Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
172-013
STATE OF ALASKA �.F_VIS ED ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑� Suspended❑ 20Anc 25.105 2onnc 25.110 GINJ ❑ WINJ ❑ WAG[] WDSPL ❑ No. of Completions: 1b. Well Class: Development ❑� Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: Hilcorp Alaska, LLC 6. Date Comp., Susp., or a 3/17/2019 14. Permit to Drill Number / Sundry: 172-013 1319-013 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 7. pudded: June 12, 1972 15. API Number: 50-133-20239-00-00 4a. Location of Well (Governmental Section): Surface: 1641' FNL, 631' FEL, Sec 33, T7N, R10W, SM, AK Top of Productive Interval: N/A Total Depth: 1503' FNL, 932' FWL, Sec, 34, T7N, R10W, SM, AK 8. Date TO Reached: November 26, 1972 16. Well Name and Number: BCU -04 9. Ref Elevations: KB: 166.2' GL: 148.2' BF:148.2' 17. Field / Pool(s): Beaver Creek Field Beaver Creek Oil 10. Plug Back Depth MD/TVD: 12,030' MD / 11,948' TVD 18. Property Designation: FEDA028083 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 315181 y- 2433577 Zone- 4 TPI: x- N/A y- N/A Zone- Total Depth: x- 316746 y- 2433702 Zone- 4 11. Total Depth MD/TVD: 15,940' MD / 15,717' TVD 19. DNR Approval Number: N/A 12. SSSV Depth MD/TVD: N/A I 20. Thickness of Permafrost MD/TVD: N/A 5. Directional or Inclination Survey: Yes L (attached) No Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 1 21. Re-drill/Lateral Top Window MD/TVD: 12,030' MD / 11,948' TVD 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, 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 if necessary N/A 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH NHOLE SIZE CEMENTING RECORD D AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 20" 94# H-40 Surf 288' Surf 288' 26" 60sx 13-3/8" 72/68# N80/J55 Surf 2,989' Surf 2,989' 17-1/2" 2300sx 9-5/8" 47# N80/S95 Surf 12,030' Surf 11,948' 12-1/4" 2800sx 24. Open to production or injection? Yes ❑ No Q If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): /I��26. DATE (1 VE--� F� 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) N/A N/A N/A ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes LJ No s Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) 1AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: I Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity -API (torr): Form 10-407 Revised 5/2017 �„O CONTINUED ON PAGE ORIGINAL nl RB�MS,AUG 2 2 20�b � 28. CORE DATA Conventional Corals): Yes ❑ No Q Sidewall Cores: Yes ❑ No Q If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Permafrost - Base Attach separate pages to this form, if needed, and submit detailed test Tap of Productive Interval N/A information, including reports, per 20 AAC 25.071. Formation at total depth: West Foreland 31. List of Attachments: Wellbore Schematic, Decomplete Reports Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Monty Myers Contact Name: Cody Dinger Authorized Title: Dri ng!ManagerA Contact Email: cdinger@hilcgfp.com Authorized131Z_( /� Contact Phone: 777-8389 Signature:0ZK Date: OG ( / INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: 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. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: 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. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: 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. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Bax 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: 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. Item 30: 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. Item 31: 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. Form 10-407 Revised 512017 Submit ORIGINAL Only OF SUPERSEUEDAND G STCONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: Oil Gas ❑ SPLUG❑ Other ❑ Abandoned ❑� Suspended E] 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG[—] WDSPL ❑ No. of Completions: 1b. Well Class: Development Q Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: Hilcorp Alaska, LLC 6. Date Comp., Susp., or Aband.: 3/17/2019 14. Permit to Drill Number / Sundry: 172-013 / 319-013 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 T dded: June 12, 1972 15. API Number: 50-133-20239-00-00 4a. Location of Well (Governmental Section): Surface: 1641' FNL, 631' FEL, Sec 33, T7N, R10W, SM, AK Top of Productive Interval: Total Depth: 1553' FSL, 900' FEL, Sec, 34, T7N, R10W, SM, AK 8. Date TO Reached: November 26, 1972 16. Well Name and Number: BCU -04 9. Ref Elevations: KB: 166.2' GL: 148.2' BF:148.2' 17. Field / Pool(s): Beaver Creek Field Beaver Creek Oil 10. Plug Back Depth MD/TVD: 12,030' MD / 11,948' TVD 18. Property Designation: FEDA028083 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 315181 y- 2433577 Zone- 4 TPI: x- y- Zone- Total Depth: x- 316740 y- 2433699 Zone- 4 11. Total Depth MD/TVD: 15,940' MD / 15,717' TVD 19. DNR Approval Number: N/A 12. SSSV Depth MD/TVD: N/A I 20. Thickness of Permafrost MDrVD: N/A 5. Directional or Inclination Survey: Yes U (attached) No El Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 1 21. Re-drill/Lateral Top Window MD11VD: 12,030' MD / 11,948' TVD 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, 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 if necessary N/A 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" 94# H40 Surf 288' Surf 288' 26" 60sx 13-3/8" 72/68# N80/J55 Surf 2,989' Surf 2,989' 17-1/2" 2300sx 9-5/8" 47# N80/S95 Surf 12,030' Surf 11,948' 12-1/4" 2800sx 24. Open to production or injection? Yes ❑ No Q If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): GOMWDq,I Z T E -_�/-E�r2.1[FIE�t/j 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) N/A N/A N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No Q Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: I lCalculated 124 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 RBDMSL"( AUG 2 12019 Submit ORIGINAL only 28. CORE DATA Conventional Core(s): Yes ❑ No 2 Sidewall Cores: Yes ❑ No E] If Yes, list formations and intervals cored (MD/TVD, Fromrro), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071, 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No Q If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Permafrost - Base Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval N/A information, including reports, per 20 AAC 25.071. Formation at total depth: West Foreland 31. List of Attachments: Wellbore Schematic, Decomplete Reports Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Monty Myers Contact Name: Cody Dinger Authorized Title: Drilling Manager Contact Email: cdinger@hilcorp.com Authorized�jContact Phone: 777-8389 Signature : Date: /3/19 10,10— INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: 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. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: 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. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil R 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. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: 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. Item 30: 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. Item 31: 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. Form 10-407 Revised 5/2017 Submit ORIGINAL Only mACTUAL SCHEMATIC Rilcon 91as4s.1J.0 KB Dev2166.Y/ BF/GL Elm: 148.Y CPBIao.d. TOW @ 12,030' MO BOW @ 12A47 MD eventually became whipstak was installed;w@ 11,373 MD•• TD =15,940' (MD)/ TD= 15,717' (IYD) PBTD =12,031' (MD) / PBTD =11,948' (NDI 261 Beaver Creek Unit Well: BCU 04 Abandoned: 3/17/19 PTD: 173-013 API: SO -133-20239-00-00 JEWELRY DETAIL No. Depth CASING DETAIL OD I Item 1 1 12,100' 1 - I CIBP Drift Size Type Wt Grade Conn. Btm IDTop 20" Conductor 94 H-40 N/A Surface 288' 13-3/8" Surface 72 N-80 12.415 Surface 2,989' 9-5/8" Production 47& N-80,5-95, 8,681 Surface 12,030' 53.5 P-110 JEWELRY DETAIL No. Depth ID OD I Item 1 1 12,100' 1 - I CIBP u71,3 cµp Updated by CJD 08-12-19 Hilcorp Energy Company Composite Report Well Name: BCU-04RD Field: Beaver Creek County/State: Kenai, Alaska (LAT/LONG): from crane. Spot up to well house. Remove well house and set on edge of pad.,Equipment left SLB shop. Arrive on location with SLB CTU,SLB crews avation (RKB): 18 API #: 50-133-20239-01-00 Spud Date: 3/17/2019 Job Name: 1910116P BCU-04RD PreDrlll Contractor AFE #: AFE $: Activity Datel Ops Summary _ 2/8;2019 On location. Prep well house for removal. Waiting on SLB. 48 hr ROPE test notification sent to ELM. Witness waived by Amanda Eagle. 24 Hr BOPS test witness notification sent to state on 2(7/19 @ 0942 his. AOGCC rep Jeff Jones confirmed witness.,Cruz crane operators on location. Remove snow from crane. Spot up to well house. Remove well house and set on edge of pad.,Equipment left SLB shop. Arrive on location with SLB CTU,SLB crews arrive. Hold safety meeting and PTW.,Lay pit liner. Spot CTU equipment. Rig up coil unit. BOPE on well. Pipe stabbed in Injector head. 3x rain for rent tanks spotted. Ground thaw unit delivered to location and rigged up to supply tank steam coils.,Cement crews will arrive in the am to rig up. Jeff Jones will be on location for BOPE test at 0800 hrs. 2/9/2019 Arrive on location. Hold safety meeting. Review BOPE test procedure. Fill out permit to work.,Fire equipment. RU field triplex test pump loaded with 60/40 methanol. Fluid pack well stack to return tank. Change out two chiksans leaking from weep holes. Noticed wellhead did not have wing valve installed. Unable to close SSV due to direction of BOPE. Break BOPE flange and rotate BOPE.,Call AOGCC rep Jeff Jones to inform him Rig is ready for BOPE test-AOGCC Rep on location. Start BOPE test. Test all rams and valves to 250/4000 psi. Slow bleed down on high pressure tests. Highest loss was 50 psi after 5 minutes. Average loss was 35 psi after 5 minutes. Bleed off was leaking through production tree. Called out HAK grease crew.,Greased upper, lower master and swab valve. Continue BOPE test. Still having leak off. Located replacement 3 1/8" SM gate valve and had hot shot to location. AOGCC rep more comfortable with the amount of pressure drop. AOGCC rep confirmed small loss in pressure acceptable by Jim Regg due to no visual leaks while testing each valve to atmosphere.,Continued BOPE test. All valves and rams passed. Perform accumulator draw down test. Good test. AOGCC rep accepts test. Rep will be on location in AM to witness inner reel valve test. Did not test today due to having to stab on well and fluid pack with 42 bbls of water. And then having to blow reel down with N2. We will perform inner reel valve test prior to RIH for cement job. BOPE test completed.,Fuel equipment. Perform location walk through with SLB supervisor. SDFN. 2/10/2019 Obtain PTW. Hold safety meeting. Review SLB JSA.,Fire equipment. Pick injector head and 10' lubricator . RU ball catcher on CT end. Stab on well. Drop 1.125" drift ball. Fluid pack reel. confirm returns at tank. 31 bbis. Same as calculated reel volume. Pressure test Inner reel valve 250/4000 ps.. Good PT. Pop off well. Drift ball recovered.,Make up CT cementing BHA. 1.75" CC, 2x 1.75" stingers, 1.75" check valves, 2.0" ball drop nozzle. 9.615' BHA length. Stab on well. fluid pack to tank. Pressure test stack 250/4000 psi.,Confirm flow line closed. Open master and swab 23.5 turns. RIH . Initial whip 543 psi. Bleed off pressure to tank. All gas. Pump 130 bbis no returns to surface. Tag top of fill 15,170' Pick up clean 39K. Hold pre cement job safety meeting.,Mixing up chemicals in cement pump. 14:49 cement is wet. Pump 5 bbl spacer ahead followed by 23 bbis of cement. Plan calls for 21.5 bbis. Had to pump additional cement due to not being able to cleanup and send to G&I. 70'F mix water. 15.8 ppg class G cement pumped. Lay in cement from 15,170'- 14,350'. Had returns to surface when cement was laid across the per s and then lost them. Cement is in place.,POOH to surface. Have to stop and clean injector head chains. Coil is covered in paraffin and slipping on injector blocks. Cementers rigged down and off location. Tagged up at surface. Master swab closed., Pump 20 bbls out to return tank. Online with N2 to blow down reel. Reel dry.,All surface equipment freeze protected. Popoff well. Break down BHA. Stack down lubricator and injector head. Move crane to edge of location to make room for pollard E -line in am. Location secure. Note: coil was covered in paraffin. Prior to another coil intervention a paraffin treatment should be pumped. 2/11/2019 Pollard E -line arrive at office. PTW. hold safety meeting .,RU E-llne.,PT stack 250/4000 psi. RIH with 2.75" Gauge ring (drift size of 3.5" CIBP). Tag below upper master valve. Attempt to work through with no luck. Install trunk heater at wellhead. Pop off, gauge ring is full with a paraffin ball. Break off gauge ring and install 1 11/16" dart. Stab on well-RIH with 1 11/16" BHA. No issues passing through tree. Tagged TOC @ 13,710'. AOGCC and BLM waived witness to cement plug tag. Pull correlation pass. Get on depth with GLV @ 13,206'. Send PDF and LAS files to town.,POOH to surface. Break down 1 11/16" dart. Make up 2.5" Gauge ring (size of cutting torch). RIH look for paraffin to 2000'. Looks clean. Continue in hole and tag TOC 13,700'. POOH to surface.,RU 2.5" Spectra 2 Jet cutter. RIH. Run correlation pass to GLM at 13,206'. RIH to 13,633.2' cot depth. Puts cutting torch at 13,650'. Cut tubing. Good communication between annulus and tubing. POOH with E -line. At surface. confirmed torch cut. From cement top there will be a 12' stub of 3.5" tubing sticking up.,Swab, both masters closed. Night cap installed on ctu bope. Flow cross and choke skid closed. Well secure. Continue Rigging down PEST. Tomorrow coil and crane crew will be out to rig down SLB CTU #1. 2112/2019 Hold safety meeting. PTW.,Rlg down SLB CTU and Cruz Crane.,MIRU Hak hot oil truck. Fill 480 bbis of PW in supply tank. Start bleeding down IA (lift gas). Bleed down 180 psi. Shut in IA. Construction crew needs to use torch to cut flow line supports. Production night operator will finish bleeding down IA. 2/13/2019 PTW. Hold safety meeting.,Hot oil truck pluming and triplex pump frozen. Cover with tarp and heater trunk., Pt lines to 250/4000 psi. Good PT. Online down 9 5/8" IA. Taking returns up the 3.5" Production tubing. Heat produced water to 156'F to help clean paraffin from tubing walls. 860 bbis pumped before returns to surface. Pumped 900 bbis. Shut down pump. Close in Tubing and prep for state witness,24 Hr MIT witness notification sent 2/12/19 @ 13:27 hours. AOGCC Rep. Lou Laubenstein confirms witness. Start PT at 14:44 hrs 2585 psi. initial pressure. 15 minutes 2551 psi. 30 minutes 2525 psi. (end test 15:15 his. 60 psi drop over 30 minute test. AOGCC accepts test results.,Continue to circulate heated PM. 165'F at 3.5 bbls/min. Pump pressure 260 psi. Returns have cleaned up. Pump 215 additional bbis at temp. Shutdown. Freeze protect Hot oil truck with Methanol. Pump 3 bbls down IA and 3 bbis down tubing . Wellbore is freeze protected., Rig down hot oil truck. Clear Rain for rent tank heat coils. Empty tanks. 3x rain for rent tanks will be removed in AM. Pit liner folded up. SDFN. 2/18/2019 Clear snow from pad using Peak and Production loaders. Clear snow at staging pad to allow access to peak trailers. Remove metal dumpster from location, run string lines and mark pad for felt/liner/matting. Lay out fell and liner. Bring in peak crane, pick and remove 2 wellhouses from location. Bring in pushers shack and DSM office trailers, spot same., Bring in rig mats one trailer load at a time, offload and set same. Vac out glycol from line heater for moving. Set pony walls. Clear snow from around line heater skid and remove same. Set last of rig mats. Working day crew only, second crew coming Wednesday.,Rest day crew. 2/19/2019 PJSM with Peak operators and rig crew, spot cranes, bring in subbase. Stage HPU and test pump, pick and set subbase on pony walls. Center up rotary over tree. Set doghouse/water tank. Set 1-2 gen skid. Bring in carrier, pick and set same on sub. Bring in derrick, set drill line spool, pick and set derrick on carrier. Set iron roughneck on rig floor. Fire up floor motor, raised doghouse.,Raise and pin derrick board windwalls. Re -locate pusher shack on pad. Transport pits 1 and 2 from D&D to BC field. Set pit #1, set pump #1, set pit #2, set pump #2. Dig out ice and equipment from cuttings box. Set pit #3. Set boiler skid. Set transformer for office trailers, contain and wire in camp gen. Start gen and start warming up office trailers. Inspect and stand derrick mast.,Rest day crew. 2/20/2019 PJSM with Peak operators and rig crew, brought in cranes and R/U, removed snow from roof tops on rig modules. Held pre spud meeting with rig crews, rig support, and Hilcorp drilling team. Continued R/U and spotting VFD, HPU, along with both top drive generators. Hung wind walls on rig floor and pits while plugging in modules and hooking up plumbing Iines.,Spotted gas buster. Fired up rig gen sets. Put heat on rig boiler and water tank pumps for the night.,Rest both crews. 2/21/2019 Cleared snow from around rig and location, burned in new brake pads on draw -works, spooled up drill line on drum and secured on deadman, filled rig water tank (from water well on pad 3), installed vent line on poorboy degasser, set bulk fuel tank in back yard, spotted crane and pulled service loops from tubs, layed out same for PU, scoped up derrick, received MPD equipment, received wellhead section„test plug and wear ring, hung service loop horsehead in derrick, installed Handy Berm around rig footprint, took on 4479 gals rig fuel, filled boiler hotwell with fresh water, set Canrig and Baroid shacks.,Hung and tied in service loops in derrick with crane, tarped in roof over centrifuge., Fired boiler and letting warm up before putting into operation, removed drill line wraps off draw- works drum and installed back onto drill line spool. Continued to clean rig floor and pump room of ice and snow. 2/22/2019 Warmed up crane and hung service loop saddle in derrick, hung last of service loop with crane, shut down and held environmental/wildlife compliance meeting with Drilling Environmental Compliance Specialist Keegan Fleming and Drilling Tech Cody Dinger. Hilary Garvey did boiler exhaust VE reading. Set Sperry shack, set 400 bbl upright tank at rig, set MPD choke skid, set felt/liner for catwalk„set catwalk and beaver slide, installed torque rail "T” bar, staged torque rail sections on catwalk for PU, removed topdrive from shipping container, start steam throughout the rig, PU and MU torque rail.,Continue to PU torque rail and then hang top drive, remove shipping blocks from top drive, started tying in service loop to top drive. Built handy berm around cat walk and choke hose, started installing 5” liners and swabs in rig mud pumps.,Plumbed water and steam to modules, hooked up koomey lines, aired up boots in pits and mud pump suctions. Installed bull plugs in centrifugal pump snails and checked and filled agitator gear boxes. Finished chinking in pits, continuing to ready pits far Fluid acceptance and got lights and heaters running in cellar. 2/23/2019 Cont install of service loops and Kelly hose to topdrive, removed shipping beams from sub, RU Pason on rig, office trailers, doghouse and service shacks, dressed #2 pump with 5" liners, brought in BOP stack, picked slack off cradle with crane, removed single gate and spool, hung stack on cellar trolly, line 400 bbl upright and MPD choke skid for berming„cont stringing cordage for topdrive VFD, hung Geronimo line in derrick with crane, hung bales on topdrive. Cont RU/troubleshoot Pason system, installed steam heaters in pits, wired up bolts on service loop at the board, put socks on mast lift cylinders. Installed rig floor stand pipe manifold, bleeder, and hung make up tongs. Cleaned out drilling conex, choke house and got steam running in choke house. Started thawing ice from rig baskets„Hung tarps on both ends of sub base, rigged up steam heater in the pits and cellar to start warming them up. Bermed up MPD choke house and vertical 400 bbl water tank on pad 3. Spotted C&D dumpster, located and started warming service loop tarps. Slipped 175' of drilling line back onto spool. 2/24/2019 Installed panic line off choke manifold, serviced and repaired hydraulic valve cluster on rig floor, assembled pipe skate buggy and functioned skate, cont hanging tarps and thawing pit bottoms, thawed service loop sock, gathered and secured service loop lines, installed camera on doghouse, finished install and tested Prion in service shacks, electrician replaced worn,control cable to iron roughneck and hard wired topdrive cable to control panel in doghouse , mechanic hooked up of cables to VFD house, plug board and gen sets, started pump motors, installed service loop sock, dressed rig floor with tongs/snub lines, notified SLIM of possible BOP test Tuesday. Troubleshoot breaker #9 in VFD house (keeps tripping).,Identified possible issue in top drive control panel cord, the seven pin female end was grounding out inside the plug, continuing to work through problem with rig foreman and NOV field service supervisor. Continued to thaw out pits, organized tool room on rig floor, and put 2” high pressure hose in cellar to warm up. Silicone front and sides of rotary table„organized parts conex, and brought in 90 bbls of water into pits 9&10 run pumps and agitators while checking for leaks. Hooked up communication in mud lab for all service companies and rig floor, cleaned koomey room, got TIW and dart valve to rig with the sub rack. Fixed tarp on dog house, gathered up swing and quarter turn valves for circulating well. Continued to work on rig acceptance checklist. 