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179-009
David Douglas Hilcorp North Slope, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 01/07/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL Well:PCU-02 PTD: 179-009 API: 50-283-20022-90-00 SFTP Transfer - Data Folders: Please include current contact information if different from above. 179-009 T39930 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.07 15:44:41 -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: _0 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:9. Ref Elevations: KB: 17. Field / Pool(s): Pretty Creek Unit GL: 82' BF: N/A 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- 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: 23. BOTTOM 20" H-40 339' 13-3/8"J-55 2,032' 9-5/8"P-110 2,070' 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 Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl:Water-Bbl:Flow Tubing Choke Size: Surface Per 20 AAC 25.283 (i)(2) attach electronic information 2,070' (TOW)Surface 94 339' Water-Bbl: PRODUCTION TEST N/A Date of Test:Oil-Bbl: N/A Gas-Oil Ratio: Surface Surface 1335 sx 26" SIZE DEPTH SET (MD)If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 61 Surface 2,032'Surface 17-1/2" N/A 2,070' MD / 2,070' TVD N/A 12,025' MD / 12,025' TVD 2,070' MD / 2,070' TVD N/A 1608' FNL, 2128' FEL, Sec 33, T14N, R9W, SM, AK AMOUNT PULLED N/A 342548 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. GRADE CEMENTING RECORDSETTING DEPTH TVD 2654865 TOP HOLE SIZEBOTTOMCASINGWT. PER FT. 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 342548 2654865 50-283-20022-90-00April 1, 1969 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 9/11/2024 179-009 / 324-344 N/A PCU 02July 18, 19691608' FNL, 2128' FEL, Sec 33, T14N, R9W, SM, AK 100.5' Undefined Gas Pool ADL 63048 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, 2130 sx12-1/4" TUBING RECORD 600 sx N/A PACKER SET (MD/TVD) 47 N/A G s d 1 0 p d B P L s (att Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 8:54 am, Dec 12, 2024 Abandoned 9/11/2024 JSB RBDMS JSB 121724 xG DSR-4/7/25BJM 3/13/25 SFD 2/5/2025 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD N/A N/A Top of Productive Interval N/A N/A Beluga 7260' 7260' 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Cody Dinger Digital Signature with Date:Contact Email:cdinger@hilcorp.com Contact Phone: 907-777-8389 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: Formation Name at TD: 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. 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. 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. 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. TPI (Top of Producing Interval). Authorized Name and Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. INSTRUCTIONS P&A Schematic, Decomplete + P&A Reports Authorized Title: Drilling Manager 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 N Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2024.12.11 15:08:02 - 09'00' Sean McLaughlin (4311) Updated by CJD 12-11-24 P&A SCHEMATIC Pretty Creek Unit Pretty Creek Unit (PCU) 02 Last Completed: 10-11-07 PTD: 179-009 API: 50-283-20022-90-00 PERFORATION DETAIL Zone Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Date Status Sterling X2 3,271'3,276'3,271'3,276'5'12/18/2021 Open Sterling 45-8 3,319'3,325'3,319'3,325'6'2007 Isolated 7/28/21 Sterling 47-1 3,396'3,416'3,396'3,416'20'Sqz'd 2/79, 6/86 Sterling 48-0 3,442'3,452'3,442'3,452'10'Isolated 3,525'3,570'3,525'3,570'45'Sqz'd 2/79, 6/86 Upper Beluga 3,700'3,780'3,700' 3,780'80'Isolated Long String 3,892'3,893'3,892'3,893'1'Tubing Punch, 5/93 Mid Beluga 3,915'3,980'3,915'3,980'65'Isolated 4,794'4,812'4,794'4,812'18'Isolated Beluga 7,260'7,280'7,260'7,280'20'Isolated Open hole 8,550'12,025'8,550'12,025'3,475'Isolated CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM.Hole Size CMT 20”94 H-40 Butt 19.124 Surf 339’26”600sx 13-3/8”61 J-55 12.515 Surf 1048’ 17-1/2” 675sx w/ Top jobDV Collar 1048’1050’ J-55 Butt 12.515 1050’2032’660sx 9-5/8”47/43.5 P-110 Surf 4525’ 12-1/4” 1020sx TOC @1500’ Ratty from 1500’-2000’ CBL DV Collar 4525’4527’ N-80 4527’8550’1110sx Tubing 2-7/8”LS 6.5 N-80 2.441 ~2750’3988’200sx TOC @3060’ Temp Log 2-7/8”SS 6.5 N-80 2.441 ~2750’3788’ JEWELRY DETAIL NO.Depth Length ID OD Item Long String 2070’Whipstock (TOW @ 2070’ MD) 2134’CIBP ~3252’CIBP w 25’ cmt (TOC @ 3227’) 1.3303’CIBP w/ 10’ cement (TOC @ 3293’) (07-29-2021) 2.3369’CIBP w/ 12’ cement (TOC @ 3357’) 09-2006 3.3600’CIBP 4.3608’2.85 2.31 3.6875 2-7/8”EU 8RD Sldg Slve 5.3630’CIPB 6.3646’14 3.00 8.50 9-5/8” Baker AL-5 Dual Packer w/ Brown Safety Joint (3640) 7.3688’99 2.44 3.50 2-7/8” EU 8RD Baker Blast Joint 8.3819’0.96 2.31 3.6875 2-7/8” EU 8RD Baker F nipple 9.3852’2.76 2.25 3.375 2-7/8”EU 8RD Sldg Slve 10.3854’7.85 2.44 8.437 9-5/8” Baker FH Packer 11.3894’0.81 2.25 3.6875 2-7/8” EU 8RD Baker R nipple 12.3899’89 2.44 3. 5 2-7/8” EU 8RD Baker Blast Joint 13.3988’0.54 2.18 3.6875 2-7/8” EU 8RD Baker Shear out Sub Short String A.3,005’Cement retainer (Sept-2006) B.3646’13.43 3.00 8.50 9-5/8” Baker AL-5 Dual Packer C.3688’0.81 2.31 3.6875 2-7/8” EU 8RD Baker R nipple D.3689’99.00’2.44 3.50 2-7/8” EU 8RD Baker Blast Joint E.3788’0.60 2.18 3.6875 2-7/8” EU 8RD ½ Mule Shoe Tbg Punches LS 3615’–3625’ SS 3625’–3635’ Page 1/1 Well Name: PCU 002A Report Printed: 12/11/2024WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Jobs Actual Start Date:7/9/2024 End Date: Report Number 1 Report Start Date 7/9/2024 Report End Date 7/10/2024 Last 24hr Summary PJSM, Crew travel to location, Spot in & rig up, Pick up lube & tool String (CCl/Gauge ring 2.3"), Stab onto well & pressure test 250/2000-good, Run in hole to 3260' no issues, Pull out of hole, PIck up & run a 2.1" CIBP, Set @ 3252', Tag & log off-good, Pull out of the hole, Pick 30' x 2" bailer, Run in hole & bail 6 gal. 25', TOC @ 3227', Pull out of hole & rig down. Report Number 2 Report Start Date 7/10/2024 Report End Date 7/11/2024 Last 24hr Summary PJSM, Crew travel to location, Spot in & rig up Fox Energy, Load & test Short string 1700 psi for 30 min-good, Rig up on long string, Load & test to 1700 psi for 30 min-good test, Rig up on IA, Load and test to 2500 psi for 30 min-good, Shut in all strings. Rig down Fox. Report Number 3 Report Start Date 7/11/2024 Report End Date 7/12/2024 Last 24hr Summary PJSM, Travel to location with AOGGC inspector Josh Hunt, Perform MIT on Long string- 1930 psi for 30 min-pass, Rig up on Short String Pressure up to 1840 psi for 30 min-good testest, Rig up on IA & pressure up to 1800 psi- good test. Secure all strings. Report Number 4 Report Start Date 8/2/2024 Report End Date 8/3/2024 Last 24hr Summary Move in and rig up HAK 401. Circulate hole volume to bleed tank. Install BPV in LS/ TWC in SS & HS. N/D tree. Report Number 5 Report Start Date 8/3/2024 Report End Date 8/4/2024 Last 24hr Summary Prepare WH and tbg hanger. Install blanking sub in LS. N/U BOPE. Change out pipe rams for offset 2-3/8'' x 3-1/2'' VBR's. Rig up floor, choke and kill lines. Prepare 2-3/8'' test jt. Shell test and correct leaks as required. Achieved shell test to 250/2500 psi for 5/5 min. Completed BOPE pressure testing on 2-3/8'' & 2-7/8''as per AOGCC requirements, witness waived by Austin McLeod. Removed TWC from HS, installed 2-7/8'' landing joint. Rig up remaining handling equipment. Report Number 6 Report Start Date 8/4/2024 Report End Date 8/5/2024 Last 24hr Summary Circulate HS. POH w/ 2-3/8'' IBT HS, full recovery. C/O handling equipment. Pull TWC from SS. M/U landing string onto SS, pull 12k tension. P/U E-line tools and RIH w/RCT. Work tools down from 2550' to 2770'. Discuss w/town, cut tbg at 2750'. Reverse circulate clean. POH w/2-7/8'' EUE SS and L/D, full recovery of tbg. Pull blanking sub from LS. Pull BPV from LS. Install landing joints. R/U E-line and RIH w/jet cutter- mis-run. Re-run and cut tbg at 2750ft- good cut. Circulate LS. Report Number 7 Report Start Date 8/5/2024 Report End Date 8/6/2024 Last 24hr Summary Complete reverse circ. POH and stand 2-7/8'' tbg. Full recovery of cut pipe. Attempted to retreive tbg hanger bushing from WH. Had welder build retreival tool. Retreived tbg hanger bushing. P/U and RIH w/ 9-5/8'' csg scraper to 2508'. Reverse circ clean w/FW. POH and L/D 2-7/8'' EUE LS tbg. R/U E-line and RIH w/CCL/GR to 2220'. Log up and corrolate log, found setting position for 9-5/8'' CIBP at 2135'ORKB. M/U 9-5/8'' CIBP, RIH and set at 2135' ORKB-CE. Top of CIBP @ 2134'. POOH and R/D E-Line unit. Top up csg, pressure test CIBP to 2500 psi for 30 min-Good test. Rig down floor and N/D BOPE. Report Number 8 Report Start Date 8/6/2024 Report End Date 8/7/2024 Last 24hr Summary Cont. N/D BOPE, N/D 13 5/8 x 11" FMC tubing spool, Install 13 5/8 x 11" Cactus tubing spool w/ adaptor dry hole tree, test void 3k good, secure well, continue R/D 401 rig package, move toward staging for barge landing to demobe. Field: Pretty Creek Sundry #: 324-344 State: ALASKA Rig/Service: 401Permit to Drill (PTD) #:Permit to Drill (PTD) #:179-009 Wellbore API/UWI:50-283-20022-90-00 Page 1/1 Well Name: PCU 002A Report Printed: 12/11/2024WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Jobs Actual Start Date:9/7/2024 End Date:9/24/2024 Report Number 1 Report Start Date 9/7/2024 Report End Date 9/8/2024 Last 24hr Summary Cont. R/D & prepping to move. Laid over derrick. Laid felt, liner, and set rig mats on PCU-02A. Rig movers arrived on J pad at 08:00 hrs. Scattered rig modules. Moved and set with cranes- subbase, carrier, and derrick on PCU-02A. Spotted & set doghouse/rig tank, gen skid, and pit module #1. Plugged in electrical cables. Powered up generator and fired up lights. Raised doghouse and derrick. Cont. rigging up. Report Number 2 Report Start Date 9/8/2024 Report End Date 9/9/2024 Last 24hr Summary Moved & set remaining rig modules. R/D and hauled sleeper & office trailers to Pretty Creek pad. Set up offices and R/U comm’s. Scoped derrick. P/U TDS. Set & R/U service shacks. Cont. R/U and working through rig acceptance check list. Gave AOGCC notification of up-and-coming BOP test. Report Number 3 Report Start Date 9/9/2024 Report End Date 9/10/2024 Last 24hr Summary Cont. R/U. Welders knocked out welding projects. Handy Berm, bermed in rig footprint. Hung wind walls. Accepted rig @ 16:00 hrs. on 9/9/24. N/U BOP’s. Jim Reggs with AOGCC waived witness on testing BOP’s. Currently testing BOP’s as per AOGCC regulations. Report Number 4 Report Start Date 9/10/2024 Report End Date 9/11/2024 Last 24hr Summary PCU-02A: Finish testing BOP’s. RIH P/U 42 jts of DP, POOH racking back DP in Derrick. M/U Clean out BHA as per WIS rep. Single in the hole w/ 4.5” DP t/2139’ set down 12k on CIB. POOH, L/D clean out BHA. M/U whipstock BHA as per WIS rep. RIH t/2062’. R/U wireline and RIH with gyro. Currently orienting whipstock. Report Number 5 Report Start Date 9/11/2024 Report End Date 9/12/2024 Last 24hr Summary POOH and R/D E-Line. Set whipstock and mill window, TOW-2070’ BOW-2084’. Drill t/2104’. R/U and perform FIT t/ 13.2ppg MWE. POOH and L/D milling BHA. Top mill in gauge. P/U 8.5” directional BHA. Shallow pulse test good. P/U jars and RIH with 4.5” HWDP t/687’. Field: Pretty Creek Sundry #: State: ALASKA Rig/Service: HEC 147Permit to Drill (PTD) #:Permit to Drill (PTD) #: Wellbore API/UWI:50-283-20022-01-00 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, August 27, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 2 PRETTY CK UNIT 2 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/27/2024 2 50-283-20022-90-00 179-009-0 N SPT 3060 1790090 1500 525 1840 1810 1800 0 0 0 0 OTHER P Josh Hunt 7/11/2024 This MIT is for a pre rig workover. This test is for the short string on a dual string well. Long string data during the test was as follows. Pre- 0, Initial- 0, 15- 0, 30- 0 psi. Sundry # 324-344 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRETTY CK UNIT 2 Inspection Date: Tubing OA Packer Depth 760 760 760 760IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH240712160337 BBL Pumped:0.5 BBL Returned:0.5 Tuesday, August 27, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 *DVSURGXFHU 0,77 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.08.27 14:52:35 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, August 27, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 2 PRETTY CK UNIT 2 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/27/2024 2 50-283-20022-90-00 179-009-0 N SPT 3060 1790090 1500 180 1930 1930 1930 0 0 0 0 OTHER P Josh Hunt 7/11/2024 This MIT is for a pre rig workover. This is a dual string well. This report is for the long string. I will add the data for the short string here in the comments. Short string: pre- 530, initial-530, 15- 530, 30- 530 psi Sundry # 324-344 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRETTY CK UNIT 2 Inspection Date: Tubing OA Packer Depth 760 770 770 770IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH240712153445 BBL Pumped:0.5 BBL Returned:0.5 Tuesday, August 27, 2024 Page 1 of 1 9 99 9 9 9 9 9 9 9 9 9 9 9 99 9 *DVSURGXFHU 0,77 James B. Regg Digitally signed by James B. Regg Date: 2024.08.27 14:55:21 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, August 27, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 2 PRETTY CK UNIT 2 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/27/2024 2 50-283-20022-90-00 179-009-0 N SPT 3060 1790090 1500 0 40 40 40 0 0 0 0 OTHER P Josh Hunt 7/11/2024 This MIT is for a pre rig workover. This test is on the IA. The long string data is included in the test details. The short string data during this test was as follows. Short String: Pre- 520, Initial- 600, 15- 600, 30- 600 psi. Sundry# 324-344. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRETTY CK UNIT 2 Inspection Date: Tubing OA Packer Depth 750 1800 1750 1740IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH240712160956 BBL Pumped:1.5 BBL Returned:1.5 Tuesday, August 27, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 *DVSURGXFHU 0,7,$ James B. Regg Digitally signed by James B. Regg Date: 2024.08.27 14:58:09 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 8/27/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240827 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 23 50133206350000 214093 7/18/2024 AK E-LINE PPROF BRU 222-24 50283201800000 220043 8/8/2024 AK E-LINE Perf BRU 222-26 50283201950000 224035 8/6/2024 AK E-LINE Perf BRU 222-26 50283201950000 224035 7/16/2024 AK E-LINE Perf BRU 241-26 50283201970000 224068 8/12/2024 AK E-LINE Perf BRU 241-34S 50283201980000 224077 8/2/2024 AK E-LINE Perf BRU 241-34S 50283201980000 224077 7/28/2024 HALLIBURTON CAST-CBL IRU 44-36 50283200890000 193022 8/10/2024 AK E-LINE PlugPerf PBU 18-13D 50029217560400 224039 8/2/2024 HALLIBURTON RBT PBU 18-33A 50029225980100 204070 8/13/2024 HALLIBURTON RBT PBU Z-228 50029237180000 222055 7/28/2024 HALLIBURTON PPROF PBU Z-234 50029237620000 223065 7/29/2024 HALLIBURTON IPROF PCU 2 50283200229000 179009 7/9/2024 AK E-LINE TubingCut TBU M-02 50733203890000 187061 8/6/2024 AK E-LINE CBL TBU M-02 50733203890000 187061 8/12/2024 AK E-LINE Perf Please include current contact information if different from above. T39491 T39492 T39493 T39493 T39494 T39495 T39495 T39496 T39497 T39498 T39499 T39500 T39501 T39502 T39502 PCU 2 50283200229000 179009 7/9/2024 AK E-LINE TubingCut Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.27 11:27:22 -08'00' 1 Gluyas, Gavin R (OGC) From:McLellan, Bryan J (OGC) Sent:Thursday, August 1, 2024 12:19 PM To:Chad Helgeson; Regg, James B (OGC) Cc:Harold Soule - (C); Darcy Dunbar - (C) Subject:RE: PC-2 BOP Change (PTD# 179-009) Sundry #324-344 Attachments:YJOS 13.625-in BOPE(9-11-20).pdf Chad, Your request to remove the single gate with the rams designed to close on two tubing strings is approved. Proposed BOP stack is attached. Condition of approval is that Hilcorp is not permitted to pull both tubing strings at once without adding this ram back into the string. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Thursday, August 1, 2024 10:10 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Harold Soule - (C) <hsoule@hilcorp.com>; Darcy Dunbar - (C) <Darcy.Dunbar@hilcorp.com> Subject: PC-2 BOP Change (PTD# 179-009) Sundry #324-344 Bryan/Jim, We would like to change our BOP stack we submitted in our Sundry # 324-344 from including the extra single gate to our standard stack that just has a double gate on it. This will limit our ability to pull 2 tubing strings at the same time, however we do not think we will need to pull them at the same time. If I am wrong and we have to pull them simultaneous we will have to nipple down the annular and install the extra single gate. Attached is the new BOP schematic for PC-2 decomplete. Let us know if you need any more information on this change of BOP stacks. Chad Helgeson Operations Engineer CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 Kenai Asset Team 907-777-8405 - O 907-229-4824 - C The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 13-5/8" 5m BOP Package W/ 4-1/16" Valves Full Mud Cross Assy. width w/ valves installed Width: 98.5" Weight: 2200 lbs. Height Addition for Ring Gaskets: 0" BOP Total Height: 111.5" YELLOW)#CKET OILFIELD SERVICES BOP Total weight: 24,906 lbs. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 7/12/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240712 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU B-24 50029226420000 196009 7/8/2024 READ Caliper Survey MPU I-40 50029236890000 220071 7/4/2024 READ Caliper Survey MPU I-40 50029236890000 220071 7/9/2024 READ Caliper Survey PCU 2 50283200229000 179009 7/8/2024 AK E-LINE Tubing cut Revision Explanation: There are additional images added to the final report and a few new .las files. In the Emeraude folder there are 2 new .las files and in the Field Data folder the RIH and POOH are new .las files Please include current contact information if different from above. T39179 T39180 T39180 T39181PCU 2 50283200229000 179009 7/8/2024 AK E-LINE Tubing cut Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.15 10:32:44 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 12,025'N/A Casing Collapse Structural Conductor Surface 1,540psi Intermediate Production 3,810psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16.Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Baker AL-5, Baker FH Pkr; N/A 3,646' MD/TVD; 3,854' MD/TVD; N/A, N/A 12,025' 3,293' 3,293' Pretty Creek Undefined Gas 20" 13-3/8" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Pretty Creek Unit (PCU) 02Undefined Same 8,550'9-5/8" ~1,144psi 8,550' See Schematic Length June 27, 2024 2-7/8" SS; 2-3/8" Htr 8,550' Perforation Depth MD (ft): See Attached Schematic 3,090psi 339'339' 2,032' Size 339' 2,032' MD Hilcorp Alaska, LLC Proposed Pools: 6.5# / N-80; 4.6# / N-80 TVD Burst 3,788' LS; 1,799' HS 6,330psi 2,032' Tubing MD (ft): 3,988' MD; Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0063048 179-009 50-283-20022-90-00 Tubing Size: 1-7/8" LS; PRESENT WELL CONDITION SUMMARY Jake Flora, Operations Engineer AOGCC USE ONLY Tubing Grade: 6.5# / N-80; jake.flora@hilcorp.com 907-777-8442 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Perforate Repair Wepair Well Exploratory Stratigraphic Development Service BOP TestMechanical Integrity Test No Wellbore schematic Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 2:18 pm, Jun 14, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.06.14 13:34:20 - 08'00' Noel Nocas (4361) DSR-6/17/24 XX Plug for Redrill 10-407 SFD 6/17/2024 Pressure test tbg LS, SS and IA to 1500 psi to verify P&A plug integrity before cutting tubing. Provide 48 hrs notice for AOGCC witness. BOP test to 2500 psi. BJM 6/19/24 ($8JLC 6/19/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.06.19 15:52:01 -08'00'06/19/24 RBDMS JSB 062024 Pretty Creek #2 Well Name:Pretty Creek #2 API Number:50-283-20022-90-00 Current Status:Gas Producer Permit to Drill Number:179-009 First Call Engineer:Jake Flora (907) 777-8442 (907) 301-1736 (C) Second Call Engineer:Chad Helgeson (907) 777-8405 (720) 988-5375 (C) Maximum Expected BHP: ~ 1471 psi @ 3,271’ TVD Calc. on a 0.45 psi/ft gradient Max. Potential Surface Pressure: ~ 1144 psi Gas gradient to surface @ 0.1 psi/ft Well Status PC-02 is currently a low rate cycled gas producer. Well Summary: This well was originally drilled in April of 1969 as the Theodore River #1. In February of 1979, the well was re- named the Pretty Creek #2 after it was re-entered. The sand interval at 3,915 – 3,980 was tested in this year. In June of 1986 the well was re-entered and three intervals were tested. Two of the three intervals were productive with the lower interval (3,915-3,980’) testing ate a 1.3 MMSCFD rate at 1625 psig and the Middle interval testing at 5.25 MMSCFD at 860 psig. In November 1986 Unocal assumed operatorship of Pretty Creek. In December of that same year, the well was re-completed with the current dual string completion. The Long String (LS) was completed in the C3 and the Short String (SS) was completed in the Sterling C1 sand. The short string was soon SI due to high water production. The long string flowed until 1999 when it eventually loaded up and died. In 2006 a coil cleanout was performed of both the long and short strings. A CIBP was set at 3,630’ in the LS and at 3,638’ in the SS. Both strings were tubing punched and a cement retainer set in the SS at 3,005’. Coil was utilized to circulate cement around both tubing strings in the annulus creating a cement packer. The height of the cement packer was measured to be 3,060’ by a temperature survey. The Sterling A3 was then perforated and IP’d at 3.5 MMscfd, flowed for a while and then loaded up with sand. In 2007 a CIBP was set in the long string at 3,369’ and the Sterling A1 (3319 – 3,325’) was perforated. Minor initial flow was encountered and the well sanded up and died. In 2019 a slickline tag was made. Fill was tagged at 3,130’. Bailed down to 3226’ and the fill came back in to 2,318’. In late 2021 the well was plugged back and perforated in the Sterling X2 seeing a pressure response with limited flow rate. Objective The objective of this work is to decomplete the wellbore in preparation for a sidetrack planned in the 2024 drilling season. Wellbore Condition Inclination: near vertical 2021-12-29 MITIA to 1400 psi PASSED (Witnessed) 2021-12-19 Perforated Sterling X2 sand 3271-3276’ w 1-11/16 spiral strip gun 2021-08-29 D&T w 2.27” GR to 3290’ 2021-07-29 Coil Tubing FCO to 3323’, Set CIBP at 3303’ 2019-07-17 2.25” DDB to 3039’ 2006-08-31 MITIA to 2500 psi, bled to 2450 psi in 30 min 2006-08-28 Pumped 40 bbls cement down SS, up annulus, TOC at 3060’ This well was originally drilled in April of 1969 as the Theodore River #1. In February of 1979, the well was re- named the Pretty Creek #2 after it was re-entered. Pretty Creek #2 Procedure 1. MIRU E-line, PT lubricator to 2000 psi 2. Long String: Set CIBP at ~ 3250’, dump bail 25’ cement on plug, cut tubing at ~3000’ 3. Short String: Cut tubing at ~3000’ with RCT 4. Provide AOGCC 48hrs notice of upcoming BOPE Testing 5. MIRU 401 Workover Rig 6. Circulate wellbore down LS or SS, through tubing cut, up 9-5/8” casing 7. Set TWC/BPV(s) 8. ND tree 9. NU BOPE & test to 2500 psi 10. Pull TWC/BPV(s) 11. Install landing joint, Pull & LD Heater String 12. Install landing joint, Pull & LD Short String 13. Install landing joint, Pull & LD Long String 14. RU E-line, set 9-5/8” CIBP at 2990’ 15. MIT 9-5/8” casing to 2500 psi 16. RDMO 401 -------- Rig 169 Sidetrack Planned for September/October 2024 --------- Attachments Current Schematic Proposed Schematic Current Wellhead Diagram Proposed Wellhead Diagram BOPE Diagram RWO Sundry Revision Change Form Pressure test LS, SS and IA to 1500 psi to verify plug integrity before cutting tubing. -bjm Updated by JLL 01/18/22 SCHEMATIC Pretty Creek Unit Pretty Creek Unit (PCU) 02 Last Completed: 10-11-07 PTD: 179-009 API: 50-283-20022-90-00 TD = 12,025’PBTD = 4675’ RKB = 17.6’ 6 4 Cmt Ret @ 4675’ DV@ 4525’ DV@ 1048’ TOC @ 1500’ 8 9 10 11 12 13 A B C D E 1a 2a 3a 7 CIBP @ 3638’ Cmt Ret @ 3005’ TOC @ 3060’ Tagged Fill @ 3644’ on 06/14/06 Sterling 48-0 Sterling 47-77 1 Sterling 45-8 Sterling X2XX 1 2 5 3 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Sterling X2 3,271' 3,276' 3,271' 3,276' 5' 12/18/2021 Open Sterling 45-8 3,319' 3,325' 3,319' 3,325' 6' 2007 Isolated 7/28/21 Sterling 47-1 3,396' 3,416' 3,396' 3,416' 20' Sqz'd 2/79, 6/86 Sterling 48-0 3,442' 3,452' 3,442' 3,452' 10' Isolated 3,525' 3,570' 3,525' 3,570' 45' Sqz'd 2/79, 6/86 Upper Beluga 3,700' 3,780' 3,700' 3,780' 80' Isolated Long String 3,892' 3,893' 3,892' 3,893' 1' Tubing Punch, 5/93 Mid Beluga 3,915' 3,980' 3,915' 3,980' 65' Isolated 4,794' 4,812' 4,794' 4,812' 18' Isolated Beluga 7,260' 7,280' 7,260' 7,280' 20' Isolated Open hole 8,550' 12,025' 8,550' 12,025' 3,475' Isolated CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. Hole Size CMT 20”94 H-40 Butt 19.124 Surf 339’26”600sx 13-3/8” 61 J-55 12.515 Surf 1048’ 17-1/2” 675sx w/ Top jobDV Collar 1048’1050’ J-55 Butt 12.515 1050’2032’660sx 9-5/8” 47/43.5 P-110 Surf 4525’ 12-1/4” 1020sx TOC @1500’ Ratty from 1500’-2000’ CBL DV Collar 4525’4527’ N-80 4527’8550’1110sx Tubing 2-7/8” LS 6.5 N-80 2.441 Surf 3988’200sx TOC @3060’ Temp Log 2-7/8” SS 6.5 N-80 2.441 Surf 3788’ 2-3/8” Htr 4.6 N-80 1.995 Surf 1799’ JEWELRY DETAIL NO.Depth Length ID OD Item 17.60’ FMC-OCT type TC-3C Tubing Hanger, 2-7/8” x 2-7/8” , 11” Long String 1. 3303’ CIBP w/ 10’ cement (TOC @ 3293’) 2. 3369’ CIBP w/ 12’ cement (TOC @ 3357’) 09-2006 3. 3600’ CIBP 4. 3608’ 2.85 2.31 3.6875 2-7/8”EU 8RD Sldg Slve 5. 3630’ CIPB 6. 3646’ 14.21 3.00 8.50 9-5/8” Baker AL-5 Dual Packer w/ Brown Safety Joint (3640) 7. 3688’ 99.00 2.44 3.50 2-7/8” EU 8RD Baker Blast Joint 8. 3819’ 0.96 2.31 3.6875 2-7/8” EU 8RD Baker F nipple 9. 3852’ 2.76 2.25 3.375 2-7/8”EU 8RD Sldg Slve 10. 3854’ 7.85 2.44 8.437 9-5/8” Baker FH Packer 11. 3894’ 0.81 2.25 3.6875 2-7/8” EU 8RD Baker R nipple 12. 3899’ 89.00 2.44 3. 5 2-7/8” EU 8RD Baker Blast Joint 13. 3988’ 0.54 2.18 3.6875 2-7/8” EU 8RD Baker Shear out Sub Short String A. 910’ 0.96 2.31 3.6875 2-7/8” EU 8RD Baker F nipple B. 3646’ 13.43 3.00 8.50 9-5/8” Baker AL-5 Dual Packer C. 3688’ 0.81 2.31 3.6875 2-7/8” EU 8RD Baker R nipple D. 3689’ 99.00’ 2.44 3.50 2-7/8” EU 8RD Baker Blast Joint E. 3788’ 0.60 2.18 3.6875 2-7/8” EU 8RD ½ Mule Shoe Heater String 1a. 20’ 0.81 1.99 2-7/8” x 2-3/8” Cross-over 2a. 707’ 1.80 1.87 3.125 2-3/8” EU 8RD Baker F nipple 3a. 1800’ 0.66 2.00 2.875 2-3/8” Buttress ½ Mule Shoe Tbg Punches LS 3615’–3625’ SS 3625’–3635’ Updated by JMF 5/29/24 PROPOSED Pretty Creek Unit Pretty Creek Unit (PCU) 02 Last Completed: 10-11-07 PTD: 179-009 API: 50-283-20022-90-00 TD = 12,025’PBTD = 4675’ RKB = 17.6’ 6 4 Cmt Ret @ 4675’ DV@ 4525’ DV@ 1048’ 9-5/8” TOC @ 1500’ 8 9 10 11 12 13 B C D E 7 CIBP @ 3638’ Cmt Ret 3005’ TOC @ 3060’ Temp Log Tagged Fill @ 3644’ on 06/14/06 Sterling 48-0 Sterling 47-1 Sterling 45-8 Sterling X2 1 2 5 3 Cut tubing strings ~3000’ Whipstock Depth TBD Optional CIBP for Depth Control ~2990’ CIBP w 25’ cmt ~3250’ PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Sterling X2 3,271' 3,276' 3,271' 3,276' 5' 12/18/2021 Open Sterling 45-8 3,319' 3,325' 3,319' 3,325' 6' 2007 Isolated 7/28/21 Sterling 47-1 3,396' 3,416' 3,396' 3,416' 20' Sqz'd 2/79, 6/86 Sterling 48-0 3,442' 3,452' 3,442' 3,452' 10' Isolated 3,525' 3,570' 3,525' 3,570' 45' Sqz'd 2/79, 6/86 Upper Beluga 3,700' 3,780' 3,700' 3,780' 80' Isolated Long String 3,892' 3,893' 3,892' 3,893' 1' Tubing Punch, 5/93 Mid Beluga 3,915' 3,980' 3,915' 3,980' 65' Isolated 4,794' 4,812' 4,794' 4,812' 18' Isolated Beluga 7,260' 7,280' 7,260' 7,280' 20' Isolated Open hole 8,550' 12,025' 8,550' 12,025' 3,475' Isolated CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. Hole Size CMT 20”94 H-40 Butt 19.124 Surf 339’26”600sx 13-3/8” 61 J-55 12.515 Surf 1048’ 17-1/2” 675sx w/ Top jobDV Collar 1048’1050’ J-55 Butt 12.515 1050’2032’660sx 9-5/8” 47/43.5 P-110 Surf 4525’ 12-1/4” 1020sx TOC @1500’ Ratty from 1500’-2000’ CBL DV Collar 4525’4527’ N-80 4527’8550’1110sx Tubing 2-7/8” LS 6.5 N-80 2.441 ~3000’3988’200sx TOC @3060’ Temp Log 2-7/8” SS 6.5 N-80 2.441 ~3000’3788’ JEWELRY DETAIL NO.Depth Length ID OD Item Long String ~3250’ CIBP w 25’ cmt 1. 