorago Classifications (oil, gas, otc.) I Type completion (single, dual, etc.) I Producing method ~ Official reservoir name(s) I Potential test data CUM:$1,037,291 ETD:S1,037,291 EFC:$1,370,000 RECEIVED Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P, Water % GOR Gravity Allowable Effective date corrected The above is correct -~-~t~ J~ ! ~(~,c~/-/'z. I ~/(~[~' (' I"lrillino Supt. AR3B-459-3-C Number all dally well history forms consecutively as they are prepared for each well. iPage no. Dl~lllofl of AtlsntloRk:hfieldCompany A GYRODATA DIRECTIONAL SURVEY FOR ARCO ALASKA INCORPORATED KUPARUK RIVER UNIT, WELL NUMBER 3G-13 NORTH SLOPE BOROUGH, ALASKA. DATE : 06 DECEMBER 1990 , i OFILRED RECEIVED Anchorage 01/02/91 S .P~T LAND DIRECTIONAL DRILLING, INC. fo,~yrodata Services, Inc. C.llent .... :. ARCO ALASKA, INC. ~,C~~ ~% computation...: RADIUS OF CURVA~ Field ...... KUPARUK RIVER UNIT ~. ~.~, ~ &~ Survey Date·..: 11/13/90 Well ....... KRU 3G-13 ' ~%~ \2 ~ RKB Elevation.' 90.00 ft Section at: S,37.82,W ~' ~% ~" Job Number..:.: AKl190G251 Surveyor·.: ROB SHOUP -- -k~ -~%' API Number .... : 50-103-20137 ' === : =_-= ======================= _-_-_-_-_-_-_-_-_- ___-_____ =____: s S .O ON DX .C XO. 'i----DL DEPTH ANGLE BKB 100 0.24 100.0 10.0 . 200 0.21 200.0' 110.0 300 0.34 300.0 210.0 400 0.35 400.0 310.0 500 0.35 500.0 4~0.0 SUB-SEA DISTNCE BEARING FROM-WELL-HEAD -0.2 N 46·24 E ~.~ 0.2 N -0.6 N 54.55 E ~.~f 0.4 N -1.0 N 65·04 E ~-~1 0.7 N -1.5 N 74.76 E 7~,~ 0.9 N -2·0 N 79·25 E ~ 1.0 N 0.1 E 0.4 E 0.8 E 1.4 E 2.0 E DISTNCE BEARING / 100 0.2 N 23.12 E 0.24 0.6 N 41'.15 E 0.0'3 1.0 N 49.57 E 0.13 1.6 N 56.96 E 0..01 2.2 N 62.40 E 0.00 7 600 0.22 600.0 510.0 7 700 1.60 700.0 610.0 7 800 2.20 799.9 709.9 7 900 6.45 899.6 809.6 7 1000 12.68 9.98.2 908.2 7 1100 17.45 1094.7 '1004.7 ? ~20.0 17.'87 1190.0 1100.0 ? ~ ~300 19.81 1284.6 1194.6 ? ~-~400 23.04 1377.7 1287'.7 7 1500 24.41 1469.3 1379.3 -2.3 S 78.24 E ~l,]~ 1.0 N -1.6 S 32.75 W 2~.~ 0.2 S 1.7 S 31.53 W2;I,55 3.0 S 9.2 S 35·00 W~f0ou 9.3 S 25.8 S 33·91 W~I%,~I 23·0 S 51·7 S 34.25 W2~'~- 44.6 S 82.0 S 36.01 W~l~.01 69·4 S 114·3 'S 37·81 WA~%~I 95·2 S 150.8 S 41.24 W~1'~123.4 S 190.9 S 41.99 W~%,~ 153.4 S 2.5 E 3.0 E 1.2 E 2.9 W 12.3 W 26.9 W 44.3 W 63.7 W 87.0 W 113.7 W 2.7 N 67.43 E 0,13 3.0 S 85.62 E 1.38 3.3 S 21.72 E 0.60 9.8 S 17.40 W 4.25 26.1 S 28.15 W 6.23 52.0 S 31.10 W 4.77 82.3 S 32.59 W 0.45 114.5 S 33.80 W 1.95 150.9 S 35.19 W 3.27 191.0 S 36.54 W 1.38 7 1600 27.06 1559.3 1469.3 7 1700 31.99 1646.3 1556.3 7 1800 39.00 1727.7 1637.7 7 ~900 41.47 1804.0 1714.0 7 2000 44.78 1877.0 1787.0 7 2100 46.82 1946.7 1856.7 234.2 S 42.68 W21~,~185.5 S 283.3 S 43.11 W~k%,~ 221.6 S 341.1 S 40·98 W~0,~f264.7 S 405,6 S 41.97 WA~I~ 313.1 S 473·7 S 43·00 W~'00363.5 S 545.1 S 42.54 W~'?~/416.1 S 142.9 W 176.5 W 215.3 W' 258.1 W 304.3 W 352.9 W 234'.2 S 37.61 W 2.65 283.3 S 38.53 W 4.93 341.2 S 39.13 W 7.06 405.8 S 39.50 W 2.51 474.0 S 39.93 W 3.35 545.6 S 40.30 W 2.05 ^Survey Codes: 7/GYRO (RRU3G13G) ~(RU 3G-13 Page 2 01/02/91 MEAS DEPTH 2200 2300 ~"~400 500 2600 INCLN ANGLE 50.61 51.31 53.88 53.41 52.52 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 2012.7 1922.7 620.1 2075.7 1985.7 697.8 2136.4 2046.4 777.2 2195.7 2105.7 857.7 2255.9 2165.9 937.4 2700 55.91 2314.4 2224.4 1018.4 2800 56.32 2370.1- 2280.1 1101.4 2900 56.25 2425.6 2335.6 1184.5 3000 55.92 2481.4 2391.4 1267-.4 3100 55.71 2537.6 2447.6 1350.0 3200 55.62 2594.0 2504.0 1432.4 3300 55.66 2650.5 2560.5 1514.7 3400 55.91 2706.7 2616.7 1597.2 3500 55.78 2762.8 2672.8 1679.6 3600 55.88 2819.0 2729.0 1761.9 55,53 2875.3 2785~3 I843'9 55.49 2932.0 2842.0 1926.1 55.53 2988.6 2898.6 2008.5 55.16 3045.5 2955.5 2090.7 55.02 3102.7 3012.7 2172.6 37'00 3800 9.00 000 100 4200 54.52 3160.4 3070.4 4300 54.04 3218.8 3128.8 4400 54.31 3277.3 3187.3 4500 54.17 3335.7 3245.7 4600 54.20 3394.2 3304.2 , 4700 53.99 3452.9 3362.9 RECORD OF SURVEY · Sur~ey Codes: 7/GYRO 2254.2 2335.2 2416.1 2497.1 2578,1 2659.0 DIRECTION RELATIVE-COORDINATES BEARING FROM-WELL-HEAD S 39.44 W2%~.q9472.8 S S 38.65 W~&%' 533.2 S S 38.92 W&l~,~k595.1 S S 41.40 W2~I,~% 656.6 $ S 40.81 W~O,~ 716.8 S 402.2 W 451.1 W 500.9 W 552.8 W 605.3 W S 39.46 W~t~,q% 778.8 S S 39.24 W~,;~ 843.0 S S 39.91 WA~9'ql 907.1 S S 41.05 W/~,~- 970.2 S S 41.36 W~14~1032.4 S CLOSURE DISTNCE BEARING S 42 15 W~,~1094 0 S S 42]25 W~';~;~'~'-1155]2 S S 41 93 W~'~1216 6 S S 43;58 W~X~,*~2~7;3 S S 44.50 W~;4,fo1336.8 S 620.8 S 40.39 698.4 S 40.24 777.8 S 40.09 858.3 S 40.10 938.2 S 40.18 S 44.8'2 W~%~139'5.6 S S 38.36 WA~,~1457.2 S S 39.61 W~lq,~l1521.2 S S 39.67 W21%~71584.6 S S 40.92 W1~1647.1 S 657.6 W 1019.3 S 40.18 710.2 W 1102.3 S 40.12 763.2 W 1185.5 S 40.08 817.1 W 1268.4 S 40.10 871.6 W 1351.1 S 40.17 S 41.27 WA~'~)1708.7 S S 41.34 W~)~'~.1769.7 S S 41.35 W~u'%I_1830.5 _S. S 41.05 WA~'°~1891.6 S S 40.98 WD~'~1952.8 S 926.6 W 1433.7 S 40.26 982.0 W 1516.2 S 40.37 1037.5 W 1598.9 S 40.46 1093.6 W 1681.5 S 40.57 1151.1 W 1764.1 S 40.73 1209'.~2 W 1846.6 S 40-91 1263.9 W 1928.9 S 40.94 1315.8 W 2011.3 S 40.86 1368.2 W 2093.5 S 40.81 1421.3 W 2175.6 S 40.79 1475.0 W 2257.2 S 40.80 1528.5 W 2338.4 S 40.82 1582.1 W 2419.5 S 40.84 1635.6 W 2500.6 S 40.85 1688.8 W 2581.7 S 40.85 S 41.00 W~'~02013.9 S 1741.9 W W W W W W W W W W W DL /lOO 2662.7 S 40.86 4.22 0.85 2.58 1.67 0.96 3.51 0.44 0.47 0.85 0.30 W 0.55 W 0.08 W 0.33 W 1.14 W 0.64 W O.4I W 4.39 W 0.85 W 0.37 W 0.85 W 0.55 W 0.48 W 0.27 W 0.24 W 0.05 W 0.21 KRU 3G-13 Page 3 01/02/91 $ MEAS C DEPTH 7 4800 7 9oo 7 ~. 3000 7 5100 7 5200 INCLN ANGLE 54.85 55.47 55.31 55.18 55.17 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 7 53OO 7 5400 7 5500 7 5600 7 5700 3511.1 3421.1 2740.1 3568.2 3478.2 2822.0 3625.0 3535.0 2904.2 3682.0 3592.0 2986.2 3739.1 3649.1 3068.1 5800 5900 6000 6100 6200 6300 5.oo -6600 6700 55.46 3796.0 3706.0 3150.1 56.52 3852.0 3762.0 3232.9 56.59 3907.1 3817.1 3316.3 56.48 3962.2 3872.2 3399.6 56.71 4017.3 3927.3 3483.0 7 6800 7 6900 7 7000 7 7100 7 '7200 RECORD OF SURVEY 56.22 4072.5 3982.5 3566.3 55.98 4128.3 4038 .'3 3649.3 55.78 4184.4 4094.4 3732.0 56.00 4240.5 4150.5 3814.8 55.81 4296.5 4206.5 3897.5 56.32 4352.3 4262.3 3980.4 56.32 4407.8 4317.8 4063' 6 56.17 4463.4 4373.4 4146.7 55.64 4519.4 4429.4 4229.5 55.91 4575.7 4485.7 4312.2 DIRECTION RELATIVE-COORDINATES BEARING FROM-WELL-HEAD S 42.04 W2~,~2074.8 S S 41.49 W~,~2136.0 S S 41.54 W)~'~2197.7 S S 41.13 W~,~2259.4 S S 42.07 W2~'072320.7 S CLOSURE DL DISTNCE BEARING /100 ^Survey Codes: 7/GYRO 7 7300 57.96 4898.1 4808.1 4817.7 S 35.06 WA1~,~3685.8 S 3108.6 W 4821.7 S 40.14 W 0.29 57.15 4630.8 4540.8 4395.6 S 36.08 W~%~,~3340.9 S 2864.5 W 4400.8 S 40.61 W 2.46 57.58 4684.7 '4594.7 4479.7 S 35.20 WA~,~3409.3 S 2913.6 W 4484.7 S 40.52 W 0.76 57.75 4738.2 4648.2 4564.1 S 35.71 W~%~13478.1 S 2962.6 W 4568.9 S 40.42 W 0.40 57.87 4791.5 4701.5 4648.7 S 35.02 W;~3547.1 S 3011.6 W 4653.2 S 40.33 W 0..51 57.69 4844.8 4754.8 4733.2 S 34.93 WA1%~)3616.5 S 3060.1 W 4737.4 S 40.24 W 0.19 S 41.21 W~la~2382.2 S S 40.48 W~,~2444.9 S S 40.16 W~O,%~2508.5 S S 40.34 W~,~2572.2 S S 39.75 W~,7~636.1 S 2068.4 W 3154.9 S 40.97 W 0.65 2122.6 W 3237.8 S 40.96 W 1.18 2176.6 W 3321.2 S 40.95 W 0.23 2230.5 W 3404.6 S 40.93 W 0.17 2284.3 W 3488.1 S 40.91 W 0.47 S 39.83 W~W)2700.1 S S 39.89 W~%%g~2763.9 S S 39.70 WJd~2827.5 S S 39.66 WA~,%~2891.2 S S 39.66 W~%~2954.9 S 2337.6 W 3571.4 S 40.88 W 0.49 2390.8 W 3654.4 S 40.86 W 0.24 2443.8 W 3737.2 S 40.84 W 0.24 2496.6 W 38'20.0 S 40.81 W 0.22 2549.5 W 3902.8 S 40.79 W 0.19 S 40.20 W~,=o3018.6 S S 39.58 W~.