2/25/2019 Continue to circulate water around pits and function valves, hoppers, guns. Replace suction rubber and gun line valve. Replace 6” transfer hose between hopper rooms. Continue work on rig acceptance checklist. Continue cleaning and organizing throughout the rig. Hardwire the e -stop cable to topdrive console and plug into VFD house. Troubleshoot and resolved iron roughneck functions.,Expediter worked on getting topdrive hydraulic motor starter switch ordered and goldstreaked to Kenai ASAP (Wednesday). Open cover on topdrive for electrical inspection. Offload 40 bbls produced water into pit 96. Prep BOP studs for NU stack, calibrated flow sensor.,Cleaned oil up in generator house #3, pulled wires off top drive and inspected them for any issues and then reattached. Cleaned up quarter turn valves and swings for up and coming circulating, lest run trip tank pump, changed light on top of dog house, heat traced the shock hose from the pump room to the sub base, cleaned and organized lube room -Clean up test pump and functioned, pulled inventory of mud pump parts, continued to work on rig acceptance checklist. Cleaned out hot house, thawed out pipe rack on rig floor and laid down mats, put together fittings for annulus, and continued to melt ice around rig on rin mats. 212612019 Electrician removed HPU hydraulic starter switch, found it's terminals to be extremely dirty, cleaned it up, re -installed and hydraulic pump worked. Hydraulic oil heat exchanger radiator on HPU started leaking oil. Shut down and removed radiator, started pump and topdrive has robotics. Rigged up Production bleed tank to 9 5/8” x 3 1/2" annulus and bled gas for 2 M. hours. Had no pressure on annulus at,start of bleed off (tried two gauges), had 40 psi on tubing at start of bleeding annulus, still had 30 psi on tubing at end of bleed off. RD bleed tank and MU 2" high press hose from annulus to poorboy degasser. MU high press hose to top of tree from kill line. Primed both rig pumps and test ran. Vacuum degasser access panel was opened, inside of vessel inspected, all OK.,Swaco Rep removed shipping blocks on centrifuge and test ran, all ok. Agitator in pit #6 was running backwards, Electrician solved that issue. Mechanic attempted to install radiator on HPU but it was too large, so other measures will be taken to fix that. Updated BLM for noon Wednesday for BOP test. Notified AOGCC at 11:45 am of BOP test on Wednesday. Checked topdrive gear oil, function tested OK, installed saver sub,and clamps, adjusted grabber, installed link tilt clamps on bales -Broke circulation at 115 gpm-307 psi. with 23 bbls away had returns at poorboy degasser (vessel holds 14 bbls, possum belly holds 1 bbl) so filled 8 bbl void in annulus. Had good amount of crude so overboarded first 5 bbls to cuttings box, then cont taking returns to pit #7. PSI dropped to 185 fairly quick. No loss, no gain. Called out wellhead Rep with BPV.,Staged pump up to 257 gem -919 psi with 19% return flow, we had clean fluid half way through BU, circulated to BU at 14,000 stks and shut down pumps .,Monitored well for 30 min, well was static, shut in both master valves on annulus and tubing, rigged down high pressure hoses off annulus and tubing, opened tubing master valve to verify well was still static, removed flange by 1502 off top of tree, wellhead Rep set back pressure valve.,Held PJSM, nipple down tree, wellhead Rep installed bull plug in neck of hanger to seal off SSSV control line, made up blanking plug into top of hanger.,lnstalled spacer spool on top of tubing head, slabbed and set BOP's on top of spool, and started to nipple up BOP's, Cleaned pits 4-6 and 9-10 and started filling with fresh water for building of new mud, continued to NU BOP'S, hooked up choke and kill line hoses, hooked up koomey lines, checked pressure in all koomey bottles, installed 1502 plug on annulus,with needle valve and gauge.,, Accepted rig on the 26th at 1800 Inns 2/27/2019 Cont nipple up BOP stack, installed drip pan, flow riser and flowline. Function tested BOP's. MU 3 %" test joint and assorted XO's, TIW and dart valves. Flooded surface lines, purged air and attempted a shell test. Had a couple leaks on XO top of test joint. Pulled test joint and tightened XO. Installed test joint, held good at 250 psi, had leak on kill and choke lines at 4000 psi. Tightened connections on stack and had,successful shell test at 250/4000 psi. Called out AOGCC Rep Jeff Jones. BLM Rep Quinn Sawyer on location, Total Safety Rep Tom Feaster on location. SIMOPS mechanic installed HPU hydraulic heat exchanger radiator. Electrician wired in Beyond MPD choke skid to rig. Brought in Production bleed tank and bled off the 40 psi on 9 7/8" x 3 112" annulus. Added more produced water to pits. Jeff on location at 16:30.,Got word the turbo for floor motor was delayed in Memphis, did not arrive as planned today. Supposed to be in tomorrow, Thursday 2-28. Cannot pull tubing until turbo is changed out (oil leak)., Performed initial BOP test at 250 low for 5 min each, 4000 high for 10 min each, 250/2500 on annular (Good test). Test #2 upper pipe rams, kill, mezzanine, dart valve and CM, - 1,2,3, and 11-25011ow for 5 mins. 4000/High for 10 mins (Good test). Test #3 TIW valve, kill HCR, CM valves 5,6,4, and 8 25011ow for 5 mins 4000/high for 10 mins and had to trouble shoot for leaks and induced,air due to bad low tests, found that CM valve #6 had trapped air in CM. Got a good test after we worked out air. Test # 4 upper pipe rams, inside kill, and TIW valve CM valves 7,9, and 13-250/low for 5 mins. 4000/High for 10 mins (Good test). Test #5 upper pipe rams, inside kill, and CM valves 7,10, and 12-250/low for 5 mins. 4000/High for 10 min (Good test). Started to mix new mud while testing.,Test #6 upper pipe rams, inside kill, choke HCR, and TIW valve-25011ow for 5 mins. 4000/High for 10 mins (Good test). Accumulator drawdown- Accumulator initial -3040 psi/final-1650 psi, Manifold initial -1440 psi/final-1440 psi, Annular initial -970 psi/final-1020 psi. Recharge time to get 200 psi/15 sec, final Accumulator pressure 3040 psi/79 sec.. Avg. pre charge pressures on bottles is 2,500 psi., Went to perform test #8 after draw down test and notice we had frozen up the test hoses and test joint due to extreme temperature drop, Decision was made to stop testing, AOGCC Rep Jeff Jones and BLM Rep Quinn Sawyer would be back at 9:00 am to resume testing. We started thawing out test lines, test joint, TIW, Dart valve, and choke line with tarps using heaters & steam blankets. 2/28/2019 Thawed and blew down test hoses and choke line. Blew through topdrive to verify it was clear. Wrapped choke shock hose and degasser hose with return steam hose from catwalk and wrapped in felt blanket. Flooded surface lines and purged air. Had AOGCC Rep Jeff Jones and BLM Rep Quinn Sawyer on location to witness testing.,Tested super choke and manual choke on choke manifold at 1500 psi. Bled down and caught pressure as per BLM Rep. Fail pass on super choke. Tested manual choke on mudcross, blinds and both IBOP valves on topdrive at 250 low, 4000 high. Fail pass on manual choke valve. Testing complete at 14:00 hm.,Blew down and RD down surface lines, topdrive and test equipment. Expediter checked on status of floor motor turbocharger in Anchorage, package arrived empty. Turbocharger was re -ordered and is to be in Kenai by 3PM 3-1-19. MU landing joint to blanking plug and removed same from tubing hanger. Broke down blanking plug and XO. Troubleshot ironroughneck. Electrician found HPU electric motor starter switch was bad.,Cont pre- mixing water based mud in pits 9-10. Took on rig fuel. Beyond MPD Reps MU hardline from choke skid to rig sub for use Iater.,Finished mud in 9-10 and started mixing new mud in 4-6, Cleaned and organized tool room on rig floor, Accumulator room, and lube room. Hooked up 2" bleeder line to flow line, rigged up trip tank hose to riser nipple, put 3 1/2 EUE thread protectors for tubing string in hot house to warm up.,Chipped ice around rig modules and spread ice melt in high traffic areas to mitigate slip hazards , cleaned and scrubbed inside of boiler room. After replacing starter on iron roughneck HPU discovered electric motor was bad and needed replaced. 3/1/2019 Dressed topdrive for 3 1/2" tubing handling, replace electric motor on iron roughneck HPU and test run (OK), replaced turbocharger on floor motor with the old one off old motor, warmed up and test ran, seems ok with empty blocks. With roughneck working, broke down TIW/Dart/side entry sub and XO from landing joint. Broke blanking plug and XO off bottom of landing joint. Cont mixing water based mud. Called out wellhead Rep., Notified Weatherford for upcoming tubing pull. Checked annulus for any pressure build (none), prep'd "T" bar to retrieve BPV from hanger. Pulled BPV, filled hole and monitored 15 min, well appears to be static. MU 3 1/2" landing joint with CDS-40 XO on top into hanger. MU topdrive. BOLUs.,Unseated hanger with 110K, pulled hanger through rig floor, started to circulate bottoms up, had CO & combustible gas alarms sounded and 65% LEL seen at gas monitor, closed annular and continued to circulate through the poor boy gas buster with a wide open choke. Max PIU seen 116K.-SPM=60, SPP=308, GPM=146.,Pumped bottom up 14K strokes, shut down pump and flow checked well, well was static. Blew down top drive, mud pumps, choke, and sucked out poor boy gas buster.,Held PJSM with Weatherford on rigging up there equipment, rigged up Weatherford power longs and hydraulic slips, held another PJSM with Weatherford and rig crew on UD tubing hanger and tubulars.,Broke out & UD CDS-40 XO on top of landing joint and out of top drive, terminated control line from hanger, UD landing joint and tubing hanger, circulated across top of hole keeping hole full, started POOH F/13,650', UD 3.5" tubing and GLM, removed 250' of control line and 10 banding clamps from tubing, monitoring pipe displacement on trip tank..,While moving Vac truck to back side of rig Peak Vac truck operator notice truck leaking produced water/oil from hatch on vessel, he proceeded to get duck pond under leak to contain it, estimated amount was less than a half gallon, we property cleaned up the spill and reported right away to Hilcorp safety Rep Matt Hogge. After further investigation we found vessel hatch clamp had come loose. 3/2/2019 Continue Pooh I/dn 3-112" gas lift completion w/ calculated hole fill f/ 9744't/ 7155' ( Pipe ID very good, Pipe OD still coated in + 1/8" paraffin having to rough neck scrape wire ),service rig grease blocks TDS and crown while repairing leak on oil cooler on TDS HPU,Continue Pooh I/dn 3-1/2" gas lift completion f/ 7155' t/ 5560' w/ calculated hole fill ( Pipe ID very good, Pipe OD still coated in paraffin but appears to be getting better not having to scrape wire any more ),Inspected and adjusted brakes and Iinkage,Continue Pooh Udn 3-1/2" gas lift completion 1/5560' U 5080'w/ calculated hole fill( Pipe ID very good, Pipe OD still coated in paraffin and about the same still not having to scrape wire any more ),Finished UD 3.5" gas lift completion string, with complete recovery to cut, 1 cut half joint, 420 joints of 3.5 tubing, 30 pups, 13 GLM, and 1 SSSV. complete completion string was coated with a 118" of paraffin wax., had proper hole fill during whole trip, R/D Weatherford tongs, Cleared and cleaned floor.,Held PJSM with Pollard wireline, RU wireline shive & wire in derrick, PU gauge ring 6.96 OD, junk basket, CCL, weight bar, and rope socket, RIH and set down at 12,345' wireline measurement, attempted three times with gauge ring tools, lost footage every time with no overpull or stickiness observed, POOH with wireline and R/D.,Tools were covered with a light coat of paraffin wax and a few balls in junk basket.. RU to test rams & annular on 4.5", Notified BLM and AOGCC to test BOP's. Called out Baker tool Rep Clint Pettit to PU tandem scraper and a drift run. 3/3/2019 PJSM, Continue r/up test equipment. flood test jt w/ water and purge air and shell test w/ 4-112" jt U 4000 psi (ok),Test annular 250L 5 min /2500H 10 min and VBR 250L 5 min /4000H 10 min on chart both good and send paper work and chart to BLM as per regulations, Rl do test equipment and blow do equipment as needed,Load pipe racks w/4-112" CDS-40 S-135 17.8 ppf dp and verified count was in field, 36.8 ppf HWDP strap and tally pipe and bha and install mouse hole chg out turbo to new one on dwks mtr,PJSM and attempt P/up Bha #1,Trouble shoot Elect over hyd valve body system for m/up and brk out tongs found and replaced faulty solenoids ( chk and confirm torque of tong line pull, IR and TDS against each other ok ),Resume p/up and m/up of bha #1 = 6" bit + 7" scraper + BS w/ float + XO + 18 jts 4-112" HWDP + 31 jts 4-1/2" dp + XO + DBI pin + 9-5/8" scraper + BS + 8-3/8" upper window mill + jars + Xo = 1584.27',TIH F/1,5091 -T/3,900', PU 4.5" DP of the walk, strapped and rabbiting every 10 jts with a 2.35 rabbit. Remove ice from the containment around the rig.., Lined up and CBU at 3,909, brought on both pumps at 3 bbls per/min and staged pumps up to 6 phis per/min-GPM 506, SSP 1,332, Flow 45%, PU wt -74K, SO wt -72K. Pumped BU and had a minimal amount of paraffin coming across the shaker during circulation. Flow checked well for 10 mins, well was static, max gas 997 units.,Cont RIH F/3,900'- T/4,328', float stuck in the wide open position, fluid started U -tubing out of pipe„lined up to the pumps and started circulating to clear float , pumped a STS, gas climbed to a max of 2,045 units. Flow checked, well was static but still flowing out of pipe. Line up and pumped another BU.,Shut down the pumps and flow checked again, well was static with no U -tubing out of pipe. GPM 492, SSP 1,259, Flow 42%, PU wt - 76K, SO wt. -74K, Blew down top drive, cont. PU pipe & TIH F/4,326 -T/5,952', PU-95, SO -93, with no drag. Had Peak skim oil off top of suction pit. 3/4/2019 Continue p/up rabbit and strap 4-1/2" CDS-40 dp and rih w/ Bha #1 H 5952't/ 8001',Kelly up brk circ and stage pumps U 6 bpm @ 530 psi and circ surface to surface w/ max gas 986 units and trending do w/ > i bbl of BB sized balls of paraffin in returns adjusted weight indicator and pason weight to proper weight of TSD and block 25k & swap out pop -off on #2 mp for back up one and rebuild bad one while circ, monitor well static,Continue p/up rabbit and strap 4-1/2" CDS-40 dp and rih w/ Bha #1 f/ 8001' t/ 11,390' PU=178K SO=180K,Held PJSM over TIH w/ tight tolerances & scraper assembly inside 7' liner, verified pipe count TTL=430,Continued p/up rabbit and strap 4-1/2" CDS-40 dp and rih w/ bha #1 F/11,390'-T/11,635' PU=180 SO=180,Notice link tilt "U" bolts interference w/ linkage, looked up specs in the manual and discovered the measurement from the center of bail eye to the link tilt bracket was to 31.9 inches, loosened "U" bolts & bracket on bails, slide bracket & "U" bolt higher on bails to keep link tilt arms from making contact with "U" bolt threads and nut, problem was solved.,continued to PU 4.5" DP and TIH, F/11,635'-7/12,187', shut down and lined up to circulate STS just above top of 7" liner hanger.,Kelly up brk circ and stage pumps t/ 12 bpm @ 2027 psi and circ surface to surface wl max gas 1012 units and trending do w/ X1/4 bbl of BB sized balls of paraffin in returns, obtain samples for Joe Kaiser monitor well static, SPM=207 GPM=502 SSP=2027 PU=180 $0=180, Flow=-43%. Blew down lop drive,When to PU and TIH with 4.5" DP, when the derrick hand noticed we had a glycol hose on mud pump motor #1 spring a leak and spill 3 gals of glycol in the rig containment, shut down and cleaned up spill, removed and replaced hose, notified HSE Rep Matt Hogge.,Continued to PU 4.5" DP and RIH F/12,187'- T/12,996, set down 30K and hydraulic jars tripped, PU & Kelley up, bought pump on at slow rate 3 bpm to establish circulation, staged both pumps up to 12 bpm, kicked in rotary RPM=30 and set torq to 4K,, Began washing and milling, had to mill F/12,973'-T/12,976'. F/12,984'-T/12,988', 12,994'-T/12,996', washed F/12,996- T/13,002' with no torp. Torqued up from 3-7K while mill, back reamed stand, seen every tight spot on the way up, drifted back to bottom with no drag. POW=203K SOW=202K,Continued to PU 4.5" DP and TIH on elevators F/13,002'-T/13.110' and set 1 OK. While RIH Peak lead hand informed us that we had a 2 gal spill of glycol on pad #3 from the Peak vac truck while filling up with water from the water well, truck had a duck pond under the engine, vac pump, and the valves in the back, radiator hose appeared to have split and blew coolant,into the fan motor and all over the wheel while he was doing his 360 degree walk around, mechanic is location to verify issue and check all rolling stock, spill was cleaned up and HSE Rep Matt Hogge was notified.,Milled F/13,009'-T/13,115' w/ torq set at 10K, had 3-10K torp GPM=507 SSP=2376 Flow--43% SPM=209. Continued PU 4.5" DP RIH on elevators, F/13,115'- T/13,153' and tagged up, Continued milling F/13,153'-T/13,160' SPM=209 GPM=508 SSP=2346 flow=43% 3/5/2019 Continued milling F/13,115'-T/13,167' SPM=209 GPM=508 SSP=2346 flow=-43% Tq F/ 5-10k @ 30 rpm,Not making any more footage and Stalling top drive @ 1 Ok shut do pump set do 30k and trip on jars once and had pull 30k over and fire up jars to get free up/dn/rot 198/198/180 k,Monitor well static while clearing catwalk and prep to I/dn dp and blow on lines and discuss options with town, Pooh I/dn 4-1/2" dp f/ 13,168' U 12,259',Sewice rig grease top drive , blocks, crown and DWK & chg out leaking oil cooler hoses on dwk mtr. Monitor well static during sewice,Continue I/dn 4-1/2" dp f/ 12,259' t/ 11,451' (total 56 its Vdn and 1st 28 its moved off cat walk and placed on containment and timbers in front of drilling office trailer 2nd 28 its on off drillers side cat walk, Pooh and rack back in derrick f/ 11,451' t/10, 497' found four bad its and I/dn same,James Sweetsir and mech Leif adjusted dolly extend/retract pressure and house cleaning and rig maintenance while waiting on Dukowitz hands to arrive w/ thread gauge PTSM w/ night crew and Go over Hilcorps expectation #1 of drilling contractor personnel tell it was perfectly clear to all hands,Hand meeting w/ Dukowitz hands after they had a chance to inspect the pipe we UD (56 its), decision was made to break every connection and inspect pin end for galled threads, if threads are galled UD that joint and the one below it to be sent in for service, if the threads only have burs or sharp edges we will polish the threads with a special unitized polishing disk on a die grinder provided by Dukowitz.,Once threads are polished, remake connection and torq up, break connection again, inspect threads for burs or galled threads. If all looks good continued process at every connection, racking back all good stands and kicking out any bad its to be serviced. Making sure to keeping good track of pipe count-While waiting for unitized polishing disk to arrive from Dukowitz, worked house keeping around the rig, separated bad thread protectors out, cleaned around sub base, sorted oily waste bags, put felt over baskets to keep out snow, cleaned out hopper house, organized boiler room and pits, cleared all walk ways of trip hazards, cleaned up accumulator room, MP's, HPU's, OWK's„inspected all steam trap disk, and continued to mix batch #3 of new mud.,Held PJSM, attempted to polish threads on pin end, make and break connections, inspect pins, to no avail pins were more galled than the first time, called town and decision was made to inspect every jt while TOOH and UD all bad it's, steaming & cleaning box and pin end to send to Tubo scope for redressed. 3/6/2019 New crew on board chg out PJSM and inspect rig and equipment .,Continue Pooh steaming & cleaning and inspecting both pin and box end and UD and sorting all good & bad it's, to send to Tubo scope for inspection. f/ 10299' U 8845,Continue Pooh steaming & cleaning and inspecting both pin and box end and UD and sorting all good & bad it's, to send to Tubo scope for inspection. f/ 8645' 6391' did inspect TDS new saver sub (threads are sharp and needs chg out but not galled ),Held PJSM on TOOH & UD bad it's and standing good stands back in derdck„TIH out of derrick w/ 13 stds, POOH F/7,167'-T/6890',and UD and sorting all good & bad jt's, to send to Tubo scope for inspection, we also hung & installed roughneck heater in pfts.,POOH F/7,167'-T/6890', UD and sorting all good & bad it's, to send to Tubo scope for inspection.,PU 24 jt's of good 4.5" DP of walk, and TIH, out of the 24 good it's we end up kicking out 6 bad jPs.,POOH and rack back 9 good stds of DP in derrick, and ended up kicking out 6 bad jt's of our original 24 good jl's for bad threads on the second time around.,Continued POOH checking threads on box & pin on every connection, DP threads proceeded to look good so we started racking back stds in the derrick F/5,964'-T14,011',TIH w/ 14 good jts we had set aside, F/4,01 l'-T/4,438'. Worked on suction valves in pill pit # pit # 7, POOH F/4,438'-T/2,991', Out of the 14 good jfs we PU we had to LD 2 bad ones on the second run, continue to steam, clean, and re check box and pin on each connection. Continued to kick out any bad it's we come across and racking back the good stds in the derrick. Total good pipe racked back in derrick is 61 stds (3,784'), best case scenario we are going to have 6,775' of good pipe, total bad its kicked out 202 jt's.,Commutive bbls haled to G&1=355 bbis 3/7/2019 Crew chg out and PJSM (202 its bad pipe , 61 std in derrick good ),Continued POOH checking threads on box & pin on every connection, Started getting bad treads again I/dn bad and rack back 3 more std of good pipe (total good pipe rack back 64 std),Switch back U Pooh steaming & cleaning and inspecting both pin and box end and UD and sorting all good & bad jt's, to send to Tubo scope for inspection. f/2588' U 1508',work upper bha I/dn and inspect jar, xo, 8-3/8" mill and 9-5/8" scraper assy ) did not appear that mill or scraper did much if any work in 9-5/8" clear and clean floor, Resume Pooh F/1,458'-T/1093' steaming and cleaning and inspecting both pin and box end and UD and sorting all good & bad it's, to send to Tubo scope for inspection.,Rih w/ all good pipe on ODS pipe rack 22 jts,POOH checking threads on box & pin on every connection, and racked back 8 good std, and/dn 5 bad it's out of 22 jts. Continued to POOH UD sorting pipe to HWDP..,Continued sorting pipe to HWDP, POOH F/599-T/surface, racking back HWDP in derrick and UO crossovers, 7" scrapers, bit sub, and bit. Bit was 1/16 out of gauge w/ no broken teeth.,Cleaned and cleared rig floor, RU test chart & test pump, PU test it, MU TIW & dart valve, drained stack, and set test plug w/ annulus valve in open position, filled stack, flooded kill, HCR, and choke-Actuated bag, rams, inside manual's, HCR's, and all choke vales to purge the system.,Test #1- annular 250 low-2,500 high (Good), Test #2- upper pipe rams, CM valves (1,3,4,5,7,&8) mezz valve, dart & Hyd IBOP 250 low- 4,000 high (Good), Test #3- CM 3,2, 6, & 8, kill HCR, TIW, and lower IBOP, we had a F/P on 250 psi low test due to CM valves 4&6, serviced and functioned valves, 250 Low-4,000 High (tested).,Test #4- inside kill, CM 7, 9, 11, & 13 250 Low-4,000 High, (Good) Test #5-CM 7,10,12 (Good), Test #6-Choke HCR (Good),Total bad it's loaded in pipe bunks 252. Total good stds in derrick 72 (4,466'), with 9 good it's on pipe rack. Total good HWDP in derrick 9 stds (56T), with 3 good jt's at staging yard. we also have 25 jt's never PU in pipe bunk in field, estimated good footage in field 6,057' Commutive bbls hauled to G&1=355 bbls 3/8/2019 Held PJSM w/ rig crew, started test #7- inside choke. CM valve 8, lest was a F/P, had to service and function inside choke.,test #8- koomey draw down - Initial Accumulator 3,050 psi, Initial manifold 1,475, after functioning annular, rams X2, HCR choke & HCR kill, Accumulator psi was 1,650 & manifold psi was 1,400. It took 18 seconds to build 200 psi on Accumulator & 88 seconds to reach 3,000 psi on the Accumulator.,Test #9- Blind rams, was another F1P due to air in rams, functioned rams, tested good. Test #10- super choke (Good), test #11 -manual choke (Good). Blew down, choke manifold, kill and choke lines, and RID testing equ.,Monitored well with trip tank, broke out dart valve & TIW valve from test jt, cleared and cleaned rig floor and prepped for wireline.,Held PJSM w/ Pollard, RU Pollard wireline , First RIH was a 9 5/8 gauge ring (8.12 OD), junk basket, set down at 11,743', had 15K over pull and had to jar it loose. POOH and had little metal on the CCL but nothing in the junk basket.,Second RIH was a 7" gauge ring (5.61 OD), and junk basket, set down at 13,685', which was 35' deeper than the wireline tubing cut, POOH with no issues and had nothing in junk basket.,Third RIH was with a 5.61 OD CIBP for inside the 7" liner, CCL detected a collar at 13,005.6', set CIBP at 13,000' with weight drop, Picked up high and verified with tag (Good), POOH and verified Cl BP had released., Held PJSM w/ Pollard, PU 40' cement bailer (5" OD), staged cement buckets & water on rig floor for mixing cement, RIH 35'w/ cement bailer, mixed 17 ppg cement at rig floor, filled bailer, RIH and dumped first load of cement on top of Cl BP at 13,000'.,POOH w/ wireline bailer assembly for 2nd load of cement.,Mixed up 2nd batch of 17 ppg cement, filled bailer wl cement, RIH w/ 2nd load of cement.,Once at depth we dumped 2nd load of 17 ppg cement, POOH and RID Pollard wireline.,RU test equip to preform casing test, started pressuring up casing to 2,850 psi, took 13.15 bbls to reach pressure. Installed retaining plates on the "U" bolts for the link tilt arms -Held for 35 min on chart, after 35 min pressure dropped to 2,700 psi for a loss of 150 psi.,Bled down pressure on casing, volume return at zero on pressure gauge was 8.9 bbls, which was a difference of 4.25 blots from what we initially pumped.,Called town to confirm the chart test results, decision was made to retest 9 5/8 casing & 7" liner. 