3303’ CIBP w/ 10’ cement (TOC @ 3293’) (07-29-2021) 2. 3369’ CIBP w/ 12’ cement (TOC @ 3357’) 09-2006 3. 3600’ CIBP 4. 3608’ 2.85 2.31 3.6875 2-7/8”EU 8RD Sldg Slve 5. 3630’ CIPB 6. 3646’ 14 3.00 8.50 9-5/8” Baker AL-5 Dual Packer w/ Brown Safety Joint (3640) 7. 3688’ 99 2.44 3.50 2-7/8” EU 8RD Baker Blast Joint 8. 3819’ 0.96 2.31 3.6875 2-7/8” EU 8RD Baker F nipple 9. 3852’ 2.76 2.25 3.375 2-7/8”EU 8RD Sldg Slve 10. 3854’ 7.85 2.44 8.437 9-5/8” Baker FH Packer 11. 3894’ 0.81 2.25 3.6875 2-7/8” EU 8RD Baker R nipple 12. 3899’ 89 2.44 3. 5 2-7/8” EU 8RD Baker Blast Joint 13. 3988’ 0.54 2.18 3.6875 2-7/8” EU 8RD Baker Shear out Sub Short String A. 3,005’ Cement retainer (Sept-2006) B. 3646’ 13.43 3.00 8.50 9-5/8” Baker AL-5 Dual Packer C. 3688’ 0.81 2.31 3.6875 2-7/8” EU 8RD Baker R nipple D. 3689’ 99.00’ 2.44 3.50 2-7/8” EU 8RD Baker Blast Joint E. 3788’ 0.60 2.18 3.6875 2-7/8” EU 8RD ½ Mule Shoe Tbg Punches LS 3615’–3625’ SS 3625’–3635’ Pretty Creek Unit PC #2 Current 06/10/2024 13 3/8'’ 9 5/8'’ 2 7/8'’ Casing head, OCT-22L, 13 5/8 3M x 13 3/8 SOW, w/ 2- 2'’ LPO Tubing head, FMC-TC, 13 5/8 3M x 11 5M, w/ 2- 2 1/16 5M SSO, BG bottom prep Valve, Masters, OCT-20, 2 9/16 3M triple segmented FE, HWO, T-21 Tree cap, 2 9/16 3M Triple segmented x 2 7/8 EUE 8rd lift Pretty Creek Unit PC #2 13 3/8 x 9 5/8 x 2 7/8 x 2 7/8 x 2 3/8 Tubing hanger, Triple, FMC- TC-3C, 11 x 2 7/8 EUE 8rd lift and susp, w/ 2 1/2'’ type H BPV profiles, AA trim 2 7/8'’ Valve, Masters, OCT-20, 2 9/16 3M triple segmented FE, HWO, T-21 Valve, Swabs, OCT-20, 2 9/16 3M triple segmented FE, HWO, T-21 2 3/8'’ Valve, Masters, OCT-20, 2 9/16 3M triple segmented FE, HWO, T-21 Valve, Masters, OCT-20, 2 9/16 3M triple segmented FE, HWO, T-21 Valve, Swabs, OCT-20, 2 9/16 3M triple segmented FE, HWO, T-21 Heater String Pretty Creek Unit PC #2 Proposed 401 06/13/2024 13 3/8'’ 9 5/8'’ Casing head, OCT-22L, 13 5/8 3M x 13 3/8 SOW, w/ 2- 2'’ LPO Tubing head, Cactus, 13 5/8 3M x 11 5M, w/ 2- 2 1/16 5M SSO, FS bottom prep Pretty Creek Unit PC #2 13 3/8 x 9 5/8 The picture can't be displayed.The picture can't be displayed.The picture can't be displayed.The picture can't be displayed. 13-5/8"SPHERICAL ANNULAR HEIGHT: 45.28" WEIGHT: 12,806 LBS 13-5/8"TYPE U SINGLE BOP HEIGHT: 33.81" WEIGHT: 7,700 LBS 13-5/8"TYPE U DOUBLE BOP HEIGHT: 55.81" WEIGHT: 14,800 LBS 13-5/8"MUD CROSS W/ 4- 1/16" OUTLETS HEIGHT: 36" APROX. WEIGHT: 2,500 LBS INSIDE TO OUTSIDE 4-1/16" 5M X 3-1/8" 5M ADAPTER SPOOL 3-1/8" 5M MANUAL GATE 3-1/8" 5M MANUAL GATE INSIDE TO OUTSIDE 4-1/16" 5M X 3-1/8" 5M ADAPTER SPOOL 3-1/8" 5M Manual Gate valve 3-1/8" 5M HCR KILL SIDE CHOKE SIDE HEIGHT ADDITION FOR RING GASKETS: 0" BOP TOTAL HEIGHT: 170.9" WEIGHT: 37,806 LBS 13-5/8" 5m BOP Package W/ 3-1/8" Valves Dual 2-7/8" x 2-7/8" rams Upper: 2-3/8" to 3-1/2" flexbore rams Lower: Blind rams Sundry Application Well Name______________________________ (PTD _________; Sundry _________) Plug for Re-drill Well Workflow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on the Form 10-403. Geologist 2 If the “Abandon” box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that checkbox and instead, check the "Suspended" box and initial those changes. Geologist The drilling engineer will serve as quality control for steps 1 and 2. Petroleum Engineer (QC) 3 When the RA2 receives a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Research Analyst 2 4 When the RA2 receives Form 10-407, they will check the History tab in RBDMS for the IPBRD code. If IPBRD is present and there is no evidence that a subsequent re-drill has been completed, the RA2 will assign a status of SUSPENDED to the well bore in RBDMS. The RA2 will update the status on the 10-407 form to SUSPENDED, and date and initial this change. If the RA2 does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Research Analyst 2 5 When the Form 10-407 for the redrill is received, the RA2 will change the original well's status from SUSPENDED to ABANDONED. Research Analyst 2 6 The first week of every January and July, the RA2 and a Geologist or Reservoir Engineer will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all Plug for Redrill sundried wells have been updated to reflect current status. At this same time, they will also review the list of suspended wells for accuracy and assign expiration dates as needed. Research Analyst 2 Geologist or Reservoir Engineer Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 1/17/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PCU 02 (PTD 179-009) Perforation Record 12/18/2021 Please include current contact information if different from above. Received By: 01/20/2022 37' (6HW By Abby Bell at 10:30 am, Jan 20, 2022 MEMORANDUM TO: Jim Regg % P.I. Supervisor FROM: Austin McLeod Petroleum Inspector Well Name PRETTY CK UNIT 2 IInsp Num' mitSAM220105135429 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, January 6, 2022 SUBJECT: Mechanical Integrity Tests F ilcorp Alaska, LLC 2 PRETTY CK UNIT 2 Src: Inspector Reviewed By:: P.I. SupryZ Comm API Well Number 50-283-20022-90-00 Inspector Name: Austin McLeod Permit Number: 179-009-0 Inspection Date: 12/29/2021 " Thursday, January 6, 2022 Page 1 of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2 e Inj N-'TVD -- - ' Tubing726 �I 735 - j 745 - 754 PTD 1790090 �— —)_ Type Test SPT - Type � Test psi:1 ii IA i 9S8 5 - 1448 � -- - - - 1435 - 1432 _ BBL Pumped 05 -BBL Returned: 0.3` OA o T o o_ 0 t Interval l OTHER PIF PI - -- -J Sundry Pre Creek 2 is a producer. Sund 321-281. MITIA to 1300psi. "cement packer". Notes: P P Proposed TOC @ 3060' MD. Well was S/1 just prior o me arriving. _—� — Thursday, January 6, 2022 Page 1 of I David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-5245 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 08/26/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL: PCU-02 (PTD 179-009) FTP Folder Contents: Log Print Files and LAS Data Files: Please include current contact information if different from above. 37' (6HW Received By: 08/30/2021 By Abby Bell at 3:08 pm, Aug 26, 2021 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: N2 Operations Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 12,025 feet See schematic feet true vertical 12,025 feet N/A feet Effective Depth measured 3,293 feet 3,646 & 3,854 feet true vertical 3,293 feet 3,646 & 3,854 feet Perforation depth Measured depth 3,271 - 3,276 feet True Vertical depth 3,271 - 3,276 feet 2-7/8" LS 6.5 / N-80 3,988 (MD) 3,988 (TVD) Tubing (size, grade, measured and true vertical depth)2-7/8" SS 6.5 / N-80 3,788 (MD) 3,788 (TVD) 2-3/8" HTR 4.6 / N-80 1,799 (MD) 1,799 (TVD) Packers and SSSV (type, measured and true vertical depth) Baker AL-5 3,646 (MD) 3646 (TVD)SSSV: N/A Baker FH Pkr 3,854 (MD) 3,854 (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Contact Email: Authorized Title:Contact Phone: 3,810psi 3,090psi 6,330psi Burst Collapse 1,540psi 339' 2,032' 8,550'8,550'9-5/8" measuredPlugs Junk measured N/A Length 339' 2,032' Size Conductor Surface Intermediate 20" 13-3/8" Production Liner 8,550' Casing STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 179-009 50-283-20022-90-00 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0063048 Pretty Creek Field / Undefined Gas Pool Hilcorp Alaska LLC 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Pretty Creek Unit 02 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 0050 0 0 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 339' 2,032' N/A 0 Structural TVD 321-281 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: Authorized Name and Digital Signature with Date: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 0 0 Jake Flora jake.flora@hilcorp.com 907 777-8442Dan Marlowe, Operations Manager L G Form 10-404 Revised 10/2021 Submit Within 30 days of Operations By Meredith Guhl at 1:19 pm, Jan 21, 2022 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2022.01.21 12:14:54 -09'00' Dan Marlowe (1267) Updated by JLL 01/18/22 SCHEMATIC Pretty Creek Unit Pretty Creek Unit (PCU) 02 Last Completed: 10-11-07 PTD: 179-009 API: 50-283-20022-90-00 TD = 12,025’ PBTD= 4675’ RKB = 17.6’ 6 4 Cmt Ret @ 4675’ DV@ 4525’ DV@ 1048’ TOC @ 1500’ 8 9 10 11 12 13 A B C D E 1a 2a 3a 7 CIBP @ 3638’ Cmt Ret @ 3005’TOC @ 3060’ Tagged Fill @ 3644’ on 06/14/06 Sterling 48-0 Sterling 47-1 Sterling 45-8 Sterling X2 1 2 5 3 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Sterling X2 3,271' 3,276' 3,271' 3,276' 5' 12/18/2021 Open Sterling 45-8 3,319' 3,325' 3,319' 3,325' 6' 7/28/2021 Isolated Sterling 47-1 3,396' 3,416' 3,396' 3,416' 20' Sqz'd 2/79, 6/86 Sterling 48-0 3,442' 3,452' 3,442' 3,452' 10' Isolated 3,525' 3,570' 3,525' 3,570' 45' Sqz'd 2/79, 6/86 Upper Beluga 3,700' 3,780' 3,700' 3,780'80' Isolated Long String 3,892' 3,893' 3,892' 3,893' 1' Tubing Punch, 5/93 Mid Beluga 3,915' 3,980' 3,915' 3,980' 65' Isolated 4,794' 4,812' 4,794' 4,812' 18' Isolated Beluga 7,260' 7,280' 7,260' 7,280' 20' Isolated Open hole 8,550' 12,025' 8,550' 12,025' 3,475' Isolated CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. Hole Size CMT 20” 94 H-40 Butt 19.124 Surf 339’ 26” 600sx 13-3/8” 61 J-55 12.515 Surf 1048’ 17-1/2” 675sx w/ Top jobDV Collar 1048’ 1050’ J-55 Butt 12.515 1050’ 2032’ 660sx 9-5/8” 47/43.5 P-110 Surf 4525’ 12-1/4” 1020sx TOC @1500’ Ratty from 1500’-2000’ CBL DV Collar 4525’ 4527’ N-80 4527’ 8550’ 1110sx Tubing 2-7/8”LS 6.5 N-80 2.441 Surf 3988’200sx TOC @3060’ Temp Log 2-7/8”SS 6.5 N-80 2.441 Surf 3788’ 2-3/8”Htr 4.6 N-80 1.995 Surf 1799’ JEWELRY DETAIL NO.Depth Length ID OD Item 17.60’ FMC-OCT type TC-3C Tubing Hanger, 2-7/8” x 2-7/8” , 11” Long String 1. 3303’ CIBP w/ 10’ cement (TOC @ 3293’) 2. 3369’ CIBP w/ 12’ cement (TOC @ 3357’) 09-2006 3. 3600’ CIBP 4. 3608’ 2.85 2.31 3.6875 2-7/8”EU 8RD Sldg Slve 5. 3630’ CIPB 6. 3646’ 14.21 3.00 8.50 9-5/8” Baker AL-5 Dual Packer w/ Brown Safety Joint (3640) 7. 3688’ 99.00 2.44 3.50 2-7/8” EU 8RD Baker Blast Joint 8. 3819’ 0.96 2.31 3.6875 2-7/8” EU 8RD Baker F nipple 9. 3852’ 2.76 2.25 3.375 2-7/8”EU 8RD Sldg Slve 10. 3854’ 7.85 2.44 8.437 9-5/8” Baker FH Packer 11. 3894’ 0.81 2.25 3.6875 2-7/8” EU 8RD Baker R nipple 12. 3899’ 89.00 2.44 3. 5 2-7/8” EU 8RD Baker Blast Joint 13. 3988’ 0.54 2.18 3.6875 2-7/8” EU 8RD Baker Shear out Sub Short String A. 910’ 0.96 2.31 3.6875 2-7/8” EU 8RD Baker F nipple B. 3646’ 13.43 3.00 8.50 9-5/8” Baker AL-5 Dual Packer C. 3688’ 0.81 2.31 3.6875 2-7/8” EU 8RD Baker R nipple D. 3689’ 99.00’ 2.44 3.50 2-7/8” EU 8RD Baker Blast Joint E. 3788’ 0.60 2.18 3.6875 2-7/8” EU 8RD ½ Mule Shoe Heater String 1a. 20’ 0.81 1.99 2-7/8” x 2-3/8” Cross-over 2a. 707’ 1.80 1.87 3.125 2-3/8” EU 8RD Baker F nipple 3a. 1800’ 0.66 2.00 2.875 2-3/8” Buttress ½ Mule Shoe Tbg Punches LS 3615’–3625’ SS 3625’–3635’ Rig Start Date End Date CTU 7/28/21 12/28/21 08/11/2021 - Wednesday 07/28/2021 - Wednesday MIRU SLB Coiled tubing with 1.75" coil. MU scaffolding around production tree. NU BOPs and function test. NO BOPE test required since last test was within a week on 7/24/2021. PU injector, lubricator and MU BHA. 1.75" CTC, 1.75" DFCV, 1.75" stinger, 1.75" DJN. Go to the well and PT 250 psi low / 4000 psi high. Test check valves. Open well. WHP = 0 psi. RIH and dry tag at 2264'. Pump KCl down coil and take returns to surface. Once perf interval was reached at 3323' ctmd, lost all returns. PUH and bullhead into formation. PUH to 2500' and pump KCl down backside. Pump tubing volume and shut down pump. RIH and dry tag at 3323'. POOH. Break lubricator above BOP's and lay down BHA. MIRU AK E-line. MU wireline valves and lubricator on top of coil BOPE. PT lubricator to 250 psi low / 3000 psi high. MU and RIH with 2.25" gauge ring. Tag at 3303' (uncorrected) Correlate to OH log and add 17'. Tag depth = 3321'. Send correlation data to Geo and confirm on depth. POOH,MU and RIH with 2-7/8" CIBP. GR/CCL to top of plug = 12.6'. Tag ~ 17' shallower with CIBP than with gauge ring. Send correlation data to Geo and confirm on depth. Set CIBP at 3303'. POOH. MU and RIH with 2" cement bailer. Dump bail 10' of cement on top of CIBP. TOC = 3293'. POOH. RDMO. WOC. 07/29/2021 - Thursday SLB coiled tubing with 1.75" coil. PU injector and lubricator joints. MU BHA to blowdown well with N2. Go the well and stab onto BOP's. PT 250 psi low / 3000 psi high. RIH with slim BHA, 1.75" DJN. Stop at 3285' ctmd and blow down well with N2. POOH. Pressure up well to 1200 psi with N2 and close swab. RDMO. 08/12/2021 - Thursday Arrive at airport, fly to BRU. check in, Recover equipment move to location. Rig up. Return to camp. Go to location, JSA/Rig up, Build Gun's, PT lubricator 250 low 3k high. O-ring failure, Laydown lubricator replace O-ring. RIH with 1-11/16" WB, 1-11/16" GGR, 1-11/16" SS, 2-1/8" x 5' strip gun, Unable to fall, hitting something at tree. POOH Stab off to diagnose issue. Re-bent carrier end added weight bar. RIH caught up in tree again, working line. Line freed RIH caught up again at 10.3' worked line to 17.8' unable to gat past obstruction POOH. OOH standby, RIH with 1-11/16" WB, 1-11/16" GGR to tag cement. fell good after 30'. Correlating 3,295.5' to 2,900. POOH, OOH standby, RIH with 2.15 GR hung up at 17' worked tool to 80' POOH. OOH, Decision made to Rig up with slickline. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name PCU-02 50-283-20022-90-00 179-009 Rig Start Date End Date CTU 7/28/21 12/28/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name PCU-02 50-283-20022-90-00 179-009 12/28/2021 - Tuesday MITIA witnessed by AOGCC Inspector Austin McLeod. Start psi 1448 added 15 gallons of methanol. 15 minutes 1435. 30 minutes 1432. Bleed off 10 gallons. 12/18/2021 - Saturday PJSM and PTW. Mobilize equipment to location. Spot equipment, M/U lubricator, stab on well and PT, Replaced 2 lubricator o-rings that were leaking during the test, tested again to 250psi/3000psi - Test good SITP 1065psi of N2,M/U 2" weight bar, gamma, ccl, and 5ft - 2-1/8" , 4SPF spiral strip gun (CCL to top shot 8.75') and RIH. Cannot make it through the tree. Hand spang with no luck, L/D strip gun. RIH with 2" weight bar, gamma, ccl, with bull nose. RIH to 100ft with no problem. POOH,M/U 2" weight bar, gamma, ccl, and 5ft - 1-11/16"OD, 9.5gram, 4SPF spiral strip gun (CCL to top shot 8.2') and RIH. Pull correlation pass and send to town. On depth,Pull on depth and perforate the Sterling X2 sands from 3,271-3,276. POOH. SITP 0min - 1061psi, 5min - 1061psi, 10min - 1057psi, 15min - 1053psi, 30min - 1044psi. Lay down guns. All shots fired. RD E-line. Secure well and SDFN 09/25/2021 - Saturday Conduct JSA and approve PTW. AK E-line arrive on location and spot equipment. Wait on man lift to arrive. MU pump-in sub on top of 'long string', MU 2-1/8" x 5' strip gun. Wait on SLB N2 to arrive before stabbing on with gun BHA, SLB nitrogen rigged up to pump-in sub and PT to 3,000 psi. Pressure well from 700 psi to 1,240 psi. Wireline attempt to RIH, but cannot get through tree. Attempt to hand spang and still cannot get through tree. RDMO both AK E- line and SLB N2 pump. 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: __N2_________________ 2. Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6.API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 12,025'N/A Casing Collapse Structural Conductor Surface 1,540psi Intermediate Production 3,810psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Ted Kramer Operations Manager Contact Email: Contact Phone: 777-8420 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: July 1, 2021 2-3/8" HS 8,550' Perforation Depth MD (ft): See Attached Schematic 8,550'8,550'9-5/8" 20" 13-3/8" 339' 2,032'3,090psi 339' 2,032' 339' 2,032' N-80 TVD Burst 3,988' LS; 1,800' HS 6,330psi MDLengthSize Undefined Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 63048 179-009 50-283-20022-90-00 Pretty Creek Unit (PCU) 02 Pretty Creek / Sterling Undefined Gas COMMISSION USE ONLY Authorized Name: Tubing Grade: N-80 Tubing MD (ft): 3,788' See Attached Schematic tkramer@hilcorp.com 12,025'3,354'3,354'1,163 See Schematic Baker FH; AL-5 Dual; N/A 3,854' MD/TVD; 3,645' MD/TVD; N/A, N/A Perforation Depth TVD (ft):Tubing Size: 2-7/8" LS & SS m n P 66 t _____ Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 1:20 pm, Jun 04, 2021 321-281 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.06.04 09:56:59 -08'00' Taylor Wellman (2143) DLB 10-404X DSR-6/7/21DLB 06/09/2021 00 CT BOP Test to 3000 psi. Provide 48 hrs notice to AOGCC inspectors to witness MITIA to 1300 psi. See comments on attached procedure. X BJM 6/18/21 dts 6/18/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.06.18 10:30:11 -08'00' RBDMS HEW 6/21/2021 Well Prognosis Well: Pretty Creek #2 Date: 6/1/21 Well Name: Pretty Creek #2 API Number: 50-283-20022-90-00 Current Status: SI Leg: N/A Estimated Start Date: 7/1/2021 Rig: Coil / E-line Reg. Approval Req’d? 10-403 Sundry Number: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 179-009 First Call Engineer: Ted Kramer (907) 777-8420 (985) 867-0665 Second Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (C) Maximum Expected BHP: ~ 1480 psi @ 3,179’ TVDss Calc. on a 0.452 psi/ft gradient Max. Potential Surface Pressure: ~ 1163 psi Gas gradient to surface @ 0.1 psi/ft Well Status PC-02 is currently SI. Well Summary: This well was originally drilled in April of 1969 as the Theodore River #1. In February of 1979, the well was re-named the Pretty Creek #2 after it was re-entered. The sand interval at 3,915 – 3,980 was tested in this year. In June of 1986 the well was re-entered and three intervals were tested. Two of the three intervals were productive with the lower interval (3,915-3,980’) testing ate a 1.3 MMSCFD rate at 1625 psig and the Middle interval testing at 5.25 MMSCFD at 860 psig. In November 1986 Unocal assumed operatorship of Pretty Creek. In December of that same year, the well was re-completed with the current dual string completion. The Long String (LS) was completed in the C3 and the Short String (SS) was completed in the Sterling C1 sand. The short string was soon SI due to high water production. In May of 1993 the long string was SI due to a Susitna River Pipeline Rupture. The pipeline was repaired and the long string returned to production in January 1994. The long string flowed until March 1999 when it eventually loaded up and died. In September of 2006 a coil cleanout was performed of both the long and short strings. A CIBP was set at 3,630’ in the LS and at 3,638’ in the SS. Both strings were tubing punched and a cement retainer set in the SS at 3,005’. Coil was utilized to circulate cement around both tubing strings in the annulus creating a cement packer. The height of the cement packer was measured to be 3,060’ by a temperature survey. The Sterling A3 was then perforated and IP’d at 3.5 MMscfd, flowed for a while and then loaded up with sand . In October of 2007 a CIBP was set in the long string at 3,369’ and the Sterling A1 (3319 – 3,325’) was perforated. Minor initial flow was encountered and the well sanded up and died. In August of 2019 a slickline tag was made. Fill was tagged at 3,130’. Bailed down to 3226’ and the fill came back in to 2,318’. The well was then SI. September of 2006 a Both strings were tubing punched and a cement retainer set in the SS a Coil was utilized to circulate cement around both tubing strings in the annulus creating a cement packer. The height of the cement packer was measured to be 3,060’ Well Prognosis Well: Pretty Creek #2 Date: 6/1/21 Objective: The objective of this work is to clean out the sand with coil tubing, set a plug and move up hole and perforate the Sterling X1 and X2 sands. Procedure 1. MIRU Coil Tubing Unit. Pressure test bop stack to 3,000 psi high / 250 psi low. 2. PU RIH W/coil tubing jet nozzle and C/O fill using water to 3,369’ (+/-). 3. RU E-line on top of the coil BOPs and pressure test lubricator to 3,000 psi. 4. PU and RIH W/ a 2-7/8” CIBP and set same @3,308’ (+/-). Dump 10’ of cement on top (Est. TOC = 3,298’). RD E-line. WOC. Note: Hilcorp requests a waiver from 20 AAC 25.112.(c)(E) – the placing of 25’ of cementon top of a CIBP. Because of the distance restriction, we only have room for 10’ of cement. 5. RIH With Coil tubing and blow down well W/ nitrogen to 3,290’. Trap 1,100 psi on well. 6. RDMO Coil Tubing Unit. E-line Procedure 7. MIRU E-line. Pressure test lubricator to 3,000 psi. 8. Perforate the following sand intervals, one at a time, from bottom to top. Test each interval after perforating. Proposed Perf Adds to Sundry: FORMATION INTERVAL (Status) MD TOP MD Base Total Ftg Sterling X1 ±3,166 ±3,222’ 56’ Sterling X2 ±3,270’ ±3,277’ 7’ a. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Geologist, Reservoir Engineer, and Operations Engineer for confirmation (Matt Petrowsky, Anthony McConkey, Ted Kramer- respectfully) b. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record a tubing Surface pressure before each run and after each gun firing of 5, 10, 15 min reading intervals. c. The Sterling Sands at Pretty Creek are governed as “Sterling Undefined” d. Should the X2 produce water, sand, or both, Hilcorp as a contingency will set a plug and cement above this interval before moving up to perforate the X1. 9. POOH. RD e-line. 10. Turn well over to production. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Coil BOP Stack 4. Standard Nitrogen Procedure Variance is not required if these perfs are all part of the same pool. bjm Proposed work will take place in the long string. Provide 48 hrs notice for AOGCC to witness BOP test. Hilcorp requests a waiver from 20 AAC 25.112.(c)(E) – the placing of 25’ of cementon top of a CIBP. Because of the distance restriction, we only have room for 10’ of cement. MITIA to 1300 psi within 10 days after returning the well to production after the second set of perforations are shot. If, sustained casing pressure develops after the first set of perforations are shot, submit wellhead pressure trend data to AOGCC and discuss plan forward before shooting 2nd perf interval. Provide 48 hrs notice to AOGCC to witness test. bjm Updated by DMA 06-01-21 SCHEMATIC Pretty Creek Unit Pretty Creek Unit (PCU) 02 Last Completed: 10-11-07 PTD: 179-009 API: 50-283-20022-90-00 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. Hole Size CMT 20” 94 H-40 Butt 19.124 Surf 339’ 26” 600sx 13-3/8” 61 J-55 12.515 Surf 1048’ 17-1/2” 675sx w/ Top job DV Collar 1048’ 1050’ J-55 Butt 12.515 1050’ 2032’ 660sx 9-5/8” 47/43.5 P-110 Surf 4525’ 12-1/4” 1020sx TOC @1500’ Ratty from 1500’-2000’ CBL DV Collar 4525’ 4527’ N-80 4527’ 8550’ 1110sx Tubing 2-7/8” LS 6.5 N-80 2.441 Surf 3988’ 200sx TOC @3060’ Temp Log 2-7/8” SS 6.5 N-80 2.441 Surf 3788’ 2-3/8” Htr 4.6 N-80 1.995 Surf 1799’ JEWELRY DETAIL NO. Depth Length ID OD Item 17.60’ FMC-OCT type TC-3C Tubing Hanger, 2-7/8” x 2-7/8” , 11” Long String 1. 3369’ CIBP w/ 12’ cement (TOC @ 3357’) 09-2006 2. 3600’ CIBP 3. 3608’ 2.85 2.31 3.6875 2-7/8”EU 8RD Sldg Slve 4. 3630’ CIPB 5. 3646’ 14.21 3.00 8.50 9-5/8” Baker AL-5 Dual Packer w/ Brown Safety Joint (3640) 6. 3688’ 99.00 2.44 3.50 2-7/8” EU 8RD Baker Blast Joint 7. 3819’ 0.96 2.31 3.6875 2-7/8” EU 8RD Baker F nipple 8. 3852’ 2.76 2.25 3.375 2-7/8”EU 8RD Sldg Slve 9. 3854’ 7.85 2.44 8.437 9-5/8” Baker FH Packer 10. 3894’ 0.81 2.25 3.6875 2-7/8” EU 8RD Baker R nipple 11. 3899’ 89.00 2.44 3. 5 2-7/8” EU 8RD Baker Blast Joint 12. 3988’ 0.54 2.18 3.6875 2-7/8” EU 8RD Baker Shear out Sub Short String A. 910’ 0.96 2.31 3.6875 2-7/8” EU 8RD Baker F nipple B. 3646’ 13.43 3.00 8.50 9-5/8” Baker AL-5 Dual Packer C. 3688’ 0.81 2.31 3.6875 2-7/8” EU 8RD Baker R nipple D. 3689’ 99.00’ 2.44 3.50 2-7/8” EU 8RD Baker Blast Joint E. 3788’ 0.60 2.18 3.6875 2-7/8” EU 8RD ½ Mule Shoe Heater String 1a. 20’ 0.81 1.99 2-7/8” x 2-3/8” Cross-over 2a. 707’ 1.80 1.87 3.125 2-3/8” EU 8RD Baker F nipple 3a. 1800’ 0.66 2.00 2.875 2-3/8” Buttress ½ Mule Shoe PERFORATION INTERVAL Interval Accum. Zone Top Btm Amt spf Comments Sterling 45-8 3,319' 3,325' 6' 6 Open Sterling 47-1 3,396' 3,416' 20' Sqz'd 2/79, 6/86 Sterling 48-0 3,442' 3,452' 10' 6 Isolated 3,525' 3,570' 45' Sqz'd 2/79, 6/86 Upper Beluga 3,700' 3,780' 80' 12 Isolated Long String 3,892' 3,893' 1' 3 holes Tubing Punch, 5/93 Mid Beluga 3,915' 3,980' 65' 12 Isolated 4,794' 4,812' 18' Isolated Beluga 7,260' 7,280' 20' Isolated Open hole 8,550' 12,025' 3,475' Isolated Tbg Punches LS 3615’–3625’ SS 3625’–3635’ Updated by DMA 06-01-21 PROPOSED SCHEMATIC Pretty Creek Unit Pretty Creek Unit (PCU) 02 Last Completed: 10-11-07 PTD: 179-009 API: 50-283-20022-90-00 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. Hole Size CMT 20” 94 H-40 Butt 19.124 Surf 339’ 26” 600sx 13-3/8” 61 J-55 12.515 Surf 1048’ 17-1/2” 675sx w/ Top job DV Collar 1048’ 1050’ J-55 Butt 12.515 1050’ 2032’ 660sx 9-5/8” 47/43.5 P-110 Surf 4525’ 12-1/4” 1020sx TOC @1500’ Ratty from 1500’-2000’ CBL DV Collar 4525’ 4527’ N-80 4527’ 8550’ 1110sx Tubing 2-7/8” LS 6.5 N-80 2.441 Surf 3988’ 200sx TOC @3060’ Temp Log 2-7/8” SS 6.5 N-80 2.441 Surf 3788’ 2-3/8” Htr 4.6 N-80 1.995 Surf 1799’ JEWELRY DETAIL NO. Depth Length ID OD Item 17.60’ FMC-OCT type TC-3C Tubing Hanger, 2-7/8” x 2-7/8” , 11” Long String 1. ~3308’ CIBP w/ 10’ cement (TOC @ ~3298’) 2. 3369’ CIBP w/ 12’ cement (TOC @ 3357’) 09-2006 3. 3600’ CIBP 4. 3608’ 2.85 2.31 3.6875 2-7/8”EU 8RD Sldg Slve 5. 3630’ CIPB 6. 3646’ 14.21 3.00 8.50 9-5/8” Baker AL-5 Dual Packer w/ Brown Safety Joint (3640) 7. 3688’ 99.00 2.44 3.50 2-7/8” EU 8RD Baker Blast Joint 8. 3819’ 0.96 2.31 3.6875 2-7/8” EU 8RD Baker F nipple 9. 3852’ 2.76 2.25 3.375 2-7/8”EU 8RD Sldg Slve 10. 3854’ 7.85 2.44 8.437 9-5/8” Baker FH Packer 11. 3894’ 0.81 2.25 3.6875 2-7/8” EU 8RD Baker R nipple 12. 3899’ 89.00 2.44 3. 5 2-7/8” EU 8RD Baker Blast Joint 13. 3988’ 0.54 2.18 3.6875 2-7/8” EU 8RD Baker Shear out Sub Short String A. 910’ 0.96 2.31 3.6875 2-7/8” EU 8RD Baker F nipple B. 3646’ 13.43 3.00 8.50 9-5/8” Baker AL-5 Dual Packer C. 3688’ 0.81 2.31 3.6875 2-7/8” EU 8RD Baker R nipple D. 3689’ 99.00’ 2.44 3.50 2-7/8” EU 8RD Baker Blast Joint E. 3788’ 0.60 2.18 3.6875 2-7/8” EU 8RD ½ Mule Shoe Heater String 1a. 20’ 0.81 1.99 2-7/8” x 2-3/8” Cross-over 2a. 707’ 1.80 1.87 3.125 2-3/8” EU 8RD Baker F nipple 3a. 1800’ 0.66 2.00 2.875 2-3/8” Buttress ½ Mule Shoe PERFORATION INTERVAL Interval Accum. Zone Top Btm Amt spf Comments Sterling X1 ~3,166' ~3,222' 56' Proposed Sterling X2 ~3,270' ~3,277' 7' Proposed Sterling 45-8 3,319' 3,325' 6' 6 Isolated Sterling 47-1 3,396' 3,416' 20' Sqz'd 2/79, 6/86 Sterling 48-0 3,442' 3,452' 10' 6 Isolated 3,525' 3,570' 45' Sqz'd 2/79, 6/86 Upper Beluga 3,700' 3,780' 80' 12 Isolated Long String 3,892' 3,893' 1' 3 holes Tubing Punch, 5/93 Mid Beluga 3,915' 3,980' 65' 12 Isolated 4,794' 4,812' 18' Isolated Beluga 7,260' 7,280' 20' Isolated Open hole 8,550' 12,025' 3,475' Isolated Tbg Punches LS 3615’–3625’ SS 3625’–3635’ STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS R~~~1 0/ ~D APR ~ 7 2008 1. Operations Abandon Repair Well Plug Perforations ~ f Stimulate aS OnS. Otpfn Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension^ Anchorage Change Approved Program ^ Operat. Shutdown^ Perforate Q Re-enter Suspended Well^ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development^ • Exploratory^ 179-009 • 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic^ Service^ 6. API Number: 50-283-20022-90-00 7. KB Elevation (ft): 9. Well Name and Number: 17.6' PCU #02 8. Property Designation: 10. Field/Pool(s): Pretty Creek Unit / ADL 63048 ' ~I Pretty Creek Field/Sterling u/~c•~~ G~R.S _2.2. •~ 11. Present Well Condition Summary: Total Depth measured 12,025' feet Plugs (measured) 3005',3638', SS,3369'3600',3630' LS true vertical 12,025' feet Junk (measured) None Effective Depth measured 3354' feet true vertical 3354' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 339' 20" 339' 339' Surface 2,032' 13-3/8" 2,032' 2,032' 3,090 psi 1,540 psi Intermediate Production 8,550' 9-5/8" 8,550' 8,550' 6,330 psi 3,810 psi Liner ~~NNE~ APR ~ ~ 2008 Perforation depth: Measured depth: See attach SChematlC True vertical deptn: See Attach Schematic Tubing: (size, grade, and measured depth) 2-7/8" LS & SS, 2-3/8" HS, N-80 3788' SS, 3988' LS, 1800' HS Packers and SSSV (type and measured depth) Baker FH Pkr - 3854' AL-5 Dual Pkr - 3646' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: ~ - -~ ~~ ~~'~ ~ ~ ~a~~ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 950 psi Subsequent to operation: 0 131 0 0 940 psi 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil^ Gas Q WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-252 Contact Steve Tyler - 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature ~ ~ Phone 907-276-7600 Date 4/15/2008 Form 10-404 Revised 04/2006 ~ K ~ ~ ~ ~ A L ~a~ ~/v~3 Submit Origina~ ~~ ~g ~IOIi Chevron Chevron -Alaska Daily Operations Summary Wetl Name PCU-02 Field Name PRETTY CREEK, API/U1M 502832002290 Lease/Serial ADL0063048 Orig KB Etev (ftK6) 96.0 Water Depth (ft) Primary Job Type Recompletion Primary Wellbore Affected Main Hole Jobs AFE No. QC Eng R7033 Daily Operations 10/8/2007 00:00 - 10/9!2007 00:00 Operations Summary Mobe and spot equipment. 