~3082.4 S S 39-15'~%w 3210.6 S S 39.09 W~%~3274.8 S 2602.7 W 3985.7 S 40.77 W 0.63 2656.1 W 4068.9 S 40.75 W 0.43 2709.0 W 4152.1 S 40.73 W 0.17 2761.5 W 4234.8 S 40.70 W 0.57 2813.7 W 4317.5 S 40.67 W 0.27 1795.8 W 2744.1 S 40.88 W 1.11 1850.5 W 2826.1 S 40.90 W 0.72 1905.0 W 2908.4 S 40.92 W 0.16 1959.3 W 2990.6 S 40.93 W 0.31 2013.8 W 3072.7 S 40.95 W 0.63 KRU 3G-13 Page 4 01/02/91 RECORD OF SURVEY MEAS INCLN DEPTH ANGLE 7400 58.32 f.~. 7500 58.66 (7600 58 82 . 7700 55.15 7800 54.84 VERTICAL-DEPTHS BKB SUB-SEA SECTION DIRECTION RELATIVE-COORDINATES CLOSURE DL DISTNCE BEARING FROM-WELL-HEAD DISTNCE BEARING /100 4950.8 4860.8 4902.5 S 33.82 W~,~3755.8 S 3156.7 W 4906.2 S 40.05 W 0.97 5003.1 4913.1 4987.6 S 34.02 W~,0~3826.6 S 3204.2 W 4991.0 S 39.94 W 0.37 5055.0 4965.0 5072.8 S 32.76 W;~'T&3898.0 S 3251.3 W 5075.9 S 39.83 W 0.94 5109.5 5019.5 5156.2 S 31 57 wAil,Tr968.9~ S 3295.9 W 5159.0 S 39.71 W 3.76 31~75 5166.8 5076.8 5237.7 S 038.6 S 3338.9 W 5240.1 S 39.58 W 0.33 7 7900 54.84 5224.4 5134.4 5318.8 S 30.04 WA~0, e14108.8 S 3380.9 W 5321.0 S 39.45 W 1.14 7 8000 54.26 5282.4 5192.4 5399.6 S 31.18 Wgll,lf4178.9 S 3422.4 W 5401.5 S 39.32 W 0.95 7 8100 53.95 5341.1 5251.1 5480.3 S 34.65 W;~'I,~f4246.9 S 3466.4 W 5482.0 S 39.22 W 2.29 7 8200 53.69 5400.1 5310.1 5560.9 S 34.26 WA~,~4313.5 S 3512.0 W 5562.4 S 39.15 W 0.36 7 8300 55.26 5458.2 5368.2 5642.1 S 32.88 W~1~'~4381.3 S 3557.0 W 5643.4 S 39.07 W 1.83 7 8400 55.32 5515.1 5425.1 5724.0 S 33.03 WQI),o~4450.2 S 3601.8 W 5725.2 S 38.98 W 0.12 7 8500 55.29 5572.1 5482.1 5805.9 S 32.66 Wg~'~4519.3 S 3646.4 W 5806.9 S 38.90 W 0.25 7 8600 54.99 5629.2 5539.2 5887.6 S 32 52 W;1~'~4588.5 S 3690.5 W 5888.5 S 38.81 W 0.31 7 8700 55.07 5686.5 5596.5 5969.2 S 32~44 W~1~'~14657.6 S 3734.6 W 5969.9 S 38.72 W 0.10 7 8800 55.54 5743.5 5653.5 6051.1 S 32.74 W~0~4726.9 S 3778.8 W 6051.7 S 38.64 W 0.51 8900 53.83 5801.3 5711.3 6132.5 S 34.97 W~*~,~74794.6 S 3824.3 W 6133.0 S 38.58 W 2.24 9000 52.80 5861.0 5771.0 6212.6 S 3.7.20 W~%~4859.4 S 38'71.5 W 6213.1 S 38.54 W 1.75 51.57 5922.3 5832.3 6291.6 S 36.90 W~4922.5 S 3919.1 W 6292.1 S 38.53 W 1.24 49.73 5983.2 5893.2 6365.8 S 39.56 Wa1%54980.8 S 3965.1 W 6366.3 S 38.52 W 2.51 9320 49.73 6063.3 5973.3 6460.4 S 39.56 WA1%~5053.7 S 4025.3 W 6460.9 S 38.54 W 0.00 ^Survey Codes: 7/GYRO X/EXTRAPOLATED KRU 3G-13 Page 5 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 01102191 SUBSEA MEAS INCLN DEPTH DEPTH ANGLE TVD BKB 0 90 0.22 90 90 190 0.21 190 30 290 0.33 290 300 390 0.35 390 400 490 0.35 490 500 590 0.23 590 600 690 1.46 690 700 790 2.14 790 800 890 6.04 890 900 992 12.16 990 1000 1095 17.21 1090 1100 1200 17.87 1190 1200 1306 19.99 1290 1300 1413 23.22 1390 1400 1523 25.02 1490 1500 1635 28.77 1590 !.400 1753 35.68 1690 )0 1881 41.01 1790 -~00 2018 45.15 1890 1900 2165 49.27 1990 2000 2323 51.90 2090 2100 2490 53.45 2190 2200 2657 54.46 2290 2300 2836 56.29 2390 24b0 3015 55.89 2490 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 0 0 N 46.24 E 0.15 N 0.06 E 0 0 N 53.72 E 0.42 N 0.35 E 0 0 N 63.99 E 0.65 N 0.74 E 0 0 N 73.79 E 0.87 N 1.31 E 0 0 N 78.80 E 1.01 N 1.90 E 0 0 N 44.51 W 1.38 N 2.07 E 0 0 S 21.67 W 0.00 S 3.00 E 0 0 S 31.65 W 2.72 S 1.41 E 0 0 S 34.66 W 8.47 S 2.33 W 2 1 S 34.00 W 21.54 S 11.31 W 5 3 S 34.23 W 43.34 S 26.06 W 10 5 S 36.01 W 69.36 S 44.34 W 16 6 S 38.01 W 96.71 S 64.92 W 23 8 S 41.34 W 127.29 S 90.43 W 33 9 S 42.15 W 160.52 S 120.09 W 45 12 S 42.83 W 197.45 S 153.96 W 63 18 S 41.99 W 243.18 S 196.26 W 91 29 S 41.79 W 303.94 S 249.89 W 128 37 S 42.92 W 373.01 S 313.11 W 175 46 S 40.53 W 452.17 S 384.87 W 233 58 S 38.71 W 547.27 S 462.45 W 300 67 S 41.16 W 650.85 S 547.78 W 367 67 S 40.04 W 751.82 S 635.17 W 446 79 S 39.48 W 866.01 S 729.13 W 525 79 S 41.10 W 979.74 S 825.41 W 2500 3193 55.63 2590 603 78 S 42.09 W 1089.68 S 922.63 W KRU 3G-13 Page DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 6 01/02/91 SUBSEA DEPTH 2600 C.... 00 30 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 ~.00 4500 4600 4700 4800 4900 5U00 MEAS DEPTH 3370 3548 3726 3902 4078 4251 4422 4593 4764 4938 5114 5289 5469 5650 5831 6010 6188 6368 6548 6726 6910 7097 7285 7475 7665 INCLN TVD MD-TVD VERT DIRECTION ANGLE BKB DIFF CRRT BEARING 55.84 2690 680 77 S 42.03 W 55.83 2790 758 78 S 44.02 W 55.52 2890 836 78 S 43.15 W 55.52 2990 912 77 .S 39.61 W 55.05 3090 988 75 S 40.64 W 54.28 3190 1061 73 S 41.31 W 54.28 3290 1132 71 S 41.28 W 54.20 3390 1203 71 S 40.99 W 54.54 3490 1274 71 S 41.66 W 55.41 3590 1348 75 S 41.51 W 55.18 3690 1424 76 S 41.26 W 55.43 3790 1499 75 S 41.30 W 56.57 3890 1579 80 S 40.26 W 56.60 3990 1660 81 S 40.04 W 56.14 4090 1741 81 S 39.85 W 55.80 4190 1820 79 S 39.70 W 55.83 4290 1898 78 S 39.66 W 56.32 4390 1978 80 S 39.78 W 55.92 4490 2058 80 S 39.32 W 56.23 4590 2136 78 S 38.32 W 57.60 4690 2220 84 S 35.25 W 57.87 4790 2307 87 S 35.04 W 57.92 4890 2395 88 S 35.04 W 58.57 4990 2485 90 S 33.97 W 56.42 5090 2575 91 S 31.98 W RELATIVE COORDINATES FROM WELL HEAD 1198.25 S 1020.99 W 1306.17 S 1121.31 W 1410.91 S 1224.04 W 1522.81 S 1317.06 W 1633.38 S 1409.41 W 1739.77 S 1502.26 W 1843.83 S 1593.78 W 1948.34 S 1684.92 W 2052.65 S 1775.96 W 2159.74 S 1871.45 W 2268.00 S 1966.87 W 2375.62 S 2062.67 W 2488.77 S 2159.94 W 2604.31 S 2257.68 W 2720.19 S 2354.32 W 2833.83 S 2449.06 W 2947.56 S 2543.38 W 3061.86 S 2639.07 W 3177.12 S 2734.14 W 3291.40 S 2826.99 W 3416.07 S 2918.39 W 3545.19 S 3010.23 W 3675.26 S 3101.24 W 3808.77 S 3192.22 W 3944.57 S 3280.83 W 5100 7840 54.84 5190 2650 75 S 31.06 W 4066.70 S 3356.04 W KRU 3G-13 Page 7 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 01/02/91 SUBSEA MEAS INCLN DEPTH DEPTH ANGLE TVD BKB 5200 8013 54.22 5290 '00 8183 53.73 5390 00 8356 55.29 5490 5500 8531 55.20 5590 5600 8706 55.10 5690 5700 8881 54.16 5790 5800 9048 52.21 5890 5900 9207 49.73 5990 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 2723 73 S 31.63 W 4187.88 S 3427.84 W 2793 70 S 34.33 W 4302.10 S 3504.30 W 2866 73 S 32.96 W 4419.79 S 3581.98 W 2941 76 S 32.62 W 4541.09 S 3660.30 W 3016 75 