3/9/2019 Crew change and PJSM Continue monitor csg test #2. that had been pressure up w/ 10.7 bbls U 2790 psi > 2650 on chart for 30 min w/ 140 psi loss bled back 9.1 bbls, difference of 1.56 blots ok,Inspecl and clean w/ wire brush 25 jts of non run DP. Culled 4 jts while Chg out saver sub„bha #2 = PU and MU Johnny Wacker on btm of HWDP, Rih w/ hwdp out of derrick. p/up DP, Make and brake clean and inspect every connection, p/up storm prk an set top of valve @ 92.61' up/dn 44/40k laid out 1 bad jt hwdp, out of 21jts dp p/up 11 jts and laid out 10 bad ones wl 1087' pipe below the packer (8.5 stands hwdp 9 std die ),R/up t/test flood and purge air form lines close blind ram and pressure up w/ less then 114 bbl pumped 2610 > 2595 psi in 20 min ok,Held PJSM over N/D BOP's, proper tools, hand placement, tie off over 4'and line of fire.,Removed flow line, flow box, flow nipple, Bled down koomey lines & isolated, remove koomey line and tagged line for proper placement, N/D stack from spacer spool, removed spacer spool from top of tubing hanger spool, removed tubing hanger spool from wellhead, dressed top of tubing hanger spool. Welders fixed four suction valves in the pits and worked on the bottom of the beaver slide.,Brought in new tubing hanger spool, stabbed, set, and NIU to wellhead, pressure tested hanger, 250 psi Low 10 min - 2,500 psi High 10 min (Tested Good), slung & tailed in new single gate rams, stabbed & set, N/U single gate rams to tubing hanger spool. Finished containment around 5,000 gal diesel tank., -Hauled 0 bbls solids to KGF G&I Cumulative: 0 bbis -Hauled 90 bbls fluid to KGF G&I Cumulative: 445 bbls -Hauled 0 bbls cement to KGF G&I Cumulative: 0 bbls -Daily downhole losses: 0 bbls Cumulative:0 bbls -Daily metal: 0lbs 0 lbs 3/1012019 Crew change PJSM, Continue to stack up triple bope stack, turn stack to hook up choke and kill hoses & torque stack bolts to spec. chg out inside manual kill valve. Electrician chased tds electrical issues on top drive, install Teflon guides on skate buggy.,Continue nip/up remove 4-1/2” solid body rams from old single gate and install into new single gate, hook up koomey hoses,Held PJSM wl MPD, NU Beyond MPD rotating head, flow nipple T and large orbit valve on the flowline to the shakers, changes lube oil fitter on top drive, cleaned up in sub base.,Crew change PJSM, Buttoned up turtle shell on top drive, installed TD test sub, centered BOP stack, re -configure flowline to run over top of possum belly, installed second orbit valve on side flange on flowline, installed MPD vertical hardline to orbit valve. Installed MPD hardline from catwalk over to vertical hardline, tied MPD lines into annulus w/ hardline and a three way T w/ three quarter turn valves -Removed MPD test plug on top of rotating head, PU & MU test jt, TIW, dart valve, and test plug, pulled inner bushings, chained down BOP stack, took RKB measurements, energized koomey, configured new stack on digital koomey screen in doghouse, function tested koomey, checked for leaks on BOP, greased CM valves and functioned them, modified possum belly splash guard plate to ft reconfigured MPD flowline., Flooded BOP stack, choke lines & CM valves, kill lines, and TD w/ water. Removed valve off old tubing hanger, and cleaned it to be sent back to valve & wellhead shop., Preformed shell test against upper pipe rams to 4,000 psi (Good test), re -purged to shell tested against annular, inside choke, inside kill, and dart valve to 2,500 psi (Good test), started BOP test, Test #1- Annular 250 psi Low - 2,500 psi High (Good test). Test #2 -Upper pipe rams, CM# 1,3,4,5,7,& mezzanine kill valve, dart valve & hydraulic IBOP,tested to 250 psi Low - 4,000 psi High, isolating back to find leak or air., -Hauled 0 bbls solids to KGF G&I Cumulative: 0 Iles -Hauled 90 bbls fluid to KGF G&I Cumulative: 535 bbls -Hauled 0 bbis cement to KGF G&I Cumulative: 0 bbls -Daily downhole losses: 0 bbls Cumulative:0 bbls -Daily metal: 0 Itis Cumulative: 0 lbs 3/11/2019 Crew change PJSM continued to isolate back looking for leak or air. Purge air out of choke manifold and lest to verify CMV # 4 and #6 are not leaking (Good). Retest #2-leaking off isolate TDS and retest #2 Upper pipe ram CMV # 1,3,4,5&7 Mea Kill, dart valve (Good), purged air. test #3 UPR , CMV #2,4,5,6,&8 Kill HCR, TIW, and hyd IBOP (Good), purged air from CM.,Test #4- UPR, Inside kill, TIW and CMV # 7,9,11,&13 (leaked 250 psi) service inside kill and re-test #4 OK Test #5- UPR , inside kill , CMV# 7, 10 & 12 (Good), Test# 6 tool pusher did not like low test, purged air & re-tested #6 UPR, inside kill , choke HCR , TIW ok, Test #7- UPR inside choke inside kill, tiw, 250 psi leaked purge air and retested ok , test#8-LPR, TIW valve ok„Test #9- blinds, out side mea, inside choke, lower IBOP (leak 250 psi ) isolate lower IBOP test blinds ok, Test #10 -elect choke U 2000 Psi bled U 1400 psi ok. test # 11-manual choke U 2000 psi bleed U 1300 psi ok„Welder worked on Flow nipple, flow line for MPD and cut access window into pit wind wall,PJSM- Change out lower Ibop on TDS,Crew change PJSM continue chg out lower IBOP, installed new saver sub & clamp, torqued to spec, removed dart valve and TIW from 4.5” test jt, MU to a 207 5” test jl.,Slarted testing 5' DP. Test #1- Annular, inside choke, inside kill, & dart valve (Good test), Test #2-Upper pipe rams, CMV- 1,3,4,5,7, and meaanine kill valve, dart valve, hydraulic IBOP, 250 low/4,000 high, high test failed, purged out air through TD, closed lower manual [BOP and tested and leaked. Called out rig mechanic to rebuild manual IBOP.,isolated Hydraulic IBOP and tried to test against upper variable pipe rams, 2-7/8"/5-1/2", Low test failed. Tried to functioning rams X3 and re-purge through dart valve, tried re-testing upper pipe rams shutting inside manual choke/kill & HCR choke/kill, Low test failed-Blew down TD. test pump lines, pulled lest jt & test plug, drained stack, closed blinds, bled down koomey and isolated, opened upper pipe ram doors, inspected VBR's, noticed significant damage to rubber elements, changed out VBR's to back up VBR's, buttoned & torqued up doors, filled stack with water, purged lines of air, tested VBR's and hydraulic IBOP (Good test)„Re-tested 5” on new chart, Test #1- Annular, inside choke, inside kill, dart valve (Good test), Test#2- Upper pipe rams, CMV 1,3,4,5,7, mezzanine kill, dart valve, hydraulic IBOP, held like a jug. Remove bad manual IBOP, working on installing rebuilt manual IBOP.,Hauled 0 bbis solids to KGF G&I Cumulative: 0 lbs -Hauled 90 bbis fluid to KGF G&I Cumulative: 535 bbis -Hauled 0 bbis cement to KGF G&I Cumulative: 0 bbls -Daily downhole losses: 0 bbis Cumulative:0 bbls -Daily metal: 0 be Cumulative: 0 lbs 3/12/2019 Crew change and PJSM, removed lower IBOP and installed rebuilt valve. Torqued valve to 46k and installed clamps. Torqued clamp bolts to 180 fUlbs. Installed saver sub and torqued to 42k. Changed to large die inserts on grabber box.,Broke TIW and Dart off 5" test jt and LD same. P/up 4-1/2" test jt and MU TIW and Dart. Flooded surface lines and purged air. Obtained good shell lest on bag at 250-2500 psi.,Tested all BOPE at 250/4000 psi. 250/2500 on annular. Held 5 min on low, 10 min on high. Had one fail pass on test #7 low test (TIW not quit closed, functioned TIW and re-tested OK).,Blew down choke manifold and choke lines. PJSM with MPD Reps on stabbing joint into sealing element. PU joint 4 1/2", PU stabbing base and seal element. Stabbed element onto joint and landed in rotating head. PJSM with MPD Reps on flooding MPD hardlines and testing. Gave 3 hour notice to Halliburton storm packer Rep and BOT Rep Clint Pettit-Pulled rotating head & UD, PU test jt MU and pulled test plug, removed TIW F/ 4.5" test it, installed MPD's trip nipple, and closed annulus valve. Finished building containment for tank farm, loaded 284 bbis of new mud in one of our four tiger tank on Pad #3 in the tank farm. Working on building 4th batch of mud for displacement looking ahead.,PU single 4.5" DP, RIH 1 stand on top of single, MU TIW and 5' pup, screwed in storm packer, opened TIW valve to check for pressure below storm packer, pressure was present, screwed into pup w/ TD, opened 2" bleeder on floor, opened TIW slowly and bled off pressure, pulled storm packer off seat, flow checked well (static), lined up to pumps and circulated X2 BU. 250 slks,Flow checked well (static), POOH w/ storm packer, broke out XO's and UD storm packer, (9 stds of 4.5" DP & 8 stds of HW DP and 1 single HWDP),POOH and racked back 9 stds of 4.5" DP & 8 aids of HWDP and UD 1 single HWDP,Cleared & cleaned rig floor to PU & MU BHA #2 cleanout assembly, installed wear ring 9" ID and tighten 4lock down pins. Staged BHA on catwalk, strapped and got all OD's & ID's with BOT Rep.,PU & MU mule shoe, flex collar, 8-3/8 upper mill, 2 magnets, 5" HW DP, XO, 18 jts of 4.5" HWDP,Found 2 sheared bolts on TD grabber box bell guide, removed guide cover & broken studs.,Hauled 0 bbls solids to KGF G&I Cumulative: 0 lbs -Hauled 90 bbls fluid to KGF G&I Cumulative: 625 bbis -Hauled 0 bbis cement to KGF G&I Cumulative: 0 bbis -Daily downhole losses: 0 bbis Cumulative:0 bbls -Daily metal: 0lbs Cumulative: 0 lbs Conductor annulus pressure- 0 psi 13-3/8 X 9-5/8 annulus pressure- 0 psi 3/13/2019 PJSM, covered hole and stump, remove front half of bell guide on topdrive grabber box. Had two of three bolts sheared/broken. Drilled two new bolts for safety tie wire and re-installed bell guide section.,PJSM, PU drilling jars and RIH. Strapped 5" DP, PU singled in hole from 657'to 4761' drifting joints as we PU.,CO handling equipment from 5" to 4 1/2", MU XO on stump, strapped 4 1/2" CDS-40, PU singled in hole from 4761' to 5695'. Up wt 112K, dwn wt 115K.,Service rig and topdrive. Found driveline bolts were loose. Checked brake linkages and pins, no issue.,New night crew on shift. Discussed recent issues with drill pipe, tight spot in casing, spills, PU and single in hole.,Finished torque up of driveline bolts. Checked well control alignment of CMV's, finished mixing fourth batch of water based mud in pits 9-10.,Cont PU single RIH in hole with CDS-40 DP from 5695' to 10,536', at 10,536' we got into our first 9 jts of re-cuts, new cut pins going into a old box showed threads sharping and minimal galling. New cut threads to a new cul box showed significant galling, this all happened after preforming our make & break at 60%, 80%, and 100% (13K, 16K, 21 K) cleaning threads after each make & break„kicked out a total of 4 jts, current depth of 10,692'.,Hauled 0 bbls solids to KGF G&I Cumulative: 0 lbs -Hauled 0 bible fluid to KGF G&I Cumulative: 715 bbls -Hauled 0 bbls cement to KGF G&I Cumulative: 0 bbis -Daily downhole losses: 0 bbls Cumulative:0 bbls -Daily metal: 0lbs Cumulative: 0 be Conductor annulus pressure- 0 psi 3/14/2019 Cont PU single in hole with 4 1/2" CDS-40 DP from 10,692' to 11,283'. Did surface pipe count while racking/strapping the next batch of 20 joints. Pipe in the yard was off by one joint shy. Re-counted numerous times with same results. Appears we had an extra joint in hole. Notified Drilling Manager we are pulling up hole to locate missing joint., POOH racking 4 1/2" DP back in derrick. Pulled 105 stands from 11,283' to 5" XO at 4763' and joint count was correct at 210 jnts in the hole.,Stabbed TIW, hung blocks, cut and slipped 110' drill line, spooled line on drum, checked crown saver.,TIH from 4763' to 6327' tripping out of derrick -Cont TIH with 4 1/2" CDS-40 DP out of Derrick from 6327' to 11284', pick up 4 1/2" CDS-40 DP singles from 11284'to 11719' called out Baker Rep for milling tight spot in casing. Tag up with 15k wt @ 11719',Establish milling parameters, 420 GPM, 50 RPM. Mill tight spot from 11719' to 11724'. 1-3k WOB, 4-13k Tq, 875 psi. Backream up then S/O through with no rotary -Clean - Dress 2x @50 RPM, 420 GPM. She metal recovered from surface magnets,After dressing the milled section and slacking off to set the slips for connection, the brakes did not engage fully to stop the drawworks, the Topdrive continued a slow decent until bell guide rested on table. After troubleshooting it was observed that there is oil leaking from the chain -case chain guard onto the brake drum. Heat brakes up to clean off oil residue.,Cont TIH with 4 1/2" CDS-40 DP singles off catwalk from 11724'to 12152'. No tight spots encountered. Monitor brakes for slipping while RIH, no issues seen. Brakes functioning properly when hot from frequent use.,Circulate 15 bbl Hi -Vis sweep around. 550 GPM, 1304 psi. Dump sweep when return to surface. 21bs metal recovered from surface magnets., Rig up test equipment, test casing t 2500 psi for 30 min, rig down equipment. Pressure bled down 150 psi which is consistent with previous casing test of 140 psi loss. Pumped 10.47 bbls, bled back 8.2 bbls.,lnspect oil leak on drawworks, blow down topdrive and service lines. Lock out floor motor and remove guards in preparation for repair of oil leak., Hauled 0 bbls solids to KGF G&I Cumulative: 0 lbs -Hauled 90 bbls fluid to KGF G&I Cumulative: 805 bible -Hauled 0 bbls cement to KGF G&I Cumulative: 0 blols -Daily downhole losses: 0 bbls Cumulative:0 bbis -Daily metal: 7 lbs Cumulative: 7 lbs Conductor annulus pressure- 0 psi 13-3/8 X 9-5/8 annulus pressure- 0 psi 3/15/2019 MU TIW on stump, MU topdrive on TIW and hung blocks. Put well on trip tank to monitor. Locked out floor motor and draw -works, removed chain case cover from draw -works. Removed drillers side brake band while cleaning old silicon from chain case sections. Cleaned and inspected brake drum, removed chain and large sprocket from drum shaft. Dry fitted chain case to identify any gaps, siliconed chain case and re-installed,sections to draw -works, used heat gun to warm up silicone to start a dry skin. Installed large sprocket and torqued bolts to spec's, installed brake band, kick rollers and springs, installed master link in drive chain, installed chain case access panels and draw -works guards. Test ran draw -works and checked for oil leaks while burning in brake bands., POOH from 12,153'to 11,130' laying down 4 1/2" DP. Up wt 186K. Continued to monitor draw -works for any oil Ieaks.,Continue POOH from 11,130'to 9978'. Total of 70 jts 4 1/2" DP laid down. Swapped out two joints 4 1/2" DP with bad threads.,POOH from 9978' to 5631', racking 4 1/2" DP stands in Derrick.,Continue POOH with 4 1/2" DP from 5631' to 4763'. Lay down CDS40 X NC50 crossover. Change out handling equipment to 5",POOH from 4763' to 1200' laying down 5" DP. Clean and re -dope threads on pipe prior to laying down.,Service Topdrive, Drawworks & Iron roughneck., Hauled 0 bbls solids to KGF G&I Cumulative: 0 lbs -Hauled 90 bbls fluid to KGF G&I Cumulative: 895 bbls -Hauled 0 bbls cement to KGF G&I Cumulative: 0 bbls -Daily downhole losses: 0 bbls Cumulative:0 bbls -Daily metal: 0 lbs Cumulative: 7 lbs Conductor annulus pressure- 0 psi 13-3/8 X 9-5/8 annulus pressure- 0 psi 3/16/2019 Cont POOH LD 5" DP to 657'. LD jars and 5" HWDP jnt. Cleaned and LD magnet subs, 8 3/8" mill, flex jnt and mule shoo. Had Baker Rep and Pollard a -line on location at 08:00. Recovered 46 Ibis metal from the two Baker magnet subs.,Spotted e -line unit and hung sheave. MU Baker 8.129" OD CIBP on run tool. RIH to 12,170'. Pulled up hole located casing collars at 12,112' and 12,074'. Set top of CIBP at 12,100' with no issue. POOH RD and released Pollard e- Iine.,Greased crown, topdrive, blocks, brake linkage and driveline. Inspected drill line on drum (showing some abnormal wear), C/O lube system sun cartridge (lube pressure adjustment), change gear oil in topdrive, adjusted lube oil pressure and cleared codes/alarms. Inspected driveline flange hubs and torqued bolts to specs.,PU Baker 8.375" window mill, 8.250" lower mill, flex joint, 8.375" upper mill on one jnt 5" HWDP. Set whipstock/trip anchor assembly in table after removing 3 shear screws (now set at 20K). Fastened ramp to starter mill with 45K shear bolt.,M/U MWD DM collar. Obtain rig floor offset from MWD highside to whipstock slide face.,Mobilize BHA handling equipment to rig floor.,M/U MWD TM collar and RIH w/ 2 stds 4-1/2" HW DP.,Attempt to SHT MWD and experience pressure fluctuations that appears to be pump cavitation. Trouble shoot pumps. Check pulsation dampeners, pump through bleed -offs to remove any air from system several times. Still experiencing erratic pressures and Kelly hose jumping. Possible low head pressure from mud pit causing cavitation. Send truck for extra water volume.,RIH with remaining 4-1/2" HWDP to 645' while waiting on water. Open MP#2 to inspect for wear on valves & seats, no problems found.,Obtain flow and attempt to SHT MWD again, experience the same pressure fluctuations. Bled air through bleed off line and find fluid leaking from grease fitting on 2" valve. Removed valve from line to repair. Check and clean suction screens. Attempt to pump again and MP#1 clutch not engaging.,Troubleshoot MP#1 and find faulty air to electric pressure switch which engages clutch. Change out switch while continuing to troubleshoot pressure issue using MP#2. When MP#1 operational, obtain good SHT with both pumps. Determined that pressure drop generated from the MWD pulser could possibly be stalling the tools at the shallow depth and lower flow rates but pulsing and functioning properly at designed flow rate.,RIH with WhipstocIdMilling assembly from 645' to 6049'. Fill pipe every 2500',Hauled 0 bbls solids to KGF G&I Cumulative: 0 lbs -Hauled 90 bbls fluid to KGF G&I Cumulative: 985 blots -Hauled 0 bbls cement to KGF G&I Cumulative: 0 bbls -Daily downhole losses: 0 bbls Cumulative:0 bbls -Daily metal: 48 lbs Cumulative: 55 Ibis Conductor annulus pressure- 0 psi 13-3/8 X 9-5/8 annulus pressure- 0 psi 3/17/2019 Cont TIH with Baker Gen II whipstock/anchor assembly r is 17.10' Ion 8 3/8" starter mill 8 1/4" lower mill 9.05' flex joint 8 3/8" upper mill, one jnt 5" HWDP, Sperry DM and TM collars, float sub w/float, XO, 18 jnts 4 1/2" HWDP. Total BHA length = 649.99'. SLM stands on off -side of derrick as we ran them. With 367 singles of 4 1/2" DP in the hole, MU topdrive at 12,014' and filled pipe.,Filled pipe then increased pump rate to 400 gpm-1300 psi to orient whipstock at 52° right. Up wt 175K, own wt 174K. S/O to 12,041', PU next single and MU topdrive. Pump at 412 gpm-1328 psi and orient whipstock at 46' right. S/O and tagged COP at 12,053' DPM. Set down 15K and engaged anchor. PU and pulled 10K over to 184K, 8/0 to 150K and had good indication anchor set. PU to 190K to verify anchor set, SIO to 130K,and had good indication shear bolt broke. Top of whipstock ramp at 12,030', bottom of ramp at 12,047'. PU 10' with no overpull, slow rotated with no increase in torque.,Held PJSM with Mud Engineer, rig crew and Peak drivers on displacing well to 9.5 ppg 6% KCL water based mud.,Lined up pumps and pits for displacement, pumped 20 bbl hi -vis spacer followed by 819 bbls 9.5 ppg 6% KCL mud at 216 gpm-503 psi.,Empty pits of production water and clean pits. Line up new active system with mud on hole. Set up surface equipment to take returns from milling window. Lay down single jt of 4-1/2" DP and M/U stand from Derrick.,Eslablish flow and rotary parameters. Mill 8.375' window from 12030'V 12034'. 