10/9/2007 00:00 - 10/10/2007 00:00 Operations Summary Set bridge plug at 3369' and dump bail 12' cement on top. 10/10/2007 00:00 -10/11/2007 00:00 Operations Summary Wait on cement and pressure test plug. 10/11/2007 00:00 - 10/12/2007 00:00 Operations Summary Perforate the Sterling 45-8 zone from 3319' to 3325' w/2" Omega, 6 spf, 60 degree phase. Secure well and turn over to production. Demobe equipment. Chevron Pretty Creek Well: PC-2 10/20/07 OPERATION SUMMARY: • 10/8/07 -Mobe and spot equipment. • 10/9/07 -Set bridge plug at 3369' and dump bail 12' cement on top of plug. WOC. • 10/10/07 - WOC and pressure test plug to 1500 psi, with field gas for, 12 hrs (good test and have on chart. Blow tubing down to 200 psi for negative test (1St 4 hrs). • 10/11/07 -Finish 12 hr negative test. Tag top of cement at 3354'. Perforate the Sterling 45-8 zone from 3319' to 3325' w/2" omega, 6 spf, 60 degree phase. • UNOCALO ('ACING ANiI TIIRING IIFTAIi, RKB = 17.6' TOf CIB' CIB CIB 517.E N'T GRADE CONN ID TOP BTM. Hole Size CMT 20" 94 H-40 Butt 19.124 Surf 339' 26" 600sx J-55 12.515 Surf 1048' 675sx 13-3/8" 61 DV Collar 1048' 1050' 17-1/2" w/Topjob J-~5 Butt 12.515 1050' 2032' 660sx P-110 Surf 4525' 1020sx 9-5/8" 47/43.5 DV Collar 4525' 4527' 12-1/4" TOC~1300' Rutyfrom1300'3000' CBL N-80 4527' 8550' 1110sx Tubin 2-7/8" LS 6.5 N-80 2.441 Surf 3988' 200sx 2-7/8" SS 6.5 N-80 2.441 Surf 3788' nx~ mono ,em ~~ 2-3/8" Htr 4.6 N-80 1.995 Surf 1799' oo' ~-etty Creek Unit Well PCU #2 Completion 10-11-07 IFWFI.RV IIFTAII. NO. De th Len th ID OD Item 17.60' FMC-OCT e TC-3C Tubin Han er, 2-7/8" x 2-7/8" , ] 1" Long String 1. 3608' 2.85 2.31 3.6875 2-7/8"EU 8RD Sldg Slve 2. 3646' 14.21 3.00 8.50 9-5/8" Baker AIrS Dual Packer w/ Brown Safe Joint 3640 3. 3688' 99.00 2.44 3.50 2-7/8" EU 8RD Baker Blast Joint 4. 3819' 0.96 2.31 3.6875 2-7/8" EU 8RD Baker F nipple 5. 3852' 2.76 2.25 3.375 2-7/8"EU 8RD Sldg Slve 6. 3854' 7.85 2.44 8.437 9-5/8" Baker FH Packer 7. 3894' 0.81 2.25 3.6875 2-7/8" EU 8RD Baker R nipple 8. 3899' 89.00 2.44 3. 5 2-7/8" EU 8RD Baker Blast Joint 9. 3988' 0.54 2.18 3.6875 2-7/8" EU 8RD Baker Shear out Sub Short String A. 910' 0.96 2.31 3.6875 2-7/8" EU 8RD Baker F nipple B. 3646' 13.43 3.00 8.50 9-5/8" Baker AIrS Dual Packer C. 3688' 0.81 2.31 3.6875 2-7/8" EU 8RD Baker R nipple D. 3689' 99.00' 2.44 3.50 2-7/8" EU 8RD Baker Blast Joint ' E. 3788' 0.60 2.18 3.6875 2-7/8" EU 8RD 'h Mule Shoe Heater String la. 20' 0.81 1.99 2-7/8" x 2-3/8" Cross-over 2a. 707' 1.80 1.87 3.125 2-3/8" EU 8RD Baker F nipple 3a. 1800' 0.66 2.00 2.875 2-3/8" Bumess '/, Mule Shoe 30f 38' 36: PRRF(1RSTI(lN iNTFRVAI. Interval Accum. Zone To Btm Amt s f Comments Sterlin 488 3,319' 3,325' 6' 6 O n Sterli 47-1 3,396' 3,416' 20' Sid 2/79, 6/86 Sterlin 48-0 3,442' 3,452' 10' 6 Isolated 3,525' 3,570' 45' Sid 2/79, 6/86 U r Bel a 3,700' 3,780' 80' 12 Isolated Lon Strin 3,892' 3,893' 1' 3 holes Tub' Punch, 5/93 Mid Bel a 3 915' 3,980' 65' 12 Isola[ed 4,794' 4,812' 18' Isolated Bel a 7,260' 7,280' 20' Isolated O en hole 8.550' 12,025' 3,475' Isolated Tbg Punches LS 3615'-3625' 's' SS 3625'-3635' PCU #2 Final Schematic 10-11-07.doc DRAWN BY: SLT REVISED: 10/11/07 TD = 12,025' PBTD = 4675' Max Hole Angle = Page 1 of 1 • Maunder, Thomas E (DOA) From: Tyler, Steve L [tytersl@chevron.camj Sent: Monday, April 28, 2008 2:31 PM To: Maunder, Thomas E (DOA) Cc: Brandenburg, Tim C Subject: RE: PCU #2 (179-009) Attachments: PC #2 Operation Summary dated 10-1120-07.d~oc; HP Test on BriygeWPlug.jpg Tom l'nC`.~ Cl ~J t r ~-ll~ add-1-~ Please find the revised PCU #2 Ops Summery and a copy of the pressure chart attached. The bridge plug was pressure tested to 1500 psi with field gas for 12 hrs on chart. No record of contacting AOGCC to witness the test on the morning reports. From: Maunder, Thomas E (DOA) [maiito:tom.maunder@alaska.gov] Sent: Wednesday, Apri( 23, 2008 1:52 PM To: Tyler, Steve L Cc: Brandenburg, Tim C Subject: PCU #2 (179-009) Steve and Tim, 1 am reviewing the 404 submitted for setting the BP and perforating this well. For 10110 -10/11-07 it is noted that the plug was pressure tested. Could you please provide some details as to how the plug was tested? Copies of any charts that were recorded should should also tie provided. Was an Inspector contacted? The detail in some of these reports is getting "thine. In some ways they read like a procedure not tike the report of accomplishing an operation. We may need to discuss the detail provided. Look forward to your reply. Tom Maunder, PE AOGCC ~iagiaoas Page 1 of 1 • Davies, Stephen F (DOA) From: Applewhite, Billy -APRs [contractor] [ApplewhiteB@chevron.com] Sent: Monday, Juty 30, 200711:26 AM To: Davies, Stephen F (DOA) Cc: Applewhite, Billy APRS [contractor] Subject: Pretty Creek #2, 403 sundry form info Steve, ~! ,~~. ~~ Do not need spacing excepfion and nearest property line is: 1590' south and 2140' west from northeast corner of sec. 33, T14N, R9N, SM. Pretty Creek #4 is not perforated in the zone that we are doing in PC #2. Thanks, Billy Applewhite 263-7671 4/22/2008 • Chevron LOG TYPE January 2, 2008 To: AOGCC Mahnken, Christine R 333 W. 7th Ave. Ste# 100 Anchorage, AK 99501 ~ - . ~ , ~ .JELL ~~-~09 ~~~3r - I NUTES- RUN ~ B- ~ L?,S, ~ N LINE ~ RLP;4 CD i PDS, I i I I DLIS 3100 - 3340 ~ 1 ~ 1 ~ ~ 1 PDS ~: Please acknowledge receipt by signing and returning one copy of this trans - 'J<~o~+9~=-263 7828. Francisco Castro Technical Assistant Chevron North America Exploration and Production 909 W. 9th Avenue Anchorage, AK 99501 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com ,ALE ', LOG DhTE IfJTER'/,;L LUGGED COMPLETION RECORD HES MAGNA RANGE BPNV 10' CEMENT PLUG 2" HSD POWERJET OMEGA 6 SPF 5" Received ey: l Date: I:j~3 ~ :~, ?r~,~ ~~_ Chevro n ,!*ti,~ . ~.~. December 3, 2007 To: AOGCC Christine Mahnken 333 W. 7t" Ave. Ste# 100 Anchorage, AK 99501 PERMIT # API NUf~1BER WELL ~ LOG TYPE SCALE LOG DATE INTERVAL RUN B- FILPA CD ~ NOTES - LOuGED # LINE ~; LAS, ', PDS. I DL15 COMPLETION RECORD 2' POWERJET OMEGA 179-009- 6SPF, 60 DEGREE 3300 - 0 502832002290 PCU-2LS PHAZED 5" 2-Sep-06 3535 1 1 1 PDS COMPLETION RECORD HALLIBURTON BRIDGE PLUG, CEMENT RETAINER 179-009- 1.56" TUBING 27-Aug- 2865 - 0 502832002290 PCU-2SS PUNCHER 5" 06 3650 1 1 1 PDS COMPLETION RECORD HALLIBURTON 179-009- BRIDGE PLUG, 1.56" 28-Aug- 2866 - 0 502832002290 PCU-2LS TUBING PUNCHER 5" 06 3650 1 1 1 PDS ~ 5~5~ k~ ~~:., ~ Please acknowledge receipt by signing and returning one copy of t ~Ir 'r?o 907 263 7828. Francisco Castro Technical Assistant Chevron North A•ica Exploration and Production 909 W. 9th Avenue Anchorage, AK 99501 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com ra;~~~ D ~ C ~. ~ 2007 Received By: Date: ~~ ;~ ~ ?(~~1~ ~~.9s :+ti~edi ~ ab , . ~~~~~-- · . ~V~VŒ lID~ ~~~~fK{~ / AI.lA~1iA. OILAlWD GAS I CONSERVATION COMMISSION I t SARAH PAUN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manger UNOCAL PO Box 196247 Anchorage, AK 99519 sCANNED AUG 0 3 2007 Re: Pretty Creek Field, Undefined Pool, PCU #02 Sundry Number: 307-252 \1 q -oöq Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may fIle with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this L day of August, 2007 Encl. 1. Type of Request: Abandon 0 Suspend 0 Operational shutdown 0 Perforate [] - Waiver 0 Other 0 Alter casing 0 Repair well 0 Plug Perforations [] Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development [] Exploratory 0 179-009 . - 3. Address: Stratigraphic 0 Service 0 6. API Number: P.O. Box 196247, Anchorage, Alaska 99519 50-283-20022-90-00 - 7. If perforating. closest approach in pool(s) opened by this operation to n7;:.. ~ tl 8. Well Name and Number: property line where ownership or landownership changes: - ;¡f6l>' -...~~ Spacing Exception Required? Yes 0 No [] b~ J,.!JI. PCU #02 - 9. Property Designation: C,3ot/t At. 10. KB'Ëlevation (ft): 11. Field/Pool(s): /~ ¿!¡~ Pretty Creek Unit .APt.. #",. z..7,1> 17.6' Pretty Creek Field/ ¡nQ a~ 9i/L16 CJ1 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12.025' 12,025' / 3600' 3600' 3005'.3638'.3600'.3630' Casing Length Size MD TVD Burst Collapse Structural Conductor 339' 20" 339' 339' Surface 2.032' 13-3/8" 2,032' 2.032 3.090' 1 .540 psi Intermediate Production 8,550' 9-5/8" 8,550' 8,550' 6,330 psi 3,810 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft):1800'-HS See Attached Schematic See Attached Schematic 2-7/8" LS & SS, 2-3/8" HS N-80 3788'-SS. 3988'-LS Packers and SSSV Type: Baker FH Packer, Baker AL-5 Dual Packer Packers and SSSV MD (ft): FH - 3854'. AL-5 - 3640' 13. Attachments: Description Summary of Proposal [] 14. Well Class after proposed work: . Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development [] Service 0 15. Estimated Date for .!~7 ~~'CU., 16. Well Status after proposed work: Commencing Operations: <6"1 \ 5 J ðCX)\ Oil 0 Gas [] . Plugged 0 Abandoned 0 17. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Billy Applewhite - 263-7671 Printed Name Timothy Brandenburg Title Drilling Manager Signature ~. Phone Date 7/24/2007 ---1 10 I" T~ M. ßf"''''.....L-\... r ~ . COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 20~ .. ~d- Plug Integrity ~ BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: <.o,,~,* 'I.~~<t,-Th~,·Ö~~~~~·~ ~~~"'>~ ç~~~~ ~~~.~ Subsequent Form Required: LI0lJ)q RBDMS BFL AUG 0 2 2007 ~ ~~ APPROVED BY ~--I-();- Approved by: COMMISSIONER THE COMMISSION Date: Va trG \ ~Âl ~~ i4 7·J¡·t>7 Form 10-403 Revised 06/2006 ~~ Submit i uplicate '" r::. \.J L- I V '- LJ' 0"/.7 STATE OF ALASKA It JUL 2 7 2007 ALASKA Oil AND GAS CONSERVATION COMM ION ~t \ APPLICATION FOR SUNDRY APPROVALS )~Iaska 1Ji! & Gas Cons. C(}mmission 20 MC 25 280 AnGhorage , . Chevron III . . Trading Bay Unit Well Pretty Creek #2 7/23/07 OBJECTIVE: · Abandon Sterling 48-0 Sand and Re-Complete in the Sterling 45-8 Sand. / PROCEDURE SUMMARY: · MOBE Equipment and rig up slickline. 0""' '- ~. · Run 2.32" gauge ring and tag fill at appox 3389' · Run 2.25"x10' dummy gun and tag fill. · Rig down slickline equipment and de-mobe. · Mobe e-line equipment and rig up. · Set Haliburton magna range bridge plug at 3380' (+/-). · Dump bail 10' cement on top of plug at 3380' (+/-). · WOC 12 hrs. Positive pressure test and negative pressure test. <:-c~~c...~1:'C'--c:.,~~ ~~~ ~~("'(5~ · Perforate Sterling 45-8 zone from 33l9' to 3325' (+/-)1 *~I, · Rig down e-line and turn well over to production. SRU 241-16 REVISED BY: BCA 3/15/07 RKB = 17.6' 13-3/8" 61 17-112" J-55 poll 0 9-5/8" TOC@1500' 47/43.5 DV Collar 12-] 14" RattyÍÍ1:Jm1500'-2000' CBL N-80 4527' 8550' 1 Jl Osx Tubin 2-7/8" LS 6.5 N·80 2.441 Surf 3988' 2-7/8" SS 6.5 N-80 2.441 Surf 3788' 4.6 N-80 1.995 Surf 1799' .~ VI<;I AU NO. n""III I Len!!:lh I wi OD Item I 17.60' I I I I FMC-OCT tvDe TC·3C Tubing Ranger, 2·7/8",,- 2-7/8" , 11" Long String 1. 3608' 2.85 2.31 3.6875 2-7/8"ED 8RD Sldg Slve 2. 3640' 14.21 3.00 8.50 9-5/8" Baker AL-5 Dual Packer wi Brown Safety Joint 3. 3688' 99.00 2.44 3.50 2·7/8" ED 8RD Baker Blast Joint 4. 3819' 0,96 2.31 3.6875 2-7/8" ED 8RD Baker f nipple 5. 3852' 2.76 2.25 3.375 2·7/8"ED 8RD Sldg Slve , 6. 3854' 7.85 2.44 8.437 9·5/8" Baker fR Packer 7. 3894' 0.81 2.25 3.6875 2·7/8" ED 8RD Baker R nipple 8. 3899' 89,00 2.44 3.5 2-7/8" ED 8RD Baker Blast Joint 9. 3988' 0.54 2.18 3.6875 2-7/8" ED 8RD Baker Shear out Sub Short String A 910' 0.96 2.31 3.6875 2-7/8" ED 8RD Baker F nipple B. 3646' 13.43 3.00 8.50 9·5/8" Baker AL-5 Dual Packer C. 3688' 0.81 2.31 3.6875 2-7/8" ED 8RD Baker R nipple D. 3689' 99.00' 2.44 3.50 2-7/8" ED 8RD Baker Blast Joint , E. 3788' 0.60 2.18 3.6875 2·7/8" ED 8RD 1, Mule Shoe Heater String la. 20' 0.81 1.99 2·7/8" x 2·3/8ê' Cross-over 2a, 701' I 1.80 1.87 3.125 2-3/8" ED 8RD Baker F nipple 3a. 1800' I 0.66 2.00 2.875 2·3/8" Buttress y, Mule Shoe PERFORATION INTERVAL Comments LS 3615'-3625' SS 3625'-3635' TD = 12,025' PBTD = 4675' Max Hole Angle = PCU #2 Current 9-02-06.doc DRAWN BY: SLT REVISED: 9/712006 RKB= 17.6' Hole Size 26" 600sx 675sx J 3-3/8" 6J J 7- J/2" wi Top job J-55 660sx P-JIO J 020sx TOC@1500' 9-5/8" 47/43.5 DV Collar J2-J/4" RattyfromJ500'·ZOOO· CBL N-80 4527' 8550' JJ JOsx Tubin 2-7/8" L8 6.5 N-80 2.44J Surf 3988' 2-7/8"88 6.5 N-80 2.44J Surf 3788' 4.6 N-80 1.995 Surf J799' ni'um! uv DETAIL NO. I Dentn LelJ!!tn m OD Hem I 17.60' T FMc·ocTiWe TC·3C Tubin~Hanger, 2-7/8" x 2-7/8",11" Long String 1. 3608' 2.85 2.31 3.6875 2· 7/8"ED 8RD Sldg Slve 2. 3640' 14.21 3.00 8.50 9·5/8" Baker AL-5 Dual Packer wi Brown Safety Joint 3. 3688' 99.00 2.44 3.50 2·7/8" ED 8RD Baker Blast Joint 4. 3819' 0.96 2.31 3.6875 2-7/8" ED 8RD Baker F nipple 5. 3852' 2.76 2.25 3.375 2·7/8"ED 8RD Sldg Slve '6. 3854' 7.85 2.44 8.437 9-5/8" Baker FH Packer 7. 3894' 0.81 2.25 3.6875 2·7/8" ED 8RD Baker R nipple 8. 3899' 89.00 2.44 3. 5 2·7/8" ED 8RD Baker Blast Joint 9. 3988' 0.54 2.18 3.6875 2-7/8" ED 8RD Baker Shear out Sub Short String A 910' 0.96 2.31 3.6875 2·7/8" ED 8RD Baker F nipple B. 3646' 13.43 3.00 8.50 9-5/8" Baker AL·5 Dual Packer C. 3688' 0.81 2.31 3.6875 2·7/8" ED 8RD Baker R nipple D. 3689' 99.00' 244 3.50 2·7/8" ED 8RD Baker Blast Joint , E. 3788' 0.60 2.18 3.6875 2-7/8" ED 8RD y, Mule Shoe Heater String la. 20' 0.81 1.99 2-7/8" x 2-3/8" Cross·over 2a. 701' 1.80 1.87 3.125 2·3/8" ED 8RD Baker F nipple 3a. 1800' 0.66 2.00 2.875 2"3/8" Buttress Yo Mule Shoe LS 3615'-3625' SS 3625'-3635' TD = 12,025' PBTD = 4675' Max Hole Angle = peu #2 Propopsed.doc DRA WN BY: SL T REVISED: 9/7/2006 . . Review of Sundry Application 307-252 Union Oil Company of California Well PCU #2 Pretty Creek Field, Undefined Gas Pool AOGCC Permit 179-009 Requested Action: Union Oil Company of California (Union Oil) proposes to plug the existing perforations in the well and to re-perforate the well. Recommendation: I recommend approval of Union Oil's request. Discussion: The PCU #2 well was originally drilled, and subsequently abandoned, as the Theodore River #1 well in 1969. The well was re-entered and re-named in 1979. PCU #2 began gas production in December 1986 and produced essentially continuously until January 1999 when the well was shut-in due to fill accumulation in the wellbore. Cumulative production to this time was approximately 6.4 BCF. The well was originally completed with dual strings that produced from the Beluga formation. Attempts to bail the sand and re-establish production were unsuccessful. In May 2006 the Commission approved Union Oil's request to plug the existing Beluga perforations and re-complete the well in the Sterling Formation (Sundry 306-152). This approval authorized Union Oil to perforate three different gas sands, the 48-0, 47-1, and 45-8. The work was performed in August and September 2006, but only one of the sands, the 48-0, was perforated. The well was put on production in December 2006 and produced for parts of the next seven months. Aside from January 2007, when production averaged about 675 MCFPD, the well has not been on production for an entire month since it was returned to service. Cumulative production since the workover has been about 50 MMCF. Union Oil now proposes to plug the 48-0 sand and perforate one of the other sands, the 45-8, which was approved for perforation in May 2006. Union Oil did not provide a specific reason for this proposed work in their application on August 1, 2007, I talked with Mr. Billy Applewhite about the reason for plugging the existing perforations and he confirmed my suspicions that the well had problems with fill, as it did from the previous Beluga perforations. The problem with fill is supported y the information in our records that show that the "sustained" production was at a rate significantly below the test production rate, approximately 650 versus 3,600 MCFPD, and that they were not able to keep the well in continuous production for very long and did not have a problem with water production. c . . Conclusion: It appears that the current perforations are not viable for sustained production, having only produced a total of 5 MCF over 2 days of production in the last three months, and that plugging this set of perforations and re-perforating the well in a new sand lobe is the best hope for m%this a productive well again. D.S.RObY~~ Reservoir Enginee~ August 1, 2007 . Page 1 of 1 . Davies, Stephen F (DOA) From: Applewhite, Billy -APRS [contractor] [ApplewhiteB@chevron.com] Sent: Monday, July 30, 200711:26AM To: Davies, Stephen F (DOA) Cc: Applewhite, Billy -APRS [contractor] Subject: Pretty Creek #2,403 sundry form info Steve, Do not need spacing exception and nearest property line is: 1590' south and 2140' west from northeast corner of sec. 33, T14N, R9N, SM. Pretty Creek #4 is not perforated in the zone that we are doing in PC #2. Thanks, Billy Applewhite 263-7671 7/30/2007 Oflf;' f"...._ 1. Operations Abandon U Repair Well U Plug Perforations ~ ~ Stimulate U Other L:dAIRtß~plefë'"I";)~'G Performed: Alter Casing D Pull Tubing D Perforate New Pool [2] Waiver D Time Extension D Change Approved Program D Operat. Shutdown D Perforate D Re-enter Suspended Well D 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development [2] Exploratory D 179-009 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic D Service D 6. API Number: 50-283-20022-90-00 ,., 7. KB Elevation (ft): 9. Well Name and Number: 17.6' PCU 02 8. Property Designation: , ;'or.(ß 10. Field/Pool(s): Pretty Creek Unit ¡tÞL /.:Jr- ID .2.~' (!)~ Pretty Creek Field/Sterling 11. Present Well Condition Summary: SS 3005' & 3638' Total Depth measured 12,025' , feet Plugs (measured) LS 3600' & 3630' true vertical 12,025' feet Junk (measured) Effective Depth measured 3,600' feet true vertical 3,600' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 339' 20" 339' 339' Surface 2,032' 13-3/8" 2,032' 2,032' 3,090 psi 1 ,540 psi Intermediate Production 8,550' 9-5/8" 8,550' 8,550' 6,330 psi 3,810 psi Liner Perforation depth: Measured depth: Sterling 3442'- 3452' . True Vertical depth: Sterling 3442'- 3452' 2-3/8" -HS N-80 1799' 2-7/8"-SS N-80 3788' Tubing: (size, grade, and measured depth) 2-7/8"-LS N-80 3988' TOC 3060' - --- Packers and SSSV (type and measured depth) 9-5/8" Baker AL-5 3640' 9-5/8" Baker FH Pkr 3854' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: SCANNED NO\! (} 7 2006 Pumped/placed 200sx of L TX cmt in tbg x csg annulus. TOC @ 3060' 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: NA 0 0 0 0 Subsequent to operation: NA 3600 -~ 0 0 1077 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Temp Survey Exploratory D Development [2] Service D Daily Report of Well Operations 16. Well Status after work: oilD Gas [2] WAG 0 GINJ 0 WINJ 0 WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: 306-152 Contact Steve Tyler 907 263-7649 Printed Name Tim Brandenburg,., Title Dilling Manager Signature z-:::-A g Phone 907 263-7657 Date 10/9/2006 -- __::;..,...0' ./ ð RB[u.fCf BFL 0 CT 3 1 2006 A /o·z.~ .~ . . STATE OF ALASKA ;! 'L..vc" Vf=.D ALAS~IL AND GAS CONSERVATION COMMI~DN OCT 1 _ REPORT OF SUNDRY WELL OPERATIONS A/ask "' ~ 6 2006 a 0/ & uas C n Form 10-404 ReV'r1 r¿1°~ , t\f tJ , ~~'\ _ S~~lt Onglnal Only .~ \ ~, JOhO/M' PCU-02 Primary Job Type Completion Jobs Primary Job Type Completion Daily Operations 8/24/2006 00:00 - 8/25/2006 00:00 Operations Summary Mobe Coil Tubing Unit from PCU #4 to PCU #2. 8/25/2006 00:00 ·8/26/2006 00:00 Operations Summary PJSM. Accepted CT from turn-key Mobe @ 07:15 AM. RIH wI wash nozzle. Tag fill @ 1675'. cleanout fill bridges to 3750'. Estimated 29.5' of overall bridges. CBU x 2. POOH. Release CT to tumkeyed Demobe. 8/26/2006 00:00 ·8/27/2006 00:00 Operations Summary PJSM. Mobe/Spot cementers. slickline & Eline. RU onto SS. RIH w/2/30" GR. Set down @ 3596'. POOH. RD & RU onto LS. RIH wI 2.30" GR. RI setdown @ 2743'. Work thru. RI to 3700'. No issues. POOH. 8/27/2006 00:00 ·8/28/2006 00:00 Operations Summary LD GR. PUMU 2" spent 10' Omega dummy gun. RIH Work thru 2507' & 2690'. RI to 3637'. POOH. RD slickline. RU Eline onto LS RI set CIBP @ 3630'. RD. RU onto SS. RI set CIBP @ 3638'. Jug test each string to 1500 psi. RI wI 10' tbg punch gun. Perf SS tbg @ 3625' to 3635' wI 500 psi on SS. Saw pressure drop. Circulate pkr fluid down tbg while taking diesel retums out annulus. RIH w/ cmt retainer. Set same in SS @ 3005'. POOH. RD. RU onto LS. RIH perftbg punch @ 3615' - 3625'. POOH. RU gasline from compressor. Displace LS fluid w/ gas. Recovered 19+ bbls. Trapped 1415 psi. PUMU CIBP. RIH set CIBP @ 3600' in LS. Noted tbg pressure @ 1300 psi. POOH RD Eline. 8/28/2006 00:00 . 8/29/2006 00:00 Operations Summary PJSM. Jug test tbg x csg annulus to 2500 psi. Lost 300 psi in 5 min & 518 psi in 30 min. Establish circulation down SS thru cmt retainer. Mix/pump 40 bbls of LXT blend cmt @ 2.5 bpm. Launch Wiper Ball. Displace tbg wI fresh water. Bump wiper ball. Gmt in Place @ 06:20 AM. RD cementers. RU slickline onto LS. RIH w/ temp survey to 3600'. POOH logging. RD slickline. Found TOC @ 3060'. Found fluid level in LS tbg @ 2989'. SDFN. 8/29/2006 00:00 . 8/30/2006 00:00 Operations Summary Cost Adjustment for Schlumb CT Jack Subbase. 8/31/200600:00 ·9/1/200600:00 Operations Summary Pressure test tbg x csg annulus to 2500 psi. Bled to 2450 psi in 30 min. Bleed to 2420 psi in (1) hour. 9/2/2006 00:00 ·9/3/2006 00:00 Operations Summary II' SIMOPS & PJSM. RU Eline. Tbg @ 1075 psi. RIH Perforated 48-0 gas sand (3442' - 3452'). Tbg @ 1110 psi. OOH all shots fired. IP @ 14:00 3.5 mmcfpd wI TP @ 1118 psi. SI for 24 hr build up. 9/3/2006 00:00 ·9/4/2006 00:00 Operations Summary Rebuild master valve. Tested same. 9/4/2006 00:00 ·9/5/2006 00:00 Operations Summary Cost Makup 9/5/2006 00:00 ·9/6/2006 00:00 Operations Summary Reconfigue Tree back to original set up. Pressure test upper master valves w/ well pressure @ 1300 psi. AND RKB= 17.6' SIZE WT GRADE CONN Ii) TOP DTM. 20" 94 H-40 Butt 19.124 Surf 339' 26" 600sx J-55 12.515 Surf 1048' 675sx 13 -3/8" 61 1048' 1050' w/Topjob J-55 12.515 1050' 2032' 660sx P-ll 0 Surf 4525' 1020sx 4525' 4527' TOC@lj()O' 9-5/8" 47/43.5 DV Collar 12-1/4" RatlyfromJ500'.2000< CBL N-80 4527' 8550' III Osx Tubin 2-7/8" 1"8 6.5 N-80 2.441 Surf 3988' 2-7/8"88 6.5 N-80 2.441 Surf 3788' 4.6 N-80 1.995 Surf 1799' JEWELRY DETAIL TD = 12,025' PDTD = 4675' Max Hole Angle = PCU #2 Current 9-02-06.doc NO. I Dmtb Lell<>th m OD Hem I 17.60' I I I FMC-OCT type TC-3C Tubing Hanger, 2-7/8" x 2-7/8" , ]]" Long String 1. 3608' 2.85 2.3] 3.6875 2-7/8"EU 8RD S]dg Slve 2. 3640' 14.21 3.00 8.50 9-5/8" Baker AL-5 Dual Packer wi Brown SafetyJoint 3. 3688' 99.00 2.44 3.50 2-7/8" EU 8RD Baker Blast Joint 4. 38]9' 0.96 2.3] 36875 2-7/8" EU 8RD Baker F nipple 5. 3852' 2.76 2.25 3.375 2-7/8"EU 8RD Sldg Slve , 6. 3854' 7.85 2.44 8.437 9-5/8" Baker FH Packer 7. 3894' 0.8] 2.25 3.6875 2-7/8" EU 8RD Baker R nipple 8. 3899' 89.00 2.44 3.5 2-7/8" EU 8RD Baker Blast Joint 9. 3988' 0.54 218 3.6875 2-7/8" EU 8RD Baker Shear out Suh Short String A. 910' 0.96 2.31 3.6875 2-7/8" EU 8RD Baker F nipple B. 3646' 1343 3.00 8.50 9-5/8" Baker AL-5 Dual Packer C. 3688' 0.81 2.31 3.6875 2-7/8" EU 8RD Baker R nipple D. 3689' 99.00' 2.44 3.50 2-7/8" EU 8RD Baker Blast Joint . E. 3788' 0.60 218 3.6875 2-7/8" EU 8RD Y, Mule Shoe Heater String la. 20' 0.81 1.99 2-7/8" x 2-3/8" Cross-over 2a. 701' 1.80 1.87 I 3.125 2-3/8" EU 8RD Baker F nipple 3a. 1800' 066 2.00 2.8751 2-3/8" Buttress Y, Mule Shoe ¡,/ 80' 12 I' 3 holes 65' 12 18' 20' 3,475' LS 3615'-3625' SS 3625'-3635' DRAWN BY: SLT REVISED: 9/7/2006 Pressure (psia) 1500 1200 Or.... " '\ .. \ - c ~\_ _ -- - ~ =-\: -- -.- . 1 ~ \ , '\ \ .. , ,~ I" "'--: '~ \. ". -- H\ , '\ 1300 1400 1600 1700 1800 ---- . ..-- .. - .. '·0 I·· -- . .. 200 400 600 BOO 1000 1200 1400 C :¡¡; 1600 - ..... CI.) ~ 1800 - J: ..... g. 2000 C 2200 2400 2600 2800 3000 in ","" ,. " 3590' -- -- - I - .-- : --. -- 1-- -- -- . I -" . -- - - -- ---- - . -- ---- . I - I -- -~-- ! -- - --........-- : -- .. c-- - t~ -" ---- -- --.. JH -- -- .-- -- -- ---- i .. ........ ....... ~¡::I...~,,\ ¡ """I ............. ---- ~~~~, ____ .. ~ ''''''<I 1-- .............:................. '-.. '-. -- I Toe @ 3060' \ ~rlI --- . 74 76 78 80 3200 ""'- __H '-. '" f ~ '-. "- ......... , '" - I 3400 -. 1 - 3600 50 I , 52 54 56 58 60 62 64 66 68 70 72 Temperature (Deg. F) - Perfs Report date: 10/9/2006 e e r9q - 00<1 FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AM) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager Union Oil Company of California PO Box 196247 Anchorage, AK 99519 . I'~M~j~:f, ~vr-~ .. .--- i'''> ¡fir') 'J .:;j ~.-,~ Re: Pretty Creek Field, Undefined Pool, PCU-02 Sundry Number: 306-152 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED thisÆ day of May, 2006 Encl. C(lfS~/~h ~p¿, _ STATE OF ALASKA . ALA~ OIL AND GAS CONSERVATION COMMI ON APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ~úA-- 'S /II 'U)o<. '1 /Zl It?~ t .' ì\ i , )(cJ) -" t / f)Ð b/i 11, 1. Type of Request: Abandon U Suspend U Operational shutdown U Perforate l:J Waiver U Other U Alter casing 0 Repair well 0 Plug Perforations [] gfimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: I Exploratory 5. Permit to Drill Number: Union Oil Company of California Development [] 0 179-009 / 3. Address: Stratigraphic 0 Service 0 6. API Number: PO Box 196247, Anchorage, AK 99519 50-283-20022-90-00 / 7. KB Elevation (ft): 9. Well Name and Number: 17.6' PCU-02 / rVE 8. Property Designation: 10. Field/Pools(s): LtM-de.~~A:"pf}~4 ,11r!6A- Pretty Creek Unit Pretty Creek Field/Bek:Ig;r 4.' -.. 2uOo 11. PRESENT WELL CONDITION SUMMARY'" ,>j' j", j>. :¡H)p; J'M" Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (1JIi!~~HfPeD:£! 'Jûtlk(measured): 12,025' 12,025' 4,675' 4,675' 4,675'; 2,080'; 3,570' n/a Casing Length Size MD / TVD Burst Collapse Structural Conductor 339' 20" 339' 339' Surface 2,032' 13-3/8" 2,032' 2,032' 3,090 psi 1 ,540 psi Intermediate Production 8,550' 9-5/8" 8,550' 8,550' 6,330 psi 3,810 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: / Tubing Grade: Tubing MD (ft): 3,700 to 3,980' / 3,700 to 3,980' 2-3/8"; 2-7/8"-SS; 2-7/8"-LS N-80; N-80; N-80; 1,799'; 3,788'-88; 3,988'-L8 Packers and SSSV Type: 9-5/8" Baker AL-5 Dual Pkr w/Brown safety jt.; 9-5/8" Packers and SSSV MD (ft): 3,640'; 3,854'; 3,646' / Baker FH Pkr; 9-5/8" Baker AL-5 Dual Pkr; 12. Attachments: Description Summary of Proposal L!J 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development [] Service 0 14. Estimated Date for 15. Well Status after proposed 7k: . Commencing Operations: 811t2006 Oil 0 Gas [] Plugged 0 Abandoned 0 í 16. Verbal Approval: Date: '_i· WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature ?~C.^ r7. Phone 907-276-7600 Date ¿/-Z6 Or:;.. C/ § COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~()' (t)~ ~ , Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: RBDMS 8FL MAY {I ,'oj. 2006 Subsequent Form Required: to - .-1?A;. é¡(1 APPROVED BY 5-J.-o6 Approved by: I / / CO~IONER THE COMMISSION Date: \.../ \../ ~j' . - i í Form 10-403 Revised 07/2005 Recomplete shallow gas sands U \ \ I V ì I \J t\ L Submit in Duplicate e e Pretty Creek Unit PCU #2 Isolating Beluga Sands and Recompleting in the Sterling ~ MIRU Slickline onto SS. Bail fill to EOT. ~ ~ ~ ~ ~ ~ RU pump onto SS. Attempt to inject one tbg volume into Upper Beluga. RI set "N" test plug in profile nipple @ 3688'. Pressure test SS to 3000 psi. POOH wi plug. ./ RU N2. Displace fluid level to 3000'. RIH wi PXN plug set in nipple @ 3688'. RU onto LS. Bail fill to 3650'. RI shift SS open. Estabilish circ rates & pressures. MIRU Eline onto LS. RI set emt retainer w/~t @3200'.POOHRD./ RU cementers onto LS. Mixl~ump/circu~ate40 Is ~200 sx) of 0 Neat (calculates Toe in 2-7/8" x 9-5/8" annulus @ 3000'). Launch WIper ball. DISp ce tbg tIll ball bumps. ~ RU slickline onto SS. RIH wi temp survey to 3600' to identify TOe. ~ woe for 3 days. ~ Install BPV's. ND Tree. Replace same. ~ RU Eline on SS. Pressure test BOPE's. ~ ~ ~ RIH Peforate Sterling 48-0,47-1 and 45-8 gas sands. RD Eline Unit. Package for Demobe. Turn well over to Production. / RKB::;:: 17.6' TD = 12,025' PDTD = 4675' Max Hole Angle = PCU #2 Current 13-3/8" 26" 61 17-1/2" 1-55 P-II0 47/43.5 DV Collar 12-114" N-80 4527' 8550' 6.5 N-80 2.441 Surf 3988' 6.5 N-80 2.441 Surf 3788' 4.6 N-80 1.995 Surf 1799' II JOsx 600sx 675sx w!Topjob 660sx 1020sx TOC{{!i¡~()()' 9-5/8" cm Tubin 2-7/8" LS 2·7/8" SS 2-3/8" Rtr NO. I DeDtll LelU'tll II) 00 Ue!u I 17.60' I I I FMC-OCT tvne TC-3C Tubinf! Hanf!eL -110 x ¿-IIi) ,II" Lona String 1. 