S 32.46 W 4661.78 S 3737.22 W 3091 75 S 34.54 W 4781.89 S 3815.46 W 3158 67 S 37.06 W 4889.56 S 3894.34 W 3217 59 S 39.56 W 4986.98 S 3970.18 W KRU 3G-13 Page 8 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL 01/02/91 MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD DIST BEARING .000 12.68 998 908 26 S 33.91 W 23 S 2000 44.78 1877 1787 474 S 43.00 W 364 S 3000 55.92 2481 2391 1267 S 41.05 W 970 S 4000 55.16 3045 2955 2091 S 39.67 W 1585 S 5000 55.31 3625 3535 2904 S 41.54 W 2198 S DL/ 100 12 W 26 S 28.15 W 6.2 304 W 474 S 39.93 W 3.3 817 W 1268 S 40.10 W 0.8 1368 W 2094 S 40.81 W 0.4 1905 W 2908 S 40.92 W 0.2 6000 55.78 4184 4094 3732 S 39.70 W 2827 S 7000 57.75 4738 4648 4564 S 35.71 W 3478 S 8000 54.26 5282 5192 5400 S 31.18 W 4179 S 9000 52.80 5861 5771 6213 S 37.20 W 4859 S 2444 W 3737 S 40.84 W 0.2 2963 W 4569 S 40.42 W 0.4 3422 W 5401 S 39.32 W 0.9 3872 W 6213 S 38.54 W 1.8 01/02191 by GREAT LAND DIRECTIONAL DRILLING, INC. for Gyrodata Services, Inc. Client .... : ARCO ALASKA, INC. Field ..... : KUPARUK RIVER UNIT Well ...... : KRU 3G-13 Section at: S,37.82,W Surveyor..: ROB SHOUP Computation...: RADIUS OF CURVATURE Survey Date...: 11/13/90 RKB Elevation.: 90.00 ft Job Number .... : AKl190G251 API Number .... : 50-103-20137 INTERPOLATED MARKERS REPORT Surface Location: 2538 SNL 5 EWL S24 T12N R8E MARKER IDENTIFICATION KB 9-5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A MEAS INCLN DEPTH ANGLE 0 0.00 4266 54.20 8968 53.13 9016 52.60 9016 52.60 VERT-DEPTHS SECT BKB SUB-S DIST 0 -90 3199 3109 5842 5752 5871 5781 5871 5781 BEARING DIRECTION REL-COORDINATES FROM-WELLHEAD 0 N 0.00 E 2308 S 41.32 W 6187 S 36.49 W 6225 S 37.15 W 6225 S 37.15 W ON 0 E 1749 S 1510 W 4839 S 3856 W 4870 S 3879 W 4870 S 3879 W BASE KUPARUK A 7" CASING PROJECTED TD 9170 50.23 9301 49.73 9320 49.73 5966 5876 6051 5961 6063 5973 6346 S 38.84 W 6446 S 39.56 W 6460 S 39.56 W 4965 S 3952 W 5043 S 4016 W 5054 S 4025 W Marker Identification MD N/S E/~ A) KB 0 0 N 0 B) PROJECTED TD 9320 5054 S 4025 PLAN I ARCO ALASKA. iNC. i KRU 36-t3 ICLOSURE · I DECLINATION.: i SCALE .......· I t DRA~N. · 01/02/9t 646t ft S 3B.54 kt 0.00 E t inch = 800 fes~ 400 ,/ i //i /"' / ~, 1 · <- RZ~T · EA?T -> end O/pe£tional Drillin~ Inc. 4200 4800 VERTICAL SECTION VIEW A~CO ALASKA. K~U ~G-i~ Section al: TVD Scale.: Dep Scale.: Drawn ..... : INC. 37.82 ~ inch = t~_00 feet: inch -- !200 fee% oilo2t9i Marker Identification MD TYD SEOTN A) KB 0 0 0 B) PROJECTED TD g320 8063 6460 INCLN 0.00 49.73 5400 §000 1 AOGCC GEOLOGICAL MATE~.iALS iNYENTORY LiST PERMIT # COMPLETION DATE check off or list data as it is received.*l, received date for 407. if not uired list as NR drilline histo~' survey well tests core descri ,C,O,,.red in{erv~is ' ~ '- ~ ~'; ~ " '~-' ~; , core analysis ~P.. dry ditch intervals digital data ,, ,, II IIIII I II ! I Ri ' '9) lo,I Iii] I I I ii I Iki ~k Ti:I'I} ~ I I NO. ~ {to thc nearest foot] ,i lii l[inchIlO0'} I ,, ! , ii i ARCO Alaska, Inc. Date: February 8, 1991 Transmittal #: 8008 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 items. signed copy of this transmittal. Please acknowledge receipt and return one 3G-13 3G-02 3G-13 3G-09 Pulse Echo Cement Evaluation Log Acoustic Cement Bond Log Acoustic Cement Bond Log Acoustic Cement Bond Log 11-13-90 11-12-90 I 1 -1 3-90 10-4-90 6000-9187 45OO-6547 570O-92O0 5441-10,195 Receipt Drilling Acknowledge: State of Alaska Date: NSK i '. STATE OFALASKA ALASKA OIL AND GAS CONSERVATION COMMIS~i~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Change approved program_ Repair well _ Plugging _ Pull tubing _ 5. Type of Well: Development X Exploratory _ Stratigraphic _ 99510 Service _ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK Operation Shutdown X Re-enter suspended well _ Time extension Stimulate Variance Perforate Other 6, Datum elevation (DF or KB) 4. Location of well at surface 2538' FNL, 5'' FWL, SEC 24,T12N,R8E,UM At top of productive interval 2200' Fnl, 1450'" FWL, Sec. 26, T12N, R8E, UM (approx) At effective depth NA At total depth 2435"FNL, 1268' FWL, Sec. 26, T12, R8E, UM (approx) Plugs (measured) Junk (measured) 12. Present well condition summary Total Depth: measured 9320' feet (approx) true vertical 6067' feet Effective depth: measured NA feet (approx) true vertical NA feet RKB 90' 7. Unit or Property name Kuparuk River Unit feet 8. Well Number 36-1:3 9. Permit number 90-116 10. APl number 50-103-20137 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Casing Length Size Structural Conductor 8 0' 1 6" Surface 4231 ' 9 5/8" Intermediate Production 9266' 7" Liner Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) None Cemented 220 SX AS III 920 Sx AS III & 590Sx Class G 200Sx class G Measured depth True vertical depth 1 1 5' 115'approx. 4266' 3195'(approx) REC /ED 6057' (approx) DEC - 4 1990 Alaska 0il & 6as Cons. C0mfftiss[oa Anchorage 13. Attachments Description summary of proposal _ Detailed operation program BOP sketch 14. Estimated date for commencing operation January, 1991 Oil ~; 16. If proposal was verbally approved Name of approver Date approved Service 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. Si,ned //~'~ ~'~ ~_~~ // Title Area Drilling Engineer / FOR COMMISSION USE ONLY 15. Status of well classification as:, Gas m Suspended _ Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test Subsequent form require -- ORIGINAL SIGNED BY LONNIE C. SMITH Approved by the order of the Commission IApproval No. 10- ' " Commissioner Date Form 10-403 Rev 06/15/88, Approved Copy eturned SUBMIT IN TRIPLICATE ARC~.. jil ~.d Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "lltitill R~' on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should I~ ~ummerlzed on the form giving inclusive dates only. . District J County. parish or borough I State ARCO ALASKA INC, !' I NORTtt SLOPE I AK Field ILease or Unit IWell no. KUPARUK ] ADL 25548 ALK 2662 3p-13 Auth. or W.O, no. ITitle AK5172 I DRILLING Operator I I I!ARCO W.I. ARCO 55.2521 Spudded or W.O. begun JDate JHour Prior status if a W.O. SPUD 09/21/90 23:30 Date and depth as of 8:00 a.m. 09/22/90 (1) TD: 1044'( 1044 SUPV:JMM 09/23/90 (2) TD: 4270'( 3226 SUPV:JMM Complete record for each day reposed DOYON 14 DRILLING @ 1044' MW: 8.8 VIS: 71 MOVE RIG FROM 3G-18 TO 3G-13. NU DIVERTER, SLIP AND CUT DRLG LINE. MU AND ORIENT BHA. TEST DIVERTER, SPUD WELL AT 23:30 HRS ON 9/21/90. DRILL 12-1/4' HOLE FROM 115' TO 1044'. DAILY:S71,047 CUM:$71,047 ETD:S71,047 EFC:$1,370,000 DRILLING @ 4270' 9-5/8"@ 4266' MW: 9.6 VIS: 49 DRILLING FROM 1044 TO 4270'. ART-11.0 HRS, AST-7.1 HRS. TOTAL ADT=18.1 HRS. DAILY:S53,449 CUM:$124,496 ETD:S124,496 EFC:$1,370,000 09/24/90 ( 3) MU TURBINE BHA 9-5/8"@ 4266' MW: 9.9 VIS: 44 TD: 4280'( 101 DRILL FROM 4270' TO 4280'. CIRC, SHORT TRIP TO 1032', TIGHT SUPV:JMM SPOTS AT 1820'- 1650'. POOH AND RUN 101 JTS OF 9-5/8" CASING, J-55, BTC, 36#. CEMENT WITH DOWELL: 70 BBL WATER SPACER, 318 BBL LEAD (920 SX ASIII @ 12.1 PPG), 122 BBL TAIL (590 SX CLASS G @ 15.8 PPG). DISPLACE WITH 329 BBL WATER, BUMP PLUG TO 2500 PSI AT 2200 HRS. CEMENT RETURNS TO SURFACE. MU 9-5/8" CSGHEAD. NU BOPE TEST BOPE. PU TURBINE AND PDC BIT, LOAD RLL TOOLS. DAI~Y:$217,093 CUM:$341,589 ETD:S341,589 EFC:$1,370,000 09/25/90 ( 4) ~; :DRLG 8.5 HOLE 9-5/8"@ 4266' MW: 9.5 ViS: 37 TD: 7276'( 2996)~! DttILL FLT CLR & CMT TO W/IN 20' OF SHOE, TEST CSG TO _.