295 GPM, 1000 psi. 80 RPM, 2.8- 11.5k tq. 1-2k WOB. P/U = 174k, 8/0 = 160K, Rot = 160K s/ w Winston, Hugh E (CED) From: Cody Dinger <cdinger@hilcorp.com> Sent: Wednesday, August 21, 2019 10:51 AM To: Winston, Hugh E (CED) Subject: RE: [EXTERNAL] BCU -04 and BCU-04RD Well Completion Reports Huey, See responses below. I will resubmit the 10-407s today with corrections. Thanks! Cody From: Winston, Hugh E (CED) [mailto:hugh.winston@alaska.gov] Sent: Wednesday, August 21, 2019 9:29 AM To: Cody Dinger <cdinger@hilcorp.com> Subject: [EXTERNAL] BCU -04 and BCU-04RD Well Completion Reports Hi Cody, I am entering the data from the well completion reports for BCU -04 and BCU-04RD and there are a couple questions and issues: BCU -04 • The top productive interval information is missing from box 4a and 4b. Can you tell me why this was omitted? Since the well is abandoned, the well no longer has open perfs or any productive intervals, I've marked them N/A. • The total depth location coordinates in box 4b seems to be a little off. Our database takes both sets of coordinates and calculates to make sure they match, but the reported state plane coordinates are off by about 50 ft each from the reported governmental coordinates in box 4a. Can you verify these numbers please? — I updated this, what we had on record from the original wellbore was way off, the new coordinates/measurements are correct. • Both "Oil" and "Abandoned" are checked in box 1. Please only check "Abandoned". - fixed BCU-04RD • The completion date reported in box 6 is after the reported start of production in box 27. Can you verify these dates please? Corrected to date completion tubing was run. • The API number is slightly off. It should be 50-133-20239-01-00 - fixed • The formation at total depth is missing from box 29. - fixed • The x-coordinate in box 4b appears to be incorrect. Please verify this number as well. - fixed If you would please correct these errors and send an updated signed copy of both reports, just the 2 page 10-407 is fine. Thanks Huey Winston Statistical Technician Alaska Oil and Gas Conservation Commission h uah.wi nston @a laska.¢ov 907-793.1241 MEMORANDUM TO: Jim Regg�� 3I 7 I t q P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector Section: 33 Township: Drilling Rig: NA Rig Elevation: Operator Rep: Cole Bartlewski Casing/Tubing Data (depths are MD) Conductor: 20" - O.D. Shoe@ Surface: 13-3/8" - O.D. Shoe@ Intermediate: 9-5/8" - O.D. Shoe@ Production: 7" O.D. Shoe@ Liner: O.D. Shoe@ Tubing: 3-1/2" O.D. Tail@ Plugging Data: Test Data: State of Alaska Alaska Oil and Gas Conservation Commission DATE: February 13, 2019 SUBJECT: Well Bore Plug & Abandonment - BCU -04 ' Hilcorp alaska� PTD 1720130; Sundry 319-013 7N Range: 10W Meridian: Seward ' Fullbore NA Total Depth: 15940 Lease No.: A-028083 10 10 Suspend: P&A: X Casing Removal (depths are MD): 288 - Feet Csg Cut@ Feet 2989 , Feet Csg Cut@ Feet 12521 Feet Csg Cut@ Feet 15921 Feet Csg Cut@ Feet Feet Csg Cut@ Feet 14482 Feet Tbg Cut@ 13650 ' Feet TvDe Pluq Founded on Depth Btm Depth To MW Above Verified Fullbore Bottom 15212 ft MD 13710 ft MD N/A OA 10 10 10 Initial 15 min 30 min 45 min Result Tubing 2585 2551 2525 IA 2585 2551 2525 - P OA 10 10 10 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: This was a pressure test on the cement plug prior to a rig workover for a redrill (13CU-04A). The cement plug was founded on fill tagged at 15212 ft MD (not witnessed). The tubing was cut @ 13650 it MD and is to be removed by a rig prior to kicking off for redrill. Fluid was circulated down the annulus and back up the tubing to ensure a complete fluid packed void. A passing 30 ,✓ minute pressure test was completed. Attachments: none rev. 11-28-18 2019-0213_Plug_Verification_BCU-04_11 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Beaver Creek Oil Pool, BCU 04 Permit to Drill Number: 172-013 Sundry Number: 319-013 Dear Mr.York : Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .00gcc.aloska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Z4 Daniel T. Seamount, Jr. Commissioner / t DATED this S day of February, 2019. SCANNED Ica 0 6 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECIENED AN 15 2019 AQQQQ 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 El Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development 0 Straligraphic ❑ Service ❑ 172-013 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-20239-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require a spacing exception? Yes ❑ No Q Beaver Creek Unit (BCU) 04 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028083 6 Beaver Creek / Beaver Creek Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 15,940' 15,717' 15,212' 15,010' -979 psi WA 15,212' (fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 288' 20" 288' 288' Surface 2,989' 13-3/8" 2,989' 2,989' 3,450 psi 1,950 psi Intermediate 12,521' 9-5/8'. 12,521' 12,425' 6,870 psi 4,760 psi Production 3,704' 7" 15,921' 15,699' 11,220 psi 8,530 psi Liner 1 326 1 5.1 14,813 14,623' 10,140 psi 10,500 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3# /L-80 ELIE, AS Mod Tubing 14,482' Packers and SSSV Type: Otis XXO SSSV Packers and SSSV MD (ft) and TVD (ft): 250' MD - 250' TVD (2) Baker FAB -1 Pkrs 14,484' MD -14,306' ND; 14,813' MD - 14,623' TVD 12. Attachments: Proposal Summary El Wellbore schematic 4 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic ❑ Development Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 4Y /�`� pt I� /(q - CommencingOperations: January 28, 2019 OIL WINJ ❑ WDSPL ❑ 7:I,Suspende/dtYl lY VIII GAS WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: - 30-/q Commission Representative: ` Slux,,, �-Z GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York 777-8345 Contact Name: Joe Kaiser Authorized Title: Operations Manager Contact Email: 'kBiSef Q hjlCOf .COm 11 t� Contact Phone: 777-8393 Authorized Signature: Date: � COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: n - /[ Plug Integrity BOP Test Mechanical InteLgrity Test ❑ Location Clearance ❑ LSI Other: /� �ool] � [J [) A'le S 1 ✓F PS Post Initial Injection MIT Req'd? Yes ❑ No❑�-�/ 7 Spacing Exception Required? Yes No No Subsequent Form Required: IO ' 1 0 T E] APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: (/ 41, Arm 10-403 Revise Cmrrtt R - I GMALs from the date of Submit Form and Attachments in Duplicate 9. s. 01/1i//9 H llil,.a p Alaska. LLC L. 172-013 50-133-20239-00 v Des: A-028083 ation: 164' (19' AGL) 06/12/1972 11/26/1972 Tree cxn: 6-1/2" Otis Directional Data Maximum Hole Angle: 18 (4113,780' MD Angle Through'G: 14 Angle Through Hemlock: 14 BC -04 Pad 4 1,700' FNL, 660' FEL, Sec. 33, WN, R1 OW, S.M. jevvel Depth 1. Otis XXO profile for SSSV(2.813"ID) 250' 2. Otis X Nipple (2.813 ID) 14,482' 3. 3-1/2" ha#cut Muleshoe 14,482' 4, 3-112" Baker seal assembly -x040 PBR (17.91' Depth length). Baker PBR (4.00" ID) w/concentric Valve Type coulping (4.00" ID) and Baker SBE (18.74' length). 14,464' 5. Baker FAB -1 pkr, size 83FA47 (4.00" ID) 14,484' 6. Baker FAB -1 pkr, size 83FA47 (4.00" ID) 14,813' 7. Cement retainer^ 15,361' Gas Lift Data 95/8" N-80 (47.0ppf ends 7,421') BTC S-95 (47.Oppf ends 9,938') Size for all: 3.5" IDforall: 2.867' (53.5ppf ends 12,521') TOP Bottom Depth Mandrel Valve Type Latch Port 2,737' Flopetrol SPM -2 1.5" GLV 1.5R RK 16/64 4,747' Flopetrol SPM -2 1.5" GLV 1.5R RK 16/64 6,132' Flopetrol SPM -2 1.5" GLV 1.SR RK 16164 7,200' Flopetrol SPM -2 1.5" GLV 1.5R RK 16/64 8,079' Flopetrol SPM -2 1.5" GLV 1.5R RK 16/64 8,862' Flopetrol SPM -2 1.5" GLV 1.SR RK 20164 9,596' Flopetrol SPM -2 1.5" GLV 1.5R RK 20/64 10,215' Flopelrol SPM -2 1.5" GLV 1.5R RK 20/64 10,837' Flopetrol SPM -2 1.5" GLV 1.5R RK 20/64 11,463' Flopelrol SPM -2 1.5" GLV ISR RK 20/64 12,085' Flopetrol SPM -2 1.5" GLV 1.5R RK 20/64 12,708' GLMA BST 1" GLV 1.OR BK -2 20/64 13,206 GLMA BST 1" GLV 1.OR BK -2 20/64 13,739 GLMA BST 1"GLV 1.OR BK -2 20/64 14,259' GLMA BST V GLV 1.0R BK -2 3/8 2 4 ACTUAL SCHEMATIC Conductor 29' H-40 94ppf Tom Bottom MD 0' 288' TVD 0' 288' Cmt YA 60 sks Class G 13-3/8" N-80 (72ppf ends 1,942') 8RD J-55 (68ppf ends 2,989) Tiro Bottom MD 0' 2,969' TVD 0' 2,989' Craft w12,000 sks Class G w/4% gel; followed by 300 sks Class G Intermediate Casino 95/8" N-80 (47.0ppf ends 7,421') BTC S-95 (47.Oppf ends 9,938') P-110 (53.5ppf ends 12,521') TOP Bottom MD 0' 12,521' TVD 0 12,425' Tubing 7" P-110 3-1/2" L-80 9.3ppf 8RD-MOD T� Bottom MD 0' 14,482' TVD 0' 14,304' Top of Liner Hanger @ 12,217' Shoe @ 12,521' Liner 7" P-110 (29ppf ends 12,552) BTC P-110 (32ppf ends 15,921') TVD 14,309' ]LOP Bottom MD 12,217' 15,921' TVD 12,130' 15,699' Cmt w11,400 sks Glass G Isolation Liner 5" N-80 (18ppQ TOP Bottom MD 14,487' 14,813' TVD 14,309' 14,623' perfs zone is Hemlock DST Perforations and is isolated by omt. retainer, but never Slickline fill tag 15,212' RKB (12/27/14) Hemlock 7 TO PBTD 15,940' MD 15,315' MD 15,717' TVD 15,110' TVD Well Name R Number. _M_ TVD Net Ft Zone $PF Date 3 14,535'-14,565' 14,355'-14,384' 39 Sgzd Upper'G' 4 1/73 -5 14,731'-14,743' 14,544'-14,556' 12'Sgzd Upper'G' 4 8/28188 19.2' 15,063'-15,123' 14,865'-14,923' 60' Lower'G' 6 04/15/13 15,040'-15,100' 14,843'-14,901' 60' Lower'G' 8 12/11/88 6 15,108'-15,128' 14,909-14,928' 20' Lower'G' 8 12/11/88 15,132'-15,146' 14,937-14,946' /4' Lower'G' 8 12/10/88 15,149'-15,165' 14,946'-14,962' 16' Lower'G' 6 01/15/14 15,156-15,175' 14,954'-14,974' 20 Lower'G' 8 12/10/88 15,185'-15,210' 14,984'-15,008' 25' Lower'G' 8 12/10/88 15,361'-15,376' 15,154.15,169' 15' Hemlock 4 12/12/72 15,382-15,397' 15,175'-15,189' 16 Hemlock 4 12/1202 15,416'-15,431' 15,208'-15,222' 15' Hemlock 4 12/1272 15,446'-15,461' 15,237'-15,252' 15' Hemlock 4 12/1202 perfs zone is Hemlock DST Perforations and is isolated by omt. retainer, but never Slickline fill tag 15,212' RKB (12/27/14) Hemlock 7 TO PBTD 15,940' MD 15,315' MD 15,717' TVD 15,110' TVD Well Name R Number. Beaver Creek Unit #4 Lease: I A-028083 County or Parish: Kenai Peninsula Borough Stale/Prov: Alaska Country: USA Angle QKOP and Depth: 2.0° 0 8,765' Angle/Perls: 13°15' Maximum Deviafl2n 18° 13,780' Date Completed: 01/13/73 Ground Level (above MSL): 144.8' RKB (above GL): 19.2' Revised By: Stan Pothole Downhole Revision Date: 1=7120141 Schematic Revision Date: 1 12/29/2014 klile.nq, Alnek., LLC Permit #: 172-013 AN M 50-133-20239-00 Property Des: A-028083 KB elevation: 164' (19' AGL) Latitude: Longitude: Spud: 06/12/1972 TD: 11126/1972 Rig Released: PA #: Tree cm: 6.112" Otis Directional Date Maximum Hole Angle: 18 G 13,780' MD Angle Through'G': 14 Angle Through Hemlock: 14 BC -04 Pad 4 1,700' FNL, 660' FEL, Sec. 33, WN, R1 OW, S. M. Jewel Depth 1. Otis X Nipple (2.813 ID) 14,482' 2.3-112" halfcut Muleshoe 14,482' 3. 3-112" Baker seal assembly -8040 PBR (17.91' LOP length). Baker PER (4.00" ID) wlconcentnc MD 0' coulping (4.00" ID) and Baker SBE (18.74' length). 14,464' 4. Baker FAB -1 pkr, size B3FA47 (4.00" ID) 14,484' S. Baker FAB -1 pkr, size 83FA47 (4.00" ID) 14,813' 6. Cement retainer 15,361' 9.618"CIBP-12,10P ZZ//, P2✓I7"CBP 1lop of em14,250'215 IG'n1 y 3.5" Tubing Cut IDL -14,300' T Top of Cement @-14,350' .rte>r -o to PROPOSED SCHEMATIC Conductor 20" H-40 94ppf Tag Bottom MD 0' 288' TVD 0' 288' Chit M 60 sks Class G 13-3/8" N-80 (72ppf ends 1,942') ORD J-55 (68ppf ends 2,989) '3 Tog Bottom 13 MD 0' 2,989' TVD V 2,989' Chit w12,000 sks Class G w/4% gel; .a4Y r followed by 300 sks Class G Intermediate Casing 9-5/8" N-80 (47.0ppf ends 7,421') BTC S-95 (47.Oppf ends 9,938) P-110 (53.5ppf ends 12,521') LOP Bottom MD 0' 12,521' TVD 0' 12,425' Liner T' P-110 (29ppf ends 12,557) BTC P-110 (32ppf ends 15,921') State/Prov: Tim Bottom MD 12,217' 15,921' TVD 12,130' 15,699 Cmt wU,400 sks Glass G r cin=711141 8emmck Mor - TO TO PBTD 15,940MD 15,315' MD 15,717- TVD 15,1 TO -TVD Well Name B Number: Beaver Creek Unit #4 Lease: A-028083 Isolation Liner Kenai Peninsula Borough State/Prov: Alaska Country: USA V. N-80 (18ppf) Maximum Deviation: 18° 0 13,780' Date Completed: 01/13/73 Ground Level (above MSL): Tort Bottom 1 RKB (above GL): 19.2' op of Liner Hanger Tubing Dovmhole Revision Daterl MD 14,487' 14,813' 1/14/2019 @12,21]' 3-1/2" L-80 9.3ppf ND 14,309' 74,623' 8RD-MOD Top Bottom Shoe @ 12,521' MD 0' 14,482' " TVD 0' 14,304 Tvobek Pelts: - . , ._..... _.. 1 MD TVD Net Ft Zone SPF Date 2 14,535'-14,565' 14,355-14,384' 30'Sgzd Upper'G' 4 1%73 3 4 14,731'-14,743' 14,544'-14,556' 12'Sgzd Upper'G' 4 8/28/88 15,063'-15,123' 14,866-14,923' 60' Lower'G' 6 04/15/13 15,040'-15,100' 14,843'-14,901' 60' Lower'G' 8 12/11/88 } 5 15,108'-15,128' 14,909'-14,928' 20' Lower'G' 8 12/11/88 s 15,132'-15,146' 14,932'-14,946 14' Lower'G' 8 12/10/88 15,149-15,765' 14,946'-14,962' 16' Lower'G' 6 01/15/14 15,159-15,175' 14,954'-14,974' 20' Lmer'G' 8 12110/88 15,185'-15,210' 14,984'-15,008' 25' Lower'G' 8 12/10188 15,361'-15,376' 15,154'-15,169' 15' Hemlock 4 12/12/72 15,382'-15,397 15,176-15,189' 15' Hemlock 4 12/72/72 15,416'-15,431- 15,208'-15,222' 15' Hemlock 4 12/12172 15,446'-15,461' 15,237'45,252' 15' Hemlock 4 12/12/72 Last 4 parts zone is Hemlock DST Perforations and is isolated by mt. retainer, but never r cin=711141 8emmck Mor - TO TO PBTD 15,940MD 15,315' MD 15,717- TVD 15,1 TO -TVD Well Name B Number: Beaver Creek Unit #4 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 2.0-08,765- Angle/Perfs: 13°-75° Maximum Deviation: 18° 0 13,780' Date Completed: 01/13/73 Ground Level (above MSL): 144.8' 1 RKB (above GL): 19.2' Revised By: Joe Kaiser Dovmhole Revision Daterl 12127/20141 Schematic Revision Date: 1/14/2019 H HBcorp Alaska. LL' Well Prognosis Well: BCU -04 Date: 1/14/17 Well Name: BCU -04 API Number: 50-133-20239-00 Current Status: Oil Producer Leg: N/A Estimated Start Date: January 28`^, 2019 Rig: N/A S oh, Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 172-013 First Call Engineer: Joe Kaiser (907) 777-8393 (0) (907) 952-8897 (M) Second Call Engineer: Bo York (907) 777-8345 (0) (907) 727-9247 (M) AFE Number: Maximum Expected BHP: 2,427 psi @ 14,482' TVD Static Builtup data 11-19-16 Max. Potential Surface Pressure: -979 psi (0.10 psi/ft gas gradient) Brief Well Summary The well was drilled in 1972-1973 to a TD of 15,940' MD (15,717' TVD) and completed with 5" liner set at 14,487'. Initial PBTD was 15,315' MD. The well was completed in the Tyonek G formation in January 1973. iii In 1987 a workover was completed and the upper G zone was added. A portion of the upper G zone was then installed with pipe between packers to isolate a water zone. In 1988, 1989, 1990, 1991, 1992, 1993 & 1997 the zones were reperforated. A sand in the Lower Tyonek G was re -perforated in 2013. The purpose of this work/sundry is to plug back the existing open intervals and prep the well for a sidetrack. COh . � Notes Regarding Wellbore Condition C(jr lee zvyl aeO? E'mq,� �/ Well is currently producing 73 BOPD, 55 BWPD, and 39 Mcfd at 90 psig FTP. Coiled Tubing Procedure: / 1. Submit 24 hr. witness notification to AOGCC via web base notification for BOPE TEST. 2. Submit 24 hr. witness notification to AOGCC via web base notification for Plugging Activity per 20,AAC 25.112 (h). *N — 3. MIRU Coiled Tubing, PT BOPE to 250/ psi. 'fpo✓ 4. Make up BHA. Stab on well and PT lubricator to 250/ 0 psi. 5. Rig up cement equipment. 6. RIH and tag top of fill at±15,212'. POOH. 7. Fill the tubing with 8.4 ppg produced water and establish circulation (if possible). 8. Batch mix cement and begin pumping spacer and cement. As cement exits the nozzle, begin pulling up o coiled tubing and lay cement to 14,350'. Once all cement has been placed, circulate any contaminated ti.{35 cement to surface. POOH. 9. Stand by Coiled Tubing for 3 hrs. RIH and tag top of cement (TOC). Record MD. 10. Rig down Coiled Tubing. 1. MIRU slickline, PT lubricator to 250 psi low/2,500 psi high. 2. RIH and tag top of cement and record depth. POOH. Well Prognosis Well: BCU -04 ffil m AMska,iu Date; 1/14/17 Contineencv - If cement is below 14,464'. 2A. RIH with bailer and dump bail cement to 14,350'. 3. RU Jet Cutter tool. RIH with Tubing Cutter. Cut 3.5" tubing in middle of joint above top of cement at "'14,300'. POOH. 4, RDMO. (0 5. Circulate well with 8.4 ppg (PW/3% KCI), ensure all oil and gas are circulated out the well. 6. Pressure test well bore and plug to 3RMpsi, for 30 min on chart.16a — eSGr^✓J�: GM t T .� =t- Saxon #169 Procedure 1. MIRU Saxon #169 Rig. 2. Notify AOGCC 24hrs and BLM 48hrs in advance of BOP Test. 3. Set BPV. ND Tree. 4. NU BOPE. 4/j *1 5. Test BOPE to 250 psi Low/4,psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 10 -min). Record accumulator pre -charge pressures and chart tests. `p a. Confirm test pressures per the Sundry Contitions of Approval b. Perform Test. ` c. Notify AOGCC 24 hrs in advance of BOP test. d. Test VBR rams on 3-1/2" test joint. e. Email completed 10-424 form to all AOGCC addresses listed on the form within 5 days of BOPE test. 6. L/D BOP test equipment. 7. Pump PW down tubing and up casing to ensure well is dead. Pump minimum of casing volume or bottoms up. 8. Pull tubing hanger free, LD hanger. A Contingency - If tubing doesn't pull free: 9A. RU a -line. �v a. RIH with jet cutter and cut tubing in middle of joint just above previous Tubing Cut at t!p —14,300'. l( 9B. Adjust CIBP depths in step #12 accordingly. 9. Pull tubing string (3-1/2" 8RD) and lay down tubing. Number and label each joint. 10. Clean and clear floor. 11. Ensure well is full of fluid. 12. RU a -line. i( a. RIH with 7" CIBP and set (5' above casing collar) at ±14,250' b. Dump bail 35' of cement on top of CIBP. Pressure test cement plug and casing to 2,500 psig for �'I 30 minutes. — Note: Hilcorp Alaska requests a variance from the requirement in 20 AAC 25.112(c)(1)(E) that requires the mechanical bridge plug and cement to be set within 50' of the open perforations. Due to a cement plug in the tubing, the CIBP and cement will be set just above the top of tubing. c. RIH with 9-5/8" CIBP and set at ±12,100' (5' above a collar) for whipstock. 13. RD a -line. C, Well Prognosis Well: BCU -04 IlJruro Alask,,. LL, Date: 1/14/17 ***Remaining procedure to be included on the Permit to Drill for the sidetrack starting at 11.0 of PTD*** Attachments 1. Actual Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Current Wellhead Schematic 5. Blank RWO Procedure Change Form rii rii rir €i€ €ir rir fit fit fit title[ III 111 111111 rir rir lit rir H Hil .rp Alavxk.. MA; Beaver Creek BC04 20 x 133/8 x 95/8 x 3X BHTA, Otis, 3 1/8 SM FE x 6.5" Otis quick union top Beaver Creek Field BC #4 1/14/2019 Tubing hanger, FMC -TC -1A - EN -CL, 11 X 3 % EUE lift and susp, w/ 3" Type IS profile, Y, control line port, 5.990" neck TOS nth' Valve,Swab, FMC -20, 31/85M FE, HWO, etc FF"a og,",y'y''J�m EE trim �axa05�a<\tt` Jaffe h�FE,t EF,� I\ 9��8 ppatato Valve, Master FMC -20, 31/85M FE, HWO, I EE trim Valve, Master, FMC -2 3 1/8 5M FE, HWO, EE trim Tubing head attachment, FMC -TC -60, 115M FE X 115M stdd Tubing head, FMC -TC -BG, 13 5/8 5M x 115M, w/ 2- 21/165M EFO Tubing hanger bawl profile is bad Casing spool, OCT- C-22AP- 00, 21%" 2M x 13 5/8 SM, W/ 2- 2 1/16 5M SSO/ Starting head, OCT -C22, 211/4" 2M x 20" SOW, w/ 2- 21/16 SM CFO 13 3/8" 95/8-- Adapter, FMC -ASP -C4 11 SM HE x 31/8 SM, w/ 1- 1/2" npt control line exit, p 5.990" EN profile 0 Hilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for BCU -04 (PTD 172-013) Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) "first call' engineer. AOGCC written approval of the change is required before implementing the change. Sec Page Date Procedure Change New 403 Required? Y / N HAK Prepared By Initials HAK Approved By Initials AOGCC Written Approval Received (Person and Date) Approval: Prepared: Asset Team Operations Manager Date First Call Operations Engineer Date Sundry Application Plug for Re -drill Wells Work Flow 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 Geologist 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 6, v initial it on both copies of the Form 10-403 (AOGCC's and operator's of II })19 copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist work) the initial reviewer will cross out that erroneous entry and initial then 't on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended" box and initial that change. ��/,6•B Drillih9Y7/1 Engineer The drilling engin6ers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech 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." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re -drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding" user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. Robv. David S (DOA) From: Joe Kaiser <jkaiser@hilcorp.com> Sent: Thursday, January 17, 2019 2:13 PM To: Roby, David S (DOA Cc: Boyer, David L (DOA); Schwartz, Guy L (DOA); Donna Ambruz Subject: RE: [EXTERNAL) Sundry application for BCU 04 (PTD 172-013) David, Please see answers below. If you have further questions, please don't hesitate to contact me. Joe Kaiser CIO Operations Engineer jkaiser anhilcoro.com 907-777-8393 Office 907-952-8897 Cell From: Roby, David S (DOA) (mailto:dave.roby@alaska.govj Sent: Thursday, January 17. 2019 11:29 AM To: Joe Kaiser <jkaiser@hilcorp.com> Cc: Boyer, David L (DOA) <david.boyer2@alaska.gov>; Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Subject: [EXTERNAL] Sundry application for BCU 04 (PTD 172-013) Joe, I'm reviewing the sundry application to plug the subject well for redrill and noticed that the well is the only well producing from the Beaver Creek Oil Pool and while not a great producer it's by far not the worst well in the Cl region producing —70 BOPD with a reasonable water cut and very little associated gas. So I have a few questions: 1) Why was this well chosen as a redrill candidate? This is the only wellbore available at the depth needed for a short sidetrack capable to execute w/ HAK 169 drill rig. 2) What pool will the redrill be targeting? We are targeting the Beaver Creek Oil Pool up structure. 3) If the redrill is not going to target the Beaver Creek Oil Pool are there any future development plans for oil in the Beaver Creek field? Both the BCU-05RD2 oil well and the BCU-04RD wells are and will be producing from the Beaver Creek Oil pool. Hilcorp plans to drill grassroots wells, hopefully in the next 3-5 years. Thanks in advance. Regards, David Roby Senior Reservoir Engineer Alaska Oil and Gas Conservation Commission 907-793-1232 CONFIDENTIAUTYNOTICE., This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Dave Roby at 907- 793-1232 or dave.robvC@alaska.¢ov. Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, February 5, 2019 9:42 AM To: 'Joe Kaiser' Cc: 'Bo York'; mmyers@hilcorp.com Subject: RE: 172-013 BCU -4 Decomplete Sundry Status ( #319-013) Joe, After consulting with Monty on the PTD for the sidetrack the max casing pressure for the 9 5/8" will be 2500 psi. In step 6 after CTU places cement and the tubing is jet cut the CMIT test pressure will then be 2500 psi (not 3200 psi) . have updated the procedure with this change. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC(, State of Alaska and is for the sole use of the intended reciptent(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ( or (Guv schwartz@alaska.aov). From: Schwartz, Guy L (DOA) 1 Sent: Wednesday, January 30, 2019 4:20 PM y To:'Joe Kaiser' <jkaiser@hilcorp.com>� Cc: Bo York <byork@hilcorp.com> Subject: RE: 172-013 BCU -4 Decomplete Sundry Status Joe, You have verbal approval to proceed with the CT and Slickline work on the well in order to P & A the well ( as proposed in your sundry application). I changed the test pressure for the CT unit to 4000 psi. (from 4500 psi) Also, notify AOGCC inspector to witness the pressure test to � psi before 169 rig moves in. The sundry number is 319-013. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC(, State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz of (907-793-1226) or (Guv schwartz@alaska.aov(. From: Joe Kaiser <jkaiser@hilcorp.com> Sent: Wednesday, January 30, 2019 4:09 PM To: Schwartz, Guy L (DOA) <guv.schwartz@alaska.gov> Cc: Bo York <byork@hilcorp.com> Subject: PTD: 172-013 BCU -4 Decomplete Sundry Status Mr. Schwartz, We submitted a sundry forthe decompletion of BCU -4 at Beaver Creek on January 15`h, 2019. As part of the sundry, we are utilizing coil resources in Kenai. The vendor is shipping crews to the Slope soon and will not return until late February. I understand further review may be required for the Saxon Rig work, especially under the Permit to Drill. I am requested verbal approval to rig up coil on Friday February, V, 2019 to perform the cementing portion of the sundry. Additionally, we will perform the wireline portion of the work. To clarify, we will not rig up or mobilize the Saxon Rig until a written approval is provide. If you have any question, please don't hesitate to contact me. Thank you, Joe Kaiser CIO Operations Engineer ikoiser@hilcorp.com 907-777-8393 Office 907-952-8897 Cell �-t2- oi3 Se h Nolan Hilcorp Alaska, LL GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 2 Hilrnrp:tii 4 .in; Fax: 907 777-8510 E-mail: snolan@hilcorp.com NOV 1 3 2017 DATA LOGGED /Wi2o11 DATE 02/02/2016 `' e'.: 0a1. K BENDER To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL scoop fLB 0 A Zj101a BCU 4 Electric log prints and data Prints: Leak Detect Log CD: 1 DATA jj BCU-04 LDL 07SEPT17 LAS.zip 10/19/2017 2:55 PM Compressed(zippe... 2,384 KB BCU-04_LDL 07SEPT17.pdf 10/4/2017 3:26 PM Adobe Acrobat Doc... 2,240 KB BCU-04_LDL 07SEPT17 img.tif 10/4/2017 3:26 PM TIF File 7,851 KB Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: STATE OF ALASKA ALA, OIL AND GAS CONSERVATION COMMIt. AN RECEIVED REPORT OF SUNDRY WELL OPERATIONS JAN 2 7 2014 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U�DD OC Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension El Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development Q Exploratory ❑ V 172-013 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99504 10 50-133-20239-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028083 11. d Beaver Creek Unit(BCU)04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A 5 Beaver Creek/Beaver Creek Oil 11.Present Well Condition Summary: Total Depth measured • 15,940 feet Plugs measured N/A feet true vertical 15,717 feet Junk measured 15,135(fill) feet Effective Depth measured 15,135 feet Packer measured 14,484; 14,813 feet true vertical 14,935 feet true vertical 14,306; 14,623 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 288' 20" 288' 288' Surface 2,989' 13-3/8" 2,989' 2,989' 3,450 psi 1,950 psi Intermediate 12,521' 9-5/8" 12,521' 12,425' 6,870 psi 4,760 psi Production 3704' 7" 15,921' 15,699' 11,220 psi 8,530 psi Liner 326' 5" 14,813' 14,623' 10,140 psi 10,500 psi Perforation depth Measured depth See Attached Schematic SCANNED MAY 2 1 2014 True Vertical depth See Attached Schematic 9.3#/L-80 EUE, Tubing(size,grade,measured and true vertical depth) 3-1/2" AB Mod Tubing 14,482'MD 14,304'TVD 14,484'MD-14,306'TVD Packers and SSSV(type,measured and true vertical depth) (2)Baker FAB-1 Pkrs 14,813'MD-14,623'ND Otis XXO SSSV 250'MD-250'ND 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A RBDMA_MAY 17 2014 Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 70 0 90 700 65 Subsequent to operation: 100 0 70 740 80 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development❑✓ • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil i Q Gas ❑ WDSPL❑ GSTOR ❑ WINJ p WAG ❑ GINJ ❑ SUSP p SPLUG❑ 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: 314-019 Contact Stan Porhola Email soorholaahilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature ti �-� Phone 907-777-8412 Date (I /L? / Form 10-404 Revised 10/2012 i 5/1-4:9k Submit Original Only tit Hilcorp Alaska, LLC .:: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU-04 50-133-20239-00 172-013 1/15/14 1/15/14 Daily Operations: 01/15/2014-Wednesday RU E line unit. Hold Explosives safety meeting. Check fire. No fire below Gamma/CCL. Replace tools. Snag E line while carrying lubricator to WH. Damage E line. Cut and rehead line. Place signage and silence radios. Check fire. Good. Arm 2- 1/2" x 16' perf gUns. Carry lubricator to WH. RIH to 15,165'. Unable to get deeper. Pull correlation pass to 14,380'. Pull thru both packers to get on depth. RIH and repeat correlation pass. Correlate to Schlumberger GR/CCL dated 3/8/1991 and Pollard Gamma/CCL dated 4/13/2013. Email log to town and wait for approval. Discussed log. Given the word to proceed. 9.5'from CCL depth to top shot. Receive engineer's approval. Pull up into position with CCL at 15,139.5'. Perforate from 15,149'to 15,165'with 2-1/2" guns with Connex charge 6 SPF 60 degree phasing._Lost weight. No change in tubing pressure. POOH. RD E line unit. Turn well over to production to start up gas lift. BC-04 B ACTUAL PaItileorp Alauka,LLC 1,700'FNL�660'FEL, SCHEMATIC Permit#: 172-013 Sec.33, T7N, R10W, S.M. API#: 50-133-20239-00 Property Des: A-028083L1Conductor 20" H-40 94ppf KB elevation: 164'(19'AGL) -al ! I•; Top Bottom Latitude: MD 0' 288' Longitude: ND 0' 288' Spud: 06/12/1972 Coit w\60 sks Class G TD: 11/26/1972 i Rig Released: J Surface Casing PA#: 13-3/8" N-80 (72ppf ends 1,942') 8RD J-55 (68ppf ends 2,989') To Bottom MD 0' 2,989' TVD 0' 2,989' Tree cxn:6-1/2"Otis Cmt w\2,000 sks Class G w/4%gel; J followed by 300 sks Class G Intermediate Casing Directional Data 9-5/8" N-80 (47.Oppf ends 7,421') J BTC S-95 (47.Oppf ends 9,938') Maximum Hole Angle: 18 @ 13,780'MD P-110 (53.5ppf ends 12,521') Angle Through'G': 14 Angle Through Hemlock: 14 Tom Bottom MD 0' 12,521' TVD 0' 12,425' Jewelry Depth 1.Otis XXO profile for SSSV(2.813"ID) 250' 2.Otis X Nipple(2.813 ID) 14,482' 3.3-1/2"halfcut Muleshoe 14,482' J Liner 4.3-1/2"Baker seal assembly-8040 PBR(17.91' 7" P-110 (29ppf ends 12,552') length). Baker PBR(4.00"ID)w/concentrc J BTC P-110 (32ppf ends 15,921') coulping(4.00"ID)and Baker SBE(18.74'length). 14,464' • :,p Bottom 5.Baker FAB-1 pkr,size 83FA47(4.00"ID) 14,484' MD 12,217' 15,921' 6.Baker FAB-1 pkr,size 83FA47(4.00"ID) 14,813' TVD 12,130' 15,699' 7.Cement retainer 15,361' J Tubing Cmt w\1,400 sks Glass G 3-1/2" L-80 9.3ppf 8RD-MOD Top Bottom MD 0' 14,482' Gas Lift Data TVD 0' 14,304' Isolation Liner Size for all:3.5" ID for all: 2.867' 5" N-80 (18ppf) Depth Mandrel Valve Type Latch Port TOg Bottom 2,737' Flopetrol SPM-2 1.5"GLV 1.5R RK 16/64 MD 14,487' 14,813' 4.747' Flopetrol SPM-2 1.5"GLV 1.5R RK 16/64TVD 14,309' 14,623' 6,132' Flopetrol SPM-2 1.5"GLV 1.5R RK 16/64 Top of Liner Hanger 7,200' Flopetrol SPM-2 1.5"GLV 1.5R RK 16/64 ' In- @ 12,217' 8,079' Flopetrol SPM-2 1.5"GLV 1.5R RK 16/64 Shoe @ 12,521' 8,862' Flopetrol SPM-2 1.5"GLV 1.5R RK 20/64 9,596' Flopetrol SPM-2 1.5"GLV 1.5R RK 20/64 Tvonek Perfs: 1 10,215' Flopetrol SPM-2 1.5"GLV 1.5R RK 20/64 _ MD ND Net Ft Zone SPF Date - 10,837' Flopetrol SPM-2 1.5"GLV 1.5R RK 20/64 IA 3 14,535-14,565' 14,355'-14,384' 30'Sqzd Upper'G' 4 1/73 11,463' Flopetrol SPM-2 1.5"GLV 1.5R RK 20/64 4 5 14,731'-14,743' 14,544'-14,556' 12'Sqzd Upper'G' 4 8/28/88 12,085' Flopetrol SPM-2 1.5"GLV 1.5R RK 20/64 7t 12,708' GLMA BST 1"GLV 1.OR BK-2 20/64 l 1'E - 15,063%15,123' 14,865'-14,923' 60' Lower'G' 6 04/15/13 13,206' GLMA BST 1"GLV 1.OR BK-2 20/64 * 15,040'-15,100' 14,843'-14,901' 60' Lower'G' 8 12/11/88 13,730' GLMA BST 1"GLV 1.0R BK-2 20/64 6 15,108'-15,128' 14,909'-14,928' 20' Lower'G' 8 12/11/88 14,259' GLMA BST 1"GLV 1.0R BK-2 3/8 15,132'-15,146' 14,932'-14,946' 14' Lower'G' 8 12/10/88 `� 15,149'-15,165' 14,946-14,962' 16' Lower'G' 6 01/15/14 { , 15,156-15,175' 14,954'-14,974' 20' Lower'G' 8 12/10/88 15,186-15,210' 14,984'-15,008' 25' Lower'G' 8 12/10/88 LowerG _ ri 15,361'-15,376' 15,154'-15,169' 15' Hemlock 4 12/12/72 - 15,382'-15,397' 15,175-15,189' 15' Hemlock 4 12/12/72 , 15,416-15,431' 15,208'-15,222' 15' Hemlock 4 12/12/72 15,446-15,461' 15,237'-15,252' 15' Hemlock 4 12/12/72 Last 4 perfs zone is Hemlock DST Perforations and is isolated by cmt.retainer,but never 0.,, E-line fill tag @ 15,165'RKB (01/15/14) Hemlock -- - 7 III TD PBTD 15,940'MD 15,315'MD 15,717'TVD 15,110'TVD Well Name 8 Number: Beaver Creek Unit#4 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:/ USA Angle @KOP and Depth: 2.0°@ 8,765' I Angle/Perfs:113°-'15° Maximum Deviation: 18° 13,780' Date Completed: 01/13/73 Ground Level(above MSL): 144.8' RKB(above GL)I 19.2' Revised By: Stan Porhola Downhole Revision Date: 1/15/2014 Schematic Revision Date: 1/27/2014 • �``'�1��%_`�� THE STATE i �,EI`�LOL aid Ga I h;�-rte -=�.,�_e ; / =-y ltreS t -��� __ 333 West Seventh Avenue 4, GOVERNOR SEAN PARNELL Anchorage, Alaska 99501-3572 'N�*;'e' , Main: 907.279.1433 ®�-.ALAe- M)V. 907.276.7542 SCIWIE0 KV 1 6 2014 Stan Porhola Operations Engineer Hilcorp Alaska, LLC 17g--- 0 L3 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Beaver Creek Field, Beaver Creek Oil Pool, BCU 04 Sundry Number: 314-019 Dear Mr. Porhola: 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. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, lic i :2".C--4/7(12?-•- --- Cathy P. oerster Chair DATED this� / day of January, 2014. Encl. lk• i� STATE OF ALASKA 1 1,V• ,0 f...;;., ALASKA OIL AND GAS CONSERVATION COMMISSION 07S ,I)? 19 APPLICATION FOR SUNDRY APPROVALS AOGGC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Well❑ Change Approved Program❑ .--' .� Suspend❑ Plu Perforations ❑ Perforate Q Pull Tubing❑ Time Extension❑ Operations Shutdowi❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ Other:❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development ❑✓ 172-013 • 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number Anchorage,Alaska 99503 50-133-20239-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO#237,Rule#3B Beaver Creek Unit(BCU)04 • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028083 • Beaver Creek/Beaver Creek Oil • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 15,940 , 15,717 • 15,135 14,935 N/A 15,135'(fill) Casing Length Size MD ND Burst Collapse Structural Conductor 288' 20" 288' 288' Surface 2,989' 13-3/8" 2,989' 2,969' 3,450 psi 1,950 psi Intermediate 12,521' 9-5/8" 12,521' 12,425 6,870 psi 4,760 psi Production 3,704' 7" 15,921' 15,699' 11,220 psi 8,530 psi Liner 326 5" 14,813 14,623' 10,140 psi 10,500 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3#/1-80 EUE,AB Mod Tubing 14,482' Packers and SSSV Type: Otis XXO SSSV Packers and SSSV MD(t)and ND(ft): 250'MD-250'ND (2)Baker FAB-1 Pkrs 14,484'MD-14,306'ND;14,813'MD-14,623'ND 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphies Development n Service n 14.Estimated Date for 15.Well Status after proposed work: 01/15/14 Commencing Operations: Oil ❑✓ • Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhala Phone: 907-777-8412 Email sDorhola( hilcorD.cortl Printed Name Stan Porhola Title Operations Engineer Signaturei�C �� v'�_ Phone 907-777-8412 Date rV/0 /(i- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS MAY 0 9 2014 Spacing Exception Required? Yes ❑ Noi Subsequent Form Required: /U —ti(j`1 APPROVED BY / Approved by: �T"" COMMISSIONER THE COMMISSION Date: /— /7-/it /'f C I pp g of .. l � Submit Form and Form 10-403(Revised 10/ 12) Ap r I 12 months from the date of approval. Attachments in upi' e -F pl, . „ - , • n Well Prognosis Well: BCU-04 Hilcorp Alaska,LI) Date: 1-09-14 %water)Well Name: BCU-04 API Number: 50-133-20239-00 Current Status: Oil Producer Leg: N/A Estimated Start Date: January 15, 2014 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 172-013 First Call Engineer: Stan Porhola (907)777-8412 (0) (907)331-8228(M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907)229-4824(M) AFE Number: Current Bottom Hole Pressure: 2,748 psi @ 14,959'ND (Static survey on 11/07/13) Maximum Expected BHP: 2,748 psi @ 14,959'ND Max.Allowable Surface Pressure: 1,200 psi (Gas lift pressure,with GL shut-in and bled to zero, no expected surface pressure). Brief Well Summary The well was drilled in 1972-1973 to a TD of 15,940' MD(15,717'ND)and completed with 5" liner set at 14,487'. Initial PBTD was 15,315' MD. The well was completed in the Tyonek G formation in January s 1973. In 1987 a workover was completed and the upper G zone was added. In 1988, 1989, 1990, 1991, 1992, 1993& 1997 the zones were reperforated. A sand in the Lower Tyonek G was re-perforated in 2013. • Current well status The well is currently producing with fill bailed and tagged at 15,184'. • Obiective Add and re-perforate the Lower Tyonek G interval with a total of 29'of perforations. E-line procedure: 1. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 2. RU 2.50" dummy gun and tag fill at 15,184'. 3. RU 2.50" 6 spf HC wireline guns. 4. RIH and perforate Lower Tyonek G interval from 15,144'-15,173' (29'). a. Perforate in 2 runs(15t run: 9'; 2nd run: 20'). b. Proposed perfs shown on the proposed schematic in red font. c. Correlate perf interval off of GR/CCL log dated 11/07/13. d. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. 5. RD E-line. 6. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic . . • ' ini BC-04 ACTUAL PaHil'orp A1.4,..Lis: FNL, 60'FEL, SCHEMATIC Permit#: 172-013 Sec. 33, T7N, R1OW, S.M. API#: 50-133-20239-00 p Conductor Property Des: A-028083 I (� 20" H-40 94ppf KB elevation: 164'(19'AGL) J I! CyA TOp Bottom Latitude: MD 0' 288' Longitude: TVD o 288 Spud: 06/12/1972 Cmt w\60 sks Class G TD: 11/26/1972 r Rig Released: J Surface Casing PA#: 13-3/8" N-80 (72ppf ends 1,942') J 8RD J-55 (68ppf ends 2,989') T� Bottom MD 0' 2,989' J TVD 0' 2,989' Cmt w\2,000 sks Class G w/4%gel; Tree cxn:6-1/2"Otis followed by 300 sks Class G J Intermediate Casinq Directional Data 9-5/8" N-80 (47.Oppf ends 7,421') Maximum Hole Angle: 18 @ 13,780'MD J BTC S-95 (47.Oppf ends 9,938') Angle Through'G': 14 P-110 (53.5ppf ends 12,521') Angle Through Hemlock: 14 J Tom Bottom MD 0' 12,521' ` TVD 0' 12,425' Jewelry Depth V J 1.Otis XXO profile for SSSV(2.813"ID) 250' 2.Otis X Nipple(2.813 ID) 14,482' 3.3-1/2"halfcut Muleshoe 14,482' J Liner 4.3-1/2"Baker seal assembly-8040 PBR(17.91' 7" P-110 (29ppf ends 12,552') length). Baker PBR(4.00"ID)w/concentric BTC P-110 (32ppf ends 15,921') J Tom Bottom coulping(4.00"ID)and Baker SBE(18.74'length). 14,464' 5.Baker FAB-1 pkr,size 83FA47(4.00"ID) 14,484' MD 12,217' 15,921' 6.Baker FAB-1 pkr,size 83FA47(4.00"ID) 14,813' J TVD 12,130' 15,699' 7.Cement retainer 15,361' Tubing Cmt w\1,400 sks Glass G 3-1/2" L-80 9.3ppf if J 8RD-MOD Top Bottom MD 0' 14,482' Gas Lift Data TVD 0' 14,304' Isolation Liner Size for all:3.5" ID for all: 2.867' J 5" N-80 (18ppf) Depth Mandrel Valve Type Latch Port TU2 Bottom 2,737' Flopetrol SPM-2 1.5"GLV 1.5R RK 16/64 MD 14,487' 14,813' 4,747' Flopetrol SPM-2 1.5"GLV 1.5R RK 16/64 J Top of Liner Hanger TVD 14,309' 14,623' 6,132' Flopetrol SPM-2 1.5"GLV 1.5R RK 16/64 @ 12,217' 7,200' Flopetrol SPM-2 1.5"GLV 1.5R RK 16/64 g J E 8,079' Flopetrol SPM-2 1.5"GLV 1.5R RK 16/6411 Shoe @ 12,521' 8,862' Flopetrol SPM-2 1.5"GLV 1.5R RK 20/64 9,596' Flopetrol SPM-2 1.5"GLV 1.5R RK 20/64 J Tvonek Perfs: 10,215' Flopetrol SPM-2 1.5"GLV 1.5R RK 20/64 2 MD ND Net Ft Zone SPF Date 10,837' Flopetrol SPM-2 1.5"GLV 1.5R RK 20/64 I 3 14,535'-14,565' .14,356-14,384' 30'Sqzd Upper'G' 4 1/73 11,463' Flopetrol SPM-2 1.5"GLV 1.5R RK 20/64 4 5 14,731'-14,743' • 14,544'-14,556' 12'Sqzd Upper'G' 4 8/28/88 12,085' Flopetrol SPM-2 1.5"GLV 1.5R RK 20/64 R ip 12,708' GLMA BST 1"GLV 1.OR BK-2 20/64 i'-if 1ik 5,063'-15,123' 14,865-14,923' 60' Lower'G' 6 04/15/13 13,206' GLMA BST 1"GLV 1.0R BK-2 20/64 y 15,040'-15,100' • 14,843'-14,901' 60' Lower'G' 8 12/11/88 13,730' GLMA BST 1"GLV 1.OR BK-2 20/64 6 15,106-15,128' '14,909'-14,928' 20' Lower'G' 8 12/11/88 14,259' GLMA BST 1"GLV 1.0R BK-2 3/8 15,132'-15,146' ' 14,932'-14,946' 14' Lower'G' 8 12/10/88 15,155-15,175' -14,954'-14,974' 20' Lower'G' 8 12/10/88 15,186-15,210' •14,984'-15,008' 25' Lower'G' 8 12/10/88 15,361'-15,376' •15,154'-15,169' 15' Hemlock 4 12/12/72 Lower G = 15,382'-15,397' -15,175-15,189' 15' Hemlock 4 12/12/72 \ 1S,416-15,431 '• 15,208'-15,222' 15' Hemlock 4 12/12/72 15,446-15,461'' 15,237'-15,252' 15' Hemlock 4 12/12/72 Last 4 perfs zone is Hemlock DST Perforations and is isolated by cmt.retainer,but never cmt.squeezed. Slickline fill cleanout _ @ 15,184' (01/08/14) Hemlock - TD PBTD 15,940'MD 15,315'MD 15,717'TVD 15,110'TVD Well Name&Number: Beaver Creek Unit#4 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:I USA Angle @KOP and Depth: 2.0°@ 8,765' I Angle/Perfs:113°--.15° Maximum Deviation: 18° 13,780' Date Completed: 01/13/73 Ground Level(above MSL): 14.4.8' RKB(above GL): 19.2' Revised By: Stan Porhola Downhole Revision Date: 1/8/2014 Schematic Revision Date: 1/9/2014 , , • fl . l . . - • BC-04 PROPOSED 8.•orp Alarl:,r,LLf. Pad 4 SCHEMATIC • 1,700'FNL, 660'FEL, I1 Permit#: 172-013 Sec. 33, T7N, R10W, S.M. API#: 50-133-20239-00 Conductor Property Des: A-028083I 1 i 20" H-40 94ppf KB elevation: 164'(19'AGL) I Top Bottom Latitude: MD 0' 288' Longitude: TVD 0' 288' Spud: 06/12/1972 Cmt w\( \60 sks Class G TD: 11/26/1972 Rig Released: J Surface Casing L PA#: 13-3/8" N-80 (72ppf ends 1,942') 8RD J-55 (68ppf ends 2,989') Tg Bottom MD 0' 2,989' TVD 0' 2,989' Tree cxn:6-112"Otis Cmt w\2,000 sks Class G w/4%gel: lii followed by 300 sks Class G _ Intermediate Casing Directional Data 9-5/8" N-80 (47.Oppf ends 7,421') BTC S-95 (47.Oppf ends 9,938') Maximum Hole Angle: 18 @ 13,780'MD P-110 (53.5ppf ends 12,521') Angle Through'G': 14 Angle Through Hemlock: 14 J Tom Bottom MD 0' 12,521' TVD 0' 12,425' ewe) Depth J 1.Otis XXO profile for SSSV(2.813"ID) 250' 2.Otis X Nipple(2.813 ID) 14,482' 3.3-1/2"halfcut Muleshoe 14,482' Liner 4.3-1/2"Baker seal assembly-8040 PBR(17.91' 7" P-110 (29ppf ends 12,552') length). Baker PBR(4.00"ID)w/concentric BTC P-110 (32ppf ends 15,921') coulping(4.00"ID)and Baker SBE(18.74'length). 14,464' lag Bottom 5.Baker FAB-1 pkr,size 83FA47(4.00"ID) 14,484' MD 12,217' 15,921' 6.Baker FAB-1 pkr,size 83FA47(4.00"ID) 14,813' TVD 12,130' 15,699' 7.Cement retainer 15,361' Tubing Cmt w\1,400 sks Glass G 3-1/2" L-80 9.3ppf 411-I 8RD-MOD Top Bottom P MD 0' 14,482' Gas Lift Data TVD 0' 14,304' Isolation Liner Size for all:3.5" ID for all: 2.867' J 5" N-80 (18ppf) Depth Mandrel Valve Type Latch Port Tog Bottom 2,737' Flopetrol SPM-2 1.5"GLV 1.5R RK 16/64 MD 14,487' 14,813' 4,747' Flopetrol SPM-2 1.5"GLV 1.5R RK 16/64 J Top of Liner Hanger TVD 14,309' 14,623' 6,132' Flopetrol SPM-2 1.5"GLV 1.5R RK 16/64 @ 12,217' 7,200' Flopetrol SPM-2 1.5"GLV 1.5R RK 16/64 1 J 0 8,079' Flopetrol SPM-2 1.5"GLV 1.5R RK 16/64 Shoe @ 12,521' 8,862' Flopetrol SPM-2 1.5"GLV 1.5R RK 20/64 9,596' Flopetrol SPM-2 1.5"GLV 1.5R RK 20/64 Tvonek Perfs: 10,215' Flopetrol SPM-2 1.5"GLV 1.5R RK 20/64 2 MD TVD Net Ft Zone SPF Date 10,837' Flopetrol SPM-2 1.5"GLV 1.5R RK 20/64 r L 14,535'-14,565' 14,355'-14,384' 30'Sqzd Upper'G' 4 1/73 11,463' Flopetrol SPM-2 1.5"GLV 1.5R RK 20/64 4 - : 14,731'-14,743' 14,544'-14,556' 12'Sqzd Upper'G' 4 8/28/88 12,085' Flopetrol SPM-2 1.5"GLV 1.5R RK 20/64 iIP' _ 12,708' GLMA BST 1"GLV 1.OR BK-2 20/64 JIl --- 15,063'-15,123' 14,865-14,923' 60' Lower'G' 6 04/15/13 13,206' GLMA BST 1"GLV 1.OR BK-2 20/64 r, 15,040'-15,100' 14,843'-14,901' 60' Lower'G' 8 12/11/88 13,730' GLMA BST 1"GLV 1.0R BK-2 20/64 • - 6 15,108'-15,128' 14,909'-14,928' 20' Lower'G' 8 12/11/88 14,259' GLMA BST 1"GLV 1.OR BK-2 3/8 15,132'-15,146' 14,932'-14,946' 14' Lower'G' 8 12/10/88 15,144'-15,173' 14,942'-14,970' 29' Lower'G' 6 Proposed 15,155-15,175' 14,954'-14,974' 20' Lower'G' 8 12/10/88 15,186-15,210' 14,984'-15,008' 25' Lower'G' 8 12/10/88 Lower G 1 15,361'-15,376' 15,154'-15,169' 15' Hemlock 4 12/12/72 15,382'-15,397' 15,175-15,189' 15' Hemlock 4 12/12/72 15,416'-15,431' 15,208'-15,222' 15' Hemlock 4 12/12/72 • 15,446'-15,461' 15,237'-15,252' 15' Hemlock 4 12/12/72 Last 4 perfs zone is Hemlock DST Perforations and is isolated by colt.retainer,but never Add perforations 15,144'-15,173' ler/ Slickline fill cleanout ._ _ @ 15,184' (01/08/14) Hemlock -_- I TD PBTD 15,940'MD 15,315'MD 15,717'TVD 15,110'TVD Well Name&Number: Beaver Creek Unit#4 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:) USA Angle @KOP and Depth: 2.0°@ 8,765' I Angle/Pens: 13° .15° Maximum Deviation: 18° 13,780' Date Completed: 01/13/73 Ground Level(above MSL): 144.8' RKB(above GL): 19.2' Revised By: Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date: 1/9/2014 + STATE OF ALASKA • AIL OIL AND GAS CONSERVATION COMMISSION '.h 1 5 2013 REPORT OF SUNDRY WELL OPERATIONS 0GC 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC • Development El Exploratory ❑ 172 -013 ' 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, Alaska 99504 50- 133 - 20239 -00 ' 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028083 Beaver Creek Unit (BCU) 04 . 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): N/A Beaver Creek / Beaver Creek Oil • 11. Present Well Condition Summary: • Total Depth measured 15,940 feet Plugs measured N/A feet true vertical 15,717 feet Junk measured 15,135 (fill) feet Effective Depth measured 15,135 feet Packer measured 14,484; 14,813 feet true vertical 14,935 feet true vertical 14,306; 14,623 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 288' 20" 288' 288' Surface 2,989' 13 -3/8" 2,989' 2,989' 3,450 psi 1,950 psi Intermediate 12,521' 9 -5/8" 12,521' 12,425' 6,870 psi 4,760 psi Production 3704' 7" 15,921' 15,699' 11,220 psi 8,530 psi Liner 326' 5" 14,813' 14,623' 10,140 psi 10,500 psi Perforation depth Measured depth See Attached Schematic SCANNED MAY 3 0 2013 True Vertical depth See Attached Schematic 9.3# / L -80 EUE, Tubing (size, grade, measured and true vertical depth) 3 -1/2" AB Mod Tubing 14,482' MD 14,304' TVD 14,484' MD - 14,306' TVD Packers and SSSV (type, measured and true vertical depth) (2) Baker FAB -1 Pkrs 14,813' MD - 14,623' TVD Otis XXO SSSV 250' MD - 250' TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 70 0 90 700 65 Subsequent to operation: 70 140 60 700 65 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development 0 - Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil El . Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 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: 313 -162 Contact Chad Helgeson Email chelgeson( hilcoro.com Printed Name Chad Helgeson Title Operations Manager Signature Phone 907 - 777 -8405 Date $/ S/1 FIBbMS MAY 17 201 s"•z � Form 10 -404 Revised 10/2012 / ��/ / Submit Original Only • • • ' I Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU -04 50- 133 - 20239 -00 172 -013 4/15/13 4/15/13 Daily Operations: 04/15/2013- Monday Mobe equip to location. Rig up lubricator. Pressure test lubricator to 250 psi low and 2000 psi high. RIH with 2 -1/2" x 20' HC, 6 spf, 60 deg perf gun and tie into Pollard CCL /GR log dated 13- Apr -13. Spot gun from 15,123' to 15,103' per E -mail from Operations Manager dated 4- 13 -13. Tubing pressure was 700 psi. Fired gun. No pressure change. POOH. All shots fired. RIH with 2 -1/2" x 20' HC, 6 spf, 60 deg perf gun and tie into Pollard CCL /GR log dated 13- Apr -13. Spot gun from 15,103' to 15,083' per E -mail from Operations Manager dated 4- 13 -13. Tubing pressure was 700 psi. Fired gun. No pressure change. POOH. All shots fired. RIH with 2 -1/2" x 20' HC, 6 spf, 60 deg perf gun and tie into Pollard CCL /GR log dated 13- Apr -13. Spot gun from 15,083' to 15,063' per E -mail from Operations Manager dated 4- 13 -13. Tubing pressure was 700 psi. Fired gun. No pressure change. POOH. All shots fired. Rig down lubricator and turn well over to Field. • • BCU -04 II Permit #: 172 -013 Pad 4 API #: 50- 133 - 20239 -00 Ililcorp Alaska, LLC Property Des: A - 028083 KB elevation: 164' (19' AGL) Conductor WBS #: 2 H -40 94pof _J Latitude: T� Bottom Longitude: M D 0' 288' Spud: 06 -12 -1972 TV D 0' 288' TD: 11/26/1972 Cm t w\ 60 sks Class G Rig Released: PA #: S urface Casin -3" N -80 (N -80 ends 1,942' ) J -5 5 (J -55 starts 1,942') T_O Bottom MD 0' 2,989' T VD 0' 2,989' Cmt w \2,00 0 sk s Class G w/4 % gel; 1 1 -1 -1-ii f ollowed by 300 sks Class G Intermediate Casinq 9 -5/8" N -80 4 7ppf J S -95 53.5ppf Tubin P -110 3 -1/2" L -80 AB Mod 8RD J Tom Bottom MD 0' 12,521' 13p Bottom TVD 0' 12,425' MD 0' 14,482' TVD 0' 14,304' • N -80 ends at 7,421', S -95 starts at 7,421' and ends at V' J 9,938', P -110 starts at 9,938' and ends at 12,521'. J Liner 7" P -110 Jewelry Depth "1:::% Bottom 1. Otis XXO profile for SSSV (2.81 3" ID) 250' J MD 12,217' 15,921' 2. Otis X Nipple (2.813 ID) 14,482' TVD 12,130' 15,699' 3. 3 -1/2" halfcut Muleshoe 14,482' Cmt w \1,400 sks Glass G 4. 3 -1/2" Baker seal assembly -8040 PBR (17.91' J length). Baker PBR (4.00" ID) w /concentric Isolation Liner coulping (4.00" ID) and Baker SBE (18.74' length). 14,464' • J 5" N -80 5. Baker FAB -1 pkr, size 83FA47 (4.00" ID) 14,484' & 14,813' 6. Cement retainer 15,361' T� Bottom J MD 14,487' 14,813' TVD 1 4,309' 14,623' J -Al R J zT � Tyonek Perfs: Gas Lift Data K �I MD TVD Net Ft Zone SPF Date Size for all: 3.5" ID for all: 2.867' J 14,535-14,565' 14,355-14,384' 30' Sqzd Upper'G' 4 1/73 Depth Mandrel Valve Type Latch Port 14,731'- 14,743' 14,544'- 14,556' 12' Sqzd Upper'G' 4 8/28/88 2,737' Flopetrol SPM -2 1.5" GLV 1.5R RK 16/64 2 4,747' Flopetrol SPM -2 1.5" GLV 1.5R RK 16/64 L 3 15,063'- 15,123' 14,865- 14,923' 60' Lower 'G' 6 04/15/13 6,132' Flopetrol SPM -2 1.5" GLV 1.5R RK 16/64 4 - 5 15,040'- 15,100' 14,843'- 14,901' 60' Lower'G' 8 12/11/88 7,200' Flopetrol SPM -2 1.5" GLV 1.5R RK 16/64 __ 15,106- 15,128' 14,909'- 14,928' 20' Lower 'G' 8 12/11/88 8,079' Flopetrol SPM -2 1.5" GLV 1.5R RK 16/64 , 15,132'- 15,146' 14,932'- 14,946' 14' Lower'G' 8 12/10/88 • 8,862' Flopetrol SPM -2 1.5" GLV 1.5R RK 20/64 15,155'- 15,175' 14,954'- 14,974' 20' Lower'G' 8 12/10/88 9,596' Flopetrol SPM -2 1.5" GLV 1.5R RK 20/64 15,185- 15,210' 14,984'- 15,008' 25' Lower'G' 8 12/10/88 10,215' Flopetrol SPM -2 1.5" GLV 1.5R RK 20/64 • 10,837' Flopetrol SPM -2 1.5" GLV 1.5R RK 20/64 15,361'- 15,376' 15,154'- 15,169' 15' Hemlock 4 12/12/72 , 11,463' Flopetrol SPM -2 1.5" GLV 1.5R RK 20/64 15,382'- 15,397' 15,175- 15,189' 15' Hemlock 4 12/12/72 4 12,085' Flopetrol SPM -2 1.5" GLV 1.5R RK 20/64 15,416- 15,431' 15,208'- 15,222' 15' Hemlock 4 12/12/72 12,708' GLMA BST 1" GLV 1.OR BK -2 20/64 15,446- 15,461' 15,237'- 15,252' 15' Hemlock 4 12/12/72 13,206' GLMA BST 1" GLV 1.0R BK -2 20/64 13,730' GLMA BST 1" GLV 1.OR BK -2 20/64 j= Last 4 perfs zone is Hemlock DST Perforations and is isolated by cmt. retainer, but never 14,259' GLMA BST 1 " GLV 1.OR BK -2 3/8 cmt. squeezed. t miliNr= • ' Directional Data Maximum w+ Maximum Hole Angle: 18 @ 13,780' MD Angle Through 'G': 14 Angle Through Hemlock: 14 Fill tagged @ 15,135' MD RKB >• 6 (03/14/13) 2.50" Bailer ti ter.. TD PBTD 15,940' MD 15,315' MD 15,717' TVD 15,110' TVD Well Name & Number: BC-4 Lease: Beaver Creek Gas Field County or Parish: Kenai Penisula State: Alaska 1 Country:I USA Perforations (MD): 14,435' - 15,461' (TVD): 14,258' - 15,252' Angle c KOP and Depth: Angle /Perfs: Dated Completed: 1/14/1973 Completion Fluid: 6% KCL Revised by: DMA Last Revison Date: 5/15/2013 • • OF rit, �� \ \I %% s, THE STATE T Alaska Gil m Gas Of l 1 1 SIK 1 C© serval Ccimmissizri GOVERNOR SEAN PARNELL 333 West Seventh Avenue *,R Anchorage, Alaska 99501 -3572 OF ALAS Main: 907.279.1433 Fax: 907.276.7542 Chad Helgeson APR 0 X01 Operations Manager Hilcorp Alaska, LLC O 3800 Centerpoint Drive Anchorage, AK 99503 Re: Beaver Creek Field, Beaver Creek Oil Pool, BCU 04 Sundry Number: 313 -162 Dear Mr. Helgeson: 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. 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 reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair DATED this day of April, 2013. Encl. �S.t3 . w.. e Le • , 5 - ° STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS A 0(.71‘ 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Wel❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate 0 ' Pull Tubing Time Extension ❑ Operations Shutdowi ❑ Re -enter Susp. Wel ❑ Stimulate ❑ Alter Casing] Other. ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Hilcorp Alaska, LLC 172 -013 ' Exploratory ❑ Development El 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number: • Anchorage, Alaska 99503 50-133-20239-00 1 7. If perforating: CO #237, Rule #3B 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? (See Attached Map) Beaver Creek Unit (BCU) 04 • Will planned perforations require a spacing exception? Yes L] No El 9. Property Designation (Lease Number): 10. Field /Pool(s): FEDA028083 • Beaver Creek / Beaver Creek Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 15,940 ' 15,717 ° 15,135 14,935 N/A 15,135' (fdl) Casing Length Size MD 7VD Burst Collapse Structural Conductor 288' 20" 288' 288' Surface 2,989' 13 -3/8" 2,989' 2,989' 3,450 psi 1,950 psi Intermediate 12,521' 9 -5/8" 12,521' 12,425 6,870 psi 4,760 psi Production 3,704' 7" 15,921' 15,699' 11,220 psi 8,530 psi Liner 326 5" 14,813 14,623' 10,140 psi 10,500 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3 -1/2" 9.3# /1-80 EUE, AB Mod Tubing 14,482 Packers and SSSV Type: Otis XXO SSSV Packers and SSSV MD (t) and TVD (ft): 250' MD - 250' TVD (2) Baker FAB -1 Pkrs 14,484' MD - 14,306' TVD; 14,813' MD - 14,623' TVD 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program n BOP Sketch ❑ Exploratory [ Stratigraphiff Development Fr Service n 14. Estimated Date for 15. Well Status after proposed work: 04/08/13 Commencing Operations: Oil 0 • Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chad Helgeson Phone: 907- 777 -8405 Email chelgeson@hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature /1 G Aj✓ ✓✓ Phone 907 - 777 -8405 Date `/"2 /l3 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ,. ( 2_ _ X13- w Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: . R8DMS APR 0 8 201 Spacing Exception Required? Yes ❑ No [/ Subsequent Form Required: /0 — yO if 1 / APPROVED BY Approved by: - / y y �( --- COMMISSIONER THE COMMISSION Date: Q-. —5.... 13 Submit Fonn and �� o raisteN2A L Approved application is valid for 12 months from the date of approval. Attachm Dui ,_ • • Well Prognosis Well: BCU -04 Hilcorp Alaska, LL Date: 4 -2 -13 % water)WeII Name: BCU -04 API Number: 50- 133 - 20239 -00 Current Status: Oil Producer Leg: N/A Estimated Start Date: April 8, 2013 Rig: Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777 -8305 Permit to Drill Number: 172 -013 First CaII Engineer: Chad Helgeson (907) 777 -8405 (0) (907) 229 -4824 (M) Second Call Engineer: Jeff Allen (907) 777 -8402 (0) AFE Number: Current Bottom Hole Pressure: 2,596 psi @ 14,885' TVD (static survey on 06/8/12) Maximum Expected BHP: 2,596 psi @ 14,885' TVD Max. Allowable Surface Pressure: 1200 psi (Gas lift pressure, with GL shut -in and bled to zero, no expected surface pressure). Brief Well Summary The well was drilled in 1972 -1973 to a TD of 15,940' MD (15,717' TVD) and completed with 5" liner set at 14,487'. Initial PBTD was 15,315' MD. The well was completed in the Tyonek G formation in January 1973. In 1987 a workover was completed and the upper G zone was added. In 1988, 1989, 1990, 1991, 1992, 1993 & 1997 the zones were reperforated. Current well status The well is currently producing with fill tagged at 15,135'. Objective Re- perforate the Tyonek G -2 intervals a total of 25'. Brief Procedure: 1. MI RU E -Line Unit 2. Pressure test lubricator to 2000 psi. 3. RIH with 2.75 gauge ring to tag bottom or a 2.5" x 20ft dummy gun run. 4. Clean tubing as necessary to get guns to bottom, with gauge rings, or if necessary hot oil treatment. 5. RU 2.5" scalloped TT perforating guns, 6 shots /ft, 60deg phase, RIH w/ safe detonating system and perf 15,108- 15,120' (12'). 6. POH laydown guns and check to ensure all guns fired. 7. PU 2.5" 15,062- 15,075' (13'). 8. POH laydown guns and check to ensure all guns fired. Attachments: 1. As -built Schematic 2. Spacing map • • • BCU -04 11 Permit #: 172 -013 Pad 4 API #: 50- 133 - 20239 -00 IIil.•orp :11.. -1.:.. !it' Property Des: A - 028083 KB elevation: 164' (19' AGL) Conductor WBS #: i I 20" H -40 94ppf ' ' Latitude: L T op Bottom Longitude: MD 0' 288 Spud: 06 -12 -1972 TVD 0' 288 TD: 1 1/26/1972 Cmt w\ 60 s ks Class G Rig Released: PA #: J Surface Casinq 13 -3/8" N -80 (N -80 ends 1,942' ) i J -55 (J -55 starts 1,942') Tom Bottom MD 0' 2,989' TVD 0' 2,989' Cmt w \2,000 sks Class G w/4 % gel; followed by 300 sks Class G J Intermediate Casinq I 9 -5/8" N -80 47ppf J S -95 53.5ppf Tubing P -110 3 -1/2" L -80 AB Mod 8RD J Two Bottom MD 0' 12,521' Top Bottom TVD 0' 12,425' MD 0' 14,482' N -80 ends at 7,421', S -95 starts at 7,421' and ends at TVD 0' 14,304' 11'J 9,938', P -110 starts at 9,938' and ends at 12,521'. J Liner 7" P -110 Jewelry Depth lan Bottom 1. Otis XXO profile for SSSV (2.813" ID) 250' J MD 12,217' 15,921' 2. Otis X Nipple (2.813 ID) 14,482' TVD 12,130' 15,699' 3. 3 -1/2" halfcut Muleshoe 14,482' J Cmt w \1,400 sks Glass G 4. 3 -1/2" Baker seal assembly -8040 PBR (17.91' length). Baker PBR (4.00" ID) w /concentric Isolation Liner coulping (4.00" ID) and Baker SBE (18.74' length). 14,464' . 5" N -80 5. Baker FAB -1 pkr, size 83FA47 (4.00" ID) 14,484' & 14,813' / E Bottom 6. Cement retainer 15,361' t MD 14,487' 14,813' 1 P-10 ,4'1 41 ' 4 3. TVD 14,309' 14,623' J 1 t��j Gas Lift Data _....IE J gib- MD TVD Net Ft Zone SPF Date Size for all: 3.5" ID for all: 2.867' J 4.35' .114,258- 14,384' 30' Sqzd Upper 'G' 4 1/73 Depth Mandrel Valve Type Latch Port 14,731-15,743 14,544 - 14,556' 12' Sqzd Upper'G' 4 8/28/88 2,737' Flopetrol SPM -2 1.5" GLV 1.5R RK 16/64 4,747' Flopetrol SPM -2 1.5" GLV 1.5R RK 16/64 3 15,040'- 15,100' 14,843- 14,901' 60' Lower 'G' 8 12/11/88 6,132' Flopetrol SPM -2 1.5" GLV 1.5R RK 16/64. 5 15,108'- 15,128' 14,909 - 14,928' 20' Lower 'G' 8 12/11/88 7,200' Flopetrol SPM -2 1.5" GLV 1.5R RK 16/64 15,132'- 15,146' 14,932- 14,946' 14' Lower 'G' 8 12/10/88 8,079' Flopetrol SPM -2 1.5" GLV 1.5R RK 16/64 1 15,155- 15,175' 14,954 - 14,974' 20' Lower 'G' 8 12/10/88 8,862' Flopetrol SPM -2 1.5" GLV 1.5R RK 20/64 -- r 15,185'- 15,210' 14,984- 15,008' 25' Lower 'G' 8 12/10/88 9,596' Flopetrol SPM -2 1.5" GLV 1.5R RK 20/64 10,215' Flopetrol SPM -2 1.5" GLV 1.5R RK 20/64 15,361- 15,376' - 15,154- 15,169' 15' Hemlock 4 12/12/72 10,837' Flopetrol SPM -2 1.5" GLV 1.5R RK 20/64 15,382' - 15,397' 15,175- 15,189' 15' Hemlock 4 12/12/72 11,463' Flopetrol SPM -2 1.5" GLV 1.5R RK 20/64 15,416- 15,431' ' 15,208- 15,222' 15' Hemlock 4 12/12/72 12,085' Flopetrol SPM -2 1.5" GLV 1.5R RK 20/64 15,445- 15,461' . 15,237- 15,252' 15' Hemlock 4 12/12/72 12,708' GLMA BST 1" GLV 1.0R BK -2 20/64 13,206' GLMA BST 1" GLV 1.0R BK -2 20/64 = - Last 4 perfs zone is Hemlock DST Perforations and is isolated by cmt. retainer, but never 13,730' GLMA BST 1" GLV 1.0R BK -2 20/64 = cmt. squeezed. 14,259' GLMA BST 1" GLV 1.0R BK -2 3/8 Directional Data Maximum Hole Angle: 18 @ 13,780' MD Angle Through 'G': 14 Angle Through Hemlock: 14 Fill tagged @ 15,135' MD RKB (03/14/13) 2.50" Bailer TD PBTD 15,940' MD 15,315' MD 15,717' TVD 15,110' TVD Well Name & Number: BC -4 Lease: Beaver Creek Gas Field County or Parish: Kenai Penisula State: Alaska I Country:I USA Perforations (MD): 14,435' - 15,461' (TVD): 14,258' - 15,252' Angle @ KOP and Depth: Angle / Perfs: Dated Completed: 1/14/1973 Completion Fluid: 6% KCL Revised by: DMA Last Revison Date: 4/1/2013 • • -15452 - 1491 BCU 15 BCU 0500k ga Gas Sands PA • 1 5 00' I BC . 4: Ara _.: -15,425 BCU 06 1 660' I Hilcorp Alaska NORTH KENAI Beaver Creek Lower Tyonek G / Heml ck PA .,T,on.kSt H.m..Rw.r 0 1 218 FEET POSTED WELL DATA BCUO2 15'541 Well Label BCU 07 FMTOPS - TD[JW S] (SS) ATTRIBUTE MAP re Zone: FMTOPS - BC_G_MKR' JWS] IS PRESENT () - 15,329 WELL SYMBOLS • Oil Well - Gas Well 0' Injection Well X Abandoned Location - Pt rnit ♦ - Plugged and Abandone2 March 8, 2013 e+ ID A PETRA 3/82013 8:08:32 AM y OF 7•4 • 0. \ THE STATE Alaska Oil and Gas i "' 1 s t ' "' Of Conservation _ _ __ ALAS fSth GOVERNOR SEAN PARNELL t w''' 333 West Seventh Avenue FALAS1� Anchorage, Alaska 99501 -3572 Main: 907.279.1433 Fax: 907.276.7542 November 8, 2012 Mr. Jim Senn Operations Manager Marathon Oil Company P.O. Box 1949 Kenai, Alaska 99611 SCANNED APR 0 8 2013 Re: Defeated Safety Valve System Beaver Creek Unit 4 (PTD 1720130) Dear Mr. Senn: The Alaska Oil and Gas Conservation Commission (AOGCC) has received the Incident Investigation Report as requested in the notice of violation dated October 15, 2012 regarding the defeated safety valve system on Beaver Creek Unit 4. The investigation performed by Marathon Alaska Production LLC (Marathon) indicates inadequate communications among Production Operators assigned to Beaver Creek Unit as the root cause for this failure. Documentation provided with the investigation report shows Marathon has an active process to manage the safe temporary disabling of engineering safeguards such as well safety valve systems, including a tagging procedure for defeated critical safety systems and devices. Following the documented procedures for disabling an engineering safeguard would likely have eliminated the violation. Marathon has satisfactorily addressed the regulatory concerns identified in the notice of violation. The AOGCC does not intend to pursue any further enforcement action regarding the Beaver Creek Unit 4 defeated safety valve system. Sincerely, Cathy P. Chair, Commissioner cc: AOGCC Inspectors (via email) . ,, ,f Alaska.'! ,, Domestic ~roduction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 July 21, 1997 Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Mr. Wondzell: Please find attached Form 10-404, Report of Sundry Well Operations. BC-4 was reperforated in the Lower G-Zone on July 16 and 17, 1997. If you have any questions, please contact me at 564-6315. Sincerely, Michael R. Ol$on Production En~±noor ~ttachment$ cc: CEF A subsidiary of USX Corporation Environmentally aware for the long run. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Stimulate Plugging Pull Tubing Alter Casing m Repair Well Perforate X Other 2. Name of Operator Marathon Oil Company 3. Address P.O. Box 196168, Anchora~le, AK 99519-6168 4. Location of Well at Surface 1700' FSL, 660' FWL, Sec. 33-7N-10W-SM At top of Productive Interval 1467' FSL, 711' FEL, Sec. 34-7N-10W-SM At Effective Depth 1492' FSL, 768' FEL, Sec. 34-7N-10W-SM At Total Depth 1553' FSL, 900' FEL, Sec. 34-7N-10W-SM 5. Type of Well: Development X Exploratory Stratigraphic Service 10. 6. Datum Elevation (DF or KB) 19' KB above GL feet 7. Unit or Property Name Beaver Creek Unit 8. Well Number BC-4 9. Permit Nurol~r/Approval Number 397-115 ~'~ "7 c~ -~ l~.'~ APl Number 50-- 133-20239 11. Field/Pool Beaver Creek Field 12. Present Well Condition Summary Total Depth: measured true vertical 15921 feet Plugs (measured) 15715 feet None Effective Depth: measured 15529 feet Junk (measured) true vertical 15290 feet None Casing Length Size Cemented Structural Conductor Driven Surface 2989' 13-3/8" 2000 sx Intermediate 12521' 9-5/8" 2868 sx Production Liner 3704' 7" 1400 sx Measured Depth 2989' 12521' 15921' True Vertical Depth 2890' 12445' 15715' Perforation Depth: measured true vertical See attached Tubing (size, grade, and measured depth) 3-1/2" 9.3# L-80 EUE, AB Mod Tubing @ 14482' Packers and SSSV (type and measured depth) Otis XXO Profile for SSSV @ 250', Baker FAB-1 Packer @ 14484', Baker FA-1 Packer @ 14813' ORiGiNAL 13. Stimulation or Cement Squeeze Summary Intervals Treated (measured) Treatment Description Including Volumes Used and Final Pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to Well Operation 229 1 650 5O Subsequent to Operation 250 6 770 8O 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of Well Classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev. 06/15/88 Date 7/21/97 Submit in Duplicate MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 7/15/97 FIELD: Beaver Creek FILL DEPTH/DATE: 15264' (7/15/97) TUBING: 3.5" 9.3# L-80 DATE LAST WL WORK: 6/19/97 WORK DONE: Run 2.55" GR to 15302' PRESENT OPERATION: SDFN, plan to continue perfin~l tomorrow PROBLEMS: Unable to work past GLM #7 w/perf gun WELL #: BC-4 CASING: 7" TREE CONDITION: OK BENCHES OPEN: Lower G zone Hemlock sanded back SUMMARY OF OPERATIONS 7/14/97 Increased gas lift rate to 1.6 mmscfpd and closed production choke to 3 turns open. SWS on location to spot equipment and perform partial RU. 7/15/97 SWS on location. Conduct operations, safely and environmental meeting. RU equipment. MU 25' Owen 2-1/8" expendable strip gun, 6 spf, +/- 45 degree phasing, Shogun NT HMX Icharges, Establish communication blackout, Arm gun. Some delay due to the guns being non-Schlumberger equipment and problems with check valve in hydrotest pump. PT w/fresh water. Replace O ring. PT to 1500 psig. Good test. Well flowing smooth at 1.6 mmscfpd gas lift rate. CP = 890 psig, TP = 95 psig. RIH. Max speed - 10,000 ft/hr. Guns sat down at 9547' (GLM # 7). Worked guns gently for 30 minutes but unable to clear restriction. POOH. Establish communications blackout. OOH. Disarm guns. Guns had traces of paraffin/asphaltenes. Bottom of strip was slightly indented - suspect strip getting stuck on lip of GLM #7. Top of strip was cracked on two sides. Remove guns and add addn'l weight bar, RIH w/CCL and weights to TT and correlate. No problems getting past GLMs. Tag fill at 15264' (hard tag - not sticky). PU and correlate to CBL dated 11/28/72 (added 4' to collars to be on depth w/DIL dated 10/18/72). Flag line at 14750'. POOH OOH. RD w/night cap on well. Bevel noses on perforating guns and cut off 1' of 25' gun and re-head. SDFN. Plan to continue perforating in the am. WELL TESTS: BEFORE: AFTER: COMMENTS: BOPD BWPD 229 1 MSCFPD 1295 TP 5O CP DATE 650 7/12/97 DAILYCOST: $ Inc CUM: $ Inc REPORTED BY: Olson MARATHON OIL COMPANY !', DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 7/16/97 FIELD: Beaver Creek FILL DEPTH/DATE: 15264' (7/15/97) TUBING: 3.5" 9.3# L-80 DATE LAST WL WORK: 7/15/97 WORK DONE: 1 Perf Misrun, ran CCL to bottom of well PRESENT OPERATION: POOH - all 6 perf runs complete PROBLEMS: Problems getting through GLMs WELL #: BC-4 CASING: 7" TREE CONDITION: OK BENCHES OPEN: Lower G zone Hemlock sanded back SUMMARY OF OPERATIONS 7/16/97 SWS on location. Discuss procedure. Establish communication blackout. Found fatigue cracks in top of 24' strip gun. Replace top 10' with new strip. Gun length now 25' of 2-1/8" Owen expendable strip gun, 6 spf, +/- 45 degree phasing, Shogun NT HMX charges. Arm gun. PT against 95 psig TP. Good test. Gas lift rate = 1575 mscfpd, TP = 95 psig, CP = 770 psig RIH at 10000 ft/hr. Slow down through GLMs. No problems. Tie into flag at 14750'. Correlate above perf target. Drop down to 15200', PU and perf: Run Interval Footage Comments #2 15185-15210' 25' Lower G - no change in pressures. POOH. Establish communication blackout. OOH. Gun fired. MU 19' gun as above. RIH. Tie into flag at 14750'. Correlate above perf target. Drop down to 15185', PU and perf: #3 15155-15174' 19' Lower G - no change in pressures. POOH. Establish communication blackout. OOH. Gun fired. MU 14' gun as above. RIH. Tie into flag at 14750'. Correlate above perf target. Drop down to 15155', PU and perf: #4 15132-15146' 14' Lower G - no change in pressures. POOH. Establish communication blackout. OOH. Gun fired. MU 19' gun as above. RIH. Tie into flag at 14750'. Correlate above perf target. Drop down to 15130', PU and perf: #5 15109-15128' 19' Lower G - no change in pressures. POOH. Establish communication blackout. OOH. Gun fired. MU 19' gun as above. RIH. Sat down in GLM #6 (8862'). PU and run through OK. Jerky through GLM #7 (9586'). Tie into flag at 14750'. Correlate above perf target. Drop down to 15090', PU and perf: #6 15076-15095' 19' Lower G - no change in pressures. 