3608' 2.85 2.31 3,6875 2-7/8"ED 8RD Sldg Slve 2. 3640' 14.21 3.00 8.50 9-5/8" Baker AL.5 PUIIIPacker wi BrownSafetyJoint 3. 3688' 99.00 2.44 3.50 2-7/8" ED 8RD Baker Blast Joint 4. 3819' 0.96 2.31 3.6875 2-7/8" ED 8RD Baker F nipple 5. 3852' 2.76 2.25 3.375 2-7/8"EU 8RD Sldg Slve 6. 3854'· 7.85 2.44 8.437 9-5/8" Baker FH Packer 7. 3894' 0.81 2.25 3.6875 2-7/8" EU8RD Baker R nipple ,,;( 11 PrAfae 8. 3899' 89.00 2.44 3.5 2-7/8" ED 8RD Baker Blast Joint 9. 3988' 0.54 2.18 3.6875 2-7/8" EU SRD Baker Shear out Sub Short String A. 910' 0.96 2.31 3.6875 2-7/8" EU 8RD Bakerl'nippl~ B. 3646' 13.43 3.00 8.50 9-5/8" Baker AL-5 Dual Packer C. 3688' 0.81 2.25 3.6875 2-7/8" EU 8RD Baker R nipple wi 2.31 Profile j D. 3689' 99.00' 2.44 3.50 2·7/8" EU 8RD Baker Blast Joint E. 3788' 0.60 2.18 3.6875 2·7/8" EU 8RD y, Mule Shoe Heater String ia. 20' 0.81 1.99 2-7/8" x 2-3/8" Cross-over 2a. 701' 1.80 1.87 3.125 2-3/8" :ED 8RD Baker F nipple 3a. 1800' 0.66 2.00 2.875 2-3/8" Buttress y, Mule Shoe ement Retainer at 4675' (6/86) agged Long String 02/05 @2080'KB agged Short String 02/05 @3570'KB ote: Well has a triple tree. DRAWN BY: CRW -" RKB = 17.6' TD = 12,025' PBTD = 4675' Max Hole Angle = FCU #2 Proposed# 1 26" 13-3/8" 61 J-55 P-ll 0 9-5/8" 47143.5 12-l/4" N-80 4527' Tubin 2-7/8" LS 6.5 N-80 2.441 2-7/8" SS 6.5 N-80 2.441 2c3/8" Htr 4.6 N-80 1.995 2-7/8" EU 2-7/8" EU 8RD Baker F nipple 2-7/8"EU 8RD Sldg Slve 9-5/8" Baker FH Packer 8RD Baker R mpple wi 2.3 I Profile 2-7/8" EU 8RD Baker Blast Joint 2-7 18"EU 8RDBaker Shear out Sub A. B. C. D. E. Heater la. 2a. 3a. 910' 3646' 3688' 2-7/8" EU 8RD Baker F nipple Dual Packer 2-7/8" EU 8RD Baker R nipple 0.96 13.43 0.81 99.00' 0.60 2.31 3.00 2.25 2.44 2.18 3.50 3.6875 2-7/8" EU 8RD Baker Blast Joint 2-7/8" EU 8RD'¡' Mule Shoe 3.125 2.875 2-7/8" x 2-3/8" Cross-over 2-3/8" EU8]Ø B*er F nipple 2-3/8" Buttress y, Mule Shoe 1.99 1.87 2.00 ement Retainer at 4675' (6/86) agged Long String 02/05 @2080'KB agged Short String02/05 @3570'KB ote: Well has a triple tree. DRAWN BY: CRW DEPT. OF ENVIRONMENTAL CONSERVATION TONY KNOWLES, GOVERNOR DIVISION OF ENVIRONMENTAL HEALTH SOLID WASTE PROGRAM 41'0 WILLOUGHBY AVE JUNEAU, ALASKA 99687 h ttp :l/www.sta te.ak.us/dec/deh Telephone: (907) 465-5162 Fax: (907) 465-5362 October 23,2001 Harry A. Eaton HES Manager Unocal Alaska t~ ~.,~\ Reference: Issuance of Permanent Closur¢Appr¢Z?g;12acrr:~};;re :Lewis:River &-l, B-l, Cxl, D-Vand Pretty Creek g 2 located on the west side of Cook Inl~ [ ~-o~ ~ ~, ' De~ Mr. Eaton: ~/~'~ ~Kn~'~% ~-~ ~ The Al~ka Dep~ment of Environment~ Conservation (ADEC) has completed review and public notice for pe~anent closure approv~ for the above reference rese~e pits located in the Susitna ~ats State Game Refuge. The closure applications provided the required i.nfo~ation describing the histo~ of the rese~e pit(s), the present condition of the rese~e pits(s), results of any required water sampling and an assessment of the potential risks posed by the drilling waste to human health and the environment. At these locations, the reserve pits are backfilled and there is no exposed drilling waste. ADEC coordinated sever~ field inspections of the sites with the Alaska Dep~ment of Fish and Game and the Alaska Department of Natural Resources. Public notice requesting comments on the closure requests was published September 20 and 21, 2001 in the Anchorage Daily News and posted on the state web site September 2 I, 2001. No public comments objecting to closure approval were received in response to this public notice. ADEC has determined that the reserve pit at this site meets the closure requirements of 18 AAC 60.440. Closure Approval Under authority of 18 AAC 60.440 (j), ADEC grants permanent closure approval to Unocal Alaska for the inactive reserve pits at the following sites' Unocal Alaska Mr. Harry A. Eaton Well Name Lewis River I (A- 1) Lewis River B-I Lewis River C- 1 Lewis River D- 1 Pretty Creek #2 Terms and Conditions APl Number 50-283-20047-00 50-283-20052-00 50-283-20061-00 50-283-20068-00 50-283-20022-90 MTRS Sec. 02, T14N, R9W, SM Sec. 10, TI 4N, R9W, SM Sec. 35, T15N, R9W, SM Sec. 35, T15N, R9W, SM Sec. 33, T14N, R9W, SM October 23, 2001 Page 2 of 2 Landowner ADF&G/ADNR ADF&G/ADNR ADF&G/ADNR ADF&G/ADNR ADF&G/ADNR This permanent closure approval is subject to the following terms and conditions: 1) 2) In accOrdance with 18 AAC 60.440(1), the Department will require additional investigation, : assessment, monitoring or remediation if new information regarding conditions at the reserve pit facilities indicates that further actions are necessary to protect human health or the environment. ..: ~ The approval granted by this letter is for the inactive drilling waste reserve pit(s) only. Closure for the pad as a whole (if required) must be coordinated between the owner/operator and the appropriat0, land owner/manager. .' Any person who disagrees with any portion of tlfis decision may request an adjudicatory hearing in accordance with 18 AAC 15.200-~310. The reqffest should be mailed to.the Commissioner of the Department of Environmental Conservation, 555 Cordova Ave. Anchorage, AK 99501. If a hearing is not requested within thirty (30) days of the date of this letter, the right of appeal is waived. If an adjudicatory hearing is requested and granted, this decision remains in full effect during the adjudicatory process. Sincerely, Heather Stockard Solid Waste Program Manager Heather S tockard @ envircon.state.ak.us cc: Tom. Maunder; -'AOGCC, Deborah Heebner, ADNR, Anchorage Wayne Dolezal, ADF&G, Anchorage John Hammelman, Unocal DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS I ? / TONY KNOWLE$, GOVERNOR 550 WEST 7TM A VENUE, SUITE 800 ANCHORAGE, ALASKA 99501-3510 PHONE: (907) 269-8800 FAX: (907) 269-8938 CERTIFIED MAIL RETURN RECEIPT REQUESTED April 8, 1999 Kevin A. Tab!er, Manager Land/Government Affairs Unocal Corporation PO Box 196247 Anchorage, AK 99519-6247 ~: Pre~y Creek Unit Suspension of Production ~ ~ ~ Dear Mr. Tabler: ~ ~ ~e, ~e ~ '~ (q~ On M~ch 26, 1999, Union Oil Company of California (Unocal) requested a suspension of production and operations for the Pre~y Creek Unit (PCU) pursuant to 11 AAC 82.670. Unocal's application complied with the requirements of 11 AAC 88.105 and the Depa~ment of Natural Resources (DNR) receipted the $250.00 filing fee on March 30, 1999. 11 AAC 05.010(~0)(I). Unocal reported that on or about January 25, 1999, gas production from the PCU #2 well, located on ADL 63048, ceased due to sand accumulation in the wellbore. Unocal's attempts to bail the sand out of the wellbore and re-establish production have been unsuccessful. Division staff met with representatives from Unocal on Marci~ 3i, i999, to discuss past Unit well performance, Unocal's attempts to re-establish and maintain production, and the time to perform necessary repairs to the well. Dave Whitacre, Unocal Gas Team Supervisor, reported that a coil- tubing rig likely would be ineffective and a workover rig may be required to get the PCU #2 well back on production. However, there are no drilling or workover rigs now available on the West Side of Cook Inlet. Unocal will continue its efforts to acquire a rig to repair the well by negotiating with other operators of West Side properties to share the rig costs. If a rig is obtained, Unocal will continue operations by repairing the well. Since the PCU #2 well is the only production well in the PCU, its malfunction impacts the entire unit area. Unocal requested approval to suspend production from the PCU until it can perform the necessary work on the PCU #2 well. "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans." ~ printed on recycled paper b y G.D. Kevin A. Tabler, Unocal Pretty Creek Unit, SOP April 8, 1999 Page 2 On June 16, 1998, DNR approved Unocal's Twentieth Plan of Development (20th POD) for the PCU. Unocal planned to continue gas production from the long string completion in the PCU #2 well during the term of the 20th POD, August 26, 1998 through August 25, 1999. I hereby amend the 20th POD and approve a suspension of production for the PCU effective April 8, 1999 through August 25, 1999. Unocal will evaluate options to repair the PCU #2 well, perform remedial operations, and attempt to re-establish unit production under the amended 20th POD. The Twenty-first Plan of Development (21st POD) is due on or before May 27, 1999, 90 days before the 20th POD expires. 11 AAC 83.343. As part of the 21st POD, DNR requests that Unocal report on its efforts to repair the PCU #2 well during the term of the 20th POD. If Unocal proposes an extension of the suspension period in the 21st POD, DNR will consider Unocal's past effbrts and future plans to re-establish and maintain production from the PCU. Please contact Carol Lee, Unit Manager at (907) 269-8813 if you have any questions concerning this decision. Sincerely, Kenneth A. Boyd Director Attachment: Delegation of Authority from Commissioner Shively CC: Commissioner Shively Nan Thompson, Dept. of Law Jack Hartz, AOGCC C :\Users\cdl\UnitsLPretty CreekLPCSOP. doc DELEGATION OF AUTHORITY Pretty Creek Unit, Suspension of Operations and Production I hereby delegate to the Director of the Division o.f.Oil and Gas, my authority under AS 38.05.140 and 11 AAC 82.670, to approve a Suspension of Operations and Production for the Pretty Creek Unit. John T. Shively, Commissione~' Alaska Department of Natural Resources t D~te UNOCAL ASSET G~S GRP :~. November 18, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Attn: Blair Wondzell FRX NO. 907263YS'F4 P. 02/02 Dear Mr. Wondzelh On Friday November 14, 1997, I spoke with you over the phone about Unocal's intention to change the subsurface structural integrity of some of our westside wells not only to boost production but also to prevent the onset of some possible operational problems. You requested that I provide you with written procedures of the exact changes we intend to make before you can advise us on which State regulations We must comply with. Here are two examples of the changes we want to make to the wells. .~-. ~60Zt Ivan River Well IRU 41-t production rate is limited by line pressure and friction pressure drop. We intend to prevent the limitation by punching holes in the casing and tubing and flowing gas to the surface through the tubing and casing annulus. --}, '-/9 -oeo Pretty Creek Well PcU-2L has been loading up with water, which hampers free flow of reservoir gas into the well. Even though our field personnel have been blowing the well down periodically to get rid of the water, we have concerns that continuous blowing down of the well might cause the well to sand which may lead to loss of reserves. To solve this problem, we would like to perforate the tubing above the packer and use a timer or tubing-casing pressure difference actuator to automatically unload water. The device will shutin the well periodically then open it to flow. The gas in the annulus would help lift the water. I would like to know the relevant or applicable State regulations that govern the reconfigurations we intend to make. Please direct questions about this subject to Sam Darkwah at 263-78-64. Sincerely, Sam A. Darkwah Reservoir Engineering Technician ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192, PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 November 3, 1992 Janet Bounds Unocal P O Box 190247 Anchorage, AK 99519-0247 Dear Ms Bounds: As we discussed on the phone October 28, AOGCC will be reassigning APl numbers for the wells listed below. In order to accommodate the revision of Unocal's records, we will not announce these changes to the public until the first week of December, or until you advise me that all the necessary changes are made. Give me a call if you would like to discuss this matter further. Well Name Permit # Old APl Number New APl Number Granite Pt St 17587 #3 66-52 50-883-10031 50-733-20437 Granite Pt St 17587 #4 89-30 50-883-10032 50-733-20438-90 Granite Pt St 17587 ~6 89-103 50-883-10034 50-733-20439 Granite Pt St 18742 ~8 67-36 50-883-20008 50-733-20440 Granite Pt St 17586 #4 67-54 50-883-20009 50-733-20441 Granite Pt St 18742 #34 79-17 50-883-20009-01 50-733-20441-01 Granite Pt St 17586 ~tl 91-45 50-883-20009-02 50-733-20441-02 Granite Pt St 18742 #14 79-33 50-883-20010 50-733-20442 Granite Pt St 18742 #20 68-16 50-883-20012 50-733-20443 Granite Pt St 18742 #20RD 91-20 50-883-20012-01 50-733-20443-01 Granite Pt St 17587 #5 68-24 50-883-20013 50-733-20444 Pretty Creek Unit #2 79-9 50-283-20022 50-283-20022-90 Nicolai Creek Unit #4 91-100 50-283-20033 50-283-20033-90 Lewis River D-1 89-72 50-283-20068 50-283-20068-90 Trading Bay Unit G-18DPN 83-135 50-733-20160 50-733-20160-90 Yours truly, Robed P Crandall Sr Petr Geologist /jo Unocal Oil & Gas D tn Unocal Corporation RO. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNO£AL Craig K. White District Exploration Geologist* Alaska District August 1, 1989 Mr. Lonnie C. Smith Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska Dear Mr. Smith: As requested by the A.O.G.C.C. through A.O.G.A., we 'are providing replacement copies of reproducible (sepia) logs for Unocal-operated wells, as follows: Canoe Bay Unit ¢1 (Pure Oil Co.) Cannery Loop Unit ¢1 Cannery Loop Unit ¢2 Cannery Loop Unit ¢3 Clam Gulch Unit ¢1 Grayling 1-A Kasilof Unit ¢1 Kenai Unit 41-18 Knik Arm ¢1 Knik Arm St. ¢1 Kustatan ¢1 Kustatan CIA Ninilchik #1 Pittman ¢1 Pretty Creek Unit ¢2 (Chevron) Trading Bay Unit West Trading Bay St. ¢1 5" E-log 2" E-log 5" BHC, 5" Density~ ~ ~LoG 5" Density, 2" DIL 2" E-log 2" E-log Mudlog 2" E-log 2" E-log 2" E-log 2" E-log 2" Sonic .-- ~e~ 5" Microlog 5" CNL, 5" Neutron Ct. Rate GR-Neutron (tie in), CET log 2" & 5" Sonic, 5" Density 2" & 5" BHC, 2" & 5" E-log Please return one copy of this letter in acknowledgement of your receipt of this data. BWS: da 2755E STATE OF ALASKA AL,. _,A OIL AND GAS CONSERVATION COMMI',,, ..ON APPLICATION'FOR SUNDRY APPROVAL 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 __ Pedorate __ Other __ 2: Name of Op_erator union Oil Company of California (UNOCAL) 3P~.~.re~ox 190247, Anch, Ak., 99519-0247 4. Location of well at surface 1590'S & 2140' W of NE Corner Sect. 33, At top of productive interval At effective depth At total depth Straight Hole 5, Type of Well: T14N, Development Exploratory Stratigraphic Service R9W SM 6. Datum elevation (DF or KB) 80.1' GR 94.5' KB feet 7._Unit.or ProE)erty qam. e . _ Fre~ty cree~ un~ 8, Well number PCU 9. Permit number 79-0009-0 10. APl number 50-- 283-20022 11. Field/Pool Pretty Creek/Beluga 12. Present well condition summary Total depth: measured true vertical 12,025' 12,025' 4,675' Effective depth: measured 4,675' true vertical feet feet feet feet Retainer @ 8420' PlugS(measured) Bridge @ 7000' Bridge @ 4750' Cement @ 4675' Junk (measured) No Junk Casing Structural Length Size Cemented Measured depth True vertical depth Conductor Surface Intermediate Production Liner Perforation depth: measured 20" 13-3/8" 9-518- See attached truevertical Heater 2-3/8" 4.6# N-80 ~bing(size. grade, and measureddepth) L.S. 2-7/8" 6.5# N-80 S.S. 2-7/8" 6.5# N-80 PackersandSSSV(typeandmeasureddepth) 9-5/8" Hydraulic @ 3643' 9-5/8" Perm @ 3854' 600 sxs 339' 339' 1,335 sxs 2,032' 2,032' 2,130 sxs 8,550' 8,550' / ~ t:~' RECEIVED ~ ~8oo' 'JUN 0 88293788,89' ~i~Ska Oil & Gas Cons. Anchorage 13. Attachments Description summary of proposal ~ Detailed operations program .Z,.. BOP sketch 14. Estimated date for commencing operation 115. Status of well classification as: July 15, 1989 16. If proposal was verbally approved Oil __ Gas X__ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/:.~Z,/F.<.., ~(?-,~--,,'.,'¥','~'-/~,< Title Environmental Engineer Roy D. ~nb/~.~-~.~ '/,,~ FORCOMMISSIONUSEONLY Conditions of a~proval: Notify Commissi~m~so representative may witness Plug integrity ~ BORTest ~ Location clearance __ ~echanical Integrity Test. Subsequent form required 10- Approved CoPY Suspended Date 6/7/89 IAppr°valN°' ¢ ~'~'._~ AsB~end/bl_.y order of the Commissioner Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LONNIE ¢. ,SMITH Ret~,rned,, ,..,, Commissioner Date SUBMIT IN TRIPLICATE ATTACHMENT NO. 1 PRETTY CREEK UNIT Well #2 Perforations M_RD 7,260' - 7,280' 4,794' - 4,812' 3,396' - 3,416' 3,915' - 3,980' (65') 3,700' - 3,780' (80') Comments Covered with Bridge Plug Covered with Bridge Plug Squeezed Open - Long String Open - Short String 0062n/4 Attachment No. 2 PRETTY CREEK - WELL ~2 Objective: To workover and recomplete well Pretty Creek Unit #2 as a gas producer. This work will include the recovery of the existing completion, casing integrity tests, production tests and recompletion as a productive gas well. WORKOVER PROCEDURE 1. MIRU. 2. Kill well. Install BPV's. ND tree. NU and test BOPE. 3. Recover existing triple completion. S. S. 2-7/8" tubing at 3788' L. S. 2-7/8" tubing at 3989' Heater Sting 2-3/8" tubing at 1800' Dual Packer at 3643' Perm. Packer at 3854' 4. Make a bit and 9-5/8" casing scraper run to PBTD at ± 4675'. 5. Run casing Caliper, CBL and Reservoir Logs. 6. Perform and clean out isolation squeezes as necessary. 7. Perform DST's as required. Four are anticipated. 8. Clean out wellbore and circulate fluid for perforating. 9. Perforate tubing conveyed as directed. 10. Run a single 2-7/8" completion with 2-3/8" heater string as directed by testing data. 11. ND BOPE. NU and test tree. Release Rig. 0062/3 Ol UPPER III 7 8 9 CEETM ' ATTACHMENT NO. 3 CASING & ABANDONMENT DETAIL I. ~0"~ g4#, H-40 Casing I~ :~sg' I1o 15-5/8", 61#, J-55 Casing (~ 2052' !11, 9-5/8", 40#-4~.5#-47#, N-80/S-95 Cosing@ 8550' TUBING DETAIL Z ONe .?,T?/N¢: 2- 7/$'; ~ 5~, N-$4 ~t~D EU TUBIN~ 1, Baker 2-7/8" EU 8RD Sliding Sleeve Il ;S608' 2. Baker Modal "AL-5" Dual Packer @ 3643' 5. Dost Joints From 3888' to 5787' 4, Baker "F" Nipple Il 5819' 5. Baker "XP" Sliding Sleeve ~ 3852' 6. 9-5/8" Baker Model "FH" Packer J) 5854.5' 7. Baker "R" Nipple llt 3894' 8. Blast Joints From 5899' to 5988' 9, Baker Shear-out Sub & Tail ~ 3989' SHO/~T ST/CiN~: 2- 7/8'; 6. 5/, N- 80 a/CD £U TUBI^'C /L Baker "P' Nipple t~ 910' B. Baker Model "AL-5" Packer i~ 5646' C. Baker "R" Nipple I~ 5688' D. Blast Joints From 5689' to 5788' E. Mule Shoe I~ ,~788' H~4TEt~ STt~/N~: 2-7//$"x2-Z//$'; ~.5~ N-SO 8t~D EU 2-7/8" x 2-;S/8" Cross-over ~ 20' b, Baker "F" Nipple (~ 707' c. Mule Shoe ~ I800' PERFORATION RECORD 5700' - 3780' U. Belug~ 5915' - 5980' M./L Beluga 6/27//88 Chkd By: ATTACHMENT NO. ~ 13 5/8" X 5000# SHAFFER 42" 13 5/8" X 5000# MUD CROSS 13 5/8" X 5000# SHAFFER SINGLE GATE 32j' 11.50 GRACE DRILLING COMPANY RIG #158 PROPOSED B.O.P. STACK i' I ATTACtLMENT NO. 5 GRACE DRILLING COMPANY RIG #158' CHOKE MANIFOLD ;-: · .: ,! STOCK No. 753 113 STATE OF ALASKA ALA,,,'(A OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate [] Plugging [] Perforate~ Pull tubing Alter Casing [] Other ~ 2. Name of Operator Chevron U.S.A. Inc. 3. Address P.O. Box 107839, Anchorage, AK 99510 4. Location of well at surface 1590' S ~ 2140' W of NE Cor. Sec. 33, 14N, 9W, SB~M 5. Datum elevation (DF or KB) G.L.=82' K.B. = 96 6. Unit or Property name Pretty Creek Unit 7. Well number PCU #2 At top of prOductive interval Same At effective depth Same At total depth Same 8. Approval number 9. APl number 50-- 283-20022 10. Pool Beluga Feet 11, Present well condition summary Total depth: measured true vertical 12,025 feet 12,025 feet Effective depth: measured 4,67,5 feet true vertical 4,67,5 feet Plugs (measured) Junk (measured) Casing Length Size Cemented Structural Conductor 20" 600 Sks Surface 13 3/8" 660 Sks Intermediate Production 9 5/8" 2130 Sks Liner Perforation depth: measured 3915'-3980' 3?00'-3?80' Measured depth 339' 2032' 8550' ~ue Verticaldepth 339' 2032' 8550' true vertical 3915'-3980' 3700'.3780' Tubing (size, grade and measured depth) 2 7/8" 6.5# N-80 3989' & 3788' 2 3/8" 4.6# N-80 1801' Packers and SSSV (type and measured depth) Baker: AL-5 3643', FH 3854' 12. Stimulation or cement squeeze summary See Attached Intervals treated (measured) Treatment description including volumes used and final pressure 13. NA Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run iq 15. i hereby certify that the foregoing is true and correct to the best of my knowledge ~ Signed _. Title Acting Area Operations SuperintendentDate //~'"'¢'~(~, Form 10-404 Submit in Duplicate Drilling Morning Report Ow~s~on Proposed TO DFS Total Roi Hfs DOL Days Hrs. Days Hrs. Shoe Fest Last Cas,rig Size ¢~ Set ~ ~0 ~D TVD EMW onCUmcasingR°t' Hrs.: ISince Last Cai. Oepth Worst Wear % Rem Liner Set ~ MD TVD - TOP ~ MD TVD Gel WL HT-HP FC Solids % 0il % Sand MBT PH Pm Pf/Mf CL CA Ix Ume [I Stab Wt. Material Gel Caustic Lig. Cms. Salt CaClz Other Avg. Drilling Max. Drilling Conn. Trip Trip Chlorides Remarks M O Angle Direction TVD Coordinates V S DLS No. Size Type Set. No. Jets In Out Feet Hrs. WOB RPM T B G Cons~szs of To~al Length (H.W.D.P.: ) Pump Liner Stroke SPM Pressure GPM Jet Vel. Ann. Vel Bit HHP Pump HHP Hrs. Operations Covering 24 Hours Ending E8 Midnmght ~, ..~':, . ' , ~,,. 4RE~s ~oR~IN 6 ~O~R LA~IN ~ ~U~ ~ 12 XR ~A~H. DailyMud .~ -- ]CumMud _~ -- Daily Tangible Cum Tangibte Dally Well /,, ~/r [Cum Wel' 73/307 _ Accldems rn J ~ ) 1 ~ ( l J I I ~c..o,.. Drilling Morning Report Comp'an, E/./£b~/"e~)/Y t~$A Re,,on bO~$/'~,qN ~,v,~,o, AL~5W~... ~ OOL Days Hrs. Days Hrs. ~ Torque ]Drag }Rm. Wt. IP/UWI JSIa~kOHWI g On Casing JSince Last Eal. Liner Set ~ MD TVD- TOP ~ MD TVD "1c'°' l ~ Pm Pf/Mf gL CA lEx L~me El Stab Wt. Material "~el JCausti~ .... Lig~, CIs. Salt' CaCl~ Other - ,,.,. ,. , M g Angle Oiremion J TVB Coordinates V S BLS ~ .. .... ... i ,, , , , No. Size Type Set. No. Jets In Out Feet Hrs WOB RPM T B G , . Total Length (H,W,D,P.: ) Consists of ~ ...... ~ ,, , , , . ,., , , ~ Pump Liner Stroke j SPM Pressure GPM Jet Vel. Ann. Vel B~t HHP Pump HHP , ,,,, , ,, ..... Hrs, O~eradons Coverm~ 24 ~ours [~Oin~ ~ ~ , . ,, ,. , . . ..... ..... ,, .......... ,,, ,, ~ gaily Mud --0 -- ICu~ Mud -- O--;, IOaily Tangible JCum Tangible ]Da'ily Welt /*, r~r lCum Well q~. ~ ~ DrillHzO PotH,O . 1Fuel JBulkWt. JBulkCmL / ITo,aIADpr. j/~r~ _ GO 1211 lCD 2 85~ Printed ~n U S A Drilling Morning Report Company ~--'~'~J~ ~.~'~ Reg,on ~Fr~N o,~,~,o~ A~A[~A ~ DOL DFS Total Roi Hrs · ~ Days Hrs. Days Hrs.. ~ Torque ~Orag Rot. Wt. PIU Wt. Slack Off Wi. Shoe les~ ~ Cum ~ot. Hrs.: Be~h Wors~ ~ear % ~em '~ On Casin~ lSince last Cal. Liner Set $ MD TVD-TOP ~ MD TVD Gel WL HT-HP FC Solids % Oil % Sand JMBT PH ~ Pm Pf/Mf CL CA Ex k,me El Stab Wt. Material Gel ]Caustic Lig. CIs. Salt CaCIz Other ~ Avg. Drilling Max. Drilling Conn. Trip Trip Chlorides Remarks ~ , M D Angle Direction TVD Coordmnates V S O LS No. Size Type Ser. No. Jets In Out Feet Hrs. WOB RPM T B G Total Length (H.W.D.P.: ) Consists of Pump Liner Stroke SPM Pressure GPM Jet Vel. Ann Vel. Bn HHP Pump HHP Hrs. Operations Covering 24 Hours Endmng ~ Midnight $ [c mM o -o- lO ,, Tangibte Cum Tangibte ]Da,lyW,,m/ . ~¢0 ]rom W,,, /b g _ Drill H,O [Poz H,O Fuel Bulk Wt. ]Bulk Cmt. Ilota' Appr. GO 1211 lCD 3 85l Pr,hied ,n US A c,,o,.. Drilling Morning Report DePth /,¢~O~,Y MD TVD ( '~'~/'7 PBTD) IPr°p°seO TD MD TVD DOL ~' Days Hrs. Days Hrs. ° Torque ]Drag [Rot. Wt. JP/U WL [Slack O, Wt. /~ , IShoe Tes; kas~ Cas,ng Siz'e ~ ~ " Set ~ ~5 ~ 0 MD TVD EMW Cum Rot. Hrs.: Depth Worst Wear % Rem On Casing [Since Last Cal. -, Liner Set ~ MD TVD- TOP ~ MD TVD Pm ] Pf/Mf CL CA' Ex Lime El Slab 'Wt. Material Gel Caustic , Lig. CIs. Salt ,.. 31her , ,, M D Angle Direction TVD Coordinates V S [ D LS ,.. No. Size Type Ser. No. Jets tn Out Feet Hrs WOB RPM I B ] G .... Total Length {H.W.D.P.: ) Consists of Pump Liner Stroke I SPM Pressure GPM Jet Vel. Ann. Vel. Bi~ HHP Pump HHP ~rs. O~era~ions Coverin~ 24 Hours [ndm~ ~ . ...... .... , o ,,vMud - O- JCumM,d --0-- 1DailyTangible ]Cum'angible [DailyWel, /27J7 CumWel, ~ 7~ G0,211 ,CD385, Pr~med ~n U S A ,c..o,.. Drilling Morning Report · I Proposed TO Depth /~O ~.'~' MD TVD ( '~ 7' PRIg) MD TVD · ~ DOE IDES JTolalRot Hrs .~ Days Hrs. Days Hrs. "" Torque . Drag. IRoi. Wt. P/UW~ JS,ackOflWt Last Cas,ng Size ? $/'~" Set ~ ~ O' MD TVD JShoe Tes, E MW .~ Cum Rot. Hrs.: Depth Worst Wear % Rem ~ On Casing ISince Last Cal. Liner Set ~ MD TVD- TOP ~ MD TVD W~. CO ~ CO ~Type FV PV YP Gel IWL ~HT-HP FC Solids °/o Oil °/c Sand [MBT PH ~ Pm Pf/Mf CL CA Ex Lime El Stab :Wt. Material Gel lCaustic Ug. Cls Salt CaCl~ Other ~ Avg. Drilling Max. Drilling lConn. [Trip Trip Chlorides Remarks M D Angle Direction TVD Coordinates V S D L S No. Size Type Ser. No. I Je~s In Out Feet Hrs. WOB RPM T B ,,, ,_ Total Length' (H.W.D.P.: ) Consists of ,,, Pump Liner Stroke SPM Pressure GPM Jet Vel. Ann Vel. Bit HHP Pump HHP ... Hrs. ~ '~ ~/~. Operations Covering 24 Hours Ending ~ Midnight ~ OailyMu,__~__ CumMud __~__ I Daily Tangible ICumTangible IDa,lyWel,~~. lCumWetl Drill H,O Pot H,O IFue, IBulk Wt. JBulk Cml. ITota, Appr. /~ ~~ _ G01211(CD385~ c,..o,.. Drilling Morning Report t IP oposed TD Depth j~. ~,, MD TVO ( ~'~ ¥ 7 ' PBTD) MD TVD E Days Hrs. ,. Days / ~ Hrs. ~ Torque Drag ~Rot. Wi. P/U W~ Slack Off W~ Last Casing Size ~ ~ 18" S,t ~ ~5~ 0 · Shoe Test MO TVD EMW ' CumRol. Hrs.: ]Depth Worst Wear ~%Rem '~ On Casing JSince Last Cai. Liner Set ~ MD TVD- TOP ~ MD TVD c,o, r co "" ~ Pm ~, ~ Pr/Mr O. 2 t /. & gL 7~ CA ~r Ex brae El S,ab Wt. Material Gel ~Caustic Lig. CIs. Salt Cagb Lother ~ ~" Angle Direction TVD Coordinates V S D LS , ,, ,., .... I ~ No. ] Size Type Ser. No.' I Jets tn Out Feet Hrs WOB RPM T ~ ~ G ,-- .. , i .... Toial Length (H.W.D.P.: ) Consists of Pump Liner Stroke SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP ~ ,, Hrs. Operations Covering 24 Hours End,nB ~ Midnlgh~ , , , .... ,, , .. , X Daily Mud 72X 7 Icum Mud 7~X ~ JDaily Tangible JCum Tangible Drill H,O Pot H,O IFue, lBulk Wt. GO 12~1 ~CO ,.385~ (~ 7yf Pr,reed ,n U S A CC.Morn. Drilling Morning Report I Proposed TD Depth /,,~0~'1~ ' MD TVD ( '~'/~ Y7' PBTD) MD TVD dOL DFS jTo~al Rot Hrs g Days Hrs. / Days /~ Hrs. Torque ~Drag Rot. Wt. P!U Wt. JSlack Off W~ Cum Rot. Hrs.: Depth Worst Wear ~°,c Rem On Casing [Since Last Cal. ,, Liner Set ~ MD TVD- TOP ~ MD TVD ,, i $ /~ [HT-HP Solids % O'l Sand Pm /. ~ Pr/Mr ~,~ / ~, ~ CL ~0 CA /~ Exbme EIStab Wt. Material Gel Caustic Lig. CIs. Sal~ SaCl~ '~ther Avg. Drilling Max. Drilling Conn. [Trip Trip Chlorides Remarks ,,, 'M O Angle Direc[ion TVD Coordinaes V S DLS No. S~ze Type Ser. No. t Jets In Out Fee~ Hfs WOB RPM T B Tmal Length (H.W.D.P.: ) Consists of Pump Liner Stroke SPM Pressure GPM Jet Vel. Ann VeL B, HHP Pump HHP ,. Hrs. Operations Covering 24 Hours Ending ~ Midmghl .... .,. / 6 7Y P,,n,ed ,n U S A Drilling Morning Report ~ep,, /,1o,t~" ..~o ~vD I ¢~''~7' ' ~ml IP'r'°p°$a~'D ~ ~DFS Total Rot Hfs DOL ? Days .Hrs: ~ Days / ~ Hrs. . Las, Cas,nc ~ize ~ ~/~" Set 0 ~5~ 0 ' MO TVD Sh~ Tes, EMW Cum Rot Hrs.: [Depth Worst Wear % Rem On Casing ]Since Last Cai. ,- Liner Set ~ MD TVD · TOP ~ MD TVD ~. ~ . /, / CL /~00 CA ~x ~,~ ~ ,, , Wt. Material ' Gel ~Caustic- Lig. CIs. Sal~ CaCI~ . , ...... ~Other Avg. Drilling Ma~. Drilling ~Conn Trip ~Trip'C~loride~" Remarks M D Angle Direction TVD Coordinates V S DES .... ...... . , ' , ,, , .... , , ,,,, No. Size Type Set. No. Jets In Out Fee~ Hrs. WOB RPM ~ B G . . ,, . ,,, Pump Liner Stroke SPM Pressure GPM Je~ VeL Ann Vel. B~t HHP Pump HHP Hrs. Operations Covering 24 Hours End~ng ~ Midmght /~ ~o~ ,.. _ _ , , DailyMud ~ ~ 1CumMud /~~ ~D~ilyTangible JCum Tangible ' JO~i,y'Wei, a~or? }Cum ~e~o~07,. Drill H20 Ipot H,O ]Fuel ]Bulk Wt. ]Bulk Cmt. I,ota, Appn ~ ~~ _ GO 1211 fl]D 3 85i ~' 7Y? Pnnted m d S A ..o,.. Drilling Morning Report I~'ITIUI II, ' ,-- -Con,any ~_X~ ~ ~ IReg~°n bt~.. ~'fo',, O,v,~,on ,. I Proposed TD Depth l ~ ~ ~ t MD TVD ( ~ ~ / PBTD) MD TVD DOL DFS Total Roi Hrs / 0 Days Hrs. B Days / ~ Hrs. Shoe les~ Las~ Cas,rig Size ~ ~/~ Set $ MD TVD EMW Cum Rot. HrSm] Depth Wors~ Wear % Rem On Casing )Since Last Cal. Liner Set $ MD TVD- TOP $ MD TVD .... V YP Pm H/M( CL ICA Ex Lmme [I Stab Wt. Material Gel . Caustic Ug. Cls. :Salt CaCb 3ther M D Angle Direction TVD Coordinates V S D L S No. Size Type Ser. No. Je~s in Out Feet Hrs. WOB RPM T B O Tolal Length (H.W.D.P.: ) Consists of ~um~ Uner Stroko S?M ~ressure ~ ~e~ Vel, Aah Vel. Hrs. Opera~ions Covering 24 Hours Ending 8 Midmgh~ ,,. BailyMuO X?