-~~/ii! sz~ DISPLACE CSG w/ 9.5 PPG mm. DRILL C~t. ~ FLOAT SUPV: JMM [ii :;:;'~!i~l~.:~TO 10; OF NEW HOLE TO 4290', TEST FORMATION TO 12,3 F.,M~'~ TRUBODRLG. 4290' TO 7276'. DAILY:S68,037 CUM:$409,626 ETD:S409,626 EFC:$1,370,000 09/26/90 (5) TD: 8815'( 1539 SUPV:JMM 09/27/90 (6) TD: 9320'( 505) SUPV:JMM RIH W/ NEW BIT AND BHA 9-5/8#@ 4266' M~:10.3 VIS: 40 TURBODRLG 8.5 HOLE 7276'-8302'. WASHOUT IN D/P, POOH, FOUND WASHOUT 19 STDS OUT, L/D BAD JT, RIH. CONTINUED DRLG TO 8815'. INCREASE MUD WT WHILE DRLG TO 10.3PPG. CIRC & COND HOLE. PMP SLUG & POOH TO 9-5/8 SHO~ F/FORM TEST. CIRC OUT SLUG TO BALANCE MUD, PERFORM FORM INT TEST TO 11.1PPG EMW @ 5766 TVD. CONT POOH TO CHANGE OUT BIT & BHA, UNLOADED RLL, M/U NEW ROTARY BHA & LOAD RLL. RIH DAILY:S66,966 CUM:$476,592 ETD:S476,592 EFC:$1,370,000 DROP SS SURVEY 9-5/8#@ 4266' MW:10.6 VIS: 40 SLIP & CUT DRILL LINE. CNT RIH. REAM 8705' TO 8815', ROTARY DRLG 8.5 HOLE 8815' TO 9320'. CIRC & COND HOLE. PH.P SLUG, BEGIN WIPE TRIP. PIPE TIGHT HOLE SWABBING, NOT TAKING MUD, RIH. CIRC & ROTATE PIPE. WIPER TRIP TO 9-5/8 CSG SHOE. CIRC HOLE & SPOT DIESEL PILL & DROP SS SURVEY. DAILY:S65,506 CUM:$542,098 ETD:S542,098 EFC:$1,370,000 The above is correct For form preparetij~ anci~dis~u~?~n,~ CEIVED AR3B-459-1-D DEC - 4 1990 Alaska Oil & Gas 0ohs. Commission Anchorage JNumber all dally well hlstow forms consecutively aa they are prepared for each well. jpage no. ARC~v iO,, and Gas Company Daily Well History-Final Report Instructions: Prepare and submit.:th~i~'~-~['t" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted ~~ration9 are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion repO~t co~.~Ol%.:~.~?representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. !Accounting cost center code District ICounty or Parish State I ARCO ALASKA INC..I NORTH SLOPE AK sE Field JLease or Unit no. I KUPARUK J 36-13 Title ADL 25548 ALK 2662 I DRILLING Auth. or W.O. no. AK5172 Operator ARCO Spudded or w.O. begun SPUD Date and depth as. of 8:00 a.m. 09/28/90 (7) TD: 9320' ( 0) SUPV:JMM IA.R.Co. W.I. Date 55.2521 09/21/90 Complete record for each day reported DOYON 14 Iotal number of wells (active or inactive) on this Dst center prior to plugging and ~ bandonment of this well our I Prior status if a W.O, I 23:30 WORKING ON WKM TREE 9-5/8"@ 4266' MW: 0.0 VIS: 0 CONT. SPOT DIESEL PILL. POOH, L/D D/P & BHA, DUF/~ RLL SOURCE. PULL WEAR BSHG R/U & RUN 216 JTS OF 7", 26# CSG. CIRC & COND HOLE. MIX & PMP 10BBLS CHEM WASH + 35 BBLS OF 10.6 PPG BRINE. BMP PLUG W/2500 PSI. BLED OFF & CHECKED FLOAT EQPMNT, OK. CIP @ 0145 HRS. NIPPLE DN BOPE & P/U SAME. SET CSG SLIPS& DISPLACE BRINE OUT OF 7" CSG & STO. BK BOPE. NIPPLE TREE & ATTEMPT TO TEST TO 3000PSI, NO TEST. DAILY:S285,765 CUM:$827,863 ETD:S827,863 EFC:$1,370,000 Old TO J NewTD J PB Depth I I Released rig Date JKind of rig I Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas Der day Pump size, SPM X length Choke size T,P. C.P. Water % GOR Gravity Allowable Effec!~v~ ca!e corrected The above is correct Signatu~&~For form -._~ distribution,~ i ///,~...//9 ~)Date. ]T~ ~ preparation~ ~ ' ' ~ see Procedures ManuEl], Section 10, Drilling, Pages 86 and 87, AR3B-459-3-C DEC - 4 1990 Alaska Oil & Gas Cons. Commission Anchorage JNumber all daily well history forms consecutively as they are prepared for each well. Page r,o. DlviNon of Atla,~,cR~M~4~omp~ly '3EP-24- ' 9c3 ~6: _?'..4 iD: ~: ,_':P ! r ...,.,2;.,:.,.,v.-, 1 MONUMRNYATION PLri~ &OUNSM, II~Y ~ ~. ffLRVATION$ SROWN AN~ 0.~,M.$.£, DATUM, $. O00ROINA ?£$ SHOWN &~ A.$.~ ZONE ~ /0 ,q'. N.l,..,,, EW.L. 0.$. /'AD R$30' R$9' 48.9 $3. R538'" R48' 40,7 84,0 g$$0'" R~O' 40.4 54.0 $~$0'~' 1~5' 40. R ~4.0 g558'"' I?0' 4z,8 E~$O' ~ 98' 46.~ R~SO'~ ~' 47.3 ~0'~ 4~' 47./ ~3.~ ~0'~ ~0' ~,9 e~$O'-- 98' 48.8 ~.0 R~SO' R~O ' 48, g ~ r~r ~ OI~N$1~$ AND ARCO ALASKA,/NC. OW~. /vO. ' N$Off. $$00. CRA. 05 Gx. 6 $0 mD8 ARCO Alaska, Inc. Date: October 5, 1990 Transmittal #: 7911 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following Open hole items. Please acknowledge receipt and return one signed copy of this transmittal. 3G-13 3G-13 Receipt DISTRIBUTION: Dual Gamma Ray Compensated 9 - 2 7 - 9 0 4 2 8 0 - 9 3 2 0 Neutron Porosity Simultaneous Formation Density Dual Gamma Ray Electrmagnetic 9 - 2 7 - 9 0 4 2 8 0 - 9 3 2 0 Wave Resistivity Formatiop./ Acknowled ed ~"~ ~~' ~-~" RECEIVED Nula 011 & ~u Cons. Commission D&M Drilling Franzen Vendor Package(Johnston) NSK ARCO Alaska, Inc. Date: October 5, 1990 Transmittal#: 7913 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. Please acknowledge receipt and return 3 G- 1 3 LIS Tape and Listing I 0 - 3 - 9 0 Receipt Acknowl ~,,2~-~/,c~~--- DISTRIBUTION: 4100-9320 Date: .......... Lynn Goettinger ka RECEIVED OCT 0 1990' AIMi~ 011 & 6as Go~. Commission September t9, t990 Telecopy~ (907)276-7542 A. Wayne McBride Area Drilling Engineer ARCO Alaska, inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3G-13 Revised ARCO Alaska, · Inc. Permit No. 90-116 Sur. Loc. 2538'FNL, 5'FWL, Sec. 24, T12N, RSE, UM. Btmhole Loc. 2435'F~,~, 1268'F~L, Sec. 26, T12N, RSE, UM. Dear ~r. McBride: Enclosed is the approved revised application for permit to drill the above raferenced well. The provisions of the cover letter dated August 21, 1990, accompanying the original approved permit are in effect for this revision. Sincerely, ~ .,:Lonnie C. ~ith Comi,~±oner Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 September 13, 1990 Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99510-3192 Attn: Mr. Lonnie C. Smith Re: Kuparuk River Unit Well 3G-13 ARCO Alaska, Inc. Revised Permit to Drill Dear Mr. Smith: ARCO Alaska, Inc requests to revise the BHL for Kuparuk River Unit Well 3G- 13. Original 3G-13 Permit #90-116 Appr Date 8/21/90 BHL: 2232' FNL, 1044' FWL, Sec. 25, T12N, R8E, UM Revised 3G-13 BHL: 2435' FNL, 1268' FWL, Sec. 26, T12N, R8E, UM Drilling to date on 3G pad has been successful and more wells are expected to be drilled on the western edge of the field than previously anticipated. This has caused the need to revise the BHL for the previously submitted permit to drill Well 3G-13. A BHL to the west is proposed to be drilled from the conductor for Well 3G-13. The previously submitted BHL for 3G-13 will be drilled from a different conductor, probably from 3G-4 on the eastern side of the pad. Thank you for your consideration in this matter. If you have any questions, please call me at 265-6575. Sincerely, Tim y Sr. Drilling Engineer cc: A.W. McBride STATE OF ALASKA OIL AND GAS CONSERVATION COMM~,. _tON PERMIT TO DRILL 20 AAC 25.005 I la. Type of Work Drill ~ Redrill -- I lb. Type of Well Exploratory~ Stratigraphic Test _ Development Oil X Re-Entry _ Deepen --I Service -- Development Gas __ Single Zone X Multiple Zone 2_. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ^R(;;:;Q Alaska. Inc. RKB 90'. Pad 53' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25548 ALK 2662 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2538' FNL, 5' FWL, Sec. 24, T12N, R8E, UM KuDaruk River Unit At top of productive interval (TARGET) 8. Well number Number 2200'FNL, 1450' FWL, Sec. 26, T12N, R8E, UM 3G-13 Revised #U630610 At total depth 9. Approximate spud date Amount 2435' FNL, 1268' FWL, Sec 26, T12N~ R8E~ UM 24-SEP-90 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3G-14 9376' MD 1268' ~ TD feet 21' at 840' feet 2560 6073' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(®)(2)) kickoff depth 600' feet Maximum hole angle 56° Maximum surface 1880 ps,9 At total depth ITVD) 3250 psig 18. Casing program Setting Depth size specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Lencjth IVD TVD IVD TVD (include stage dataI 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +P00 Cu.Ft. , 12.25 9.625 36.0# J-55 BTC 4220' 35' 35' 4255 31 90' 1770 Cu. Ft. AS III & HF-~,RW 670 Cu. Ft. Class G 8.5 7" 26.0# J-55 AB-MO[ 4371' 35' 35' 4406' 3275' 195 Cu. Ft. Class G 8.5 7" 26.0# J-55 BTC 4970' 4406' 3275' 9376' 6073' TOC 500' above Kuoaruk HF-ERW 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true verticaltrue vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Con uc,o Cu. . R C IVED Surface Cu. R. Intermediate Production Liner '~i~ t /'~ ~,~, true vertical 20. 'Attachments Filing fee ~ Property plat ~ BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs deplh plot __ Refraction analysis _ Seabed report _20 AAC 25.050 requirements 21. I hereby certify that the foregoing is Irue and correct Io the best ol my knowledge Si~ned ~~.~ ~~ Title Area Drilling Engineer Date ~'/~ 0/¢~ · Commission Use Onl~ / PermiL Number I APl number I Approval date I See cover ~etter for '7'O-///,~ 50- /O~-- ~O/~;::' 08/23_/90 other requirements Conditions of approval Samples required ~Y e s )<' N o Mud log required ~ Y e s ~ N o Hydrogen sulfide measures~ Y e s .,~ N o Directional survey required ~ Yes ~ N o Required working pressure for BOPE ,.._,~M; ~. 3 M; ~ 5 M; ~ 1 0 M; ~ I 5 M Other: Commissioner the commission Date Approved b), ~' .... ~ /~- ~''~ I=nrrn 1(I-Ai%1 R~v 7-94-R~ ~Hhmit in trinlie~t~ DRILLING FLUID PROGRAM (3G-13) Spud to 9-5/8" Drill out to Weight up surface casing weight uo toTD Density 8.6-1 0.0 8.6-9.3 11.0 PV 15-35 5-15 10-18 YP 15-35 5-8 8-12 Viscosity 50-100' 30-40 35-50 Initial Gel 5-15 2-4 2-4 10 Minute Gel 15-40 4 - 8 4 - 8 APl Filtrate 10-1 2 8-1 0 4- 5 pH 9- 1 0 8.5-9 9.0-9.5 % Solids 10 +/- 4- 7 10-1 2 Drilling Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes' R2CEiV!:D - 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 1880 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. - The nearest well to 3G-13 will be 3G-14. As designed, the minimum distance between the two wells would be 21' to a depth of 840'. The wells would diverge from that point. - Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down 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 funnel viscosity between 100-120 to drill gravel beds. ,RCO ALASKA, ! Pad ;30, Well No: 13 Kuparuk Field. North Ravlsecl Slope, Proposal Alaska 0 . RKB ELEVATION' 90' 1000_ 2000 _ 3000 _ 4000 _ $000 _ 6000 _ 7000 ,, KOP 9 15 21 TVD=600 TMD=600 DEP=O BUILD 3 DEG PER 100 FT B/ PERMAFROST TVD=1605 TIgD=1658 DEP=286 :3 T/ UONU SNDS TVD=1755 TI"lD=1840 DEP=389 39 45 51 EOC TVD=2179 TMD=2458 DEP=835 T/ W SAK SNDS TVD=2490 TMD=3011 DEP=1292 B/ W SAK SNDS TVD=2990 Tt'ID=3900 DEP=2026 9 5/8' CS(; PT TVD=3190 TI"ID=4255 DEP=2320 K-lO TVB=3270 Tt'ID=4397 DEP=2438 K-5 TVD=4440 Ti'lB=6476 DEP=4156 AVERAGE ANGLE 55 DE(; 45 HI N TARGET - T/ ZONE C/A B/ KUP SNDS TD / LOG PT TVD=5870 TMD=9016 TVD=5960 TMD=9176 TVD=6073 TMD=9376 D DEP=6388 ~ DEP=6553 ~,. I 1000 I 2000 I I 3000 4000 VERT I CAL SECT I ON I I I 5000 6000 7000 HOR!,~NTAL PROdECTI ON -~ IN. = 1000 FEET ARCO ALASKA. Pmd 30. W, I I No, 123 Rev I .ed P~-opos, I Kupmruk Field, Nor~:h SI ope, Al ms 1000 m 1 000 _ z 2000 _ t -,- :3000 _ 4000 _ 5000 _ 6000 . WEST-EAST 5000 4000 :3000 2000 , ! I I TARGET TVD=5870 THDm9016 DEP=6255 SOUTH 4942 WEST 3835 1000 0 I I SURFACE LOCATION, 2538' FNL, 5' FWL SEC. 24, T12N. R8E TAROET LOCATION, 2200' FNL, 1450' FWL SEC. 26. TI2N. RSE TD LOCATION, 2435' FNL. 1268' FWL SEC. 26. T12N. RSE S 37 DEO 49 MI N W 6255' (TO TARGET) 1000 I 50 _ O 100 150 200 250 3OO I, 300 900 250 I 200 I 7'00 1 50 1 O0 I I ,, , , 0 !' ~oo f soo i '~'soo 500 /700 / 500 o I 4100 I 100 I I ~88o I I / I / I / t 11/~)50o I / I/ 1300 / ( / I /I / I / I / / / 300 i 250 200 150 I 100 50 500 50 100 I I 900 1100 '(,~300 I I I I I 0 I I 50 100 _ 50 0 50 .100 _ 150 .. 2OO _ 250 GENERAL DRILUNG PROCEDURE KUPARUK RIVER FIELD 3G PAD I . 1 , , . 61 . Si 1 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. Move in and rig up Doyon 14. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or RLL as needed. Run and cement 7" casing. (Isolation of the Colville sands will be performed if there is hydrocarbon presence.) Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Change over to diesel Shut in and secure well. Clean location and release rig. Fracture stimulate well. Reperforate and add additional perfs. 7 6 5 4 13 5/8" 5000 F,.,i BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING 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. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TESTALL 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 PREVENTORAND MANUAL KILLAND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. 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. 8. OPEN TOP PIPE RAMSAND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" -2000 PSI STARTING HEAD 2. 11" ~ 3000 PSI CASING HEAD 3. 11" ~ 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" -5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR SRE 8/22/89 DOYON 14 KJPARUK RIVER UNI~ 20" DIVERTER SCHEMATIC ] 5 HCR I 4 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTI~NANCE & OPERATION 3 . . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 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., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 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 6. 20" - 2000 PSI ANNULAR PREVENTER SRE 2./6~J0 August 21, 1990 Telecopy; (907)276-7542 A. Wayne. McBride Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 ~chorage, Alaska 99510-0360 Re: Kuparuk River Unit 3G-13 ARCO Alaska, Inc. Pe~it No. 90-116 Sur. Loc. 2538'FNL, 5'FWL, Sec. 24, T12N, RSE, UM. Btmhole Loc. 2232'FNL, 1044'F~L, Sec. 25, T12N, RSE, Ult. Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referen, ced 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 dete~tnattons are made. The Commission will advise you of those BOPE tests that it wishes to witness. ~ince - ly, 'David W. '-J'°hX~ston Commissione= Alaska Oil and Gas Conservation Commission BY ORDER ~.:0F ~E COMMISSION dlf Enclosure cc; Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 I la. Type of Work Drill X Redrill -- I lb. Type of Well Exploratory__ Stratigraphic Test _ Development Oil .~X Re-Entry _ Deepen --I Service _ Development Gas __ Single Zone ~ Multiple Zone _ 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska. Inc, RKI~ 90'. Pad 53' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25548 ALK 2662 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2538' FNL, 5' FWL, Sec. 24, T12N, R8E, UM Kuparuk River Unit At top of productive interval (TARGET) 8. Well number Number 1950'FNL, 985' FWL, Sec. 25 , T12N, R8E, UM 3G-13 #U630610 At total depth ~. Approximate spud date Amount 2232' FNL, 1044' FWL, Sec 25, T12N, R8E, UM 04-SEP-90 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3G-14 8205' MD 2232' @ TD feet 25' at 500' feet 2560 6099' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 500' feet Maximum hole an~le 48° Maximum surface 1845 psig At total depth (TVD) 3250 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casinc, I Weight Grade Couplincj Lenc~th IVD TVD IVD TVD (include stac, le dataI 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' ___200 Cu. Ft. 12.25 9.625 36.0# J-55 BTC 3803' 35' 35' 3838' 31 10' 1645 Cu. Ft. AS III & HF-ERW 585 Cu. Ft. Class G 8.5 7" 26.0# J-55 BTC 8170' 35' 35' 8205' 6099' 200Cu. Ft. ClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true verticaltrue vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Cu. Cu. Ft. Ft. ECEIVED Intermediate Production Liner AUG ]. Pertoration depth: measured .0ii & Gas Cons. C0mmissi r true vertical i.~,,~. ~n(~h0r:~n~ 20. Attachments Filing fee X Property plat __ BOP Sketch X Diverter Sketch ~ Drilling program ~ Drilling fluid program ~ Time vs depth plot __ Refraction analysis _ Seabed report __20 AAC 25.050 requirements ,,, 21.Al hereby certify that the foregoing is true and correct to the best of my knowledge ,,, Signed '/~ -~.,.~1~ .~. ~..~~ ~ . le , Area Drilling Engineer Date [~ ' C/~mission Use Only Permit Number I APl number ~ I Approval date See cover letter for (:::~0-//,//1~ I 50-/O,~- ~-~:~//~'~;~' I 08/2']/9 other recluirements Conditions of approval Samples required __Yes ~ N o Mud Icg required __ Yes ~' N o Hydrogen sulfide measures__ Yes ~ N o Directional survey required ,z~'Yes __ N o Required working pressure for DOPE __2M; .~3 M' __ 5M' __ I 0M' __ 1 5 M Other: ~~.,~~ ,~,~~ ........by order of ~)/~ , ,,A. pprovedCommissioner the commission Date / Form 10-401 Rev. 7-24-89 Submit in triplicate DRILLING FLUID PROGRAM (3G-13) Spud to 9-5/8" Drill out to Weight up ~urface casing w~io_ht UD to TD Density 8.6-10.0 8.6-9.3 11.0 PV 15-35 5-15 10-18 YP 15-35 5-8 8-12 Viscosity 50-100' 30-40 35-50 Initial Gel 5-15 2-4 2-4 10 Minute Gel 1 5-4 0 4- 8 4- 8 APl Filtrate 10-12 8-10 4-5 pH 9- 1 0 8.5-9 9.0-9.5 % Solids 10 +/- 4-7 10-12 Drilling Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid. Flow Sensor - Fluid Agitators Notes' RECEIVED AUG 1 5 ]990 ,41aska Oil & Gas Cons. C0m~isS[O~ - Drilling fluid practices will be in accordance with the appropriat~ch0rag~ 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 1845 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to, 3000 psi. - The nearest well to 3G-13 will be 3G-14. As designed, the minimum distance between the two wells would be 25' to a depth of 500'. The wells would diverge from that point. - Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down 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 funnel viscosity between 100-120 to drill gravel beds. ARCO ALASKA, Ins. Ped 3G, Well No, 13 Proposed Kupsruk Field, North Slope. Alsek. 1000 2000 RKB ELEVATION' 90' KOP TVD-500 TMD-500 DEP-O 3 9 BUILD 3 DEO' 15 PER I00 FT 27 33 B/ PERMAFROST TVD-I 605 TMD-1678 DEP-352 39 T/ UONU SNDS TVD-1ZZ5 TMD-1896 DEP-488 4s EOC TVD-1892 TMD-2060 DEP-602 m 3000 m o 4000 rtl 5000 T/ t4 SAK SNDS TVD-2420 TMD-2831 DEP-II64 B/ ~/ SAK SNDS TVD-2910 TMD-3547 DEP-1686 9 5/8" CSO PT TVD-3!IO TMD-3839 DEP-!899 K-lO TVD-3270 TMD-4073 DEP-2070 K-5 TVD-4470 TMD-5825 DEP-3347 AVERAGE ANGLE 46 DE(; 48 MI N 6000 _ 7000. , TROT / TOP ZONE C TVD-5828 TMD-?809 DEP-4793 . TOP ZONE A TVD-5845 TMD-?834 DEP-4811 ~....'~.'*. B/ KUP SNDS TVD-5962 THD-8005 DEP-4936 TD (LOG PT) TVD-6099 TMD-8205 DEP-5082 1 000 2000 3000 4000 5000 VERTICAL SECTION I 6000 HOR I g~3~NT^L PROJECT I ON s'L. -E 1 IN. = I000 FEET ARCO ALASKA, P.d 30,. Well No. 13 Propo.ed Kup.ruk Field. North Slope. 1000 SURFACE LOC&T I ON, 2538' FNL. S' FgL SEC. 24. T I2N. RSE ,,= 1000 _ Z , 2000 _ 3000 . 4000 . 5000 _ WEST-EAST 1 000 0 1 000 2000 I I I / SURFACE / ) S 11 DEO 48 MI N E 4793' (TO TARGET) 3000 I TARGET / C ZONE TVD=5828 TI'ID=?809 DEP=4793 SOUTH 4692 EAST 980 TARGET LOCATION' IgSO' FNL. 985' Fl, lt.. SEC. 2S. TI2N. RBE TD LOCATION, 2232' FNL. 1044' FWL SEC. 2S. TI2N. RSE 200 150 1 O0 50 0 50 1 O0 150 200~ 2500 2550 I ! soo '- ~' soo · soo,' soo soo~ ~ ,I,oo \~oo ,,~oo \,oo ~o,~O~ ~oo~ -~, ,~~ ~oo ~oo 2600 . I / 11oo 2650 . I // I/,3oo // 27oo ~ ~ I .27 I 11 oo 1 1300 2soo .... 200 150 1 O0 50 0 50 1 O0 150 200 ~ENERAL DRILUNG PROCEDURE KUPARUK RIVER FIELD 3G PAD , . . . . . . . . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. Move in and rig up Doyon 14. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or RLL as needed. Run and cement 7" casing. (Isolation of the Colville sands will be performed if there is hydrocarbon presence.) Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Change over to diesel Shut in and secure well. Clean location and release rig. Fracture stimulate well. Reperforate and add additional perfs. E ~PARUK RIVER UNIT'~-~' 20" DIVERTER SCHEMATIC 5 4 I 5 3 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION . o UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 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., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 1(7' OUTLETS. 5. 