7/17/97 POOH. Establish communication blackout. OOH. Gun fired. MU 9' gun as above. RIH. Tie into flag at 14750'. Correlate above perf target. Drop down to 15081', PU and perf: #7 15067-15076' 9' Lower G - no change in pressures. POOH. Establish communication blackout. OOH. Gun fired. RD. Note: Lower G perforated w/well flowing. No significant change in THP, CP or gas lift rate. Speed RIH was ~ lO000'/hr, POOH was ~12000'/hr. Plan to flow well today for cleanup, then test on Friday and Saturday. , See well test data below. Based on total BC oil produced, an increase of 40 bbls resulted from this work. WELL TESTS: BOPD BWPD MSCFPD TP CP DATE BEFORE: 229 1 1295 50 650 7/12/97 AFTER: 250 6 1544 80 770 7/17/97 COMMENTS: DAILY COST: $ 36,648 CUM: $ 36,648 REPORTED BY: Olson Alaska Reu';on Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 July 2, 1997 Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Mr. Wondzell: Please find attached Form 10-403, Application for Sundry Approvals, for reperfortating the Upper G-Zone in BC-4. If you have any questions, please contact me at 564-6315. Sincerely, Michael R. Olson Production Engineer Attachments cc: CEF JUL ©~.~ Oil & (~as ii:'.r~..'~;:~ uu, t~jssJo~ A subsidiary of USX Corporation Environmentally aware for the long run. O:\EXCEL\9706PERF.XLS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation Shutdown Alter Casing Repair Well Plugging Change Approved Program __ PulITubingm Variance Re-enter Suspended Well Time Extension Stimulate Perforate X Other Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchora~le, AK 99519-6168 4. Location of Well at Surface 1700' FSL, 660' FWL, Sec. 33-7N-1 OW-SM At top of Productive Interval 1467' FSL, 711' FEL, Sec. 34-7N-10W-SM At Effective Depth 1492' FSL, 768' FEL, Sec. 34-7N-10W-SM At Total Depth 1553' FSL, 900' FEL, Sec. 34-7N-10W-SM 5. Type of Well: Development X Exploratory Stratigraphic Service 6. Datum Elevation (DF or KB) 19' KB above GL feet 7. Unit or Property Name Beaver Creek Unit 8. Well Number BC-4 lO. APl Number 50-- 133-20239 11. Field/Pool Beaver Creek Field 12. Present Well Condition Summary Total Depth: measured true vertical 15921 feet 15715 feet Plugs (measured) None Effective Depth: measured true vertical 15529 feet 15290 feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured true vertical Length Size 2989' 13-3/8" 12521' 9-5/8" 3704' 7" See attached Cemented 2000 sx 2868 sx 1400 sx Measured Depth. 2989' 12521' 15921' Tubing (size, grade, and measured depth) 3-1/2" 9.3# L-80 EUE, AB Mod Tubing @ 14482' Packers and SSSV (type and measured depth) Otixx XXO Profile for SSSV @ 250', Baker FAB-1 Packer @ 14484', Baker FA-1 Packer @ 14813' True Vertical Depth 2890' 15715' "~" ,,,,, Ancho~..ag~ ~;ommJssJo~ 13. Attachments Description Summary of Proposal X Detailed Operations Program__ BOP Sketch 14. Estimated Date for Commencing Operation July/10, 1997 16. If Proposal was Verbally Approved Name of Approver Date Approved 15. Status of Well Classification as: Oil X Gas Service Suspended 17.1 hereby certify that the for~o, ing is true and correct to the best of my knowledge. Signed ~/~~,~~'J ~'~ Title Production En~lineer I - v "' ~ - / FOR COMMISSION USE ONLY IConditions of Approval: Notify Commission so representative may witness Plug Integrity BOP Test f Location Clearance Mechanical Integrity Test -'"'~ubsequent Form Required 10- /~ ,Approved by Order of the Commission Date July 2, 1997 IApproval No- q ...._ Form 10-403 Rev. 06/15/88 Original Signed By r~avid W. Johnston Commissioner Date'? '/0 Submit in Triplicate BC-4 PERFORATIONS MD 15040' - 15100' 15108' - 15128' 15130'- 15146' 15150'- 15175' 15185'- 15210' PERFORATIONS TVD 14840'-14900' 14907'-14926' 14928'-14944' 14947'-14972' 14981'-15006' SAND Lower G-Zone Lower G-Zone Lower G-Zone Lower G-Zone Lower G-Zone 15361'-15376' 15382'-15397' 15416'-15431' 15446'-15461' 15152' - 15166' 15172' - 15187' 15205' - 15219' 15234' - 15249' Hemlock Hemlock Hemlock Hemlock Note: Hemlock zone perforated in 1972 for DST. Hemlock perforations currently covered in fill. Field' Beaver Creek Location: Beaver Creek Site: Pad 4 Sand: Lower G Hemlock- Sanded back Marathon Oil Company Wireline Work Request Well BC-4 Packer: 14484', 14813' Tbg: 3-1/2", 9.3, L-80 EOT: 14813' Min ID: 2.813" X nipples Tubing Clear: Yes Lease: APl #: 50-133-20239-01 Fill depth: RKB: 16' SI WHP: Est Start Date: 7110~97 Est Compl Date: 7/12/97 OBJECTIVE: 15392' (5/3/93) Tree Connection' 3-1/2" 8rd EUE IRU GR, Perf Lower G sands POTENTIAL PROBLEMS: IParaffin and asphaltene deposits on tubing and casing, chance of getting blown up hole, oil spills. LAST WELL WORK: 5/11/93 - Reperf Lower G sands PROCEDURE: 7/9/97 RFC?"" g 1. Increase paraffin dispersent in lift gas from 4 gpd to 10 gpd. 2. Increase gas lift rate to 1.6 mmscfpd. 3. Choke well back to 3 turns on production choke. 7/10/97 4. Conduct operations, safety, and environmental meeting. 15. RU E-line unit. Place spill containment material below engines, shivs, etc. 6. Establish communication blackout and arm 2-1/8" expendible strip guns, 6 spf, +/- 45 phasing, deep penetrating charges. 7. PT equipment to 1500 psig using fresh water and PD pump. 8. Insure well is stable and RIH to perf the following Lower G zone intervals. 9. Once outside the TT, increase lift gas to 1.6 mmscfpd and open choke. 10. Flow well for 30 minutes after perforating interval. POOH. Run # Interval Footage 1 15185-15210' 25' 2 15155-15175' 20' 3 15132-15146' 14' Test well for 24 hours and determine if additional perforating is necessary. 4 15108-15128' 20' 5 15080-15100' 20' 6 15060-15080' 20' 11. RD and secure well. Clean up area. 12. Flow test well. Comments Lower G-zone Lower G-zone Lower G-zone Lower G-zone Lower G-zone Lower G-zone QUESTIONS/COMMENTS? APPROVALS: Contact Mike Olson, 564-6315 (Terry J. Kovacevich) Fax to KGF Supervisor H :excel\wireline\bc4\aogccbc4.xls [:]r.,glnmt RK~ 19' ~ove GL Come,on D~m iO/IO/BB To~ o~ 'G' Zone~ 14,435' H~ H~x~m Hole Angie~ iB ~ 13,780' MD Top oF He~tack~ I5,313' MD Angle Thpau~ ~G9 14 Annutu~ Fluid. iD.3 ppg C=CI~ Angle Through He~ 14 Reference Log~ D~ ~/11 [ 11/~3/7~ ALi depths ~pe RK~ H~ ~o 3 o~ equipment. 10 L Veil. Type ~:im [::] Vo~<ove,- Recompte~ l. FMC TC-1A-EN Tb~ Hgt. D~:Is XXF! prO,lie ~or S~V (~.813' II)). 3. 3-1/8' 3.3# L-BO, 8RI) EUE, AIl Mod Tbg. 5. 3-1/8' I)mker semi ~ssemioiy-@040 PI)R (17.~1' length). 7. ]~ker PBR (4.00' II)) w/cone:,nfl:rio coupling (4.00' IT~) ~nd ;laker SIIE (18.74' length). 8. B~ker FAIl-1 pi<r, slze 83FA47 (4.00' II)). 9. 5' I~oim~on liner mzsemioiy (~ee Tubing C~lng 10. B~ker FA-1 pkr, size 83FA47 (4.00' 16' :=50' 14,48~' 14,4~8' 14,464' 14.48~' 14,464' 14.484' 14,484' 14,813' GAS LIFT ]3AT~i E737' 3.5' FlopeZ~ol SPM-~ 2.867' 1.5' GLV 1.5 R RK 16/64 4747' ' ' ' ' · · 613;=, · , , , , · 7l=00 ...... , 8079' ' ' ' ' ' 16/64 BB6~' ' · ' ' ' 20/64 9586 .... · · · 10:315 .... , · · · 10 837' ' ' - , , , · 1L463 ....... 1~,085' ' FloDezrol SPM-E ' 1.5' GLV 1.5 R RK ' 12,708 ' GLMA ~ST 2.867' 1' GLV 1.0 R 2K-E ' 13 206 .... , · · e 13,730' ..... ;:=0/64 14,~59' ' GLMA RST ~.867' ' RK-E 3/8 CASING & TURING S;ze ~/elgh~ Grade ~ Bottom 20' 94 H-40 0 888' ST&C c~g 13-3/8' 78 N-BO 0 i948' 8RD · 68 J-55 1948' ~989' · 9-5/8' 47 N-80 0 74~1' ~u~. ' 47 ~-95 74~1' 9938' ' 53.5 P-110 9938' l~SEl' ' 7' 89 P-110 1~17' 1~55~' ' ' 3~ P-110 1~55~' 15,9~1' 5' 18 N-80 14,487' 14,813' Izo[=t~on Lme~ 3-1/;::" 9.3 L-BO 0 14,488' NOTE~ KB ~o ~OD o? ~0' c=g = 84'. BRD AB Mod Tiog PERFBRAT!BN DATA -' In~erv=~ Zone F__iT SPF D=~e 14,435'-565' UDDer 'G' 30' 4 1/73 Squeezed 14,731'-743' 18' 4 8/~8/88 Squeezed 15,040'-100' Lower 'G' GO' 8 18111/88 DP 15,108'-1~8' ' 80' ' ' ' 15,13~'-146' ' 14' ' 1~/10/88 ' 15,155'-175' ' ~0' 15,185'-210' ' 25' ' ' ' Hemlock 15' 4 18/1:=/7~ Jumbo DST 15' · ' · 15' ' ° · Per~orm~ons 15' ' ' ' 15,361'-376' 15,38E'-397' 15,416'-431' 15,446'-461' NO~E~ Hemloci< per'ore,ions were Isol~e~ ~?ter DST by ~ cm~. ~e~mlner Iou~c were never CM~. ~queezed. F~ll ~gged E 15,347 !8/17/90. PI)TI) = 15o5~9' TI] = 15,9~1' Reservolm D~WM, 14,800' Sub Ee~ Revision D~ff:e. 3/ES/gl Revised Ily, TM/evo Ree$on. Reper~ Loeer G Previous Revision. l~/R1/8B Alaska F~ ¢ Domestic P~'oduction Marathon Oil Company P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 June 8, 1993 Mr. D. W. Johnston Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Enclosed is the AOGCC "Application for Sundry Approvals" form for Beaver Creek Well BC-7 and the "Report of Sundry Well Operations" for Well BC-4. Should you have any questions regarding any application or report, please contact E. V. Oberts at 907/564-6436. Sincerely, ~i~? · ,,,,' ,,, v' L. 6. fbele 0perations Engineering Supervisor LCI/EVO/crc Attachment cc E. V. Oberts H: \wp\Sundry. t tr A subsidiary of USX Corporation RECEIVED J UN - B 199 Alaska Oil & Gas Cons. 6ommtSslot~ ;Anchorage AL/-,bnA OIL AND GAS CONSERVATION CO i~,,,~SION REPORT OF SUNDRY WELL OPERATIONS Operations Shutdown Stimulate Plugging Perforate X "~r/H/ Pull Tubing Alter Casing Repair Well Other ~'. ~";~e ~ WelL'~ -- ~.. ~ (D~'; ~-'~ Development X 19' GL 1. Operations Performed: Name of Operator Marathon Oil Company 3. Address P. O. Box 190168 Anchorage, AK 99519 Exploratory Stratigraphic Service 7. Unit or Property name Beaver Creek 4. Location of well at surface 1,700' FSL, 660' FWL, Sec. 33-7N-10W-SM At top of productive interval 1,467' FSL, 711' FEL, Sec. 34-7N-10W-SM At effective depth 1,492' FSL, 768' FEL, Sec. 34-7N-10W-SM At total depth 1,553' FSL, 900' FEL, Sec. 34-7N-10W-SM 8. Well number BC-4 9. Permit number/approval number 72-13 / 93-102 10. APl number 50- 133-20239 11. Field/Pool Beaver Creek Field 2. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 1 5,921' feet Plugs (measured) None 15,715' feet 15,529' feet Junk (measured) None 1 5,290' feet Length Size Cemented Measured depth 2,989' 13-3/8" 2,000 sx 2,989' 12,521' 9-5/8" 2,868 sx 12,521' 3,704' 7" 1,400 sx 15,921' See Attachment #1 True vertical depth 2,890' 12,445' 15,715' 13. Tubing (size, grade, and measured depth) 3-1/2" 9.3" L-80 EUE, AB Mod Tubing @ 14,482' Packers and SSSV (type and measured depth) Otis XXO Profile for SSSV (~ 250'; Baker FAB-1 Pkr (~ 14,484', Baker FA-1 Pkr @ 14,813' Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure RECEIV£D JUN - 8 199 Alaska 0il & Gas Cons. Anchorage 14. Representative Daily Average Production or Injection Data Oil-Bbl. Gas-Mcr Water-Bbl. Casing Pressure Prior to well operation 315 450 0 790 Subsequent to operation 340 459 0 800 Tubing Pressure 80 65 15. Attachments Copies of Log and Surveys run Daily Report of Well Operations X -- 16. Status of well classification as: Oil X Gas Suspended Service Date ~/~/?~, SUBMIT IN DUPLICA~ Attachment #1 Well BC-4 Perforations Bench Lower G-Zone MD 15,040'- 15,100' 15,108' - 15,128' 15,130'- 15,146' 15,150'- 15,175' 15,185'- 15,210' TVD 14,840'- 14,900' 14,907'- 14,926' 14,928'- 14,944' 14,947'- 14,972' 14,981'- 15,006' Hemlock 15,361' - 15,376' 15,382'- 15,397' 15,416' - 15,431' 15,446' - 15,461' 15,152' - 15,166' 15,172' - 15,187' 15,205' - 15,219' 15,234' - 15,249' Note: Hemlock zone perforated in 1972 for DST. Hemlock perforations currently covered by fill. [SUNDRY2.XLW]Perf Database RECEIVED JUN - 8 199~ Alaska 0il & Gas Cons. 6ommissto~ Anchorage DAILY WELL OPERATIONS BC-4 REPERF 5/.9/93 Held pre-job safety meeting. RU E-line. Pressure test lubricator to 1500 psi -- good. RIH w/2-1/8", 45° phased EJ guns, 6SPF, 14g DP. Flowed well to obtain underbalance and perforated the following intervals: Run Interval (DIL) Length Result 1 15,190'- 15,210' 20' Fired RIH w/ 12' of 1-11/16" pivot guns, 180° phased, 22 g. DP charges, 4SPF deploy and attempt to fire -- dead short. POOH w/gun. 5/10/93 RIH w/2-1/8", 45° phased EJ guns, 6SPF, 14g DP. Flowed well to obtain underbalance and perforated the following intervals: Run Interval (DIL) Length Result 3 15,152'- 15,172' 20' Misfire--Dead Short 4 15,152' - 15,172' 20' Fired 5 15,130' - 15,146' 16' Fired 5/11/93 Run Interval (DIL) 6 15,107' - 15,127' 7 15,082'- 15,102' 8 15,058' - 15,078' Length 20' 20' 20' Result Fired Fired Fired RD. Return well to production. H:\wp\WELLOPS\BC4 R'ECEIVED J U N - 8 199;~ Alaska Oil & Gas Cons. Commiss%or~ Anchorage Alaska I~ Domestic r'roduction Marathon Oil Company P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 April 23, 1992 Mr. D. W. Johnston Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ORIGINAL RE: Beaver Creek Well BC-4 Dear Mr. Johnston: Enclosed for further handling is the AOGCC "Application for Sundry Approals" form for Beaver Creek Well BC-4. Should you have any questions regarding any application or report, please call Mr. Ed Oberts at 907/564-6436. Sincerely, Operations Engineering Supervisor Attachments LCI/EVO/crc H -' \wp\Sundry REEEIVED APR ~ G 199~ Alaska Oil & Gas. Cons, :C. om~issi.o.~ ~ncl~_rage A subsidiary of USX Corporation · STATE OF ALASKA ~i ALASr~ OIL AND GAS CONSERVATION COM~,,-$,ON ORIGINAL APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation shutdown Re-enter suspended well Alter casing Repair well Plugging Time extension Stimulate Change approved program Pull Tubing Vadance Perforate X Other 2. Name of Operator Marathon Oil Company 3. Address P. O. Box 190168 Anchorage, AK 99519 4. Location of well at surface 1,700' FSL, 660' FWL, Sec. 33-7N-10W-SM At top of productive interval 1,467' FSL, 711' FEL, Sec. 34-7N-10W-SM At effective depth 1,492' FSL, 768' FEL, Sec. 34-7N-1 OW-SM At total depth 1,553' FSL, 900' FEL, Sec. 34-7N-10W-SM 5. Type of Well: Development Exploratory Stratig raphic Service 6. Datum elevation (DF or KB) 19' KB above GL 7. Unit or Property name Beaver Creek Unit 8. Well number BC-4 9. Permit number/approval number 72-13 10. APl number 50- 133-20239 111. Field/Pool Beaver Creek Field feet 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 15,921' 15,715' 15,529' 15,290' Length feet feet feet feet Size Plugs (measured) Junk (measured) Cemented None None Measured depth True vertical depth true vertical 2,989' 13-3/8" 2,000 sx 2,989' 2,890' 12,521' 9-5/8" 2,868 sx 12,521' 12,445' 13. 3,704' 7" 1,400 sx 15,921' 15,715' RECEIV£D Tubing (size, grade, and measured depth) 3-1/2" 9.3" L-80 EUE, AB Mod Tubing @ 14,482' Packers and SSSV (type and measured depth) See Attachment #1 APR 2 6 199 Alaska 0il ,& Gas Cons. C0~missio~ /~nch0rage Otis XXO Profile for SSSV @ 250'; Baker FAB-1 Pkr @ 14,484', Baker FA-1 Pkr @ 14,813' Attachments Description summary of proposal ~ Detailed operations program BOP sketch X Estimated date of commencing operation April 28, 1993 If proposal was verbally approved Name of approver Date approved 15. Statis of well classification as: Oil X Gas Service Suspended /,/ ..... v - ~ FOR COMMISSION USE ONLY Conditions of al:~roval: Notify Commission so representative may witness Date Plug integrity_ BOP Test__ Location clearance__ Mechanical Integrity Test__ Subsequent form required 10- IApproval No. ApprOved by order of the Commision 0 ri g1 n 3,~ ......... ¢, David W. johnston Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment #1 Beaver Creek Well BC-4 Perforations (as of 8/20/92) Lower "G" Zone Hemlock 15,040' - 15,100' MD 15,108' - 15,128' MD 15,132'- 15,146' MD 15,150' - 15,175' MD 15,185' - 15,210' MD 15,361' - 15,376' MD 15,382' - 15,397' MD 15,416' - 15,431' MD 15,446' - 15,461' MD 14,840' - 14,900' TVD 14,907' - 14,926' TVD 14,928' - 14,944' TVD 14,947' - 14,972' TVD 14,981' - 15,006' TVD 15,152' - 15,166' TVD 15,172' - 15,187' TVD 15,205' - 15,219' TVD 15,234' - 15,249' TVD (Note: Hemlock zone perforated in 1972 for DST. Hemlock perforations currently covered by fill.) NEF/em/BC-4/BC RE( EIVED APR ~ ~ 199;~ A~aska Oil & Gas Cons. ComT~iss~o~,~ ;Anchorage PROCEDURE BC-4 REPERF 1. Hold pre-job meeting with involved parties. Locate sorbent pads, waste drum, etc. near well. Ensure adequate lighting is available for night operations. 2. RU E-line on liner material. PT lubricator to 1500 psi, with weight bars only. e Pinch well back to 6 turns open on production choke. Monitor two pen recorder for stability. 4. NOTE: Prior to arming guns and until guns are 1000' in the hole, notify appropriate personnel and establish communications blackout following BC Perforating Safety Checklist. Re-establish blackout when POOH above 1000'. Arm 2-1/8" strip guns, 6 SPF, +/- 45° phasing loaded with 13,5 g. Enerjet deep penetrator charges, or 1-11/16" Pivot Guns, 4 SPF, 180 degree phasing, 90 degree offset, loaded w/ 22.5 g. charges as described below to reperforate the following intervals: RUN INTERVAL FOOTAGE GUN I 15,190 2 15,176 3 15,164 4 15,130 5 15,107 6 15,082 7 - 15,210 - 15,164 - 15,149 - 15,146 DI - 15,127 DI - 15,102 DI 15,058 - 15,078 DI DI_ DI_ DI_ -- 20 12 15 16 20 2O 20 EJIII Pivot Pivot EJIII EJIII EJIII EJIII Open choke fully when out of tubing tail and increase lift gas to 2 MMCFD prior to shooting. Allow well to flow 30 minutes before pinching choke back to 6 turns to POOH. 5. RD E-line unit and return well to stabilized production. Obtain minimum two 24-hour production tests. H: \wp\WLPRO\BC- 4 RE E VED APR Oil .& Gas Cons. Commissio~ Anchorage WELL, BCU-4 gpud I)~te: 6/12/72 Original RKB: 19' above GL Top o¢ 'G' Zone~ 14,435' MD Top oF HeMlock, 15,313' MI) Annulus Fluid~ 10,3 ppg CaCIe All depths are RKO MD to "cop oF equipment. MARATHON OIL COMPANY BEAVER CREEK UNIT APl ~: 50-133-20239-01 CompLetion Da"ce: 10/10/88 MaX;MUM Hole Angle, 18 8 13,780' MD Angle Through 'G', 14 Angle Through Hem, 14 ReFerence Log, OIL 9/11 & 11/23/72 Well Type: Oil Producer New [] Workover [] Recompletion [] JEWELRY 1. FMC TC-1A-EN Tbg, Hgr, 2. Dtis XXD profile For SSSV (2.813' ID). 3. 3-1/8' 9,3~ L-80, 8RD EUE, AB Nod Tbg. 4. Ot;s X N;pp~e (2,813' ID). 5. 3-1/2' Baker seal asseMbty-8040 PBR (17,91' ~enQth). 6. 3-1/8' hdFcut Mu[eshoe. 7. Baker PBR (4.00' ID) w/concentric couptln9 (4.00' and Baker SBE (18.74' length). 8. Baker FAB-1 pkr, size 83FA47 (4.00' ID). 9. 5' Isdat;on Hner aSSembly (See TUb;hQ Casing Beta;D. 10. Baker FA-1 pkr, slze 83FA47 (4,00' ID). GAS LIFT DATA Death Size ManCre~ II) 2737' 3,5' Flopetrol SPM-2 2,867' 4747' 6138 .... 7200 8079' 8868 9586' 10,215 10,837 11,463 12,085' 12,708 ' GLMA BST 2,867' 13,206' 13,730 14,259' ' GLMA BST 8,867' CASING & TUBING DEPTH 16' 250' 14,482' 14,428' 14,464' 14,482' 14,464' 14,484' 14,484' 14,813' V(~tve Tvoe Latch Port 1,5' GLV 1.5 R RK 16/64 # , · ' · 16/64 ' ' 20/64 1,5' GLV 1,5 R RK 1' GLV 1,0 R BK-2 , # ' ' 20/64 3K-2 3/8 Size ~/elght Grade TOp Bottom Descrlpt. 20' 94 H-40 0 288' ST&C cs9 13-3/8' 72 N-80 0 1948' 8RD cs9 ' 68 J-55 1948' 2989' 9-5/8' 47 N-80 0 7421' Butt. csg ' 47 S-95 7421' 9938' ' 53.5 P-Il0 9938' 12,521' 7' 29 P-Il0 12,217' 12,552" ' ' 32 P-Il0 12,552' 15,921' 5' 18 N-80 14,487' 14,813' Isolation Liner 3-1/8' 9.3 L-80 0 14,482' 8RD AB Mod Th9 NOTE: K3 to top o¢ 80' cs9 = 84'. PERFORATION DATA Interval ~one F_~_T SPF Date Gun Type 14,435'-565' Upper 'G' 30' 4 1/73 Squeezed 14,731'-743' 12' 4 8/28/88 Squeezed 15,040'-100' Lower 'G' 60' 8 12/11/88 DP Carrier 15,108'-128' ' 20' ' ' 15,138'-146' ' 14' ' 18/10/88 15,150'-175' ' 20 15,185'-210' ' 25 15,361'-376' Hemtock 15' 4 12/12/78 Jumbo Jet 15,382'-397' DST 15' ' ' 15,416'-431' 15' ' 15,446'-461' Per¢oratlons 15' ' Hemtock perforations were Isolated a?ter DST by o retainer but were never 6Mt. squeezed. NOTE: Fllt togged 8 15,301' 8/19/98 · Alaska Oil & Gas Cons. Commiss # Anchorage PBTD = 15,529' TI] = 15,921' R APR 2 6 1993 Reservoir Datum, 14,800' Sub Sea Revision Dote~ 8/88/98 Revised By: TM/eva Reason: Reper¢ Lower G Previous Revision: 3/86/91 BEAVER CREEK Wireline Lubricator w/Associated BOPE Grease Head (Hydralically Activated) -- Lubricator Manually Operated BOP Tree Cap Swab Valve 2' Wing Valve APR 2 ~ t~993 A/aska Oil & Gas Cons, Corm'nissim'~ Master Valves Anchorage 3-1/2" 5000 Chrlltmas Tree Seal Flange Unocal North America~ Oil & Gas Division ~, Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region DOCUMENT TRANSMITTAL December 1, 1992 TO' Larry Grant LOCATION' 3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 ALASKA OIL & GAS CONSERVATION COMM. FROM' Eric Graven LOCATION' P.O.BOX 196247 ANCHORAGE AK 99519 UNOCAL TRANSMITTING AS FOLLOWS BEAVER CREEK//2 1 blueline and 1 sepia Completion Record// BEAVER CREEK//4 1 blueline and 1 sepia Perforation Depth Record PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU R E C [IV E D RECEIVED BY: /.--'----- - -o/' .... D[C 0 ~ i¢ t DATED: Anchorage Marathon Oil Company ALaska ~ )n Domestic r'roduction P.O. Box 190168 Anchorage, AK 99519-0168 Telephone 907/561-5311 October 8, 1992 Mr. D. W. Johnston Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Enclosed is the AOGCC "Reports of Sundry Well Operations" with appropriate attachments for Beaver Creek Well BC-4, approval #91-403 and #92-208. Should you have any questions regarding any application or report, please contact E. V. Oberts at 907/564-6436. Sincerely, L. C. Ibele Operations [ngineering Supervisor LCI/EVO/crc . Attachment cc E. V. Oberts H: \wp\Sundry. t tr RECEIVED 0 CT 1 1997. Alaska Oil & Gas Cons. Com~tssiO~ Anchorage A subsidiary of USX Corporation ir STATE OF ALASKA [ J ALASKA OIL AND GAS CONSERVATION COMMIS,51ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations pedormed: 2. Name of Operator Marathon 3. Address P.O. Box Operation shutdown __ Pull tubing __ Alter casing Anchnran~__ AK qqRlql 1 qO 16g Stimulate __ Plugging __ Perforate .~ Repair well __ Other 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) 10' It'R ~hnv~ CI ~:U nit' ~'~ P Fo-p~ ~t~' n a-n~e Reaver Creek IInit feet 4. Location of well at surface 12. ' 0 FWL, Sec. At to ~ 6fT~(~r(Dr~u c[[~.Lrdte r§~ ' 1.,4'67" FS'L, 7'I'1' FEL, Sec. At effective depth 1,492' FSL 768' FEL, Sec. At total depth ' 1.~' FSI _ q00' FFI _ Sec. Present well c0nditi(~n summary Total depth: measured 15,921 ' true vertical 15,715 ' Effective depth: measured true vertical Casing Length Structural Conductor 2,989 ' Surface 12,521' Intermediate 3,704' Production Liner Perforation depth: measured 15,529' 15,290' 13 9 8. Well number 33-7N-lOW-SM 34-7N-lOW-SM RECEIVED OCT 1 2 1992 34-7N-lOW-SM Alaska Oil & Gas Cons. 6omn ~4- 7 N- 1 flW- qM Ant. horace JCpe4rmit number/approval number , 7o_13 10.'-APl nu~nb~r" '""' 50-- · ~Uld/P°$1- Beaver Creek Fi eld feet Plugs (measured) feet feet Junk (measured) feet Size Cemented Measured depth True vertical depth 3/8" 2,000 sx 2,989' 2,890' 5/8" 2,868 sx 12,521' 12,445' 7" 1,400 sx 15,921' 15,715' See Attachment #1 true vertical Tubing (size, grade, and measured depth) Packers a n %SaSkSeVf(t y ~ ~_dj.m ~aKs~ r e (:14:l.e~), 3 1/2" 9.3# L-80 EUE, AB Mod Tubing 0 14,482' MD Otis XXO Profile for SSSV (2.813" ID) 0 250' MD ID) 0 14,484', Baker FA-1 pkr (4.00" ID) 0 14,813' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressu re Prior to well operation 1.50 39.5 0 580 140 Subsequent to operation 17..5 ,/ ...... 0 0 5 2 0 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run __ I Daily Report of Well Operations ~ Oil ~ Gas ~ Suspended ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-40~ Rev 06/15/88 Service Fngineering SUDV. 130 Date / ¢~,/~/?