~ / ICumMuO ~lYCf DailyTangibme Cum Tangible Ba,lyWe,t ~r~$o ~c..o,.. Drilling Morning Report ~ /t Days Hrs. ~ Days /& Hrs. , ,, Last Casing Size ~ '/S Set 0 ~ ~ 0 ' MO TVD ]Shoe Tes, EMW ~ On Casing ISince Last Cal. ~ ..... Liner Set ~ MD TVD -TOP ~ MD TVD Se, ~/,;, WL / ~ IHT-HP -- I~C ~ ]Solids ~ ~' °/° Oil, ] Pm ~l ~ Pr/Mr CL CA Ex Ume El Stab W~. Mamriat ...... '" Gel ~CausTic Lig. CIs. Salt CaCI~ Other , , M D Angle Direction TVD Coordinates V S O L S ,, , ~ ,, i No. Size Type Ser. No. Jets In Out Fee~ Hfs, WOB RPM T P~mp Liner S,roke SPM Pressure GPM ~ Je, Vel. Ann Vel. ~ Bd HHP Pump HHP ~J .... Hrs. Operations Covering 24 Hours Ending ~ Mldmght .... , ~. ~.,~.~'; ~/ ~,;~ ~i~~ ~oo~ o~ ~.~r Drill~ DailyMud ¢~C ~um'Mud~'~OH,O ~adyTangible Cum Tangible . , ]DadyWel, w,. Pr,reed m d S A c,...o,.. Drilling Morning Report ,--, MD TVD DOL IDFS ~Total Rot Hfs , / ~ Days Hrs. ~ Days / 8 Hrs. ~ Torque IDrag Rot. Wt. P!UWl ~SlackOHWt Last Casing Size ~ ~/~" Set g ~ ~ 0 ' MD Tva EMW Cum RoL Hrs: Depth Wors~ Wear I% Rem On Casing JSince Las~ Cal. Liner Set ~ MD TVD- TOP ~ MD TVD "~'/~/* I~° z~~ ,,~ ~/~,.~ ~v ~ ~v P~ Pr/Mr CA Ex Ume El S~ab Wt. Material Gel Caustic Lig. CIs. Salt CaCI~ O~'her M D Angle Direction TVD Coordinates V S D LS No. Size Type Ser. No. Jets In Out Fee~ Hrs. WOB RPM T B G ~ ~',~ ~c-~2 ~ ~.z ~-a~ ~~;-~ ~ d~ ~,4//~ Total Length (H.W.D.P.: ) Consists of Pump Liner Stroke SPM Pressure GPM Jet Vel. Ann Vel Bd HHP Pump HHP Hrs. Operations Covering 24 Hours Ending ~ Mldmght ~ ~p~2 ~ ~;~ ~/~, I '~ ~ DcM/~,;~. ~ 2..~,>~ N~/~. ~y~ ,,; -,,,~ ~k. V ~'' Pnnled m U $.A ~c..o,.. Drilling Morning Report f ]Proposed TD Dep,h t ~..~ MD TVD ( '~ '~'~ PBTD) I MD ... TVD / 7 Days Hrs. , ~ Days /8 Hrs. Las~ Casing S,ze ~¢/~" Sero ~550 ' MD TVD ]Sh;; Te's~ EMW Cum Rot. Hrs.: lOepth Worst Wear % Rem On Casin9 [Since Last Cal. ,, Liner Set ~ MD TVD-TOP $ MD TVD ~t. Material Gel Caustic.. Lig' CIs. Salt CaCI~... Other ,, ,, ,, ,, M D Angle Oireaion TVD Coordinaes V S DLS ,, , , ,- ..... No. Size Type Ser. No. Oe~s In Out Feet Hrs. WOB RPM Pump Liner Stroke SPM Pressure GPM Jet Vel. Ann Vel. B~t HHP Pump HHP Hrs. ~ Operalions Covering 24 Hours Ending ~ Midnlghl ~ ~/~ ~;~ ~ o_~/~/Cct~ ~ :?7 ~ / ~o ' ~1~ h~r~. ' i O¢~u~ 0Y ]Cum Mud CX, O, [D'~ily Tangible JCum Tangible ~Da,ly WelIX~ ~ GO 12~1 ~CD 3 85 Pr,nled m d $ A CC-Morn. Drilling Morning Report Depth t/,~02 5 ., MO TVD ( Z.//~ '75 PBTD) ]Proposed TO MB TVD DOL /~ Days Hrs.] 7 Days /~ Hrs. ]DFS To[al Rot Hrs "Torque ]Drag IRot. Wt. ~P/UW~ lSlackOflWt Las, C~sing Siz~ ~ ~/~ Set ~ ~5 5 0 MD Tva , EMW .~ Cum Rot. Hrs.: Depth Worst Wear ]% Rem ~ On Casing ~Since Las~ Cal. ! Liner Set ~ MD TVD - TOP ~ MD TVD ~ Pm Pf/Mf CL CA Ex Ume El Stab Wt. Material Gel ~Oaust~c ' Lig ~ls, Salt I Other M D Angle Direction TVD Coordinates V S D LS No. Size Type Ser. No. Jets In Out Feet Hrs WOB RPM T B G To~al Length (H.W.D.P.: ) Consists of Pump Liner Stroke SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Hrs. Operations Covering 24 Hours Ending ~ Midnight ~ - . I ~ DailyMud/~O? [CumMud ~[~/7 ]DailyTangibie ICumTangible ' Drill H=O " ' Prmled m U S A c,.,,o,.. Drilling Morning Report Well ICh. Code lField P/'~,,~t~, ~c.~ ~ ~.o. . w~,~ol~7 - - ~ lProposed ID }DF'S Total RoL Hrs Last Casing Size ? S/~ Set 0 ~5~0 MD TVD [Shoe Tea EMW ~ On Casing Jgince Last CoL Liner "- Set ~ MD TVD-TOP ~ MD TVD ,'5/,, I""""- I / 1 ~ Pm Pf/Mf CL CA Ex bme EIStab W~. Maerial Gel Caustic Lig. Cts. Salt CaCl~ Chlorides ~ Avg, ~ril{ing Max. Drilling ~Conn. ~Trip, Trip ~Remarks , M D Angle Direction TVD Coordinates V S D L S ,. , .... No. Size Type Ser. No. Jets In Out Feet Hrs. WOB RPM T B G ~ , , .... I, ~ , ...... Pump Liner Stroke ' SPM t Pressure ' GPM ' Jet Vel. Ann. Vel. ' B,t HHP Pump HHP Hrs. Operations ~overia~ 24 Hours [n0m~ */~Y Ig~.F~,' ~2o~ ; 0.3 /*/6? 1~7o .. ~o ..,, .i, ~G .... ~/~q /~ " ~o ".. ~, 7o ~ - . , Pr,reed ~n U SA cc..o,.. Drilling Morning Report Proposed ID Depth l~e~' ~ MD TVD ( '~'~ 7.~ PBTD) MD TVD I DOL DFS ITotal Rot Hfs Z ~ Days Hrs. ~ Days /~ Hrs. Torque Drag Roi. Wt. P,~U Wt. [Slack Off Wt kastCasing Size ~/~ t~ Set~ ~0 / MD TVD lSh°e Test EMW onCUmcasingR°t' Hrs.: ~Since Last Cal. Depth Worsl Wear % Rem Liner set ~ MD TVD- TOP ~ MD TVD P Pm Z' 5 Pf/Uf ~, 3 / ~, ~ CL /~0 CA ~~0 ExUme EIStab Wt. Material Gel [Caustic Lig. ~ CIs. Sail CaCI~ Other Av9. Drilling Max. Drilling Conn. Trip Trip Chlorides Remarks M O Angle Direction TVD Coordmaes V S DES No. Size Type Ser. No. Jets In Ou~ Feet Hrs. WOB RPM T B G Total Length (H.W.D.P.: ) Consists of Pump Liner Slroke SPM Pressure GPM Jet Vel. Ann Vel. Bd HHP Pump HHP Hrs. Opera~lons Covering 24 Hours Ending 9 MidnighI - / I- f f ,., 'DallyMud /0~7 JCumMud ~'?¢r/ Daily Tangible Cum Tangible ]DailyWel, ~///b ]CumWd, GO 12]] ICD 3.85~ Printed ,n U S A Drilling Morning Report ,, · /? Days Hrs. , /0 Days /~ Hrs. Torque Brag Rot. Wt. PiU Wt " Slack OH W~ Last Casing S,ze ? ~/~" Set ~ ~ ~ ' MD TVD lSh°e Test EMW Cum Rot. Hrs.: Depth Worst Wear [°/o Rem On Casing JSince Last Cal. ILiner Set ~ MD TVD-TOP ~ MD TVD w,. ~.~ Ic°z~o ' [,,,~.~,~/~~ ~v ¢~ ~v Pm Pr/Mr CL 'CA Ex brae El S~ab Wt. Material Gel ~austic , Lig. ~ls. Sal~ .. . O~her ~v~.~r,,,n,. ,,x.O~,,,,~o V' ~"" )~"~'~"" ",,~,r~. ,. ......,. M D ~ngle Direction TVD ~oordina~es V S D LS ..... ,, ,, No. Size Type ~ Set' No. Je~s In Out Feet . Pump Liner Stroke SPM Pressure OPM' Jet Vel, Ann Vel. Dt HHP Pump HHP Hrs. Operations Covenng 24 Hours Ending ~ Midnight ~ c~ ' ~/u' ~~ a ~x _~~ -¢~' ~. ' . ,, Prlnled in U $ A cc..o,.. Drilling Morning Report ICh. Code Proposed TD Oeoth /~ ~ MD TVD ( Y6 7 ~ PBTD) MO Tva .~ DOL DFS Hrs.[T°tal Rot Hfs ~ / ~ Days Hrs. // Days / ~ Shoe les~ Las, Cas,ng Size ~ ~/~" Set 0 ~ffO ' MD TVD EMW '~ On Casing ~Since Lasi Cal. Liner Set ~ MD TVD-TOP ~ MD TVD ~ Pm Pf/Mf CL iCA Ex bme El Slab Wt. Material Gel Caustic. Lig. CIs. Salt CaCl~ Other ,,, ~. Driltm~ Mox. ~rillin~ Conn. [lri~ lrip Chlorides ~emarks , ,, M D Angle Direction TVD Coordinates V S D L S No. Size Type Set. No. Je~s In Out Feet Hrs, WOB RPM T Total Length (H.W.D.P.: ) Consists of Pump Liner Stroke SPM Pressure GPM Jet Vel Ana Vel. B~ HHP Pump HHP Hrs. O~emons Co~erin~ 24 Hours ~n0m~ ~ ~ ~/~ ~// ~F ~. ~ vl~ V / V~ot,,' ~ ' o. ~ ~ 5~307Z _ Drill H,O Bulk W,. Bulk Cra,. lTD t al A ppr. / Rig ~[ ~e ]Rig PhY~o~h ~'~7~ Z Drilling Rep. /~ / Acc,dents GO 1211 lCD 3 851 Pr,med ~n U S A CC-Morn, Drilling Morning Report A/.- A S KA. I~age Company (-,,N~"~ ~'~)N [,/,~"'A lCh` Code Oepth / 2 ~~ MO TVO ( fig 7~ PBTO) . MO TVD Proposed TD .~ OOL ~OFS ~Tota, Ro~ Hfs. ~ /~ Days Hrs. / ~ Days Hrs. ~ Torque JOrag.. ]Ro,.Wt. P/UWL ~SlackOffWt. . " Las~ Casing Size Shoe Tes) Set ~ MD TVD EMW ,~ Cum RoL Hrs.': ~ On Casing JSince Last CaL Depth Worst Wear ]% Rem Liner ' Set ~ MD TVD-TOP ~ MD TVD ~ Pm ~ Pr/Mr CL CA ' Ex brae Et Stab '" ~t. 'Material Gel )Causvc Lig. I CIs. Salt CaCI~ " Other M O Angle Direction TVD Coordinates V S DLS ., . ,,. ~ - , ,,, , , No. Size Type Ser. No. I Jets In Out Feet Hrs. WOB RPM T BG ,,. , , , , Pump Liner S~roke SPM Pressu[e GPM Jet Vel. Ann. V~I Bit HHP Pump HHP ~ · , ~ , ,, , Hfs, Operations Covering 24 Hours Ending ~ Midnight · ~P= i763./ ~SIP = /~7~.~ ~ C~l~ ~o~R P~ . _ pooO /np. sAm I'/~ pl~ ~1~ * P~" cAx/~ ~~R- P/~ r~ pSr~ ~Z?~r . ~ " , . ~ Daily Mud~. O~ ~ ~Cum Mud VO. ~S ~Oaii, Tangible ICum Tangible JDail, WeIIv~ 30 r Cum Wel[~ ~rill H,O ' [Pot H,O ' ~Foel JBolk WL )Bulk Cmt. ' JTo,,J Apo,. (, ~ Pflnled ,n US A CC.Morn. Drilling Morning Report 1Regl°n ~~m~1oiv's'°n ALASK,4 ?c~ ~ ~_ W.&. wAD ~o/v7 I~'~'° ?~~y c~K ~ ~r-t~~ / , I Depth / ~ 0 2~ MD TVD ( ~t ~ PBTO) ~Proposed TD MO TVD DFS Total Rol Hrs. ~ Torque ]Drag IRot. Wt. P/UWt. SlackOflWt Shoe les~ Last Casing Size ~~ Set ~ ~~ MD TVD EMW ;urn Rot. Hrs.: ]Depth Worst Wear % Rem On Casing lSince kasl Cal. liner Set $ MD TVD · TOP ~ MD TVD Wt. Type _ IFV PV ~YP /0, S+ co ~Mco s~u~k/~O~.~ Y2 ~ /~ ~' ,//o 7~ ~.~ """~- ~c / ~o,,~,3 %0,0 i~,~o~ ~,_ Pm t Pf/Mf CL CA Ex L~me [I Stab Wt. Material Gel CauStic Lig. CIs. Salt CaCI, Other Avg. Drilling Max. Drilling Conn. Trip Trip Chlorides Remarks ,, M D Angle Direction TVD Coordinates V S D LS No. Size Type Ser. No. Jets In Out Feet Hrs, WOB RPM T B G lotal length {H.~.D.P.: } Coasis~s of Pump Liner Stroke SPM Pressure GPM Jet Vet. Ann Vel. 8i~ HHP Pum~ HHP Hrs. Operations ~overmg 24 Hours [nOmg ~ Midnigh~ Daily Mud 0 i po[C;; Mud Tangible Bulk Wt. IBulk Cmt. Appr-,, ~ ~'0 __ CC-Morn. Drilling Morning Report IRe§,on ~ 'Dei h / 2,, ~)'~...~" MD TV§ ( Y~ 7~' PBTD) IPr°p°seO TO ~D TVD 2 / o., ,,,. /y Days Hrs. Las, Casing Size ~~ Set~ ~SS~ ~D TVD[Sh°e Tes' .. EMW On Casing ~Since Last Cal. ........... Liner Set ~ MD TVD-TOP ~ MD TVD Ge. ,//, ,~ ~HT-HP __ . /. ]Solids , , ]%Sandm ~MBT- Pm / Pf/Mf gL CA lex Ume [I Stab Wt.'Material Gel ~Cau~tic Lig. ¢ CIs Salt ~aCb i ,, Other M O Angle Direction TVD Coordinates V S D LS , No. Size Type Ser. No Jets In Out Feet Hrs. WOB RPM T B , To~al Length (H.W.D.P.: ) Consists of ,, Pump Liner Stroke SPM Pressure GPM Jet Vel. Ann. Vel Bd HHP Pump HHP Hrs. O~eravons Co~erm~ 24 Haurs [nd~a~ ~ ~ FI~I~ R~I~ Ou~L 2~/~'' ~. ~~LL ~/~ ~/~ ~~ ~ ~ 9tO~ ' , . DailyMud__0 -- ]CumMud ,O,r~~FuellDa,l, Tangible Oum'Tangibie IBa'lvWeli~'e~o(alJCUmWel' Bril' HzO IPot H,O ' " IBulk Wt. JBulk Cmt. Prm~ed ~n U SA Drilling Morning Report CC-Morn. k~'lllUI II, IRegion D~wston .~ DOL DFS Total Rot Hfs · ~ ~ ~ Days Hrs. / ~ Days Hrs. ~ Torque Drag ~Ro~. WL P/U WL Slack OH Last Casing Size ~ ~ Set ~ ~~ MD TVD Shoe Test EMW ~ Cum Rot. Hrs.: Depth Worst Wear % Rem '~ On Casing ~Since Last CaL Liner Set ~ MD TVD - TOP ~ MD TVD ~ Pm PfiMf CL CA Ex bme El Stab ~ / Wt. Material Gel Caustic Lig. CIs. Salt CaCIz Avg. Drilling Max. Drilling Conn. Trip Trip Chlorides Remarks M D Angle Direcvon TVD Coordinates V S D L S No. Size Type Ser. No. Jets In Out Fee~ Hrs. WOB RPM T B G Total Length (H.W.D.P.: ) Consists of Pump Liner Stroke SPM Pressure GPM Jet Vel. Ann. Vel. Bd HHP Pump HHP Hrs. Operations Covering 24 Hours Ending ~ Mldmght ~ ~IppL~ ~. LO~ ~~R, ~pp~ HA~ AND ~IN~ U~LU¢~ ~ ALL Drill "20 ' Bulk Wt. Bulk Cmt. ' App,. / GO 1211 (ED 3 ~ 7 ~3 Pr,reed in U SA Drilling Morning Report Region IOivlslon Proposed TD ~ 2 3 Days Hrs. , /~ Days /~ Hrs. Las~ Casing Size *~ Set~ ~r~ MD TVD ~Shoe Test EMW .~ Cum Rot. Hrs.: Depth Worst Wear [% Rem ~ On Casing JSince Last Cal. ~ . Liner Set ~ MD TVD. TOP ~ MD TVD ~ P~ Pf/Mf gL CA Ex bme El S~ab Wt Material Gel ]Caustic, Lig, CIs.' Salt CaCl~ Other , M O Angle Direction TVD Coordinates V S DLS ....... ~ ' No. Size Type Ser. No. I Jets In Out Feet Hrs. WOB RPM T B Total Leng'th (H.W.D.P.: ) Consists of ' ' ~ump Uner Stroke SPM Pressure ~PM Jel Vel. Ann. Vel ~ ~ " ~ , , ,, Hrs~ O~eraVons Coverin~ ~4 ~ours [a~in~ ~ ~dni~ht , ,, ,., Well -- JCum Well DrillH,O ' IBulkWt. ' ']Bu'ik~t, Appr. i, Pnnled ,n USA CC-.or.. Drilling Morning Report ,,. ~ompany ~' ~"~_ ~' ~,~/t) ~ ~,~ ~ Region IProposed TO Oepth 1~1 ~2~ MD TVD ( ~7~ PBTO) MD TVO 2 ? Days Hrs. Days Hrs. Last Casing Size Set ~ MD TVD Shoe Test EMW Cum Roi. Hrs.: ~Oepth Worst Wear ~°/o Rem 0n Casing JSince Lasl Cai. Liner Set ~ MD TVD - TOP ~ MD TVD Wt. CO Type FV ]PV YP Pm Pf/Mf CL CA Ex Ume El Stab Wt. Material Gel ICaustic Lig. CIs. Salt CaCI~ Other ~v~. ~rillin~ Max. ~rillin~ Conn. lri~ ~lri~ Chlorides ~emarks M O Angle Direction TVD Coordinates V S D LS ..... No. Size Type Ser. No. Je[s In Out Fee~ Hrs. WOB RPM T B G ,., Tetal Length {H.~.~.P.: } Consists of Pump Liner Stroke SPM Pressure GPM Je~ Vel. Ann. Vel. Bd HHP Pump HHP Hrs, Operations Covering 24 Hours Ending ~ Midnighl ...... ,,. ' JBulk Wt. )Bulk Cml. Printed ~n U S A cc.,,o,.. Drilling Morning Report I Proposed TO MD TVD DOL 2r Days Hrs. Days Hrs. Last CaSing Size Set $ MD TVD Ish°e Ies~ EMW Cum Rot. Hrs.: IDepth Worst Wear % Rem On Casing [Since Last Cat. ,,, bner Set ~ MD TVD-TOP ~ MD TVD . ~m Pf/M~ CL CA Ex Ume El Stab WL Material Gel ~Caustic Lig. CIs. Salt CaCl~ Other M O Angle Direction TVD Coordinates V S D L S ,. ..... .... , No. Size Type Ser. No. Jets In Out Feet Hfs WOB RPM T B G '- ,,. ,, Total Length (H.W.D.P.: ) Consists of Pump Liner Stroke SPM Pressure GPM Jet Vel. Ann. Vel, Bit HHP Pum~ HHP Hrs. Operations Covering 24 Hours Ending ~ M~dmght ,. , , Accidents Prmled ~n U S A c,..o,.. Drilling Morning Report , Region~¢XTF~_,NID'v,s,on ~,~ ~ ,¢~¢,.~K/~j.' Company ('""'~'~'~'"~ ~ ~Ch. Code Proposed ID .Oemh I 2 0 ~ MD TVD ( y&7~ PBTD} MD TVD ~ DO[ ~ ]DFS Tolal Rot Hrs '~ 2~ Days Hrs. Days Hrs. Shoe Test Last Casing Size Set ~ MD TVD EMW ~ Cum Rot. Hrs.: IOepth Worst Wear % Rem '~ On Casing ~Since Last CaL Liner Set ~ MD TVD-TOP ~ MD TVD Wt. CO ' Type 'FV PV ]YP Gel IWL IHT-HP iFC [Solids %0i, %Sand IMBT PH ~ ~m Pf/Mf CL CA Ex Ume El Stab ~t'. Material Gel ]Caustic Lig. CIs. Salt CaCl~ Other M D Angle Direction TVD Coordinates V S BLS ,,. No. Size Type Set. No. Je~s In Out Fee~ Hrs. WOB RPM T B G .... To~a! Length (H.W.D.P.: ) Consists of Pump Liner Stroke SPM Pressure GPM Jet Vet. Ann. Vel. Bd HHP Pump HHP Hrs. Operations Covering 24 Hours Ending ~ Midnigh~ ,,, .,, ,,. .,, ,,, ~ DailyMu' 0 ipo?;;Mud ~*, '~ Fuel ~DadyTangible C~mTang,ble Drill H20 ' ]Bulk WZ. ~Bul' Cmt. Appr.~, Z~5m G0 1211 ~CD 3 Pr,nted ~n U S.A c,..o,.. Drilling Morning Report IReglon lOlvlsiOn , We,J 1Fie,d [Date , lPage Proposed TO Depm / ~ 02 ~ MD TVD ( ~7~ PBTD) MD TVD ~ DOL ' ~ " DFS Total Ro~ H'r's ~ Days Hrs. Days Hrs. : TOrque ]Drag ~Rol. Wl. ]P,'UWt }Slack Off Wt Shoe Tes~ Last Casing Size Set ~ MD TVD EMW .... ~ Cum Rot, Hrs.: ~Depth Worsl Wear % Rem '~ On Casing JSince Las~ Cal. ~ ...... Liner Set ~ MD TVD -TOP ~ MD TVD I I ...... 1" Wt. Material ~el Caustic Ug. CIs.' Salt CaCI~ Othe; Avg. Drilling Max. Drilling Conn. Trip Tr~p Chlorides Remarks M D Angle Direction TVD Coordinates V S O L S ,,_ ~ - No. Size Type Ser. No. Jets In Out Feet Hrs. WOB RPM T B ~ G I Total Length (H.W.D.P.: ) Conststs of Pump Line~ Stroke SPM Pressure GPM Jet Vel. Ann. Vel. Bn HHP Pump HHP ~ , Hrs. Operations Covering 24 Hours Ending ~ M~dmght , ,. ~ .... .,, . ,. .... , GO 1211 ~CO 3 85;, 1~793 Pr,n,ed m U S A STATE OF ALASKA ALASKA C..,. AND GAS CONSERVATION COl-, ,MISSION WELL cOMpLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well 1. Status of Well OIL [] GAS ~] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Chevron U.S.A. Inc. 79-0009 3. Address 8. APl Number P.O. Box 107839, Anchorage, AK 99510 50-283-20022 4. Location of well at surface 9. Unit or Lease Name 1590' S & 2140' W of NE corner Section 33, 14N, 9W, SM Pretty Creek Unit At Top Producing Interval 10. Well Number Same PCU #2 At Total Depth 11. Field and Pool Same Wildcat - Beluga 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. G.L-=82' K.B-=96'I ADL 63048 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. or Aband.__~ ,~[ 15. Water Depth, if offshore 116' No. of Completions 4/16/69 7/18/69 ~ ~/,~/~ NA feet eSL 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set I 21. Thickness of Permafrost 12,025 '; 12,025 4675 '; 4675 ' YES [] NO E~ I NA feet MDI NA 22. Type Electric or Other Logs Run CNL/GR/CET 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" 94.4.~ H-40 !8' 339' 26" 600 SK$ C! "T" 13 3/8' 61# J-55 16' 2032' 17 1/2" 660 SKS C1 "I" (a 1)48' 810 SKS C1 "] 9 5/8' 40:43.5' N-RO;.R- )5 lA' g550' 12. 1/4" 1110 RKR Cl "t"= DV Ca_ 4525' 1020 SKS 47 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. Attached TUBING RECORD i.nterval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3915'-3980'; 3915'-3980' 65' .50" 12 JSPF 3-700'-3780'; 3700'-3780' 80' .50" 12 JSPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. : DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED ,, 3570'- 3525' & 200 SKS C1 "G'!.CMNT 3416'-3396' 27. See Attached PRODUCTION TEST Date First Production I Method of OperatJ0n (F ow ng, gas lift, etc.) I Date of Test Hours Tested 'PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~I .... Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (c0r'r) Press. 24-HOUR RATE I~ 28. NA CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. C1 "I" Submit in duplicate~- Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE r, 29. ': . . ..30. ., GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase, See Attached 31. LIST OF ATTACHMENTS Supplementary Record 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed . .. Title ST'. At-~_~ E~gin~t-Date (~"5~'~,~ : __ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. I'tem 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". SUPPLEMENTARY RECORD 25. 27. Tubing Record: SIZE DEPTH SET (MD) 2 7/8" 3989' 2 7/8" 3788' 2 3/8" 1801' Production Test: Intervals: 1. 3980'-3915' 2. 3780'-3700' PACKER SET (MD) 3854', 3643' 3643 PRODUCTION FOR TEST PERIOD Hours Interval Date Tested I 6/21/86 13:54 2 6/24/86 13:52 Oil Gas Water Choke Gas/Oil BBLS MCF BBLS Size Ratio 0 2447 0 32/64 NA 0 1148 9.5 20/64 NA Calculated 24 HR. Rate Flow Tbg CSG Oil Gas Water Interval Press Press bbls MCF BBLS Oil Gravity-API (Corr) I 1250 0 0 5,691 0 NA 2 1340 0 0 2,198 24 NA 30. Formation Tests: DST #1: Peforated 3980'-3915' with 12 ½" JSPF and opened tool with 1900 PSI underbalance. IFP 0:02 IIFP=1717 PSI FIFP=1725 PSI. ISIP 1:28 ISIP=1920 PSI. FFP 13:52 IFFP=1917 PSI FFFP=1674 PSI. FSIP=13:27 FSIP=1907 PSI. IHP=2148 PSI FHP=2126 PSI. GTS at 10:36 AM 6-20-86 FTS at 6:00 PM 6-20-86. Final rate 5,691 MCFD 32/64" Choke 1250 PSI FTP. Rcvd approximately, I BBL water as mist. DST #2: Perforated 3780'-3700 with 12 -}" JSPF and opened tool with 400 PSI underbalance N2 cushion at 6:49 PM 6/22/86. 7:11 IIFP=1324 PSI FIFP=1443 PSI. 10:32 ISIP=1669 PSI. 6:41 IFFP=1609 PSI FFFP=1560 PSI. 6:18 FSIP=1663 PSI. IHP=2023 PSI FHP=2046 PSI. GTS at FTS at 11:42 PM 6-22-86. Final rate 2,198 MCFD 20/64" ~n~t~ ~4~ FTP. Rcvd 9.5 BBLS formation water total for the test. TRANSMITTAL AND ACKNOWLEDGEMENT OF RECEIPT OF CLASSIFIED MATERIALS Alaska Oil & Gas ConServation Com mission Attn: Mr. W.M. Van Alen 3001 Porcupine Dr. Anchorage, AK 99501-3192 WELL NAME: We are sending the material tabulated below. Please acknowledge receipt and return one copy to: Mr. j. L. Weaver Chevron U.S.A. Inc. 3001 C Street Anchorage, AK 99503 [, II 1 RECIPIENT PLEASE ACKNOWLEDGE BY: ~i.T_~.~_ _~/__~~t ueve iopmenc~eu lU915 COMPANY: ~'¢ ~: ~ BY: ~!~ i!~[i Senders~ Instructions:- These transmittal sheets are made on NCR (No CaPbon Required) paper with three sheets per set. Retain one copy fo~ originator's file. Include one copy with transmitted material. Send original unde~ sepa- rate cover to addressee. (I~ sending by air ~reight, put air bill numbe~ on backside of envelope.) Please use ball-point pen when filling out this fo~. EXP-180-8 (CD-3-82) Printed in U.S.A. WELL ~URVEY Pro-~12 o M.I,I, & ii,, ,, ATIOI OiiTdJC.8 lite IIIi moIYN 8011fdki ,. , · · . i IL i · . ... ' ,,I ..... __ ' . i . ... · i il Il [ i i i i · , , ,, ~ ..... C.C. DIV. '1 .... STATE OF ALASKA ALAb..,~ OIL AND GAS CONSERVATION COM~,,iSSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well E3 Alter casing E] Time extension [] Change approved program ~ Plugging [] Stimulate [] Pull tubing [] Amend order LTJ Perforate [.] Other [] 2. Name of Operator 5. Datum elevation(DF or KB) Chevron U.S.A. Inc. G.L. = 82' K.B. = 96 feet 3. Address 6. UnitorProperty name P.O. Box 107839, Anchorage, AK 99510 Pretty Creek Unit SM 7. Well number ?CU #2 4. Location of well at surface 1590' S & 2140' W of NE Corner Section 33, T14N, R9W, 8. Permit number 9. APInumber 50-- 283-20022 10. Pool Wildcat At top of productive interval same At effective depth same At total depth same 12,025' 12,025' feet feet 11. Present well condition summary Total depth' measured true vertical Effective depth: measured 4647 ' feet true vertical 4647 ' feet Casing Length Size Structural Conductor Surface 325 ' 20" Intermediate 2,018' 13-3/8" Production 8,536 ' 9-.5/8" Liner Perforation depth: measured 3,980' - 3,915' true vertical 3,980' - 3,915' Tubing (size, grade and measured depth) N/A Plugs (measured) 4647', 7000', 8420' Junk (measured) 4100' Cemented Circ Circ Measured depth True Vertical depth 339' 2,032' 8,550' 339' 2,032' 8,550' 3,780' 3,780' 3,700' RECEIY"ED 3,700' JUN 2 4 1986 Alaska 0il & (~--~:; Cons. ~-,~ Packers and SSSV (type and measured depth) N/A Description summary of proposal [] Detailed operations program ~ BOP sketch 12.Attachments In Progress 13. Estimated date for commencing operation Date ¢~..~ '- ~2 ~ 14. If proposal was verbally approved Name of approver Date approved 15. I hereby~ertj~y th~}t the foregoing is true and correct to the best of my knowledge Signed~-.,~ ~,,,~~,,.,~.,/~--'-'-'~ Title Area Operations Superintendent / Commission Use Only Conditi'oCis of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI Commissioner by order of the commission Date ~ '~~''s'~9 Approved by Form 10-403 Rev 12-1-85 Submit in triplicate CHEVRON WESTERN ALASKA WELl=WORK ORIGINAL SUMMARY 1'3 OBJECTIVE' 7'~.5'~'- U.S.A. INC. RE GION PRCX~DURE SUMMARY /5-GO '.r 3- LOC.' .~c. ~$. 7-'/~_ TYPE WELL' ~-~ S TYPE JOB' SUPPLEMENTAL SUMMARY NO. ~ wELL DATA' K.B.I. ZZ ',~,.¢(/,~a,, CASING' LINER' TUBING · PERFORATIONS' NOTES' ~. 4. PROGRAM _ DETAILS ATTACHED [:] Distribution: Original to Well. File Orig. Superintendent £ngr. ($) Field Office (I) Preparer (I) Engr. Technician ( I ) 1986 ed by Date WELL' CHEVRON U.S,A. INC. WESTERN REGION ALASKA AREA WELLW0t:~ P~DURE ~UMMARY EROC-RAM (CONTINUED)' DETAILS ATTACHED [:::] Distribution: Original to Well-Kilt Orig. Superintendent £ngr. ($} Field Office PrepOrer (I) Engr. Te¢l~ni¢ion (I) Date CHEVRON U.S.A. INC. WESTERN REGION ALASKA A/~F_.A WELLWORK PF~DURE SUMMARY PAGE 0 F PROGRAM (CONTINUED DETAILS ATTACHED Distribution: Original to Will-File Orlg, Superintendent E:ngr. ($) Field Office Preparer Engr. Technician { I ) Date D(3te WELL' CHEVRON U.S.A. INC. WESTERN REGION ALASKA AREA WELLWORK PROCEDURE ~UMMARY PAGE , / OF PR(DC-RAM (CONTINUED ~7. '~A y 2~~ __ DETAILS ATTACHED Dlstributlofl: Original to Well-File Orig. Superintendent E:ngr. Field Office Prel)orer (I) Engr. Technician ( I ) Date Di3te WELL' 3.(,,. CHEVRON U.S,A. INC. WESTERN REGION ALASKA AREA WELLW~ P~DURE SUMMARY (CONTINUED): PAGE "~ 0 F RELbiV~u JUN 2 ~ ].986 DETAILS ATTACHED DIstribution: Original to Well. File Orig. Superintendent £ngr. Field Office (I) Preparer (I) Engr. Technician (I) Prepa. red/by n //.~./-/~F~ ~- Apl~'oved by Dote P~FFE~,EtJT!~ L Pftc l'r, £ R ,, ~6 /-':ZAP Ec H L U/z ~FPG E~ ~D -- S" , o o © 1o 'T Aias-;<a Division -:,'£ IF PIN MAX oD t.S ' DP ' 67' ;, OD : to. I?' OD: ~ RECEIVED J L1 N 2 4 1986 (}ii ~;'~ (k'.: "--,' ...' .~ , ,.'~ MFE SCHEMATIC JUNE 12, 1986 tEVRON PRETTY CREEK FLOWHEAD AND MANIFOLD WORKSTRING X X X DRILL COLLARS CIRCULATING SUB DRILL COLLARS 90' CIRCULATING SUB DRILL COLLARS 90' MFE SSDP RECORDER CARRIER SSDP RECORDER CARRIER HYDRAULIC JARS PRESSURE TRANSFER SUB POSITEST PACKER SLOTTED TAILPIPE FIRING HEAD GUNS CENTRALIZER J-200 RECORDER O.S. RECEIVED JUN 2 4 19!{6 Alaska Oil & MEMORANP-UM TO: THRU: FROM: State of Alaska DATE: June 18, FILE NO.: D.JFB. 4 TELEPHONE NO.: ALASKA OIL A~_~ GAS .CONSERVATION COb~MISSi ~C'~,~V( Chatterton Lonnie C, Smith---~ Commissioner Doug Amos, P.I. John- F. Boyle, P.E.A.~ -~/i 1986 SUBJECT: BOP Test Chevron PCU ~2 Permit No. 79-09 Exploratory 33, T14N, R9W, SM Thursday, june 12, 1986: Doug Amos and I traveled this date from ~~'~e '~o'BeiUga v'i'~ Troy Air Service to witness the BOP test on Chevron Pretty Creek Unit ~2. The test began at 11:00 p.m. and concluded at 9:30 a.m. on Friday, June 13, 1986. The following equipment failed: a) Gas detector not connected; b) Pit level indicator not connected; c) The opening/closing lights on remote unit for the pipe rams inoperative~ d) A.P.I. ring on the annular leaked; e)The door-seal on the pipe rams leaked. Ail failures were repaired. We filled out an AOGCC report which is attached. In summary, Doug Amos and I witnessed the BOP test on Chevron's Pretty Creek Unit #2, Brinkerhoff rig No. 58, and there were 5 failures. O&G fl4 . ' '5/84 , .f:-'t:.:b,: :- % :i . STATE OF ALASKA ALASKA 0IL & GAS CONSERVATION COMMISSION B.0.P.E. Inspection Report Location: Sec ~; '~ T ~"~,:R ~:';~: .... M Drilling Contractor Location, General ~) ~ Well Sign General Housekeeping e [~;~ Rig- ~i~. Reserve Pit ~' / Mud Systems ~ Visual Date Well Trip Tank Pit Gauge Representative Permit ~t " Flow Monitor Gas Detectors · . BOPE Stack- Annular Preventer Pipe Rams Blind Rams - Choke Line ~ves"~[~ KiWi Li~e Valves Check Valve Audio Test Pressure. Casing Set Representative ft. ACCUMULATOR SYSTEM Full Charge Pressure Pressure After Closure I~,, psig psig min [~'"~ sec. _ m~nc!~:, sec. psig Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: · N2 ,_..~o~,~ ~_.' o." :> ~.~" Controls: Master Remote ~9;- Blinds switch cover Kelly and Floor Safety Valves Upper Kelly<)~"x? Test Pressure Lower Kelly-,'~'~, Test Pressure Ball Type ~ ~ Test Pressure Inside BOP [3~. Test Pressure Choke Manifold '~"'b~ Test Pressure No. Va!vesl" .... /~'~' No. flanges ,-- ~/ Test Results: Failures Repair or Replacement of failed equipment to be made within Commission office notified. Remarks: Adjustable Chokes . Hvdrauicallv o~erated choke Test Time hrs. ~ ( ,.' days and Inspector/ Distribution orig. - A0&GCC cc - Operator cc - Supervisor Inspector /' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~21 OTHER [] 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 79-0009 3. Address 8. APl Number P.O. Box 107839, Anchorage, AK 99510 50-283-20022 4. Location of Well 1590'S & 2140'W of NE Corner Section 33, T14N, R9W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) G.L. : 82' K.B. -- 122' I 6 . Lease Designation and Serial No. ADL - 63048 12. 9. Unit or Lease Name Pretty Creek Unit 10. Well Number PCU #2 11. Field and Pool Wildcat Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing [] Perforations [] Altering Casing [] Stim u late [] Abandon [] Stim utation [] Abandonment [] Repair Welt [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [J~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). See Attached Program. We plan to begin operation 1-15-86. RECEIVED ,qlaska Oil e~ G;~s Cons. Corrimission Anchoraoe 14. I hereby certify that the I~oregoing is true and correct to the best of my knowledge. Signed ~/~'-j~/ Title Area Operations Superintendent The space below for Commission use Date Conditions of APproval, if any: Approved by Approved Copy Returned -8 By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate CHEVR(~ U.S.A. INC. WESTERN RE GION ALASKA ~ WEll.WORK I~DURE S~ (SUPPLEUE~T) WELL' , Pcu//2 LOC.' RELD' Pretty Creek ..... TYPE WELL' Pretty Creek Unit: Alaska Gas Well (currently shut-in) NO' WAD50147 TYPE J(~' Completion ORIGINAL SUMMARY El SUPPLEMENTAL SUMMARY I~ NO. , ] OBdECTIVE · Test existin~ BeluFa Sand perforations prior to perforating and testing St~rling Sand. - These perforations need to be tested because they have been shut-in exposed to drilling mud since 1979. WELL DATA' K.B. ~ ~-~-' T.D. CASING' 9-5/8" cmt'd ~_ 8550' LINER .... 12025 PBTO 4647 TUBING: None in Hole PKR. None in Hole PERFORATIONS: ,. 3980'-2915'~ 3780'-3700'~ 3570'-3525'~ 3416'-3396'(squeezed) NOTES: The following chanties should be made on the PRO 316-1 for Pretty Creek Unit//2 ' pROGRAM 16B) Eliminate 16D) Prior to DST's 1-3, existing perforated intervals 3980'-3915' and 3780'-3700' are to be perforated and tested separately. (4 SPF, 5" Tubin~ conveyed gun.s) R E'c/EI\/ED DETAILS ATTACHED E! Alichu~'a!]