1(7' HCR BALL VALVES WITH 1(7' DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 2(~ - 2000 PSI ANNULAR PREVENTER SRE 2/6/90 7 5 4 1. 16" - 2(X)O PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8' - 5(X)O PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8' - 5(X)0 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 13 5/8" 5000 BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING 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. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTORAND MANUAL KILLAND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. 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 RAMSAND CLOSE BOTTOM PIPE RAMS. TEST BO'Fi'OM RAMS TO 250 PSI AND 3000 PSI. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUT OF HOLE. 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 AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. TEST STANDPIPE VALVES TO 3(X)0 PSI. 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 8o 9. 10 11. 12. 13. 14. OPERATE BOPE DAILY. SRE 8/2~89 DOYON 14 CHECK LIST FOE NEW ~ P-,r~}~T$ OA Z (2) Lo_c (2' =ru 8) (8) (10 and 13). (14 thru ~2) (23 ::hr: 2.8) Company~F~C.(O Is the perm.it fee at:ached .......................................... 2. Is well t~ be located in a defined pool ............................. 3. Is well located proper distance from proper=y line .................. 4. Is well located proper dis=ante from other wells ........ ~ ........... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well =o be deviated and is we!lbore plat included ................ 7. Is operator the only affected parry, ................................. 8. Can permit be approved before fifteen-day wait ...................... e 10. 11. 12.' 13. Does operator have a bon~ im force .................................. Is a conservauion order needed~, ...................................... . ,. Is administrative approval needed ................................... Is :he lease amber appropriate ..................................... ~ ,,, Does the well have a unique name and number ......................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. IS c6nducUor s:ring provided ........................................ Will surface casing protect al! zones reasonably exy. ected to serve as an underground source of drinking water ..................... Is enough cement used :o circuiata on conduc=or and surface ......... W'~!i cement tie in surface and intermediate or produc=ion strings ...' Wi!l cement cover ~ known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is :his well to be kicked off from an ~_isting wel!bore ............. Is old wel!bore abandonment procedure included on 10-403 ............ is ad quate wellbore separation proposed Is a diver=er system required ....................................... ,~ Is the drilling fluid program schematic amd list of equipment adequate ~ ,, Are necessary diagr~ and descriptions of diver=ar and BOPE at=ached. ,/~, Does BOPE have sufficient pressure rat/ag - Test to ~6)D6) ,, psig .. ~ Does the choke manifold comply w/API EP-$3 (~ay 84) .................. Is :he presence of H2S gas probable ............................. ~... , ~ (6) orm m (29 thru 31) (6) Add: ,, , Geoio~y: DWJ Enz~neer~_ug: ' _ rev: 01/30/89 6.011. ~or 29. 30. 31. 3Z. exy. loratory amd Strauigraphic wells: Are data presented on pouentiai overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional re~uiremen:s ............................................. Additional Re~_~rks: k/~-// _ ' " CHECK LEST FOR NEW WELL PER}!ITS Company ~/C~ . . Lease & Well No./~.zP~ Ir__~'~ ~PROVE DATE YES NO Is .......................................... ' (2) Loc (2 thru 8) (8) (f~ thr~ 'ZZ) (5) BOPE , , ""(z3 :hr=' Z8) thru '31) rev: 01/30/89 6.011. 2. Is well no' be locaued in a defined pool ............................. 3. Is well located proper disuance from properuy line .................. 4. Is we!! located proper distance from ouher wells ........ ' ........... 5. Is sufficienu undedica~ed acreage available in chis pool ............ 6. Is we!! uo be deviated and is we!!bore plat included ................ 7. Is opera:or =he only affected paruy ......... ' ....................... 8. Can permit be approved before fifteen-day wain ...................... , 9. Does operator have a bond in force .................................. 10. is a conservation order needed ...................................... 11. Is administrative approva~ needed ................................... 12.' Is :he lease number appropriate ..................................... 13. Does =he well have a unique name and number ......................... 14. 15. 16. I7. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. ~or 29. 30. 31. 3Z. Is a diver=er system required ....................................... Is cdnduc=or string provided ........................................ Will surface casing pro,act all zones reasonably expec=ed Co serve as am underground source of drinking wa=er ..................... ~__ Is enough cemen= used uo circulate on conduc=or and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... ~_ Will all casing give adequa=e safe=y im collapse, tension and burst.. Is =hAs well to be kicked off from am ez~sting wellbore ............. Is old wel!bore abandommen~ procedure included on 10-403 ............ Is adequate wellbore separation proposed ...................... ' ...... Is the drilling fluid program schematic amd list of equipment adequate ~ Are necessary diagr~ amd descriptions of diver=er and BOPE attached. Does BOPE have sufficiaut pressure rating - Test uo ~ psig .. ~ Does ~he choke mauifold comply w/API RP-53 (May 84) .................. Is the presence of HZS gas probable ............................. ~... exploratory amd Stratigraphic wells: Are data presented on potential overpressure zones? ................. ,, Are seismic analysis data presented on shallow gas zones ............ If am offshore loc., are survey results of seabed conditions presented Addi=ional requirements ............................................. ~ Additional R-m~rks: ' ,i INITIAL GEO. UNIT ON / OFF POOL CLASS STATUS AREA NO. SNORE o/oo zPez.., //"Co ,.3 '' i 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. (NOTE: ** REEL HEADER ** **** LIS READ **** MAXIMUM RECORD LENGTH - 8192 BYTES) SERVICE NAME: SSDS DATE: 90/10/04 ORIGIN OF DATA: FEWD REEL NAME: ARCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: REEL SEQUENCE # 1 RECEIVED OCT 0 19gO PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: SSDS DATE: 90/10/04 ORIGIN OF DATA: FEWD TAPE NAME: ARCO CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE ('EOF # 1) ********** ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: 3G13.MWD SERVICE NAME: SSDS VERSION #: V2.4 DATE: 90/10/04 MAX. RECORD LENGTH: 1024 FILE TYPE: EO PREVIOUS FILE NAME: ** COMMENTS ** COMPANY: ARCO ALASKA INC.// WELL: 3G-13// API#: 50-103-20137// DATE: 27-SEP-90 LOCATION: 2538' FNL & 5' FWL, SEC. 24, TWP. 12N, RANGE 8E, KUPARUK FIELD, NORTH SLOPE BOROUGH, ALASKA, USA// RIG: DOYON 14// CO. REP.: McCAULEY// KB=90' DF=88', GL=53'// LOGS MEASURED FROM KB @ 90' AMSL// NO TVD CALCUALTIONS MADE. COMMENTS >>>>>> NEUTRON AND DENSITY LOGS ARE CALIPER CORRECTED. PROCESSING ASSUMES A SANDSTONE MATRIX @ 2.65 GM/CC, FLUID DENSITY = 1.0 G/C3, FORMATION WATER SALINITY @ 11,545 PPM CL- & WATER BASE MUD SALINITY @ 1200 PPM CL-. NO TOOL WEAR CORRECTIONS REQUIRED. ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# DEPT EWR MWD ROP MWD FXE MWD CAL MWD NFO MWD NFl MWD NN0 MWD NN1 MWD GRC MWD NPSC MWD RHOB MWD LOG TYP CLS MOD NO. LVL CODE FT 0 0 0 0 1 4 0 1 68 OHMM 0 0 0 0 1 4 0 1 68 FT/H 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 INCH 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 API 0 0 0 0 1 4 0 1 68 P.U. 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 1 4 0 1 68 EWR ROP FXE CAL NF0 NFl NN0 NN1 GRC NPSC RHOB MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD FT/H HOUR INCH CTS CTS CTS CTS API P.U. G/C3 68 68 68 68 68 68 68 68 68 68 68 DEPT NN0 4000 -999 4100 -999 4200 2376 4300 2696 4400 2600 4500 2573 4600 2472 4700 2552 4800 2520 4900 2808 5000 2520 5100 2613 5200 2616 5300 2824 5400 2696 5500 2648 5600 2760 5700 2762 ** DATA VERIFICATION 5800 2872 .000 .250 .000 .250 .000 .000 .000 .000 .000 .000 .O0O .041 .000 .000 .000 .000 .000 .000 .000 .000 .000 .000 .000 .396 .000 .000 .000 .000 .000 .000 .000 .000 .000 .000 .000 .955 .000 .000 5900.000 2808.000 (every 100 FT) ** EWR NN1 ROP GRC FXE NPSC -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 8.681 2376.000 -999.250 58.974 -999.250 45.698 6.525 2712.000 206.348 90.033 .562 35.053 5.400 2600.000 285.712 91.164 .536 37.203 4. 314 2580.714 321.094 94.931 .644 37.632 4.218 2440.000 250.781 91.164 .488 40.806 3.879 2648.000 3.984 2696.000 298.096 102.466 202.832 97.945 678 918 528 704 6.677 2744.000 94.228 65.548 .655 30.498 4. 156 2616.000 270.075 82.877 .485 39.519 3.306 2568.000 265.053 91.164 .450 37.129 3.529 2712.000 242. 695 89.204 .626 35 476 4.107 2744.000 207.598 80.102 .764 33.994 3.793 2696.000 197.805 99.452 .653 33.153 3.093 2792.000 227.527 87.564 .453 35.065 3.032 2616.000 352.202 72.590 .406 36.371 3.879 2730.786 371.426 110.692 .411 32.695 3.721 2968.000 338.965 89.658 .563 29.791 3.601 2920.000 231.250 83.688 .715 31.140 CAL RHOB -999.250 -999.250 -999.250 -999.250 8.530 3.037 8.550 2.405 8.510 2.364 8.470 2.405 8.490 2.435 8.890 2.711 8.550 2.435 8.480 2.660 8.530 2.395 8.450 2.598 8.410 2.680 8.490 2.497 8.400 2.568 8.690 2.374 8.790 2.517 8.610 2.486 8.680 2.527 8.670 2.823 NFO -999.250 -999.250 445.000 535.000 551.000 545.959 519.000 559.000 591.000 679.000 511.000 563.403 551.000 559.000 575.000 567.000 535.000 600.393 647.000 615.000 NFl -999.250 -999.250 477.000 591.000 559.000 564.260 551.000 567.000 599.000 671.000 511.000 557.698 591.000 551.000 679.000 543.000 535.000 625.174 591.000 591.000 uO0.O00 2584.000 6100.000 2504.311 6200.000 2680.000 6300.000 2552.000 6400.000 2536.000 6500.000 2520.000 6600.000 2573.000 6700.000 2504.000 6800.000 2456.000 6900.000 2561.771 7000.000 2680.000 7100.000 2680.000 7200.000 2536.000 7300.000 2760.000 7400.000 2808.000 7500.000 2664.000 7600.000 2692.158 7700.000 2856.000 7800.000 2664.000 7900.000 2841.002 8000.000 2712.000 8100.000 2744.000 8200.000 2648.000 2.707 2584.000 2.138 2546.701 2.756 2600.000 3.371 2648.000 2.329 2504.000 2.707 2664.000 3.169 2672.999 4.054 2552.000 3.748 2520.000 4.428 2489.893 4.757 2744.000 4.023 2664.000 3.691 2632.000 4.097 2872.000 3.999 2792.000 4.057 2776.000 4.193 2686.079 4.407 2776.000 4.445 2712.000 5.442 2788.336 4.913 2728.000 3.660 2792.000 6.497 2744.000 113 .787 .767 283.722 90.411 405.344 108.042 320.947 136.370 312.825 110.000 227.856 163.493 238.594 154.497 252.996 143.151 202.148 110.753 218.589 118.686 247.734 99.452 164.317 116.781 157.439 106.475 212.178 96.438 216.935 106.986 190.584 104.726 204.924 106.819 153.149 102.466 220.244 93.983 114.862 85.890 124.623 100.959 246.843 102.466 84.818 87.397 .465 36.457 .431 38.432 .816 35.553 .480 34.281 .508 37.691 .789 34.017 .509 33.565 .593 36.324 .614 39.132 .754 37.906 .630 35.156 .818 34.267 .828 37.038 .625 31.829 .599 31.264 1.036 34.736 .957 33.919 .706 31.232 .712 33.863 .540 31.239 .774 33.605 .660 32.670 .807 32.585 8.8. 2.94D 8.400 2.823 8.530 2.975 8.630 2.925 8.750 2.965 8.720 3.016 8.510 2.914 8.740 3.098 8.600 2. 619 8.780 2.649 8.850 2.731 8.820 2.649 8.840 2.497 8.710 2.639 8.650 2.466 8.700 2.456 9.020 1.987 8.590 2.466 8.610 2.476 8.550 2.558 8.870 2.537 8.950 2.711 9. 040 2.894 599.000 543.052 551.000 639.000 599.000 703.000 658.501 639.000 535.000 571.336 567.000 575.000 559.000 615.000 639.000 575.000 595.960 591.000 607.000 623.000 647.000 607.000 647.000 575.000. 580.402 615.000 663.000 575.000 631.000 665.500 615.000 591.000 585.443 551.000 639.000 583.000 599.000 631.000 559.000 621.079 663.000 615.000 632.002 559.000 607.000 663.000 8300.000 2680.000 4.466 186.998 2648.000 109.247 2.324 8.670 647.000 34.104 2.323 591.000 8400.000 2504.000 4.932 372.606 2584.000 153.699 .559 8.580 623.000 36.747 2.558 591.000 8500.000 2584.000 4.073 230.713 2552.000 224.360 .809 8.780 767.000 33.015 2.486 703.000 8600.000 2600.000 5.547 250.781 2568.000 170.386 .772 8.890 679.000 34.072 2.609 671.000 8700.000 3.559 175.408 2374.542 2390.542 99.063 8800.000 3.901 49.155 2347.236 2316.967 98.442 1.257 8.750 565.542 43.023 2.537 12.779 9.180 527.554 38.990 2.363 487.380 524.003 8900.000 2.884 55.493 2282.290 2302.104 102.731 1.213 8.840 508.108 46.549 2.293 479.149 9000.000 66.083 65.290 3304.278 3294.817 47.226 1.408 8.720 727.139 22.317 2.547 732.495 9100.000 8.952 51.970 2789.364 2732.462 78.249 1.431 8.910 605.470 33.012 2.334 619.840 9200.000 3.801 28.125 2488.502 2510.648 95.186 1.898 9.010 553.865 39.824 2.374 547.644 9300.000 -999.250 30.087 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 9400.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** 515 DATA RECORDS ** FROM 4000.00 TO 9400.00 FT ** FILE TRAILER** FILE NAME: 3G13.MWD SERVICE NAME: SSDS VERSION #: V2.4 DATE: 90/10/04 MAX. RECORD LENGTH: FILE TYPE: EO NEXT FILE NAME: 1024 ********** END OF FILE (EOF # 2) ********** ** TAPE TRAILER** SERVICE NAME: SSDS DATE: 90/10/04 ORIGIN OF DATA: FEWD TAPE NAME: ARCO CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** REEL TRAILER ** SERVICE NAME: SSDS DATE: 90/10/04 ORIGIN OF DATA: FEWD REEL NAME: ARCO CONTINUATION #: 01 NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** TAPE TERMINATED BY REEL TRAILER **********