~ Distribution: Original to Well File Orig. SuplrintenOent Engr. Field Office Preparer (~1 F. ngr, Technict¢in (I D~te , lO'lO - ~f' L~-~ ~Y' _ PRO 316-1 PROPOSAL FOR WELL OPERATIONS PRETTY CREEK UNIT {2 WELL: Pretty Creek Unit #2 FIELD: Wildcat LOCATION: 1590'S. & 2140'W. of NE Corner Section 33, T14N, R9W, S.M. ELEVATION: G.L. = 82' Original K.B. = 122' PRESENT STATUS: TD = 12,025' PBTD = 4647' CASING: PERFORATIONS: TUBING: 20" CMNTD ~ 339' 13-3/8" CMNTD ~ 2032' 9-5/8" CMNTD ~ 8550' Open Hole 8550'- TD 3980'-3915' 4JHPF 3780'-3700' 4JHPF 3570'-3525' 4JHPF 3416'-3396' (Squeezed) None in Hole (see attached schematic) PROGRAfv! -. J. Portor Jr, , . _ i ~.. PLUGS: Howco EZSV ~ 3860' Howco EZSV ~ 3645' Howco EZSV ~ 3487' with 105 sks below and 39 sks above RTNR (estimated) JUNK: Wireline set bridge plug drilled ~ 3375' and pushed to 4100' BLOWOUT CONSIDERATIONS: 1. GAS: This well is capable of producing 10+/- MMCFD. Care must be exercised at all times not to swab the well. The hole must be kept full at all times. 2. LOST CIRCULATION: None anticipated, however, material should be readily available. 3. PRECAUTIONS: During the re-entry and testing of this well in 1979, a blowout occurred after perforating the zone from 3980'-3915'. The fluid ~ECE/VEDgradient in the hole at the time was .472 PSI/Ft and the formation ~J~'J 0~ ~ gradient was .492 PSI/Ft. Any kicks should be handled by normal ~lask~ Oil & ~as CO~s me 5~ procedures. Rig crews should be made aware of these methods, and care must be exercised at all times. MAXIMUM ANTICIPATED FORMATION PRESSURE: 1930 PSI Programmed workover fluid weight of 10.9 to 11.9 Lb/Gal will provide 300 to 500 PSI overbalance. MAXIMUM ANTICIPATED SURFACE PRESSURE: 1735 PSI BLOWOUT PREVENTION EQUIPMENT: Minimum of Class III 3000 PSI. PROGRAM 1. Move in and rig up the workover rig. 2. Open the valves on the tubing spool and check for flow. Kill the well as required with 10.9+ PPG workover fluid. 0 Nipple down the 13-5/8" -3000 PSI x 11" -5000 PSI tubing spool. Nipple up the 13-5/8" -3000 PSI x 11" -3000 PSI tubing spool. 4. Nipple up the 11"-3000 PSI Class III BOP stack as per the BOP schematic. 5e Test the rams, manifold, and surface valves to 3000 PSI. Test the annular to 3000 PSI. The AOGCC and BLM may witness the test and must have 24 hours notice. e Pick up and trip in the hole to the top of the plug (estimated at 3397') with an 8{" bit, 6 {" drill collars as required, and 4 {" drill pipe. ge Circulate and condition the mud weight to 10.9 PPG and pretreat for cement contamination. 8. Drill the plug, retainer, and plug from 3397'- 3570'. e Stage in the hole to the top of the bridge plug at 3645'. 10.9+ PPG. Condition the mud to 10. 11. 12. 13. 14. 15. 16. Test the casing to 2000PSI. will follow. If there is a leak, a squeeze procedure Drill the bridge plug at 3645'. Stage in the hole to the top of the bridge plug at 3860'. Condition the mud to 11.5+ PPG. Drill the bridge plug at 3860'. Stage in the hole to the top of the bridge plug at 4100'+/-. Drill up the junk at 4100' and push all junk to PBTD at 4647'. Circulate the well clean. Pull out of the hole and lay down the drill string. 16(A). Run the following logs as directed by the Area Production Engineer: A. CET B. Neutron o 16(B). Set a drillable bridge plug or wireline at 3650' +/-. 16(C). From analysis of CET log cement squeeze jobs above and below the following test intervals may be required for isolation prior to testing. 16(D). Test the following intervals per the supplementary programs to follow: Ae Be Ce DST #1: 3613' - 3604' 3595' - 3586' 5" tubing conveyed guns DST#2: 3450' - 3440' 5" tubing conveyed guns DST #3: 3392' - 3385' 3334' - 3319' 5" tubing conveyed guns Note: DST #3 is contingent on results of DST #1 and #2. Depending on results of individual tests a retrievable bridge plug will be set above' gas productive intervals and water productive intervals squeezed off. 16(E). Pick up and trip in the hole with an 8-1/2" bit and BHA. 16(G). Drill the cement and bridge plug from 3000' - 3650'. 16(H). Trip in the hole, and push all junk to 4647'. APPR(~VED- PROGRA~vl -- 16(I). Circulate the well clean. Pull out of the hole, and lay down the drill string. 17. Additional completion program will be issued giving details on final perforations and tubing string(s). The mechanical detaii attached will apply if the intervals tested are unproductive. V. W. Angell R. D. Lambert 9/14/85 GRAM/ ETO¢ (~ 3397' L m '20" PROGRAM -- 5396' , PERFS SOZD (~TSTD TO 2000p$i 3416 3525 -- 3570' PERFS SOZD BUT NOT TESTED I m RTNR a 3645 -- 3700' 3780' FORMAT~ON PRESSURE = 1690 psi .460 ps, f! RTN R ~ 3860 ' 3915' 3980' FORMATION PRESSURE = 1900 psi .492 ps~,ff. I BP PUSHED DOWN HOLE TO 4100 CMT (~ 4647 BP (~ 4750' ' PBTD (~4647 -- 4794,' -- 4812 P z o ooL R TNR~ 8420' --~ 7260; ... 7280 -- TD = 12,025' CHEVRON USA INC. PCU 2 PRESENT CONDITIONS 25/8" HEAT STRING AS REQUIRED - ~ $700' -- --$780' ,3915' 3980' A = C C SAFETY JOINT 8 = SLIDING SL EE VE --DUAL PACKER SWIVEL SUB WI KEYS POSITION NIPPLE PUP JTS. AS REQUIRED PORTED EQUALIZING SUB APPROVED PROGRAM PUP JTS. AS REQUIRED ~ FIRING HEAD ~$,3/$" TUBING CONVEYED GUN PACKER ,,, POSITION NIPPLE ~ 2 7/8" TUBING AS REQUIRED PRESSURE .ACTUA TED GUN RELEASE PORTED EQUALIZING SUB PUP JTS. AS REQUIRED FIRING HEAD 5" TUBING CONVEYED GUN 5" TUBING CONVEYED GUN 4 JHPF 4 JHPF ~ PBTD 4647' CHEVRON U.,SA. INC. PCU PROPOSED TUBING '~TAIL ANNULAR PREVENTER I 3 5/B"- 5000 psi · ---13 5/8 "-5000 psi 13 5/8 "- 5000 psi DOUBLE GATE 2". 5000 psi KILL LINE 7 2%5000 psi PIPE RAMS BLIND RAMS · -'~3 5/8"-5000 psi TUBING HEAD w" Ii - OOO psi 3"- 5OOO psi ! TO MANIFOLD BULL PLUG t I I SOW 13 5/B"- 3 000 psi 3000 psi BLIND FLANGE · · 95/8`' ~8" CEMENT · -',_.L' L! o . o . ~1 ~l t ' I . I I 1"20" 30" ti! ~l' CLASS ~ BOP APPROV~i7) ~ PROGRAM Chevron CHEVRON U.S.A. PRETTY CREEK UNIT "2 SUBSTITUTE $O00'psi TUBING SPOOL IF AVAIL ABLE NPB STATE OF ALASKA :~' ALASKA t..x. AND GAS CONSERVATION CO..,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER I~ Suspended 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 79-9 3. Address 8. APt. Number P.O. Box 107839, Anchorage, Alaska 99510 50-283-20022 4. Location of Well 1,590' S & 2,140' W of the N.E. R9W, S.M. CDr., Section 33, T14N, 9. Unit or Lease Name Pretty Creek Unit 10. Well Number Pretty Creek Unit ~2 11. Field and Pool 5. Elevation in feet (.indicate KB, DF, etc.) I 6. Lease Designation and Serial No. ,/~/~,,)/ Wildcat G.L. 81.9' . i ADL-63048 ~/~/ 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other E~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) [] [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Due to the fact that surface facilities have not been installed to enable the production of this well, Chevron U.S.A. Inc. requests a one-year extension of regulation 20 AAC 25.170, location cleanup. The location has been left in a clean and orderly condition. Alaska Oil & Gas Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed 1~- ~, ~ Title Area Engineer The space below for Commission use Conditions of Approval, if any: Approved Copy Date ,proved by COMMISSIONER Returned By Order of the Commission Date q 10-403 '-1-80 .- Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate MEMORANDUM State of Alaska ALASKA~//OIL¢'~AND GAS CONSERVATION CO}~iISSION TO: Co V.~C~~erton DATE: October 17, C'~ i~~~'''/ FILE NO: THRU: FROM: 1984 ~.: .~;::../ D. 1 I. 34 Lonnie C. Smith ii' ~ Commissioner ~ ~/ ~ TEL/q . TELEPHONE NO: Ben LeNorman ' Petroleum Inspector '-?;' Suspended Well, J Pretty Creek Unit #2, Sec. 33, T14N,R9W,SM. Tuesday, October 16, 1984: I departed my home at 12:30 pm for a ~-~-~--~ah'd i:'00"pm departure via Chevron chartered Troy Air Piper Seneca for Beluga Airstrip arriving at 1:30 pm. I was accompanied on this trip by Chevron. representatives Eon Thomas and Nancy Blackman. Inspection of Well Pretty Creek Unit #2 and two additional wells was completed by 4:00 pm. Suspended well and location report is attached. I departed Beluga Airstrip at 4:30 pm, arriving irt Anchorage at 5:00 pm and at my home at 5:15 pm. In summary, I inspected Chevron's muspended Well Pretty Creek Unit #2. 02-00IA(Rev. 10/79) Suspended Well and Location Report 20 LAC 25, ARTICLE 2 FILE INFORMATION: Operator ..... (~,Z/~'- V~~J . ..U~ ~ ~. Date Suspended Address ~~ ~'~. ~~-4'-_-~-~~, Surface Lo-ca£1on of w~ll - - - Permit No.. .... ?.~_--~ _~/_~_.~ Ft. F ~ L, ,~./~ Ft. F~f~~'~' API No. 50 - ~_~.~ r ~~~-. Sec.~_~, T./~( ~__, a ~ ~4) , ~-~M. Unit or Lease Namer--S__ ~6~ Well No.. ...... Field & Pool Condition of Pad Condition of Pits Well head - Ail outlets plugged ~ No Wel 1 sign - Attached to well head Yes Attached to well guard Yes a t t a Ohs d t o ~---~F~ _/~_/'.~_.~ Information correct No No Cellar - Opened Yes No Rat Hole 'Fil led Yes No Covered ~ No WaterWell - Plugged off Capped Open Explanation Ye s No Ye s No Covered Yes No Photographs taken to verify above conditions~ No Explanaton Work to be done to be acceptable This well and location is ~ (unacceptable) to be suspended for the per~ of Inspected by: classified as 19~_. Revised 8/24/82 Sept~ber 28, 1983 Ch evron U. S. A. Inc. R. L. Thomas, Area Lngineer P. C. Box 107~39 Anchorage, Alaska 99510 Cleanup Inspection of Sus~nded Wells: Pretty ~eek ~ntt~No.- 2~ Sec. 33, ~-14~, Rg~~, S.~.~i. Ivan River 14-31, Sec. 1, T13b, R9W, S.~i. Stump Lake 41-33, Sec. 33, T14N, Our representative ins~ected these well sites on Septer:~ber 7, 1983 and it was found t~hat cieanu~ was satisfactor~'~ for su~n~eu locations. Returned are a~proved 10-403's, Sundr~ ~otlces and ~e~orts on Wells, for a one ~ear extension. A suk~sequent inspection will ke necess&r~~ by August, 19S4. Sincerely, LCS/J~ :lc: 103L TRANSbIITTAI,~-~ND ACKNO~rLEDGEbIENT OF RECEIPT ~. Fb\TERIAL - (ALASKA) DATE FD- Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueline THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. -- 33z--9" ? ', /( - -- ' ii i ii i i J i BOX 7-839 I~£MARKS O.N OTHEIR SIDE, THIS Sl4E~T AI~IORAGE, ALASKA 99510 STATE OF ALASKA ALASi OIL AND GAS CONSERVATION )MMISSlON SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] 2. Name of Operator Chevron U.S.A. ;[nc. 3. Address P. 0. Box 7-839, Anchorage, Alaska 4. Location of Well 1,590' S & 2,140' W of the N.E. R9W, S.M. 5. Elevation in feet (indiCate KB, DF, etc.) G.L. 81.9' ' 12. COMPLETED WELL r-I 99510 CDr., Section 33, T14N, OTHER Suspended 7. Permit No. 79-9 8. APl Number s0-283-20022 9. Unit or Lease Name Pretty Creek Unit 10. Well Number Pretty Creek Unit #2 11. Field and Pool I 6. Lease Designation and Serial No. ' Wildcat ADL 63048 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEOUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] . Perforations Stimulate [] Abandon [-] Stimulation Repair Well [] Change Plans [] - Repairs Made Pull Tubing [] Other ~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) r-] Altering Casing r"] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Due to the fact that surface facilities have not been installed to enable the production of this well, Chevron U.S.A, Inc. requests a one year extension of regulation 20 AAC 25.170, location .cleanup. The location has been left in a clean and orderly condition. RECEIVED SEP 2 3 1982 Alaska 011 & Gms Cons, Commission 14, I hffre,by certify that the foregoing is true and correct to the best of my knowledge. Signed ~¥~/~ Title Area Engineer Date 9/2l/R2 .. Thesp~ceb~lowforCommiss,o/~' ' ~use Condit~oj3s/of Approval, if an~)~r represeatatiVe .i~spected this suspended site o~ Jul~ '8, 1982 a~d clean-up is satisfactory for suspension. by August .1983 {)~,~:~, Approved by It will be necessary to reinspect this site By Order of COMMISSIONER the Commission Date Form 10-403 ' Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate M EM O RAN D U M State of Alaska A!~kSK~ OIL ~-]D GAS COI~TSERVATIOI-~ TO: ~'/. ~fi/Ch~ at t er ton DATE: September Lonnie C. Smith / Commissioner TELEPHONE NO: FROM: Bobby Fost Pe~zoleum Inspec~o~ Thru: 9, 1983 SUBJECT: Inspect ,Suspended Chevron. Locations Listed o ,~,e lovz for Clean Up. .W.e.dnesday, .Se...ptember 7, .!983: I traveled this date ';zith Bill Siefke and Bob Kloppen?OUrg, Chevron representatives, to tb.e locations listed below and inspected for wellhead status and clean up. Attached to this report are pictures showing locations and weliheads. Pretty Cree~,~ '%.. Ivan River 14-31 Stump Lake 41-33 It is my recommendation to the Commission that these locations ° ¢~ o accepted as suspende:~ from September 1983 to September 1984 Attachments Suspended Well and Location Report 20 AAC 25, ARTICLE 2 FILE Operator ~ . /~_'~.~, ._ ~ Date Suspended ~-~'~ Address ~.D.~' ~-~e. ~_~o~/;,~5~ /d~ Surface f6~a~tion of Well- ' ~ Permit No. %~-~ Sec.~, T /~ ~ , R~ ~,' ~m. ~Uni~or Lease Name~~'~8~ ~ ~ .... Well No.[~ ~ ; ..... Fi el d & Pool ~ ~/~.~-j ' Condition of Pad Condition of Pits ~7/~._._~ Well head - Ail outlets plugged No Well sign - Attached to well head Yes No Attached to well guard Yes No Attached to Information correct ~ No Cellar -' · Opened "Yes ' No 'Fi 1 led -%= s No Cove r e d '~ No WaterWell - Plugged off Capped Open Rat Hole Open~/~6~3 ~.y~s No Fi 1 led Ye s No Covered Yes No Sxp la ma ti on Photographs taken to verify above conditions ~ No Explanaton Work to be done to be acceptable .- This 'well and location is (acceptable) (~)~to.be classified as suspended for the~pe.r-~od of ~~~~'~9~__~thru _~~ ~/~_. 19~. Ins~cted by: ~ - ........ Revised 8/24/82 · ~' , ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] Suspended 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 79-9 3. Address 8. APl Number P. O. Box 107839, Anchorage, Alaska 99510 50-283-20022 4. Location of Well 9. Unit or Lease Name 1,590' S & 2,140' W of the N.E. Cor., Section 33, T14N, R9W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) __ G.L. 81.9' 12. 6. Lease Designation and Serial No. ADL-63048 Pretty Creek Unit 10. WellNumber Pretty Creek Unit ~2 11. Field and Pool Wildcat Check Appropriate Box Tolndicate NatureofNotice, Report, orOtherData NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] '- Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Due to the fact that surface facilities have not been installed to enable the production of this well, Chevron U.S.A. Inc. requests a one year extension of regulation 20 AAC 25.170, location cleanup. The location has been left in a clean and orderly condition. Apprcved Copy Returned 14. I hereby certify,that the foregoingjs true and correct to the best of my knowledge. Signed ~. ~. ~ Title Area Engineer The space below for Commission use Date Conditions of Approval, if any.This well site was inspected by our representative on September 7, 1983 and cleanup was satisfactory. A subsequent inspection will be necessary by August, 1984. Approved by, BY [0N!"~£ i. ~ilI~,~ COMMISSIONER the Commission Date' _ ................... Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTIC =S AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] Suspended 2. Name of Operator Chevron U.S.A. Inc. 3. Address P. O. Box 107839, Anchorage, Alaska 99510 4. Location of Well 1,590' S & 2,140' W of the N.E. Cor., Section 33, T14N, R9W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) G.L. 81.9' I 6. Lease Designation and Serial No. ADL-63048 7. Permit No. 79-9 8. APl Number 50-- 283-20022 9. Unit or Lease Name Pretty Creek Unit 10. Well Number Pretty Creek Unit ~2 11. Field and Pool Wildcat 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TQ: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing []., Perforations [] Altering Casing E~] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] [] Other ~ Pulling Tubing [] Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Due to the fact' that surface facilities have not been installed to enable the production of this well, Chevron U.S.A. Inc. requests a one year extension of regulation 20 AAC 25.170, location cleanup. The location has been left in a clean and orderly condition. . 14. I hereby certify that the foregoing's true and correct to the best of my knowledge. Signed /i~. ~,, ~ Title Area Engineer The space below for Commission use Date Conditions of Approval, if any: Approved b'~ COMMISSION ER By Order of the Commission Date l=orm 1 F~ev. 7-1 ~ Submit "Intentions" in Triplicate February 4, 1983 M~. T. L. Perryman Area Operations Superintendent Chevron U.S.A., InC. P. O. Box 7-839 Anchorage, Alaska 99410 Dear ~-fr. Perryman:' The Alaska Oil and Gas Conservation Commission has recently checked the records of wells completed since January 1, 1979. This review has revealed that the digitized data for certain logs run in a well is not on file with the Commission. The Oil and Gas Regulations require the operator to file, within' 30 days after completion, suspension, or abandonment of a drillin~ well, the digitized data, if available,~ for copying, for all logs run in' the well except velocity surveys, experimental logs and dip- meter surveys. We would request that you check your records to see if the data has been submitted to the Commission and, if not, that you comply with the regulation ~th regard to the following wells: Swanson River Unit No. 31-33 Soldotna Creek-Unit No. 44-8A Pretty Creek Unit No. 2. .0 Soldotna Creek Unit No. 12-3A Soldotna Creek Unit No. 41-9A Thank you for your cooperation in this matter. Yours very tru!y, Harry W. Kugler Commissioner BY ORDER OF THE COMMISSION be COMMISSION ..-... ~,.~'.:~:~ . ... '.?:9 ~;~/ /t/ ~/ ,' · :. ." . .: :."';;/~"':. :? UO~,~S ZO~ ~ ----~:' '--Sz--'e-. : .... TELEPHONE NO: :," :... "::'-:. '.'"-' ..... ": . ~-- ..-- -~ .. ' ,'-:,.; :., , · ~.~.~. ' '~:¢'}" FROM;.],BObb~ F te~, - ' .... _ .. ~."',, ""'':":'SUBJECT:.,.. ~. InspeCt Chevron Susmnded~2 ~trole~ Ins~ctor~ :::';'..'-" "-/: :" ;";"/- ' _' .-"' :' ~tion .... · ,..',~.-;:,..:'~.' ': :~.,~:':.: ~.:..;. , ,:.,:',<... ,.:~.?',:,¢; :. ~,::~-.';i.:9~¥'~'- .-:,~,':', .'. .:':,"-,,.. ": :~ .".. - -. -',.~¢~v :',~'.*:~'.~,,,: ..-,::., .¥ ,,.-,.? ~%, .:~,~. · ..¢. .,~,. ..' .' ~. .- .~.-,, ~.:~ ~,.,~ ,..~l¢% ..... ..,,( ,-~ · . ~ .... ~ ¢ · . . ~.' :.ThUrsday,":'~July 8,'1982 :}--.:~-I;;~.t~veled t~s ~to"to~.Beluga ." '. ~th Bili-..Si~S~,:~¢~evron'..'represen~tiye, and insetted :-' ~. -~ ............... -,., ':-. , ' '-~,'.-,;:'-,?~' '~1,.'.~f-~j,'~-',¢:t ,- .... -:.:. ,' ,.~,' ~ '., ' ~-* ,-'> ' i::' "...'.: ..... ' . '~ ". ,,.~'t'~ .,,. '*. ' :.: ': -: ...... *'~' .', ~%. · t'C , ; ....... ,' '-",',~ '~(.'"'"',~' :" ',%,;. '5':~ .... · ." .;,' ', .; ,. , ,~*i, ..:., -,: ,., ', 'ret~ 'Creek'ret 'Creek' %2~As'~the,' atoned, pictures sh~, this. ,,..:.,. ? , . . ~ ~ : · ,.. · ~ - . ;, ~ ~~i~,~-~-and.:..:-f~e'. of:~,any~trash.,' The well sign., ' ~sted ;.'~ the<col lar is :~co~red"and ':the ~11. head.' secure." ~There. is':no:~.reser~' pit'at:'t~s..~lo~tion. "' ~'.~ .~' .' -'.". ':';,.' ~.....':~ ..... ~:,.L~ ~'~,--.:~' t~: -,..% . - · ,. ' " ' ~lS m~ ~ti'on:.:~'to~' the'.~:C~ssion that this lo~tion<'. .... for one from the accepted as a'~ sus~nded.~'"location ~ar :da'~e.:'~of.-this.re~rt,.~'at which time., another inspection will".'..'~.~ ~~'rfor~d. '~".?:..."~?::..~.~ :":.::/::~/-,~', .~: :...'~ ~":." :,'.. '- ~' .~ ?. ~ .'.', ~::/,'~.: .~'.:,'"~, ._-.. --. .:.'.,': ..7 .. :.. ': ?' ... Lake' %1 - As'tthe attached; pictures 'sh~ this"location ,s level and s~ll-..areas of re'ration gro~ng, on ~e pad'. -- : , . .~. _,. ~. ~, .... : .... '.'; ;;t"', ...... .,.., ~:, ~ .,,:~, ..... ,,.-¢ ." ; :..;~,:,,..: .....:....:.. '......~,~ .?~ %.:.:...:,?,? ./.: , ':,: - . :'.~ ...... : ,., . : -.- ... ..... The.:'cellar is open,'there.'is'no-,~ll'sign,':there, is a 10' pi~ stic~ng up near the celhr ~ich..tas,used as a rat .. hole for_the kel/y'during the:..drilling' of tho well and '.' .-",.~ .here is.:.a dr~:.that nee~ 'to~'.~. removed from the location. .~..,: '"~ ,, .... · ,.... ,7, . : · ; , -;- . . - · .- ,, ~ . ';(~.~..The'-~ll~. head is .:-secure ?: the.~ rese~e pi~'-~'contains water and 'so~ trash -- e~ty. ~rrels~and c~ble -~.and the:~rn pit' . _ ,. . .~.~:-:There is~ a"'-flowing~ifreshwater: ~ll"?on this location '~nd at ~utheast corner of the pad.a 4" phstic pi~ is stic~n9 : . out: of. the pad and what ap~ared to be a buried ~. ntly this ~s used-as a ~ep~'c ta~ 'durin~ ~e drillin~ ::" "'" '" 'h~'t=ec~mn~tion*'to the Com~ssion that' this location not.'-:~ accepted until the :--foll0wing work has.~en completed: ~-.'~'.~ :~:t...".~~ ~ ~:~:-,~,.~.:~:,.'. ~:~ '.. :. <' .,.~" ..~,'~:" .'-~ '~"~': .... .-'. · . '.. ' .' - C. V. Chatt-~ton . Rat hole covered Septic tank vent capped July 22, 1982 · 5. $~ater well flow diverted off location i~?::.i.ii/!2.,',',~:. :."'::1~ .';i~.".'"~i :'~6. Well sign put up ~ :i.':," ~i i:'!~i:' ::. Logs'removed off location :~.~'.,"t ~:; ~,~"~ ' , ' '. : .~¥' · L~, ,% . .. . ,,%., · · ~:,,, . (.,., ~ ...- ;; .,~?t ~, . , , ".~"~ ."'" ~'." ' ......... - .... " ~ ~ho~ .~his ., '::' '~"~.",:'-' .~'~'~' ':/, :~::~?'wells and an a~ndoned well on this pad. ':~ ' ..... Ther~ is a ~ter ~11 that is flowing a ve~ small amount ' of fresh%rater on the location. There is an o~n cellar and - '~%,~'~ (,-~:.:~ some,.~mud pallets on location. ~ ':?~</,~?~%~.'./"~'~"'~,.:, ~'-~-:~'The"?resurve pit contains ~ter and there is a s~ll a~unt ~'~,"~ ...... ' :~-.~ .... ..- .........~,.~,,.of cable at. the south end of the pit. ;,., . :"'~ :: ,.~'. ..... """~';I rec~nd to the Co~~ion that this location not ~ .-~.... ::~.~:',:~.~,.,'~'~':?~:..::,~?~:~::,.?~: :~'1.. Blind: f~nges or plugs '~ placed on well head . ~-'.?:~. ~,,-...¥~ .... ,~..~, ,~,:~ .... ~':~,:?: 4. ~:-l.ud pallets and cabl. . · ', -; ': :. ~{;?: ~ '.":".':.', -,:~;'~:~:::~'t', ,'::.~':;'~5.~ ::;' water- ~11-,flow(~ diverted of~ loca~io~. ~?'.:'; 't" ::~ ,~': ':'~::':~:~::'"?:~'~76-' ::' P & A,~rker ~ e~'ended so all infor~t~on ~a~ .:-:. "~'??~.".:'.:,,~':".?" i.'"~(.::'I"nt?'s~a~ I ins~cted the a~ve .~sted locations for ,.-~' ". · DEPARTMENT OI~ NAT[~RAL RESO[~'RCES MINERALS AND ENERGY MANAGEMENT 3une 3, 1982 C.V. Chatterton Oil and Gas Conservation Commission 3001 PorcuPine Orive Anchorage, Alaska 99501 555 CORDOVA STREET POUCH 7-005 ~.~T~ F.,jI'~1~ ' - ANCHORAGE, ALASKA 995 (907) 276-2653 :.. : !. Refernce: Release of Confidential Well Records Dear Chat: The following wells were granted extended confidentiality by the Commissioner of Natural Resources pending the offering of adjacent unleased acreage for competitive leasing. Operator Well Union Oil Co. Chevron U.S.A. Chevron U.S.A. Chevron U.S.A. Clam Gulch Unit No. 1 Well Pretty Creek Unit No 2 Well Stump Lake Unit No. 41-23 Well Soldotna Creek Unit No. 33-33 Well The data from these wells no longer qualifies for extended confidentiality. Therefore, these data should be released to the public at your earliest convenience. Please call if you have any questions. Sincerely, D~tor, DMEM cc: Bill Van Dyke MEMORANDUM State of ALA,~(A OIL AND GAS CO~?SERVATION TO: rton TM~U: Lonnie C. Smi th ? ~' Commissioner FROM: Bobby Foster~-. ~, Fetrole um Inspector Alaska DATE: July 22, 1982 FILE NO: 108A/I TELEPHONE NO: SUBJECT: Ins~?,ect Chevron Susl~ended Location Listed Below for Clean-up in Cor,:~pliance w±th A.O.G.C.C. 5.e§ulation 20 AAC 25.170 T~ur~s~ay~_ ~ply_ 8~_ 19~ - I traveled this date to Deiuga River with Bill Sieske, Chevron representative and ins~.~c'ted the _fg!.lowing locations: tty Creek %2'-'''~ As the attached pictures show, this IocatiC, n is clean and free of any trash. The Yzell sign is F~ste~, the cellar is covered and the well head secure. There is no reserve pit at this location. It is my recommendation to the Comm/ssion that this location he accepted, as a suspended !ocaticn for one year fron-~ the date of this report, at which time another inspection will be ~ r formed. S_tpmt~ Lake #1 - As the attached pictures show this location is level and small areas of vegetation growin9 on thc a rea. The cellar is open, there is no well sign, there is a 10" pipe sticking up near the cellar %~hich %cas used as a ra-t hole for the kelly d. urinq the drillin9 of the well and there is a drum that needs to be ren]oved from the location. The ~.~ll head is secure, the reserve pit contains water and some trash -- empty barrels and cable -- and the burn is empty and. · clean. ?here is a flo~zinc~ freshwater well on this location and at the southeast corner of the pad a 4" plastic pipe is stickinG up out of the pad and %~hat appeared_ to be a buried tank. Apparently this %~s used as a septic tank 6uz'inc~ tine ~rillin5 of the well. It is my recommendation to the Commission that this location not ke acceptecl until the followin9 work has been cor,:~pleted: . Barrels removed fron-~ location and reve~ve pit Ce! lar covered. C. V. Chatte July 22, 1982 3. Rat hole covered 4. Septic tank vent capped 5, Water wall flow diverted off location 6. -Well sign put up 7. Logs removed off location I~n Ri~r 14-31 - As the attached pictures show this ~i~¢a~i6h~-is~i'~P~l and smooth. There are two suspended wells and an a~ndoned well on this pad. There is a water well that is flowing a very small amount of freshwater on the location. There is an open cellar and some mud pallets on location. The reserve pit contains water and there is a small amount of cable at the south end of the pit. I recom~nd to the Commission that this location not be accep~d until the following work has been completed. 3. 4. 5. 6. Blind flanges or plugs be placed on well head ope ni ngs. Ceilar covered Well signs put on welIs Mud pallets and cable removed from location Water ~lI flow be diverted off location P & A mar~r ~ extended so all information bead wel~d on same is above ground level. In sum~ I inspected the above listed locations for c~pliance with A,O.G.C,C. regulation 20 AAC 25.170. Chevron Chevron U.S.A. Inc. P.O. Box 7-839, Anchorage, AK 99510 · Phone (907) 279-9666 T. L. Perryman Area Operations Superintendent Production Department June 21, 1982 f. Pretty Creek No. 2 Location Clean Up Mr. Lonnie C. Smith Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Gentlemen: Chevron U.S.A. hereby notifies you that the clean up work on Pretty Creek No. 2, as requested in your letter dated December 4, 1981, has been completed. Please notify us as to when you wish to make an inspection of this location. We will make arrangements for you to visit the site. Sincerely, T. L. Perryman JBL:fw At.~.ska Oil & Gas (.;orls. Co, nmission i~nc.hora!:l~; April 26, 1982 Mr. J. J. Anders Chevron U.S.A., Inc. P.O. Box 7643 San Francisco, CA 94120 Reference: ?~-~etty creek un--Well ~' stump" a e n~o. -23 Well Soldotna Creek Unit No. 33-33 Well Dear Mr. Anders: The Division of Minerals and Energy Management recently completed a review of all wells which have been granted extended confidentiality in accordance with the provisions of AS 31.05.035(c). Our records indicate that the Pretty Creek and Stump Lake wells were granted extended confidentiality pending the offering of adjacent unleased acreage for competitive leasing in Sales No. 33 and No. 32. Those sales were conducted on May 13, 1981 and August 25, 1981, respectively; as a result, we believe the wells no longer qualify for extended confidentiality. The Soldotna Creek well was granted extended confidentiality pending the Offering of unleased acreage in the Federal OCS Sale 60 in Cook Inlet. A reasonable amount of time has lapsed since that sale was held; as a result, we believe this well no longer qualifies for extended confidentiality. Accordingly, it is my intention to request that the Alaska Oil and Gas Conservation Commission make public data from these wells on May 31, 1982. Should you have any questions regarding this decision, or if you feel that there are extenuating circumstances which should be considered prior to the release of these data, please contact me prior to May 31. Sincerely, Director cc' John Katz, Commissioner, DNR C. V. Chatterton, Chairman, AOGCC RECEIVED APR Al.~ska Oil & Gas Cons. Commissior~ Anchorage Pece~,~r 4, 1981 Che~on U.S.A. !nc. 510 !~ Street, Suite 307 Anchorage, Alaska 99501 Re: ~ Creek Uni_~_._~Q, ..... 2, Sec. 33, T14~, E9¥:, S.~i. Cent !e~n: This suspended location ~as inspected by our rel~resentative on September 3, 1981. The fol!o~;in9 deficiencies in the clean-ul~ were noted ~ A proper well sign needs to bc installed. Debris re~.ining to be removed includes a 55 c3~,llon dru~, a~ old marker post, and some scra? metal. Please nctify~ us when these corrections have been ~.~ade A subsequent inspection of this site will be necessary. It ~i]] be necessa~3~ tc submit a form 10-403, Sundry ~,.!oti.ces and. Reports on.Wells, to r~uest an extension of ~time fcr this clean-up. Thru: ALASKA OIL AND GAS CONSERVATION COMMISSION Hoy le H. Hamilton/~/~/~ Chairman Lonnie C. Smith Commi ss lone r Petroleum Inspector November 27, 1981 Conduct Clean-up Inspection on Chevron's Suspended Prett~ Creek Unit No. 2 Well Sec. 33, Ti4N, R9W, S,~. Permit No. 79-09 Monday Septe_m_ber 3, 198_1 - I accompanied Mr. Worth Langford, ChevrOn representative, to the location this date. As the attached photographs show the location is graded and level the well head is blind flanged, the cellar is covered, there is no well sign, there is a 55 gallon drum, an old well marker post and. some scrap metal remaining on the location. These items should be removed from the location and a proper well sign installed at the well head before this location is approved for clean-up. In summary= I conducted the clean-up inspection on Chevron's suspended Pretty Creek Unit #2 Well. The location is graded and fiat. There is a 55 gallon drum, old marker post and some scrap metal remaining on the location which should be removed. A proper well sign should be install on the well head before this location is granted~ clean-up approval. AAC 25.120: \,'151,1, AI;A?:I>~>:::.iEN':' }[eigh~ Above FSnal Gr;~de I.evt'.~ (:'~' Top of Harker Pipe Closed wit}~: Ce,a,.:nt PI\rE, Set: On Well lle;ld , Ou (i~ttoft: Side Outlets: All Valves and All Openings Closed , ',./i~i~ Blinds Len~jth (tt}' l-lin.) ~_, tn Cot~crete PI\Il', , () t I'L e r (List t,,'t~ere Different[ [~',;:n l"iie I~J:ot-in,~L[,.)[t) .. Well Numb,2~ , Sut'[;icc l.ocation o17 Well: [:t. F L, FZ., i" I., Sec , T , J( 20 AAC 25.170' I~OCA'FION CI. EAN-UI' PITS: Filled In t..-" , Liners Removed or BurLed ~.~ Dc,.br/s Removed SURFACI'] OF PAD ANI)/13P, I", o u/_.' h Otl~er Smooth ,/--" , COI~LOUL'Ud , Flat ~'.~..% Co;apact,e¢l , CLEAt: UP Of" [',kD A::D/()i.', I,QCA'Fi()N' Clean ~, Pipe Scrap .?.~'" , Iro~x Scrap "~ , Wood Paper , Other , 'cl'd<l , Ccrut-~n t SURllOIlN/)[NG ARE,,\: Wooded ~'~, Brush- Sand , Other , Tundra ........ , Dirt , (';r;~v e[ , CONI) IT ION Clca~_ V/, Tra~;l~ [roux Sit\_' Other ACCESS lO)AD: Dirt , Gravel--~,""Icc; , Trees and/or Brusll fcom (2].eari~g Road , Sl)O[1 fro,n Clcar].][~ l.~oa~d Oilier I NS Plr. CTED BY 05/26/8~ i)A'I' JUne 4, 1981 Chevron U.S.A. Inc. P. O. Box 7-839 Anchorage, Alaska 99510 Re: Alaska Oil and Gas Conservation Com,]ission Regulations Article 2, ADANDON~EI~T A1]D PLUGGItfC, 20 AAC 25.120 WELL ABANDON~'~ENT ~APKEE and 20 AAC 25.170 LOCATIOI.~ CLEAN UP. Gentlemen: In regard to the above referenced regulations, your attention is called to an attached list of wells which, according to our records, have not received a final location inspection and approval of clean up. In compliance with 20 AAC 25.170 Section (a), "~Tithin one year of suspeosion or abandonment of an on- shore well", all clean up work is to k'e finished. ~ection (b) provides the means for an eztension of time if a valid reason exists. Section (c) provides for on site inspection. Consequently, we are presenting the following list of your abandoned and/or suspended wells. ~any of these are now more than one year old and are not in compliance with requlations. Others should have the final inspection complete¢] this summer while weather t?ermits. This list covers the years ]975 to date. There may be some earlier wells that also need inspec- tion. If you have any earlier ~.~ells to be inspected this summer please inforra us. Therefore, we are requcsting a schedule from you for this summer when our field inspectors can accompany your representa- tives to these sites for the final clean up inspection. YQurs truly-~ Lonnie C. Smith Commi ssione r LC$/Ji<T: March 23, 1981 Mr. J. J. Anders Chevron U.S.Ao~ Inc. P. O. Box 7643 San Francisco, CAD 941-20 Dear Mr. Anders: I am granting your request of March 2, 1981 for an extension of confidentiality period pursuant to AS 3].05.035(c) on well data from Pretty Creek #2. The data will be held confidential for a reasonable time after the dispostion of the_~.~U~ounding unleased State Acreage~ Commissioner cc: Hoyle Hamilton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 Glenn Harrison, Director DMEM RECEIVED' MAR 2. 5 1981 Alaska 011 & Gas Cons. Commission Anchorage 10-J9 LH -~ "CONF IDENTIAL" F'orm P---7 SUBMIT IN ~ :. .TE * STATE OF ALASKA st ructions on OIL AND GAS CONSERVATION COSMITTEE [ I I I WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la, TYPE OF W~LL: OiL ~ ~*s" ~ v~r ~ Other EXPLO~TORY WELL WELL . b, TYPE OF COMPLE~ON: NEW ~ WOnK ~ DEEP- ~ PLUG ~ DIFF. ~ WELt, OYER EN BACK RESVR. Other SUSPE~ED 2. NAME OF OPERATOR CHEVRON U S.A. INC. 3, ADDRESS OF OPERATOR P.O. BOX 7-839; ANCHORAGE, ALASKA 99510 LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 1590' South and 2140' West from the Northeast corner of Section 33; T.14N., R.9W., S.M. At top prod. interval reported below SAME At total depth SAME '15. DATE CO'MP SUSP Oil ABAND. 2-26-79 13: DATE SPUDDED' 14. DAT~E T.D. I{F_,A, CFLED 4-16-69 7-18-69 2-02--79 18. TCMrAL DEPTH, ~ & TVD~9. PLUG, tk~CK MD & ~v-I)~. IF A~ULTZPLE COIV~PL., 21. ~OW IVi2kNY* ROTARY TOOLS 4750' MD & TVD | 4750' TVD X 22. PRODUCING !~VAL(S), OF THIS COMPI.~.TION--TOP, BOTWOM, NA2VIE (1VID AND NONE, WELL SUSPENDED 5, API N~CAL CODE 50-283-20022 6, LEASE DE~SIGNAT1ON 8. UNIT F~~ ~ P~TTY P~TTY C~EK &Z~2~' .~.---- WILDCAT O~CWIV~~, 12. P~IT ~O. 16. ~VA~ONS iDF, RKB, RT, GR, ~C)* [17.~. CASINGHEAD G.L. 8 1.9' ~ 80' INTERVALS DRILLED BY CABI,E Tf)O 1..8 23. ~V~S DIRE~ONAL ) SURVEY MADE . ~ ~o .~' 24. TYPE ELECTRIC AND OTHEI{ LOGS RUN GAMMA-RAY, NEUTRON, vARIABLE DENSITY, CBL , w CASIIMG RECOI~-D (Report all strings set in well) ' ' ' ............ CASI. NG SIZE I \VEIGHT LB/FT.~ GR.~DE t DEPTH SET. (,iVy) [ I-IOLE SIZE [ CEAILNTING RECOI'I,D AMOUNT PULLED 20" . [ 94~ '[HZ40i 339' /26" 1600 sacks C"lass i cement ..... 2"0 - ........ *' a-55 ' 0 - '" I ] ' I lClass I ~ 1048-stage b°ll~r ..... A,,l z zp sacks czass o -' i "~. uz~ ~co~ "P-110 1 ~' zuass ~o~m ~45, ~5" lstage colla:: ' "TOP (AID) [ SACKS C~5~T* SC~ (MD) SIZE DEPTH SET (SiD) PACKER SET (MD) NO~ OPEN ~ PRODUCTION. 3277'-3421' Il00 sacks Class G SET BRIDGE PLUGS ~ :3645' & 3860'. [squeezed to 2300 ~si. ~ 3525'-3570' ~125 ~acks Class G squeezed .... ~ t0 200'0 psi plUs retainer" ~ ~ ,, ~,, PRODUCTION DATE FIRST Pi%ODUCTION I Fi%oDucT1ON METHOD (Flowh]g, gas lift, pumping--size and type of pump) IX'yELL' STATUS (Producing or ~ ! - I t''I'E S''12~? YCo'w-~"ruS'mS lC.A~G Pm~-ssu~ Id~Lc,.rr_~;~"~z:, OIL--.~BL. C,.~S--r,~c~. PI~$S. I ['4'HOUR RA'TE ;I ' ' I OLL GIIAVITY'AP~'~" ~') · '~ISPOSITION OF GAS (~ol'd, used )or ~uel, vented, etc.)' '~/~a%%'~.~NE~SiD BY ,11 ,,, , .. /~/1~-,,. '~':"~ i .. ,.. 32. LIST OF ATTACHMENTS ..... 33.'! hereby certify that ~he fore$oing a.i~:l attached infor~tion ia complete and correct as determined froTM 'al¥-avallablc records -.':~__ ~<, ~'~.~.* ~ ,/~- ~' .. G- F.~ ~~.K)RKVOLD ,,.' ' AREA i i i i ii i ii i i i i i i L *(See Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS ~.. General: This form .s designed for subm~ttin9 a complete ar'~cJ c3rrect ,,x.e!l cor~.ple~'~on repot! ?r-,d [C'g OI'1 all types of lanJs and leases in Alaska. Item: 16: Indicate which elevatior~ is used as reference (vvhe, e riot o,'r~er,,,,,ise shc,..~.~;! for deD~h r'%e,~sure- merits given ~n c]her spaces on this forn~ and in ar~y Items 20, and 22:: If tills well is completed for separ,~tc r)r zJ:;cti,'~r~ trr"~,z~ r~c~,t· t}~.'~r'~ o,~e :r~tcr\,ai zc)r~e 1 (multiple completior0, so state ~n ~ten~ 20, and top(s), bottom(s) and name (s) (if any) for only the inler',,.~' rot),'~rtod ~r~ ~t,.:~ 30 ~,~hr¥~,t a se~.~,'~rate rer'~or' (page) on this form, adequately identified, for each add,t,c),~,~l it~te~val to be seperately r-~rodL~ce:t, show- ing the ackJitional data pert~ent to such ~nterval. Ite, m26: "Sacks Cement": Attached supplemental records for this well shoutJ sho,N the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each ~nierval to be separately produced (See instruction for items 20 and 22 above). 34. SUMMAILY ()b' b'()I{MA'I'I(.)N 'I'~'l'."; 1N('L.LII)IN(; iN'I'~HiVAL 'I'F~TEI) I'HE~SLJ[{E I)A'I'A WAT~;I{ ANI) MUD NAME DS~ ~1 (3915-3980) ~lowed Gas 3455 ~C~/D 3/8"CK, 1430 ps~ FTP: Rec. Gas Cu~ . ~ud. HH 2233/2333, ~P 1061/1996, SIP 1903/1885 DST g2 (3700-3780) Flowed Gas 2843 ~ICF/D, 3/8"CK, 1025 psi FTP; Rec. 10.84 bbls.I BELUGA 3643 Muddy Sandy Water; HH 2186/2175, FP 721/1590 SIP 1689/1681 psi. DST ~3 (3525-3570) Flowed Gassy Muddy Water, Est. 100 MCF Max. HH 2087/2008, FP 606/1299, SIP 1552/1570 psi. AND I)E',I',E("I~EI) SIIOWS O~' Oil,, . . Formation Evaluation Program Pretty Creek #2 Pretty Creek Unit - Farm-In DRILL STEM TEST #1 le Perforate the following DIL (Run #3) Interval: 3915' 3980' w/ 4-1/2" HPF a. Use premium charges w/ 4" carrier guns. Use full lubricator and pack-off. (Test to 2000 psi) c. Perforate in 68 pcf 10% KCL & 10 lb/bbl gel. Run Halliburton DST assembly to include the following: (No Cushion) RTTS, Hydro-spring Tester, Dual CIP Sampler, Jars, Safety Jt, Locked open by-pass and drop-bar bypass (+90' above Tester) 2 outside recorders, 3000 psi, 1-72 hr & 1-24 hr. 2 inside recorders, 3000 psi, 1-48 hr & 1-24 hr. 1 inside recorder above tester, 3000 psi, 48 hr 1 max reading bottom hole temp. recorder (Max. 150°F) +10' Screen-Wrapped Peforated Tail. e Set Packer at 3865'+. Open tester for 5 min initial flow period through 1/4" surface choke on Halliburton Manifold. Shut-in for 30 min initial shut-in. Re-open for second flow on 1/4" choke. Produce rat-hole fluid to pit. Divert flow to flare as fluid becomes gas-cut. Allow gas to stabilize and clean-up prior to metering. If Good Gas Flow (+ 1500 MCFD) Maintain stabilized flow for 3-5 hrs. (max. 10,000 MCFD). Have methanol available for injection. Collect TBG Press. and Temperature, Meter Press & Temp., Rate, Plate Size, & Gas Gravity. Flow @ Two additional lower stabilized rates for ~ 2 hr. each. Collect Liquid & Gas samples. Note: Notify Alaska Natural Resources Dept., Division of Mineral & Energy Mgmt. to witness multi-rate test to confirm productivity. If Poor Gas Flow Close tool for 30 minutes and re-open to stimulate flow. Shut-in for twice the flow period. Reverse out fluid, pull DST assembly. DRILL STEM TEST #2 e Perforate & Test interval 3700'-3780' per steps 1 through Set RTTS packer @ 3650'. DRILL STEM TEST #3 Perforate and Test Interval 3525'-3570' per steps 1 through 5. Set RTTS packer @ 3475'. ~ R. G. HOWARD, Jr. RGH:meh "CONF IDENTIAL" / · Form ~--3.9 Smbrnlt "Intentions" in Triplicate F~EV. 9 ~ & "Subsequent Reports" in Duplicate · STATE O'F ALASKA -5. APl NU~C^L CODE OIL AND GAS CONSERVATION COMMITTEE .50-283-20022 SUNDRY NOTICES AND REPORTS ON WR.L~ ~, ADL- 63048 (DO not use this form for proposals to drill or to deepen ;' ~ " · ~'~' ~; ?~ *' .,~ , ' Use "AP~L1CATION'FOR P~i'i'~' Yor such'p{o~osalsJ ~. ~ (~" ~ ~ ? ~. WELL WELL OTHER EXPLO~TORY , . ':w '2. NA~IE OF OPERATOR .,,L 8. UNIT, FA~ OR L~SE NAME CHEVRON U.S.A., INC. Alask~ l)~;,' ~, * ....... P~TTY C~EK UNI~_..J P.O. BOX 7-839; Anchorage, Alaska 99510 - P~TTY C~EK 4. LOC*klON OF W~L ~ 10. F~ ~D POOL, OR WI~C*T A~ac~ 1590' South and 2140' West from the Northeast WILDCAT FILE: ao~ne~ o~ Sea~io~ 33r T.~4~.r R. gw.r S.~. n.S~C.,T.,m,~..(BOTTO~O~ 33~ ~.14N.~ R.9W.~ S.~. - , 13. E~EVATIOHS (Show whether D~, ~T, ~, etc. 1~. PE~IT ~O. Ground level 81.9'; K.B. is 18' above G.L. 79-9 Check Al~ropriate [lox To Indicat~ Nature of N~ti'ce, Re ~, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFFI PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPI,ETE S~OOT OR *CID~ZE [~ ASA~DON* REPAIR WELL CHANOZ PLANS ~Other) SUBSEQUENT REPORT O~: WATER SI{UT-OFF i~i REPAIRING WELL (~ FRACTURE TREATMENT i~ ALTERING CASING SHOOTING 0n ACIDIZING ! i ABANDONMEI~T* lO,her) SUSPENDING WELL (NOTE: Report results of multiDle comDletion on Well Completion or RecomDletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. "CONFIDENTIAL" le Perforated 3915'-3980'. Set RTTS at 3849' with tail to 3871'. Performed DST #1. Mr. Bill V&n Dyke (Division of Minerals and Energy Management) witnessed test and verbally confirmed commercial rates. Set bridge plug at 3860' Tested to 1500 psi with 82 pcf KCl-gel drilling fluid in well. e Perforated 3700'-3780'. Set bridge plug at 3645' in well. Set RTTS at 3654' with tail 'to 3675' Performed DST ~2. . Tested to 1500 psi with 82 pcf KCl-gel drilling fluid e e Se Perforated 3525'-3570'. Set RTTS at 3471' with tail to 3492' Performed DST ~3. Set bridge plug at 3487'. Squeezed 90 sacks Class G neat cement through retainer, .. squeezing perforations to 2000 psi. Placed an additional 35 sacks Class G neat cement on top of retainer .... Displaced drilling mud with diesel in top 150' of well. Rigged down BOP equipment. Placed blind flange on top of well,wit~marker NOTE: 16. I hereby certify that the foregoin$~lS true an~..corr~ SIGNED /~_ /~,~'~, ~ .... "~'~ ~ ,~ -~.~ c. ~'. ~y'u~u ' Per telecom 2-26-79 with Mr. Russ Douglas (Alaska Oil and Gas Conservation Commission) and L. D. Cunningham (Chevron U.S.A. Inc.) the Alaska Oil and Gas ~n~rvatlon Commission gave verbal approval to suspend well as outlined above. (This space for State office use)~ ~~ APPROVED BX/~/~, CONDITIONS OF APPROVAL, IF AN~, SUPERINTENDENT TITLE PETROELUM ENGINEER D~TE 03/14/79 See instructions On Reverse Side /,pprcv~;d Copy C]{EVRON U.S.A. INC. S US PENDED Ivan River Unit 14-13 Pretty Creek Unit ~2 Soldotna Creek Unit 13-3 Stump Lake Unit 41-33 PLUC~GED & ABANDONED Eagle Creek #1 Tiglukpuk #1 (STANDARD OIL) Cape Espenberg #1 November 10, 1980 Mr. T. L. Perryman Area Operations superintendent Chevron U.S.A. 3001 "C" Street P. O. Box 7-839 . ~ Anchorage, Alaska 99510 ~ . RE: Pretty Creek Unit #2 Well Logs Dear Mr. Perryman: In reviewing our files we Can find no record of having · received copies of logs that'chevron.had run on Pretty Creek Unit #2 well, a re-entry .'of Theodore River %1 well. The completion report shows this well was'suspended February 26, 1979, and that gamma-ray, neutron, variable density, and CBL logs were run Please send a blue line print and a. sepia copy of each log run in Pretty Creek Unit #2 for our files. Thank you. Sincerely yours, ? "John Ao Levorsen Petroleum Geologist STATE toF ALASKA SUBMIT IN DUPLICATE OIL AND GAS CONSERVATION COMMrI-I'EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ~I~LL ~ELL OT]~lt EXPLORATORY 2. NA-~E OF OP~TOR CHEVRON U . S .A . INC. 3. ADDRkSS OF OPE/~ATOR P.O. BOX 7-839; ANCHORAGE, ALASKA 4 LOCAT~O~ OF 99510 1590' South and 2140' West from'the Northe~'~-:qo~m~/ ~ of Section 33, T.14N., R.9W., S.M. ~ .... ~ ? [i.~ AP1 NU.X{ERICAL CODE 50-283-20022 ~ [.EASE DESiGIxlATION AND SEIq'IAL NO. ADL -63048 IF INDIAIx]' ALOT'TF, E O11 TRIBE i~ANIE PRETTY CREEK UNIT 9 WELL NO PRETTY CREEK UNIT NO. 2 10 FIELD A3ID lPOiDL, Oil ~,VI;i.DCA. T WILDCAT sE~ T.. P,..' W~ (m)'r'ror,,~ HO~ o~rF_xyr', tv~ 33, T.14N., R.9W., S.M. 12 PE'RIVlIT NO ,,,;I15%k,719-9 13. REPORT TOTAL DEPTH AT E/ID OF MONTH. CHA.NGF-,S IN HOLE SIZE,~ - ;~;~ ~.r~CAKi~,C~~NT!NG JOBS INCLUDING DEPTH SET ~ VOL~ USED P~O~TIOHS, ~TS ~ ~SULTS FISHING JO~S J[X~K m HOLE AND SIDE-~ACKED HOLE ~ND ~Y O~R SIGNIFIC~T ~G~ m HO~ CON'DITIONS "CONF IDENTIAL" February 7-9th, 1979 Moved in rig and rigged up. Tested all BOP equipment and lines to 3000 psi per operating manual D-17. Per telecom 2-8-79 Mr. Harold Hawkins (Alaska Oil and Gas Conservation Commission and M. R. Sumpter, (Chevron U.S.A. Inc.) the Alaska Oil and Gas Conservation Commission waived witnessing test of the BOP equip- ment. Dug mouse hole. February 10-13th, 1979 Went in hole with 8 1/2" bit, 65 pcf water as the drilling fluid. Drilled cement plug 3038' to 3522'. Went in hole to 4580'. Drilled cement to 4750'. Casing would not test. Made trip with 8 1/2" casing scraper. Squeezed 3271' to 3750' with 100 sacks of Class G neat cement to 2300 psi. Drilled out firm cement 3277' to 3421'. Pressure tested 9 5/8" casing to 2000 psi, OK. Changed drilling fluid to 68 pcf KC1 system. February 14th, 1979 Ran Dresser-Atlas Gamma Ray-Neuton, Variable Density, CBL from 4100' to 2000'. Changed pipe rams to 5" for perforating lubricator. Tested to 2000 psi, OK. Perforated 3980'-3915' with 4 shots/foot. February 15-16th, 1979 Changed pipe rams from 5" to 4 1/2" for drill pipe. Well started flowing at 10:30 a.m., 2-15-79. Ran in hole with two stands of drill pipe, open-ended. Well started flowing out drill pipe. Attempted to stab shut-in valve on top of drill pipe. Unsuccessful. .Drill pipe started jacking, o~t of hole. :'CloSed pipe.ra~3~ .... Dr~.~ L. pipe continued jacking out of hole. Closed blind rams. Drill pipe stopped moving, top 75' above the rotary table. The well was flowing dry gas out the open end of the drill pipe. No leaks in the BOP stack. Built shut-in valve with guide assembly. Stabbed on top of drill pipe. Shut well in at 1:30 p.m. 2-16-79. No leaks. 1;. I 'hereby certi}y tthit th~ ~l~.~g~Oj~"~ true a_rxd ,~lOrl~ ,_:'.~ J~'. ~xvo,,o . ~ ~J~ uu~a'x'iu~s ~u~~o~:~~' NOTE--Report on this form is required for each calendar ~nth& regardless of [ha status of ooerotions, and imult ~ flied In duplicate with the oil and gas con,ervation commi~ee by the 15~ of the tu~c~dlng m~n~. u~le~ otherwise d~r~cted. PRETTY CREEK UNIT NO. 2 PRETTY CREEK UNIT CHEVRON U.S.A. INC. February 17-18th, 1979 February 19-21st, 1979 February 22nd, 1979 February 23-24th, 1979 February 25-26th, 1979 "CONFIDENTIAL" Killed'well with 82 pcf KCl-gel drilling fluid. Tripped in hole and circulated well clean. Set retrievable bridge plug at 3800'. Tested to 1500 psi, OK. Checked and tested all BOP equipment to 3000 psi, OK. Test witnessed by Mr. Bob Foster (Alaska Oil and Gas Conservation Commission). Set RTTS at 3849' with tail to 3871'. Performed DST #1 of inter- val 3915'-3980'. Mr. Bill Van Dyke (Divsion of Minerals and Energy Management) witnessed test and verbally confirmed commer- cial rates. WIH with bridge plug on electric line. Logged at 2650'. Recovered setting tool and drilled out bridge plug. Made 8 1/2" casing scraper run. Set bridge plug on end of drill pipe at 3860'. Tested to 1500 psi, OK. Perforated interval 3700'-3780' with 4 shots/foot. Set RTTS at 3654' with tail to 3675'. Performed DST #2. Set bridge plug on end of drill pipe at 3645'. Tested to 1500 psi, OK. Perforated interval 3525'-3570' with 4 shots/foot. Set RTTS at 3471' with tail to 3492'. Performed DST #3. Set retainer on end of drill pipe at 3487'. Pumped 90 sacks Class G neat cement through retainer, squeezing perforations to 2000 psi. Placed an additional 35 sacks Class G neat cement on top of retainer. Circulated diesel in top 150' of well. Install blind flange with bleed-off valve and marker on top of well. Rigged down. Released rig 12:15 p.m., 2-26-79. NOTE: Per telecom 2-26-79 with Mr. Russ Douglas (Alaska Oil and Gas Conservation Commission) and L. D. Cunningham (Chevron U.S.A. Inc.) the Alaska Oil and Gas Conservation Commission gave verbal approval to suspend the well as outlined above. ....... DRILLINC FOREMAN ' -': ':":~'":: SECTI~ XII, ~EM- 'B ~S~TION ~K LIST FOR ~P ~UIP~ Pro-515 Pa g. 1 Well No~~ The follo~ blowout preventer equipment is to be checked by the Drilli~ For~an. and this check sheet 'turned in to %he District Drilli~ Super~sor - District Superinte~~n as possible a~er the equipment has been installed or tested, 1. ~re the blo~ut preventers installed in accordance ~th ~erattng Inst~ction ~. Operating Instruction D-!77 7~,' , 3. The three aCcumulat~or nitrogen bottles were checked and contain the foll~ ............... ...... 17oo 4. What is the accumulator actuating pressure? _ ~~ .... -_ _ 5~ e e 10. n. 13. 14. 15. 16. 17. 18' Does the equipment hold the accumulator pressure' without leaking or an unusual amount of pump operation? l~ _ _ Is the ~fluid level in the accumulator reservoir O.K.? Does the accumulator, pump operate wi'thout leaking? ~ Was the accumulator diaphragm checked and found to be O.K.?~_ Is the ~zinimum pressure in the accumulator immediately after operating the blowout preventers above 750 psi? ~_~ Has the fluid in the bottom of the accumulator reservoir been checked for the presene~ of mud and/or water and cleaned if needed? - Are the floor and remote controls properly installed and ltagged? ~/~ _ / · ,.,,~= ~,~,,~s ou 5he remote control panel working properly? ~.., · Were new API steel ri~g gaskets (RX or EX, as required) used in all F~es in the BOP installation? _./:~.~'~ ..... Is the BOPE stack prOPerly braced to prevent wobble? ~ :'" Are hand Mheels or ratchets installed and tagged? ~/~ ~ ? ' Is the kelly stop cock in working order? ~ ':: '~:" , , , ,,, ~ - Is a drill pipe sub,~ and safety %~lve, or full opening stop cock as specified in Operating Instruction D-l~ ~or this class well, on the rig floor and proper operat±ng condition? . ~. Are the kill line and bean line installed in accordance vith Operating Instruction D-l?? ~~ Pro-513 Page 1 (2M-CD-i-69) Printed in U.S.A. 19. 20. 21. 22. 25. 26. 27. . DRXLLING FOREMAN IS £ION & INF~TI~ MANUAL SECTION XII, IZFEM- B - :INSPECTION CHECK LIST FOR BOP EQUIPMENT Pro-515 Pag. 2 _ -:~ ..... : u ' - , -- Are all outlets equipped with the proper fittings?_ · Has the bean line been st~ked down to prevent whipping? ! The ac¢ ul r, unit was last overhauled ..d/or serviced in s op ,,,o,/y?'?.. ...... _ Th'e lower, (.~ilili~) (sinai. e) hydraulic gate was ll~t overhauled and/or serviced tin shop on · - Closure time for the bag packer/is _~~ i': seconds, closure time for the drill pipe rams is ~ secondS~ciosure time for the ceo rams is ~- seconds. The CSO rams have b~en tested to ~OC~:': psi and found to be in satisfactory condition. The drill pipe rams have been tested to .L~¢3oo psi and found to be in satisfactory conditi0n. The b~g packer has been tested to ~ psi ami found to be in a satisfactory condition. 31. 32. 33. 55. 36. 37. 38. The kelly cock, stand pipe valve and drill pipe safety valve have been tested to ~O<~. psi a~ found to be in a satisfactory condition. The mud manifold from the pump to the k~lly cock, including the kill line, has been tested to ~...~~D_ psi 'and found to be in a satisfactory condition. The mud' cross, bleed line, and choke manifold have been tested to .-~'~d~: pei and found to be in satisfactory condition· The fluid used in conducting the aforementioned test was ~.~ ~O __~ __~_. Is the bore of all preventers and spools in the blowout preventer installation large enough to pass the largest size bit that can be-run into the last string of casing set? _~/~ _-/_~/~ ~'~~~ hours were spent in performing the above tests and inspection. Does the contrao~ pusher have a copy of Operating Instruction D-177 C~d.5 ..... :~ .. Have pertinent points of Operating Instruction D-17 and drilling progr~, been discussed with the Contract tool pusher? Are the contractor's crews familiar with operation of the b~6woUt Preventer equipment ? ~- ~(~.~_. -. .......... :-:::::-- -~.., ! Printed in DRILLINC FOREMAN t S IA,~,TRUCTI(2{ & INFORMATION MANUAL SECTION XII, 1/rEM - B Pase 3 INSPECTION CH~X~K LIST FOR BOP E~~ Pro-515 59. Are the contractor's crews familiar with procedures to be followed in the event the well should kick? NOTE: ~ke a sketch on the back of this sheet, or attach a sketch to this check list, showing location, size, and rating of all connections between cellar floor and overflow, pipe.. . .~ / ~~ / ~/. ~~ ' .~- -/.~ ~,. I Approved by b{strict D~{liih~ ' SUPerwi sO~ -Dis~ic~ Superintendent- - Pro-513 Page. ~ (2M-CD-i-69) Alaska Oil & Gas Conservation Commission Hoyle H. Hamilton /~/~ Chairman ~of Commissio~?" Lonnie C. Smith~ Commissioner Bobby Foste~ ~ Petroleum Inspector March 1, 1979 BOPE Test on Chevron's Pretty Creek Unit #2 Sec. 33, T14N, R9W, SM ~n~~eprua~y _18 - I departed my home at 8:45 AM and drove to Troy Air Service where I boarded a Chevron chartered plane and was flown to Beluga River to witness BOPE test on Chevron's Pretty Creek #2. i arrived at Brinkerhoff Rig #58 at 10:20 A/-~, where I met with Mr. Mike Sumpter, Chevron's drilling foreman and Mr. Harvey Moore, Brinkerboff's toolpusher, Mr. Sumpter informed me that on February 15, 1979, one of the rig crew observed~the drill fluid bubbling ia the BOPE. This oc- curred after a 65' interval had been perforated from 3980' to 3915' and as the rig crew prepared to run the drill pipe in the hole. The crew ran two stands, approximately 180 feet of pipe in the hole. At this point drill fluid began to flow out of the drill pipe and an attempt was made to screw a floor safety valve in the drill pipe, The safety valve could not be screwed into the pipe. The pipe began to hydraulic out of the hole and the pipe rams were closed. Approximately 60 feet of pipe had hydrauliced out of the hole. The blind rams were partially closed to insure no movement of the pipe. The well unloaded the drilling fluid through the 4%" drill pipe and began blowing dry gas at approximately 11:30 A~, The annular pressure was checked at 230 PSIG. A four and one-half inch API full hole safety valve was welded in a piece of I0 3/8 inch casing. When this assem~bly was dropped over the drill pipe the 10 3/8" acted as a guide to position the valve so that it could be screwed onto the drillpipe. This was accomplished and the valve closed to shut off the gas flow. The well was shut-in at 1:10 PM, February 16, 1979, after flowing under partial control for 25 hours 40 minutes. Heavy mud (68 ppg) was pumped into the well and it was killed at 4:00 AM, February 17, 1979. I walked over the location and found that a very small amount of dril- ling fluid had been blown out side of the retainer dike. The location and rig had been cleaned up very good. ~r. Sumpter informed me that the blind rams and pipe rams had been dismantled and checked for damage. There was no damage found, so the rubbers were changed on both pipe rams and blind rams and the units reassembled. BOPE Test on Chevron~s Pretty Creek Unit #2 2 ~rch 1, 1979 The BOPE test began at 1:00 PM with the BOPE stack, consisting of one set of four and one-half inch pipe rams, one set of blind rams and one annular preventer. During the BOPE stack test a hydraulic leak deve- loped on the blind ram door pin assembly. This was repaired and re- tested. The choke line, consisting of two three inch manual valves and the choke manifold, consisting of two adjustable chokes, one Swaco choke and six manual valves were then tested. The kill line, consisting of two three inch manual valves and one two inch check valve were then tested. The ball type floor safety valve, the dart type safety valve, and the upper and lower kelly valves were then tested. Ail the above BOPE were tested separately to 3000 PSIG, with the ex- ception of the annular preventer which was tested to 2000 PSIG. The acctmuulator unit was tested next by shu~Hng off the power to the unit and closing the pipe rams and. the annular preventer. The full pressure of 1750 PSIG dropped to i100 PSIG and stablized. (It should have been 1250 PSIG.) The puraps were turned on and a 250 PSIG gain was attained in fifty seconds and the full charge pressure of 1750 PSIG was attained in three minutes and forty-five seconds. I informed Hr. Sumpter that the accumulator unit did net meet State of Alamka Oil & Gas Conservation Commission and API standards of stabili- zation at a minimum of 1250 PSIG. Hr. Sumpter said he would have it repaired and would notify me when this was done. I informed him that there was not a well.sign up and he said he would have one put up im- mediately and would inform me by telephone. The BOPE tests were concluded at 6:00 PH. in mu~nmry; I witnessed the satisfactory BOPE test on Chevron's Pretty Creek #2. Attachment: On February 20, 1979, Hr. Sumpter called me and informed me that the well sign was up and that a repairman was scheduled to repair the accumulator unit this date. BF/LCS:emi ~- Drlg.- P~r~t No. Ope ,ra.,~or r~(__~_~/~//? 0// Sati s'f~ctory Type Inspection Yes No .... Item (,'~)"' Location,General ( ) (*~)'" 1. Well Sign (~)'-() (~.-)-() () () () () () () () () () () () () () () Ale .a Oil and Gas Conservation Commil, .e !~ Field Inspection Report ~~ Well/Platfm ~Seq~__l,J~'~ R~_/_~__, ~ ~. Represented bY~.F~.~.~m.~ Name & Number_l~_~ ~~:~/~,~...,./~l~ 2. General Housekeeping 3. Reserve Pit-(' )open( )filled 4. Rig ( ) Safety Valve Tests 5. Surface-No. Wells 6. Subsurface-No. Wells ( ) Well Test Data 7. Well Nos. , , , 8. Hrs. obser , , , 9. BS&W , , , 10. Gr. Bbls. ( ) Final Abandonment ll. P&A Marker Op] pe~tl°n Sa tis Factory Type ~' ' Yes No Item ( Tests (~ ( ) (~F~]' ( ) (~_.) ...... ( ) (~)" ( ) (~.)' ( ) (~).-' ( ) (~)- ( ) (~.) ( ) (~).- ( ) (~) () 15 ~._~'i'~-ing set 16 T~st f'luid-(~tT,-( )mud ( )oil 17 Master Hvd, Control Sys.- psig 18 _N2 btlsk~,Z~ 19 ~emote Controls 20 Drilling spool-~ "outlets 21 Kill Line-(~Check"valve 22 Choke Flowline ( ) HCR valve 23 Choke Manifold No. valvs flqs 24 Chokes-(~emote(~Pos.(~d,i 25 Test Plug-(~tellhd(' )cso( )none 26 Annular Preventer,~psie 27 Blind Rams~'psiq 28. Pipe Rams~' psig ( ) ( ) 12. Water well-( )capped( )plugged (.~-)' ( ) 29. Kelly & Kelly-cock~-c~x' psi9 ( ) ( ) 13 Clean-up ( . · (~')~'~ ( ) 30 Lower Kelly valve~ psig ( ) ( ) 14, Pad leveled ( ) 31., Safety Floor valves-(-~V (L)_Dart Total inspection observation time hrs/days Total number leaks and/or eq~ip~ fa,ilures ~ I. ~ ' ' - . ..... / ' ' .--~ 't ' , ,' . ' Remarks ~/~//~?/~ ~,/~. ~ ~ ~ ~.,~ ~/~:~ ~ ~,.~// Z~ x~'~ f ~ c.~. ' - -. Z - / ~ * ' . ' Files Alaska Oil & Gas Conservation Commission February 27, 1979 Russell A. Douglass~,.~ Petroleum Engineer Chevron Pretty Creek Unit #2- Suspension I received a call from Dave Cunningham 02/26/79 about 9:00 AM. He informed me of Chevron's plans to suspend the Pretty Creek Unit #2 well. The present well conditions include perforations from 3915' to 3980', with a bridge plug at 3880', perforations from 3700' to 3780', with a bridge plug at 3645', and perforations from 3525' to 3570'. Plans are to set a cement retainer at 3487' and squeeze the upper perfs with 125 sx of cement, leaving 100 feet of cement on top of the retainer. I verbally approved the plan and requested a P-3 describing the above conditions and operations. RAD:emi ,/' : /',<. Chevron U.S.A. Inc. P. O. Box 7-839 Anchorage, Alaska 99510 Attention' C. F. Kirkvold Area Operations Superintendent Reference' LO 79-12 Gentlemen' Thank you for your letter of January 23, 1979. .~;. The referenced Lease Operations for Pretty Creek l~ell #2 are hereby approved subject to the following stipulations' · The area around and below the fuel storage facilities shall have a dike surrounding it with impermeable membrances beneath, or the fuel storage facilities shall be of double wall construction. · A completion report must be submitted within 15 days upon termination of permit activities. This report shall contain the following information. A· Actual routes of travel and actual location of all camps depicted on a USGS topo map. B· List the vehicles used for any off-road travel that ~ay~ have taken place. / ' C. All additions to original application. D· Statement of clean up activities. RECEIV D 10-J3LH , E. Time spent in each campsite. F. Methods of disposal of garbage and other camp debris. Sincerely, James H. Lack Acting Leasing Manager Chevron Chevron U.SA. Inc. P.O. Box 7-839, Anchora§e, AK 99510 · Phone (907) 279-9666 C. F. Kirkvold Area Operations Superintendent Production Department January 23, 1979 State Oil and Gas Lease ADL-63048 Plan of Operation Pretty Creek #2 Well State of Alaska Department' of Natural Resources Division of Minerals & Energy Management 703 West Northern Lights Boulevard Anchorage, A1 aska 99503 ATTENTION' Mr. Tom Cook, Director Gentlemen' Chevron U.S.A. Inc. plans to conduct reentry operations in a well previously drilled as Theodore River #1 and abandoned. The well to be known as .Py~e~~~.~e w.orked on in behalf of Chevron U.S.A. Inc. and Union Oil Company. In order to carry out and provide logistical support for the operation, it is necessary for us to obtain your approval of our Plan of Operation. Accordingly, we are enclosing our Plan of Operation for this project. The items covered by the plan should answer any questions regarding surface operations. If you have need for further'clarification, please detail these, and we will attempt to provide answers. Your early consideration and approval of the attached plan is requested. Very truly yours, Attachment cc' Land and Water Management South Central District Attn- Mr. Ed Barber State Fish and Game Habitat Protection Attn' Mr. Bruce Barrett Kirk~ JAN 2 Minerals 1 O0 Years Helping to Create the Future PROPOSAL FOR WELL OPERATIONS PRO-316-1 RE-ENTRY OF HALBOUTY ALASKA OIL COMPANY THEODORE RIVER ~1 Field: Pretty Creek Unit Well Name: Theodore River #1 Renamed: Pretty Creek #2 Surface Location: 1590' South and 2140' West from the Northeast corner of Section 33, T14N; R9W;' S.M. Bottom Hole Location: Same Elevation: Original pad level was 81.9'. K.B.'measurement was 40.14' above pad level. New K.B. is 18' above pad elevation. All depths indicated are from the original K.B. elevation. Total Depth: 12,025 ' Plugs: 8420'-8675' cmt; 7000' B.P.; 4750'B.P. and 3296'-3416' cmt. Cas_ing: 20" cmt'd at 339'. 13 3/8" 61# J-55 cmt'd at 2032'. 9 5/8" 40#, 43.5#, & 47# N-80 & S-95 cmt'd at 8550'. Stage collar at 4525' cmt'd. Casing Detail: Top 2800' + Surface - 2800' Next 3000' 2800' - 5800' Next 2000' 5800' - 7800' Bottom 1200' 7800' - 9000' 9 5/8" 40% N-80 9 5/8" 43.5# N-80 9 5/8" 43.5# S-95 9 5/8" 47# S-95 Note: Depth and casing lengths are taken from the DOG report and are approximations only. Casi~.g Pressure Detail 9 5/8" 40# N-80 9 5/8" 43.5# N-80 9 5/8" 43.5# C-95 9 5/8" 47 C-95 Min. Yield 60% Min Yield 5750 psi 3450 psi 6330 psi 3800 psi 7510 psi 4500 psi 8150 psi 4890 psi Peforations: Four 1/2" jet holes per foot: 7260'-7280' (open); 4794'-4812' (open); 3396'-3416' (cmt'd) Pl~gge~ and Abandoned: July 28, 1969. Theodore River #1 Pressure History Subject well was spudded in April, 1969 and reached total depth of 12,025' on July 18, 1969. No major problems encountered to T.D. Made four drillstem tests. DST #1, 7260'-7280', Recovered 120' of drilling mud, FSI pressure was 1396 psi equivalent to a gradient of .19 psi/ft. DST #2, 4794'-4812', Recovered 600' of mud and water. FSI pres- sure was 1729 psi equivalent to a gradient of .36 psi/ft. DST #3 and #4, 3396'-3416'. Recovered muddy water with some gas. FSI pressure was 1522 psi equivalent to a gradient of .45 psi/ft. Subject well was plugged and abandoned on July 28, 1969. Blowout Prevention Considerations 1. Potential Problems: A. Gas: Drillstem tests in and near the current intervals of interest indicated normal hydrostatic pressure. Programmed drilling fluid weight should adequately control these pres- sures. When drillstem tests are conducted, care must be taken to circulate out any well fluids and regaining pressure con- trol prior to pulling the test tools. Be Ce Water Entries and Lost Circulation: Since the well was ori- ginally drilled and cased with no problems, it is not anti- cipated that water entries or lost circulation will be a problem at this time. Precautions: While teSting procedures are being carried out, extreme care must be used when pulling ~the test tools, so as not to have a gas bubble under the packers. 2~ Any kicks should be handled by normal procedures. Drilling crews should be made aware of these methods and care must be exercised at all time. · Maximum Anticipated Formation Pressure:' 1790 psi based on a .45 psi/ft gradient to the deepest programmed test interval. 3. Maximum Anticipated Surface Pressure: 1700 psi e Blowout Prevention Equ~.pment A. Class III, 13 5/8" - 5000 psi for all work. B. BOPE to be installed and maintained as outlined in "Operating Instructions D-!7". Depth Control: All depths used throughout this program are from the _ original Dual Induction-Laterolog, Run #3, dated 5-20-69. -2- PROGRAM 1. Move in rig. Rig up. Mix 67-69 pcf mud. Use 10 lb/bbl gel with 10% KCl as basic mud system. 2. Install 12"-3000 psi x 13 5/8"-5000 psi tubing head with secondary seal to 9 5/8" casing on the existing 12"-3000 psi x 13 3/8" SOW casing head. Nipple up 13 5/8"-5000 psi, Class III BOPE per "Operating Instructions D-17". Pressure test to 3000 psi. Note: A 13 5/8"-5000 psi BOPE is being used for convenience. The well pressure requirements indicate a 3000 psi system is more than adequate. 3. Circulate and clean out 9 5/8" casing, in stages, to top of cement plug estimated at 3296'. 4. Drill out cement plug from 3296' to 3420' +. Clean out and circu- late, in stages, to bridge plug at 4750'. 5. Pressure test 9. 5/8" casing to 2000 psi. A. If stage collar at 4525' leaks, run in open end to 4600' and plug back with Class G cement to 4400'. B. If perforations at 339~.' to 3416' break down, squeeze with Class G cement, in up to 100 sack stages until a final squeeze pressure of 2000 psi is reached. Drill out cement. Pressure test casing to 2000 psi. C. Repeat A and/or B until pressure test of casing to 2000 psi is successful. 6. Run 9 5/8" casing scraper to 4100'. Circulate and condition mud prep to log. 7. Run Variable Density Cement Bond, Neutron/GammaRay, Collar Correlation log from 4100' to 2000'. Evaluate CBL as to bonding in test intervals. Perforate and squeeze with cement if necessary. 8. Perforate interval from 3980'-3915' per attached Formation Evaluation Program. Use lubricator while perforating and test to 2000 psi. Drillstem test interval from 3980'-3915' per attached Formation Evaluation Program. 10. Wireline set bridge plug at 3870'. 11. Perforate and drillstem test interval from 3780'-3700' per attached Formation Evaluation Program. -3- 12. Wireline set bridge plug at 3660'. 13. Perforate and drillstem test interval from 3570'-3525' per attached Formation Evaluation Program. 14. Program to suspend or abandon to follow~ WDS: meh ,z:), . ~' 7 7' y C ~¢ £ £ 14tEL ~ /-/~',4 Z~ HO 0 l-q - U/:~ oz,4,s,e .zzr ~.o.,q. E. THE ALASKA REPORT .:XPLORATORY & STEPOUT WELLS - CONTIN,ED CHEVRON USA INC. liglukpuk #1 Surf: 1650'N,. 75'E fr SW cor Sec. 14, T12S, R2E, UM Btm: Straight hole API 50-057-20002 15,797'TD Ti ght hole. P1 ugged and abandoned on 12/11/78. Set 9-5/8" csg. [~ll,500'+-. Set 13-3/8" csg. E~6,411'. Set 16" csg. @l,510'. Spudded on 01/31/78. Explora- tory location ~t...~ 15 miles northeast of Anaktuvuk Pasb ~nd ~bouC 75 miles southeast of Umiat on Frccic Slcpe Regional Corporation Land. Challenger rig #49. Will remain in report until official data is released by the State. LOWER COOK INLET ATLANTIC RICHFIELD CO. OCS Y-0097 #1 Surf: 2429 meters S, 432 meters W fr NE cor OCS Block 401 Btm: Straight hole API 55-220-00002 MARATHON OIL CO. OCS Y-0168 #1 Surf: 291'S, 909'E fr NW cor OCS Block 2 X=505,077.24 Y=6,537,511.34 Btm: Straight hole API 55-219-00003 1 ,626' 2,797' PHILLIPS PETROLEUM CO. 6,100' 7,070' OCS Y-0124 ~l Surf: 609.6 meters S, 1371.6 meters E fr NW cor OCS Block 668 X=534,972 meters, Y=6,580,190 meters, UTM Grid Zone 5 Btm: Straight hole ~rI 55-220-OOOO~ PHILLIPS PETROLEUM CO. OCS Y-0136 #l Surf: 2400 meters S, 2400 meters W fr NE cor OCS Block 798 X=526,400 meters, Y=6,564,000 meters, UTM Grid Zone 5 Btm: Straight hole API 55-220-00005 Offshore exploratory location in the Lower Cook Inlet about 58 miles east of Homer. Proposed ~otal depth is ll,500 feet. Water depth is approxi- mately 215 feet. Tight hole. Waiting ~n weather on 02/OE 79. ~et 20" csg. ~i 3~5' Set 30" csg. 9814 . Spudded on 0{/11/~9. Offshore exploratory, locacion in Lower Cook Inle about 68 miles southwest of Homer. Pro- posed to~al depth is 8,000 f,~ec. Water depth is 550 feet. KB-52' obove HSL. Diamond M Dragon Drillship. Tight hole. Drilling in sidetrack hole on 02/06/79. Kickoff below 4,424 on 01/10/79. Set 13-3/8" csg. Set 20" csg. [a1,.~.55'. Re-si)uaded an 10/20/78. Spudded on 1u/e~J/TJ. tlffshor~ exploratory location in tile Lower Cook Inlet about west of Homer. Pr'o;)osed tot.'.l depr. h is 13,360 feet. Odece Ocean ~-',ounty semi- submersible. · Offshore exploratory lccation in Lower Cook Inlet aboll% 41 nautical miles southwest of !ion~er. Proposed total depth is 13,340 feet. .<B-78' above MSL. Odcco Ocean f~ou~.~y semi- s ubme rs i bl e. COOK IHLET BASIN CHEVROH USA Pretty Creek Unit #2 Surf: 1590'S, 2140'W fr NE cor Sec. 33, T14N, Rgw, SM Btm: Straight hole API 50-283-20022 CHUGACH ELECTRIC ASSOC. Robinson Loop Unit #l Surf: 1500'S, 2400'E fr NW cor Sec. 6, T5N, R9W, SM Btm: Straight hole API 50-133-20308 SIMASKO PRODUCTION CO. Simpco Moquawkie #2 Surf: 785'N, 2,046'W fr SE cor Sec. 1, TllN, R12W, SM Btm: Straight hole API 50-283-20062 Tight hole. Rigging u$~ on ~]2/05/79. Re- entry of the Halbouty Alaska Oil Com- pany's Theodore ~<iver ~;'l well located about 30 miles west of Ancilora!te. TD in original bore is 12,(~25 feet. State permit approved o:~ 01/26/79. Brinkerhoff rig ~58. Exploratory location about 12 miles east of Kenai. State drilling permit approved 12/23/77. Tight hole. Testing on 02/06/79~ Set 5" liner from 5404'-5090'. Set 7" csg. @5,739'. Set 9-5/5" csg. Iai,lO5'. Se~ l~3-3/8" cond ,~92'. Spud ed on 11/25/7~ .~xploratory iocation abo t 45 miles west of Anchorage. Brinkerhoff rig s60. February 7, 1979 Section 2, Page 3 JUNEAU STATE BUILDING DEPT NATURAL RESOURCES ( ) Commissioner ( ) Deputy Coa~Issloner ( ) Fiscal ( ) Personnel ( ) Supply ( ) Administration DISTRICTS ( ) Northcentral Dlstrlct ( ) Southcentral Dlstrlct ( ) Southeastern District ANCHORAGE ( ) Parks R~I~ARKS: / TRANS,"; rTAL SLIP , :; ~'E l~th Av - ANC LANDS ( ) Ass't Co~Issio~er/Dlr. ( ) Deputy Director 705 W. NO. LIG LANDS ( ) Engineering ( ) Records - ANC ACTION ( ) Sign & for~eard ( ) Sign & return ( ) Necessary Action ( ) Information ( ) Plan. and Class. ( ) Admlnistrative Svcs. FORESTI LANDi ,.~ATER ( ) Director ( ) Deputy Director ( ) Land Mgmt. ( ) 14ater I~jmt. ( ) Forest Fkjmt. DEPT HATURAL RESOURCES /Planning & Research DIV MIN & ENGY I~?dqT ( ~ Director ( ) Petroleu~ ( ) Leasing ( ) Mining DEPT NATURAL RESOURCES ( ) Royalty Oll ~ Gas ( ) Contact I~e ( ) Return w/coe~ent ( ) Draft reply ( ) Your Information ( ) Circulate ( ) As requested ( ) Per phone call () IO-160 9/78 / DATE 02.001B IRev. 10/761 STATE of ALASKA TO: [-Ed Barber SCDO Bruce Barrett F & G Robert Shipley DEC Hoyle Hamilton Div. of Oil & Gas James H. Lack DMEM /~1' Acting Leasing Manag~¢ DATE: FILE NO: TELEPHONE NO: SUBJECT: January 24, 1979 LO 79-12 Pretty Creek #2 Well Chevron A plan of operations for the referenced Lease Operations was delivered to you, directly by Chevron. This is for their Pretty Creek wel] #2. Please review these operations and send us your comments as soon as possible. RECEIVED 0 Aii~ 0tl & G~s I.~l,s. k,mnmmsr.,~ Ant, borage STATE OF ALASKA JAY S. t~ND, GOVERNOR, AIASKA OIL & GAS CONSERVATION CO~!ISSION 3001 Porcupine Drive Anchorage, Alaska 99501 January 26, 1979 Re: Pretty Creek Unit #2 Chevron U.S.A. Inc. Peri, it Number 79-09 Chevron U.S.A. Inc. Attn: C. ¥. Kirkvold P.O. Box 7-839 Anchorage, Alaska 99510 Dear Sir: Enclosed is the approved application for permit to drill the above referenced well at a location in Section 33, Town, ship 14 N, Range 9 W, Well mamples, core chip~, and a nmd log are not required. A directional. survey is required, if run. If available, a tape containing the digit- ized log information on all logs shall be submitted for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and ~heir drainage systems have been classified as important for ~he spawning or migration of anadro~ous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promul- gated thereunder (Title 5, Alaska Administrative Code). Prior to com- mencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Poilu~ion of any wa~ers of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of ~he Department of Environmental Con- servation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska State Department of Labor is being notified of the issuance of this permit to drill. Chevron U.S.A. Inc. 2 January 26, 1979 To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like ko be notified so that a representative of the Commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. '. In the event of suspension or abandonment please give this office ade- quate advance notification so that we may have a witness present. Very truly yours, Lonnie C. Smith Commissioner Alaska Oil and Gas Conservation Commission Enclosure cc: Department of Fish and Game, Habitat Section w/o enct. Department of Environmental Conservation w/o encl. Dept. of Labor, Supervisor, Labor Law Compliance Division encl. Form lO-~Ol REV. 1-1-71 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN TYPE OF WORK DRILL [~] b. TYPE OF WELL OIL GAS NAME OF OPERATOR Chevron U.S.A. Inc. DEEPEN ['"] SINGLE . OT.ER Explorai;ory ruNE []] 3. ADDRESS OF OPERATOR SUBMIT IN TW' (Other insttu, reverse 5, API # 50-283-20022 6. LEASE DESIGNATION AND SERIAL NO. ADL-63048 7. IF INDIAN. ALLOTFEI:, OR TPdBE NAME P.0. Box 7-839; Anchorage, Alaska 99510 4. LOCATION OF WELL Atsurface Approximately 1590' South and 2140' West Northeast corner of Section 33, T.14N., R.9W., S.M. At proposed prod. zone qamo 13. DISTANCE IN MILES ~ND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 37 + miles west of Anchoraqe 14. BOND=llqFORMATION: ~WE Statewides,re,ya,d/orNo. U80-60-55-1 MU LTl PLE ZONE F--1 8. UNIT FARM OR LEASE NAMI'-' Pretty Creek Unit 9. WELL NO. Pretty Creek Unit No. 2 10. FIELD AND POOL, OR WILLK?AI' Wildcat 11.SEC., T.. R., M., (BOTTOM HOLE OBJECTIVE) 33, T.14N., R.9W., S.M. t2. no,,, $100,000 15. DISTANCE FRONI PROPOSED * [ 16. No. OF ACRES IN LEASE LOCATION TO NEAREST , PROPERT¥ORLE^SELINE.~. 2la0 from Lease lin 1280 (A~so to nearest drig. unit, if any) ' 18. DISTANCE FROM PROPOSED LOCATION 19. PROPOSED DEPTH TO NEAREST ~fELL DRILLING, COMPLETED, OR APPLIED FOR, FT. I Approximately 15,000 '3980' from the 17.NO,ACRES ASSIGNED N~°/~"~ {~Lacat 20. ROTARY OR CABLE TOOLS Rotary 21. ELEVATIONS (Show whether DF, RT, GR, etc.) 22. APPROX. DATE WORK WILL START Estimated Ground Level 81.9' February 5, 1979 23. E ~i S ti n g ~ko CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZ'E OF CASING WEIGHT P~R FOOT GRADE SETTING DEPTH Quantity of cement _ 26" 20" 94# H-40 339' 600 sx Class 1 Cemeni~ . . 17½" '13 3/R" 61# ij-55 2.032' 660 sx Sta~.qe Co'llar @ 1048' - 8'10 ........ Class. 1 Cement ']?~' 95/8" 43.5. 47# N-80, $95 8'55Q' 1110 sx Sta§e Collar '@ 4525' 1 ~ Class G Cement' Drilling Program Attached NOTE: Subject well is an exploratory well and we request all information Pertaining to the drilling of this well to be held CONFIDENTIAL and have limit~.,c~..a~ccess. SX '20 S: ~ ~O~ SPACE DESCRIBE PRO~SED PROGRAM: If proposal is to dee~n give data on present productive zone and pro,sod ~w productive zone. If propel is to d~ or dee~n d~ection~y. Ore ~rtinent data on sub~face locations and measured and ~ue verfi~ dEpthg Give blowout p~venter pro,am. ..~ e.~/,-. ,,~ ..... Area 0perati ons SIG~D. ~:' c /~.~?~ .... ~' ~:;~;-'~ DA~January26 1979 nTLE q,,perinfondont (This Space for State office use} SAMPLES AND CORE CIilPS REQUIRED I MUD LOG [] yES ~ NO ] [] YES O~ NO DIRECTIONAL SURVEY REQUIRED D~s ~NO CONDITIONS OF APPROVAL, IF ANY: OTHER REQUIREMENTS: A.P.I. NUMERICAL CODE 50-283-20022 PERMIT SO. 79-9~/ , · ,~?, APPROVAL DATE, APPOVED BY c' (~%.~ ...... -~. .~ TITLE ?~ ~";~ ~'"-~ ~-~;~f~"~f .................... ~See Instruction On Reverse Side Janu~ 26, 1979 DATE ,-Fmmlm~xf P6; ] 079 Chevron Chevron U.S.A. Inc. P.O. Box 7-839, Anchorage, AK 99510 · Phone (907) 279-9666 C. F. Kirkvold Area Operations Superintendent Production Department January 23, 1979 State Oil and Gas Lease ADL-63048 Plan of Operation Pretty, Creek #2 Well State of Alaska Department of Natural Resources Division of Minerals & Energy Management 703 West Northern Lights Boulevard Anchorage, Alaska 99503 ATTENTION' Mr. Tom Cook, Director Gentlemen' Chevron U.S.A. Inc. plans to conduct reentry operations in a well previously drilled as Theodore River #1 and abandoned. The well to be known as Pretty Creek #2 will be worked on in behalf of Chevron U.S.A. Inc. and Union Oil Company. In order to carry out and provide logistical support for the operation, it is necessary for us to obtain your approval of our Plan of Operation. Accordingly, we are enclosing our Plan of Operation for this project. The items covered by the plan should answer any questions regarding surface operations. If you have need for further clarification, please detail these, and we will attempt to provide answers. Your early consideration and approval of the attached plan is requested. Attachment Very truly yours, cc' Land and Water Management South Central District Attn' Mr. Ed Barber State Fish and Game Habitat Protection Attn' Mr. Bruce Barrett 100 Years Helping to Create the Future PLAN OF OPERATION PRETTY CREEK UNIT #2 PRETTY CREEK UNIT AREA, ALASKA 1 2~ Well Site and Setting. The existing Pretty Creek Unit #2 location was constructed during 1969. It was constructed by Halbouty Alaska Oil Company for the purpose of drilling an exploratory well known as Theodore River #1. The well was a dry hole to oil and abandoned. The well will be reentered to determine whether commercial natural gas production exists. The location is 1590'S and 2140'W of the Northeast corner of Section 33, T.14N. R.9W., S.M. The site is on a knoll approximately 600 feet east of the existing north-south gravel road. Some gravel fill will be required to modify the location slightly to accommodate the drilling rig to be used. Gravel will be obtained from the existing source in Section 25, T.14N., R.9W. under an exist- ing materials contract with the Matanuska-Susitna Borough. The usual drilling reserve pit will not be required since the proposed work entails reentering an existing cased well. A small waste pit will be excavated adjacent to the drilling rig to contain a small amount of drilled cement cuttings, water and mud. Location Access Access to the location area will be by way of the all weather road system. (see attached area map) No new road construction is required. A 600 foot spur road is available to the existing location. ~1, _Existin~ Roads and Airstrip All roads in this area from the Superior Landing to the south to the Ivan River 44-1 well to the north were built in the 1962-65 era by Standard Oil Company of California as operator for the Beluga River Unit as well as during the course of other exploratory activity. The Beluga River Airstrip was constructed during the 1962-63 original field development. It Will also be used in s~por..t. _of.our .proposed operations at Pretty Creek ~t2. t~, Water~ Supp)y An existing water source well at the location will be used to support our operations ...... .~,, ~ ~ ~.,.. , . 5~ 6. ~Drilling Rig We plan to negotiate with Brinkerhoff Drilling Company for the use of their Rig #58 ~hich is presentlY on the Stump Lake Well 41-33 location. An ice road has been constructed to the Stump Lake location, and the drilling rig will be moved over the ice road and existing gravel roads to the Pretty Creek Unit location. Access to Site and Method of Supply_ The site is remote and is not connected to the Anchorage area by road. The only access is by one or more of the following' A. BARGING TO THE SUPERIOR LANDING (STATE RESERVED AREA ADL-Z15327)_ During most of the year, barging is possible from the Kenai or Anchorage area to the Superior Landing and thence by truck to the proposed wellsite. Use of this landing may be required to support the proposed well work. Some of the materials and supplies required may be barged to the Superior Landing. o B. AIR TRANSPORT TO BELUGA AIRSTRIP ~he Beluga Airstrip can handle Hercules-type airplanes, and we intend using thiS method to move freight and other items as can be justified economically, in addition to barging. Since the rig uses diesel fuel, we will probably barge or fly in the fuel. Sufficient hard tankage is available to eliminate consideration of "bladder" tanks. Two 1,O00 barrel tanks are available for fuel storage on the BRU 244-4 location. An approximately 20,000 gallon fuel dump will be established at the Beluga Airstrip at the same location as existing facilities installed in 1962. These tanks are installed in a diked area which will contain any fuel spillage or leakage. Personnel Support . A camp capable of housing and feeding approximately 40 men is installed in an area adjacent to the Cities Service road to their East Lewis River location and will be our base of operations. Personnel will be flown in and out on a scheduled basis of approximately 10 days working and 5 .days off. Food and other supplies will be flown in on an "as needed" basis. Sanitation facilities for the camp, consisting of a septic tank and leach pit, have been constructed with the approval of the Anchorage Office of the Department of Environmental Conservation. An approved water well is in use at the existing camp. -2- 8~ 9~ In addition to the camt~, a house trailer has been installed for Chevron supervisory personnel adjacent to the Beluga airstrip. Miscellaneous Related Drilli..ng Items Ae The waste pit ~,~ill be located, constructed, and diked as necessary to prevent the possibility of any seepage to the surrounding terrain or drainages. Upon completion of drilling activities, the ~.~aste pit will be filled, leveled, fertilized, and reseeded with natural grasses. B~ Sanitary facilities at the rig location will be chemical toilets. These toilets will be emptied periodically and the material hauled and dumped into the camp septic tank. C~ The location is about 500' north of the nearest lakes and ponds. Our operation should not disturb the area, other than modification of the existing drill pad. Abandon. ed Dry HOle Should commerCial production not be found, the following surface restoration is planned' A~ The drillsite waste pit will be backfilled before abandoning the site. B~ ToPsoil will be spotted on the location and it will be spread over the location and waste pit area. Ce Topsoil will be fertilized and seeded with natural grasses in the spring. 10. General Comments A~ Solid wastes such as mud sacks, kitchen waste, etc., will be hauled to the central waste pit near the airstrip and buried. Other hard waste such as drilling bits, etc., will be dis- posed of in the location waste pit when it is closed and covered after drilling is finished. B. Testing Any required testing will be accomplished using approved industry techniques. No hydrocarbon fluid will be disposed of on the ground surface. Gas flow testing will be to atmosphere through approved flare equipment. Attachment: Beluga River-Ivan River-Stump .ake Area Map. · - 3- ¢ P T / L~ TIPCO ADL- S HELL- C TIPCO ! -51-79 CPT · AD L - 6:5047 TtPCO,UNION ! - :51-79 ADL- 65049 CPT UNION HBU . ADL - 5 ~'~i4 .. UNION !-50-77 CHEV · ;.2'- I~ . ~0- m5-?'5. T.D 7', 000 ' 58820 UNION IVo./ 8,~06 HBU 58804 HBU ,~. ADL-S6805 BU ', ~UL'~8806 Ti PCO I - 31 -,79 \ ADL- 6;5 48 UNION HBU UNION HBU BOUTY I ~ 12,025 /28/69. I USS UNION HBU .. ADL- 58813 UNION F.H. GRANT UNI ADL- 5 8 809 CHEVROr,, H.R / ADL-32 et al ON HBU HB~j 12 ADL-58817 -58818 HBU 5'88 21 UNION 11-;51 -82E ADL' 302915 ./ .J H~ tXDt_-33~2 SOCAL FD. i5,ZG!: IVAN R. 23-/P TD i / x'~! BELUGB, RJVER ' o,?- _~' ' / .,THEODORE R. BR/IOGE // . · Formerly .:....,'~"'"'- bouty Theodore GRAVEL PiT YCK. I IVAN'- RIVER UNIT . T.I 3 N:~R 8 W , CHECK LIST ~IDR I~-~ ?{ET,I, PEttk~ITS Yes No Remarks 1. Is the pe~_~nit fee attached ..................... "~: 2. Is well !:o be located in a defined pool .............. 3. Is a registered survey plat attached ................ 4. Is well located proper distance from. ~roperty line ......... 5. Is well ], cared proper distance from. other wells .......... 6. Is suffi¢' ~mt undedicated acreage available in this pool 7. Is well to be deviated ....................... I hem: A_pprove Date -(1) Fee : /~ :~ .'.: · operator only party_ . . . 8 Is the affected 9. Can permi~ be approved before ten-day wait 10. Does opera,or have a t~nd in force ................. tl. 55 a conservation order needed ................... 12. I~ ~n~s~r~vo approval n~ded ................. 13. Is conductor string provided .................... ~_~ 14. Is enough ceraent used to circulate on conductor and surface .... /~ 15. Will ceme:~t tie in surface and intermediate or production strings . ~_~ ~ Will ce~:~t cover all known productive horizons .......... ~ 17. Will surface casing protect fresh water zones ........... ~ __ 18. Will all <~'asing give adequate safety in collapse, tension & burst . ~ 19. Does BOPE have sufficient pressure rating - Test to 3OOO psig . (2) Loc. ,." / ii,~ 2~ t('3) Admin..' 4'/ (4) Casg. ),{ Approval Recommended: C~eo!ogy: Engineering: ~ Revised 4/14/78