~.. SUBMIT IN DUPLICATE Approval # 91-403 Attachment #1 Beaver Creek Well BC-4 Perforations (as of 12/20/91) Lower "G" Zone Hemlock 15,040' - 15,100' MD 15,108' - 15,128' MD 15,132' - 15,146' MD 15,150' - 15,175' MD 15,185' - 15,210' MD 15,361' - 15,376' MD 15,382' - 15,397' MD 15,416' - 15,431' MD 15,446' - 15,461' MD 14,840' - 14,900' TVD 14,907' - 14,926' TVD 14,928' - 14,944' TVD 14,947' - 14,972' TVD 14,981' - 15,006' TVD 15,152' - 15,166' TVD 15,172' - 15,187' TVD 15,205' - 15,219' TVD 15,234' - 15,249' TVD (Note: Hemlock zone perforated in 1972 for DST. Hemlock perforations currently covered by fill.) NEF/em/B¢-4/BC RECEIVED OOT 1 2 199 . Alaska Oil & Gas Oons, Oomi~ission Anchorage BEAVER CREEK Summary of Well Operations BC-4 Permit No. 72-13 12/15-16/91 Hold Prejob/Safety Meeting. Close Swab & Rig onto Well. PT Lubricator to 1500 PSI w/Weight Bars Only. Test Good. Establish Comm. Blackout. Arm Gun. Open Swab RIH. Gun would not fall. Attempt to Release Tool Trap, Bleed Packoff, etc. Finally started Downhole. Tight hole at 480', 650', 805' (Likely Paraffin). Continue RIH to Bottom. Perforate the Lower G-Zone with well choked back to 3 turns open. 2-1/8" Dyna Strip, 4 SPF, 22 g. charges. Run Interval 1 15,190' - 15,210' Misfired - Parted Wire 2 15,190'- 15,210' Fired 3 Guns hung up @237' 12/17-18/91 Work gun free. POH, Bottom Nose Guide bent. RIH w/CCL (2-1/8" OD) & two sinker bars. RT to 3,400' KB, no problem. RIH w/same type perf gun. 4 15,150'- 15,170' Fired 12/19-20/91 5 6 7 15 8 15 9 15 10 15 11 15 12 15 15,185'-15,210' 15 185'-15,210' Misfire Fired 150-15,175' Misfire 150-15,175' Misfire 150-15,175' Fired 132'- 15,146' Fired 108'- 15,128' Fired 060'- 15090' Fired RD E-Line and place back on production. EVO H:\SU NDRY~BC\BC- 4.WK1 R[CEIVED OCT 1 992 AJaska Oil & Gas Cons. Commission Anchorage HARATHON D]L COHPANY ,~.,, B£AVr'R CR££K UNIT Spud l~te, 6lie/TO APl #: 50-133-EOE39-OI Veil Type, I~;g;n~t RK]~ 19' above GL Co~ptet~n Date: 10/10/88 Top oF 'G' Zone= 14,435' ND Nax~,m Hole Angle: 18 @ 13,780' MD New Top oF He~lock.' t$,3t3' ND Ar~gle TI, w'ou~h 'G', 14 Vorkover Annulus Flu~:~ 10.3 Ppg CoCIa Angle ThrOugh Hem 14 Reconplet~n ReFerence Lc~ OIL 9/il & Ni depths are RKB lid to top oF ec~p~ent. JEVELRY J J J J J J J J J ,J ~I1 _- N · 1. FHC TC-IA-rN Tbl~ Hgt. E. 0tis XXO proFae Foe, SSSV (8.813' ID). 3. 3-1/E' 9.31 L-gl~ 8RD CUE, AB ~d Tb~ 4. Otis X N~te (E.813' ID). 5. 3-1/~" Boke~ seal assembly-8040 P~ (17.91' te~th). 6. 3-1/~' hotFcut Nuteshoe. 7. Bekee P~ (4.00' ID) w/coflcent~ cou~MO (4.00' ~nd Beke~ SBE (18.74' length). 8. Dekee FAB-I ~e, size 83FA47 (4.00' 9. 5' Isot~t~ ti~e osse~bly (See Tub~ CQs;~ Deter). i0. B~kee FA-i ~e, size 83FA47 (4.00' lO). GAS LIFT nATA Death Size MQnd~et ~ VQlve Tvoe Latch ~137' 3.5" Ftopeteot SPM-8 ~.867' 1.5' GLV 1.5 R RK 4747 613a 7EO0 8079 886~ 9586 ..... 10215 10,837 IL463 ..... 18,085' ' Ftopet~ot SPM-E ' 1.5' GLV 1.5 R 18,708 ' aLMA BST ~.867' i" GLV 1.0 R 13206 ..... 13,730 ..... 14259' ' aLMA DST a.867' CASI~ & TU~ING Producer 16' ~50° 14,48~' 14,4E8' 14,464' I4,48E" 14,464' t4,484' t40484° t4,St3' Port 16/64 · · 16/64 L~0/64 · · · · · · BK-E · · · ~0/64 BK-~ 3/8 5 Size Vemht Grade Too Rattan 6 - 7 eO' 94 H-40 0 8 13-3/8· 78 N-80 0 · 68 J-SS 194~° ~989' a~ 9-5/8' 47 N-80 0 74~I' C o ' 47 S-95 74Et' 9938' 53.5 P-il0 9938' le, SE]' ~ 7" E9 P-IlO 1~217' " 3E P-II0 18,558' 15,9E1' · 18 N-80 14,487' 14,813' ~ 3-1/8' 9.3 L-80 0 14,48E' tO NDT£: KB to top oF ~0' csg = E4'. ~ PERFrtR~T ION DICTA ~ interval Zone FT N ~ 140435'-$65' Upper 'G' 30' 4 1/73 - 14,731'-743' 18' 4 8/88/88 ~ i$,040'-I00' Lowe~ 'G' 60' 8 18/11/88 o 1~,108'-1~8' ' L~O' · ' 15,13E'-146' ' 14' ' 1E/10/88 15,150'-175' ' ~0' · · 15,185'-810' ' ~ .... 15,361'-376' Hentock 15' 4 15,38;~'-397' DST !$' · · 15,416'-431° 15' ' · '----------- ~ ~ 15,446'-461' PerForat~ns 15' ° ? NOTE.- He~lock perFor(~tions were isolated after DST by .~ c~t, reta~e~ but were never cnt. squeezed. Fill tagged e 15,301' 8/19/98 PBTD ~ TD = 15.981' Descr~t. ST&C csg 8RD csg · Butt. csg · · · Isa[at;on L~er 8RD AB HOd Tbg Gun Type Squeezed Squeezed DP Carr~ · · Juflbo Jet · · e RECE ¥ED oCT Reservoir Datum 14~00' Sub Sea Revision Date. 8/~8/9~ .AJ~S~ Oi~ & ~S ~O~S. Revised By: TH/eva Reason, Repe~F LoweP G Previous Revis~n: 3/E6/91 STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown__ Pull tubing __ Alter casing __ 2. Name of Operator M~ ~'~t'_hnll 3. Address P.0. Box 4. Location of well at sudace At top[ ,,7001 FSL. 660' FWL of productive ~dterval 1,467' FSL 711' FEL At effective depth ' 1,492' FSL, 768' FEL, At total depth 1,553' FSL, 900' FEL, 12. Present well condition summary Total depth: measured Stimulate __ Plugging __ Pedorate ~ Repmr well __ Other __ Effective depth: Casing Structural Conductor 2,989 ' Surface 12,521 ' Intermediate 3,704' Production Liner Perforation depth: measured 5. Type of Well: Development X O'i 1 £ompanv Exploratory__ ~ I Stratigraphic __ 190168 Anchoraqe, AK 995191 Service__ Sec. Sec. Sec. Sec. 15,921' 33-7N-lOW-SM 34-7N-lOW-SM 34-7N-lOW-SM 34-7N-lOW-SM 6. Datum elevation (DF or KB) 19' KB above GL 7. Unit or Property name Beaver Creek Unit 8. Well number g£ 4 9. Permit number/approval number 72-13 / 92-208 10. APl number 5o- 133-20239 feet 11. Field/Pool Beaver Creek Field feet Plugs(measured) RECEIVED true vertical 15,715 ' feet measured feet Junk(measured) OCT 1 2 t992 true vertical15 529' , feet 15,290' Alaska Oil & Gas Cons. Oommiss'mn Length Size Cemented Measured depth ~f'lC~O["El.~Ue vertical depth 13 3/8" 2,000 sx 2,989' 2,890' 9 5/8" 2,868 sx 12,521' 12,445' 7" 1,400 sx 15,921' 15,715' See Attachment #1 true vertical Tubing (size. grade, and measured depth) 3 1/2" 9.3# L-80 EUE, AB Mod Tubing @ 14,482' MD Otis XXO Profile for $$$V (2.813" ID) ~ 250' MD Packersand¢~,V~ftkYl:~,~d~ec~ed(~e.l~l~" ID) 0 14,484', Baker FA-1 pkr (4.00" ID) ~ 14,813' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 317 183 1 535 316 395 3 500 Tubing Pressure 150 145 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X__ Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true_,,,and correct to the best of my knowledge. Signed Title Operati OhS Form 10-404 I~e'v 06/15/88 gngi,e.eri n§ Supv. D ate/'~'//~//~ SUBMIT IN DUPLICATE Approval # 92-208 Attachment #1 Beaver Creek Well BC-4 Perforations (as of 8/20/92) Lower "G" Zone Hemlock 15,040' - 15,100' MD 15,108' - 15,128' MD 15,132' - 15,146' MD 15,150' - 15,175' MD 15,185' - 15,210' MD 15,361' - 15,376' MD 15,382' - 15,397' MD 15,416' - 15,431' MD 15,446' - 15,461' MD 14,840' - 14,900' TVD 14,907' - 14,926' TVD 14,928' - 14,944' TVD 14,947' - 14,972' TVD 14,981' - 15,006' TVD 15,152' - 15,166' TVD 15,172' - 15,187' TVD 15,205' - 15,219' TVD 15,234' - 15,249' TVD (Note: Hemlock zone perforated in 1972 for DST. Hemlock perforations currently covered by fill.) NEF/em/BC-4/BC RECEIVED OOT 1 2 Alaska Oil & G~s (;oils. Anchorage BEAVER CREEK Summary of Well Operations BC-4 Permit No. 72-13 8/19-20/92 Watched Alaska Region Safety Video. Held Safety Meeting. MU LUB/BOPE and placed protective liner under all WL equipment. PT LUB to 1500 PSIG, OK. RIH w/CCL and Sinker Bars. Tag Fill @ 15,301' DIL. Pull CCL Log from Top of Fill to Packer. Established Communication Blackout. RIH and Perforated the Lower G-Zone with well choked back to 3 turns open. Run Interval 1 15,190'-15,210' 2 Gun Failed - Short in Firing Cap. 3 15,150'-15,170' 4 15,108'-15,128' 5 15,070' - 15,090' RD E-Line and place back on production. EVO H:\SU NDRY~BC\BC- 4.WK1 RECEIVED OCT 1 2 1992 Alaska Oil & Gas Cons. r.,ommiSSiO~'~ Anchorage I~i~inol RK]~ ISI' above To~ of' 'G' Zone: 14,435' iii) Top oF Hen~ock, 15,313' MD HARATHON 01L COHPANY I]I;'AV£R CR£1rK UNIT AP! Conptet~on Date, Hax~u~ Hole AngLe: AnQte ThrouG~ 'G'. ~0-133-~0~39-01 10/10/88 18 @ 13,780' HI) 14 Annulus Irtu~ 10.3 ppg CoCIt AnGte Throu9~ He~, 14 ReFerence L~ DIL 9/11 & ll/E3/?E ~t ~p~hs o~e ~B HD ~o ~ o~ e~p~n~ 10 ., cci Type: ~1 Producer New I"1 Vc~"kover' ~3 ReconpletK)n i-1 C i. IrMC TC-IA-[N Tb~ H~. E. Ot;s XXO proF~e Fo~ SSSV (E313' ID). 3. 3-1/E' 9.3t L-~ 8RD E~ AB ~ 4. 0t;s x ~e (E.813' ID). 5. 3-I/~' Boke~ seal ossem~ty-8040 P~ (17.91' te~). 6. 3-1/~' hotFcut Huteshoe. 7. Baker P~ (4.00' ID) e/concentr~ cou~m9 (4.00' on~ Boker SBE (18.74' tenoth). 9. ~oker FAB-I ~r, s;ze 83FA47 (4.00' ID). 9. 5' Iso~ot~ ~;~r osse~ly (See Tub~ Cos;~ 10. Boker FA-! ~P, s;ze 83FA47 (4.00' ID). GAS LIIrT n4TA ~eo~;h Size I~nelret ID 2737° 3.5' F'tOl~etr-ot SPN-2 2.~7' 47e7 613E .... 7E~ 8079 10~!5 .... i0~37 .... IL463 .... !~7~ ' GLHA BST ~.~7' 13~ 13,730 14,~9' CASI~ & TUBI~ DEPTH 16' ESO' 14,48~ 14,4El~ 14,464' 14,48E~ 14,464' 14,484' 14,484' 14,813' Valve Tvoe Latch Po~t 1.5' GLV 1.5 R RK 16/64 · · · · · · · · · · ' 16/64 · ' 20/64 · · · · · · · · · · · · 1.5' GLV 1.5 R RK · 1' GLV 1.0 R BK-E · · · · * 20/64 · BK-~ 3/8 ~0' 94 H-40 0 ~ ST&C cs9 13-3/8' 72 N-80 0 1942' 8RD cs9 · 68 J-SS 1942' E989' ° 9-5/8' 47 N-~ 0 74E1' Butt. cs9 ' 53~ P-IlO 9938' l~l* ' 3~ P-liD 1~552' I~g~l' 5' 18 N-~ 14,487' 14~13' [s~otiofl L~er 3-1/2' 9.3 L-~ 0 14,4~' 8RO AB H~ T~ ~ K9 ~o ~ o; ~' cs9 = 24'. pIrRIrnRAT InN DATA [nterv,~t Zone FT SPIr Dote 14,435'-565' U~per 'G' 30' 4 1/73 Squeezed 14,731'-743' 12' 4 8/28/88 Squeezed 15,040'-I00' Lower 'G' 60' 8 12/11/88 DP Carrier 15,108'-!a8' ' ~ · - 15,132'-146' ' ]4' ' 12/10/88 ' 15,1500-175, · ~ · o 1~,185o-E10· o ~ 15,361'-376' He,tack 15' 4 12/12/72 Junloo Jet 15,387/-397' 15 .... 15,416'-431' DST 15 15,446'-461' PerForates ]5 Hemlock perForatmns uere isolated after DST by a c~t. retainer but were never crt. squeezecL frill togged e 15,301' PBTD = 15,5~9° TD = RECEgVED OCT 1 2 ~ '~ Reservo;r Datuq, 14~00' Su~a. Oil & Gas Cons. C0m[~isst~ 8/19/92 Revms;on ~*e, G/Es/gE Aflchora~ Revised By: T~evo Reos~ Reperf Lo=er G ~evmus Rev:s=m 3/E6/9] Marathon Oil Company Alaskai' .,on Domestic Production~g RO. Box 190168 Anchorage, AK 99519-0168 Telephone 907/561-5311 August 17, 1992 Mr. D. W. Johnston Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Enclosed is the AOGCC "Application for Sundry Approvals" with appropriate attachments for Beaver Creek Well #4. Should you have any questions regarding any application or report, please contact E. V. Oberts at 907/564-6436. Sincerely, Operations Engineering Supervisor LCI/EVO/crc Attachment cc E. V. Oberts RECEIVED Alaska Oil & Gas 6ons. Anchorage H: \wp\Sundry. t tr A subsidiary of USX Corporation '~. STATE OF ALASKA ,t, ALASKA OIL AND GAS CONSERVATION COMMISSION O APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon m Suspend m Operation shutdown __ Re-enter suspended well __ Alter casmg__ Repair well __ Plugging __ Time extension ~ ,¢.Stimulate __ Change approved program __ Pull tubing __ Variance __ Perforate A____ Other __ 2. Name of Operator ~ 5. Type of Well: 6. Datum elevation (DF or KB) Marathon Oil Company l Development_Z_. 19' KB above GL Exploratory __ 3. Address Stratigraphic __ ,Z. Unit or Pr, opert,~ nar, ne. P. O. Box 190168 Anchorage, AK 995 9 Service__ ueaver t. ree'K unit feet 4. Location of well at sudace 1,700' FSL, 660' FWL, Sec. At top of productive interval 1,467' FSL 711' FEL, Sec. At effective depth 1,492' FSL, 768' FEL, Sec. Attot~l~, FSL, gOO' FEL, Sec. 33-7N-lOW-SM 34-7N-lOW-SM 34-7N-lOW-SM 34-7N-lOW-SM 8. Well number BC 4 9. Permit number 72-13 10. APl nu r § -2o2 9 1;I. Field/Po~ . ueaver breeK Field 12. Present well condition summary Total depth: measured true vertical 15,921' 15,715' Effective depth: measured 15,529 ' true vertical 15,290 ' feet Plugs (measured) feet feet Junk (measured) feet Casing Length Structural Conductor Surface 2,989' Intermediate 12,521 ' Production Liner 3,704' Perforation depth:measured true vertical Tubing (size, grade, and measured depth) 13 9 Size Cemented Measured depth True vertical d~pth 3/8" 2,000 sx 2,989' 2,890' 5/8" 2,868 sx 12,521' 12,445' 7" 1,400 sx See Attachment #1 3 1/2" 9.3# L-80 EUE, AB Mod AU G 1 ? 1992. Alaska 0ii & Gas Cons. 60rnmis¢or~ Tubing oAtn~,h~t~ MD Packers and SSSV (type and measured depth) Otis XX0 Profile for SSSV (2.813" ID) _ Baker FAB-1 pkr (.4..,.00" ID~ @ 14,484', Baker FA-1 pkr (4.00" 13. Attachments Description summary of proposal X Detailed operations program __ @ 250' MD ID) La 14,813' BOP sketch ~ MD 14. Estimated date for commencing operation ] 8/18/92 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby ce~tt,~.,_) ///h~e~/~s true and correct to the best of my kn ow ledg e. FOR COMMISSION USE ONLY 15. Status of well classification as: Oil _~X Gas __ Suspended __ ConditiOns of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10-._~_¢.~~ Date / Approval Approved Cdpy Returned Approved by order of the Commission Form 10-403 Rev 06/15/88 Original Signed By David W,, John.~tOr1 Commissioner / ! Date ~'/j qo/',1~ ~ SUBMIT IN TRIPLICATE Attachment #1 Beaver Creek Well BC-4 Perforations Lower "G" Zone Hemlock 15,040' - 15,100' MD 15,108' - 15,128' MD 15,132' - 15,146' MD 15,155' - 15,175' MD 15,185' - 15,210' MD 15,361' - 15,376' MD 15,382' - 15,397' MD 15,416' - 15,431' MD 15,446' - 15,461' MD 14,840' - 14,900' TVD 14,907' - 14,926' TVD 14,928' - 14,944' TVD 14,950' - 14,972' TVD 14,981' - 15,006' TVD 15,152' - 15,166' TVD 15,172' - 15,187' TVD 15,205' - 15,219' TVD 15,234' - 15,249' TVD (Note: Hemlock zone perforated in 1972 for DST. Hemlock perforations currently covered by fill.) NEF/em/BC-4/BC RECEIVED AUG 1 7 199 Alaska Oil & Gas Cons. Commission Anchorage BC-4 PROCEDURE · · . . Obtain a 24-hour well test· Hold pre-job meeting. Procedures. Review the attached Environmental Protection RU E-line unit on liner material. PT lubricator & BOPE to 1500 psi with fresh water. RIH w/ CCL and weight bars and tag fill POOH. NOTE: Prior to arming guns and until guns are 1000' in the hole, notify appropriate personnel and establish communications blackout following BC Perforating Safety Checklist. Re- establish blackout procedures when POOH above 1000'. After communications blackout is established, arm gun. Choke well back to 3 turns open and RIH. Open choke fully and increase gas lift to 2.2 MMCFPD. Correlate and perforate the following intervals with well flowing using 2-1/8" strip guns, 6 spf, +/- 45 degree phasing, oriented down: RUN INTERVAL FOOTAGE i 15,190' - 15,210' 20 2 15,150' - 15,170' 20 3 15,108' - 15,128' 20 4 15,070' - 15,090' 20 H:\wp\WLPRO\BC4 ~]~'tglnQ[ RK;ll [~' ==ove GL -"-'TOO o~ 'G' Zon~ 14,435' HD Too o~ He~oc~, 15,313' MD ~nnutus FL~ 10.3 ppg C=CIs ~tL cteo~hs are RKI} HO ~o J J !. FMC TC-IA-EN T~0g. Hgt. Otis XXO oro~ile ?or SSSV (2.813' ITl). 3. 3-I/8' ?.3~ L-BO, BR~ EU~ AB Ho~ Tbg. · . Otl~ X N~o~te (8.813' ID). ~. 3-t/~' ~kep se~L =s~emmy-B040 P~R (17.91' teng~h). 6. 3-1/~' h~i?cuz MuLeshoe. 7. ~=ke? PgR (4.00' I~) e/concen~c couOilng (4.~0' !~) =n= B=ke? S~E (iB.74' ~engzh). 8. B=ker FAB-I ~k?, size B3FA47 (4.00' 9. 5' Isoi=~on Uner =~eM=ly (See Tubing 10. B=ke? FA-I QkP, size B3FA47 (4.00' GAS LIFT DATA 8737' 3.5' FloOe~roL SPH-8 8.867' 4747 .... ~138 .... 7~00 .... ~079 .... BB6~ .... ~0,£15 .... [0, B37 .... 11,463 .... l~.085' ' Ftome~ro~ SPM-8 ' 1~o708 ' GLHA B~T ~,867' 13,806 .... 13,730 .... ~4,~59' ' F~LHA BST ~.B67' CASING & TUBING Size '~e~oh'~ ~ 80' 94 H-40 13-3/8' 78 N-BO · 68 J-55 9-5/8' 47 N-80 · 47 S-95 · 53.5 P-riO 7' ~9 P-riO · 38 P-riO 5' [8 N-BO 3-1/~' 9.3 L-BO 0 NOTE' L4,48; L4,48' 14,46 L4,48, 14,46 14,48 14,48 14,81: V¢lve Tyne ~ Po~ 1.5' GLV t.3 R RK iS/ · · · · · · ' ' 16/ ' ' 20/ 1.5' GLV [5 R RK ' l' GLV l.O R BK-8 ' · · · · ' 80/ t' Or~lce BK-8 Too Bo~om Descrlo~ 0 888' ST&C cs9 0 1948' 8Rn csg 1948' 2989' · 0 74~l' Bu~:'~, csg 74~t' 9938' ' l~,Ei7' [~,55~' 14,487' 14,8t3' Isolation Li 14,48~' 8RD AB Moa KB ~o top PERFORATION DATA In'tervoi Zone FT 14,435'-565' Upoer 'G' 30' 14,731'-743' 15,040'-100' Lower "G' GO' lS,lOB'-t~B' ' 20' 15.138'-I 46' ' 14' 15,155'-175' ' 80' 15,185'-~I0' ' ;~5' 15,361'-376' Hemlock< 15' 15,388°-397' 15' ~ 15,416'-431' DST 15' ~ ~ 15,446'-461' Per{or-'tlons F~tt 'l:agged e 15,35~' 18/11/88. PBTII - TI] = 15,981' HemLock oer?orc~-t:lons were IsoL~'tecl ~F't:er DST by <l c:q'~, r'e'~mlner bu'~ were neve~ cm'C. squeezeeg Reservoir Datum, 14,800' Sub BEAVER CREEK Wireline Lubricator w/Associated BOPE Manually Operated BOP 'Grease Head (Hydralically Activated) Lubricator RECEIVED AU~ 1 7 199[~ Alaska Oil & Gas Cons. Commission Anchorage Tree Cap Swab Valve 2" Wing Valve Master Valves 3-1/2" 5000 psi Christmas Tree Seal Flange Marathon Oil Company Alaska{ .,ion Domestic Production RO. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 December 12, 1991 Mr. D. W. Johnston Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Johnston: Attached for your approval is an "Application for Sundry Approvals" for Beaver Creek Well BC-4. Should you have any questions or need any additional information regarding any application or report, please contact L. C. Ibele at (907) 564-6450. ~e~~/ Lk~.~C. b~el e/'' C~-~] Operations [ngineering Supervisor Attachments em\docs\m1\6 REC[IVED D£O 1 6 199~ Naska Oil & Gas Cons. Commissim~ Anchorage A subsidiary of USX Corporation ~ STATE OF ALASKA O ALASKA OIL AND GAS CONSERVATION COMMISS;ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Reperf Lower' Alter casing __ Repair well __ Plugging __ Time exlens~on __ Stimulate __ Change approved program __ Pull tubing __ Variance __ Perforate .,X_ Other __ 2. Name,of Op.e, rator / 5. Type of Well: 6. Datum elevation (DF or KB) Mara~:non Oil Company Development X___ 19' KB above GL Exploratory __ Stratigraphic __ 7,., U nit or Prc, pertv,naroe. 3. Addre~.s O. BOX 190168 Anchorage, AK 99 19 Service__ ueaver ureeK unit G-Zen feet 4. Location of well at surface 1,700' FSL, 660' FWL, Sec. 33-TN-10W-SM At top of productive interval 1,467' FSL, 711' FEL, Sec. 34-7N-10W-SM At eft cti e~pt ~,~e'9~ ~SL, 768' FEL, Sec. 34-7N-10W-SM Attot~~, FSL, 900' FEL, Sec. 34-7N-10W-SM 12. Present well condition summary 15,921 ' Total depth: measured 15 715' feet true vertical ' feet Effective depth: measured 15,529 ' feet true vertical 15,290 ' feet Casing Length Structural Conductor Sudace 2,989' Intermediate 12,521 ' Production 3,704' Liner Size Plugs (measured) Junk (measured) Cemented 8. Well number B6 4 9. Permit number 72-13 10' 5AoPI nu~e~_20239 11,, Field/Pock ueaver [,reek Field KI::L.I:: ! v c u DEC 1 6 1991, Alaska Oil & Gas Cons. Anchorage Measured depth True vertical depth 13 3/8" 2,000 sx 2,989' 2,890' 9 5/8" 2,868 sx 12,521' 12,445' 7" 1,400 sx 15,921' 15,715' Perforation depth: measured true vertical See Attachment #1 Tubing (size. grade, and measured depth) 3 1/2" 9.3# L-80 EUE, AB Mod Tubing (a 14,482' MD Packers and SSSV (type and measured depth) 0t i S Baker FAB-1 p..kr.. (4..001.' ID) 13. Attachments 1, 2, Description summary of proposal ~ &3 14. Estimated date for commencing operation i December 16~ 1991 16. If proposal was verbally approved 'Oil X Date approved XX0 Profile for SSSV (2.813" ID) @ 250' MD Ia 14,.484', Baker FA-1 pkr (4.00" ID) 0 14,813' MD Detailed operations program __ BOP sketch X 15. Status of well classification as: Gas__ Suspended__ Name of approver Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ Title Operations Engineering Superv. Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance -- Mechanical Integrity Test__ Subsequent form required 10-.... Approved by order of the Commission Form 10-403 Rev 06/15/88 ORiGiNAL SIGNED BY k. ONN~E C. Commissioner Approval No. F"..2:.'.~'?:,: / Date SUBMIT IN TRIPLICATE 2. 3. 4. Attachment #1 Beaver Creek #4 Reperf Lower G-Zone Procedure Obtain a 24-hour well test. Hold pre-job safety meeting. RU E-line unit. PT equipment to 1500 psi. MU 2-1/8" strip gun (or equivalent) and arm gun. Choke well back to 3 turns open and RIH. Open choke fully and increase gas lift to 2.2 MMCFPD. Correlate and perforate the following intervals with well flowing: RUN INTERVAL FOOTAGE I 15,185' - 15,210' 2 15,155' - 15,175' 3 15,132' - 15,146' Minimum 24-hour test after cleanup 4 15,108' - 15,128' 5 15,080' - 15,100' 6 15,060' - 15,080' 25 20 14 2O 2O 20 Flow well prior to POOH after each run with well choked back to 3 turns open. NOTE: Prior to arming guns and until guns are 1000' in the hole, notify appropriate personnel and establish communications blackout following BC Perforating Safety Checklist. Re-establ ish blackout procedures when POOH above 1000'. 5. RD E-line unit. Put well in test. docs\oe55\41, doc RECEIVED D£O 1 6 1991 A)aska Oil & Gas gons. GommiSS~Oi~ Anchorage Atta c hmen t._ ~,~/'2 Spud Original RK~I, 19' e,10ove GL Top o+` 'G' Zone, [4,435' MTI Top o+` Hemlock, 15,313' 149 Annulus FLuid, 10.3 ppg C~CLe ALL dep*hs e,re RK~ MTL ~o ~op o+` equipment. L 0 MARATHON DIL CDHPANY ]~EAVER CREEK I.~nT. AP! #' 50-133-:~0~39-01 Compieaclon Tt~e, 10/10/88. Me,xlmum Hole Angle. lB e 13,780' MD Angle Thmou~ 'Gq Angle Throug~ Hem. Re~epence LoG, 9IL 9/11 & 11/~3/7~ Veil Typm DR Producer New ~] Vorkover [] RecompLe~lon 1. FMC TC-1A-EN Tbs. Hgt. 2. [3'l:ls XXD pro+`lte +'or SSSV (~.813' I])). 3. 3-1/;~' 9.3# L-BO, 8RTL IrUE, A1~ Mod Tbs. 4.. n-tls X Nipple (~.813' ITL). 5. 3-1/~' la,kef seetL ~ssembiy-B040 PIeR (17.91' Leng-t:h). 6. 3-1/2' he,i+`cu~ Muleshoe. 7. ]~ker PgR C4.00' ITl) w/Concen~crlc CoupLin9 (4.00' I97 e,nd la,kef SBE (18.74' ieng~ch). 8. ]~e,ker FAla-1 pkm size 83FA47 (4.00' ITL). 9. 5° I~oLa~clon Liner a~embiy (See Tubing C~slng Tle~c~lI). 10. 9~kep FA-1 pkr, size 83FA47 (4.00' I97. 16' 250' 14,482' 14,428' 14,464' 14,48~' 14,464' 14,484' 14,484' 14,813' GAS LIFT DATA tleog;h Size Me,ndreL ITL Ye,lye Type J.&J~ch Por~; 2737' 3.5' Flope~roL SPM-8 2.867' 1.5' OLV 1.5 R RK 16/64 4747' ' 613~ ....... 7~00 ....... 8079' ' ' ' ' ' 16/64 8862 ...... ~0/64 9586 ....... 10 :=15 ....... 10 837 .... ' · ' · 11,463' ...... 1~,085' ' Flope~rol SPM-E ' 1.5' GLV 1.5 R RK ' 1P,708 ' GLMA ]~ST 2.867' 1' OLV 1.0 R ]~K-:= ' 13 206 ....... 13,730 ...... 20/64 14,259' ' 6LMA ;~ST ~'.867' ' t~K-~ 3/8 CASING & TUEIING Size Velgh~ Grnde ToO ]~o't;'l;om Des;crlO't:. CO' 94 H-40 0 EBB' ST&C 13-3/8· 72 N-BO 0 1942' BRD ' 68 J-55 194~' E989' ' 9-5/8' 47 N-BO 0 74i~1' ]~u~c~. · 47 S-95 74~1' 9938' ' · 53.5 P-110 9938' I~,521' 7' 29 P-110 1P,217' 12~552' ' ' 32 P-110 1P~552' 15,921' 5' 18 N-BO 14.487' 14,813' IsoLation Llne~ 3-1/~' 9.3 L-BO 0 14,482' 8R9 AS Hod Tbs K~ ~o ~op o~ 20' csg = 24'. FILl :tagged e 15,347 PIiTTI = 15,529' TD = 15,921' PERFDRATIDN DATA In~erve,[ Zone FT SPF D~e 14,435'-565' Upper 'O' 30' 4 1/73 Squeezed 14,731'-743' 1P' 4 8/~8/88 Squeezed 15,040'-100' Lower 'G' 60' 8 12/11/88 DP Carrier 15,108'-1~8' ' 20 .... 15,132'-146' ' 14' ' 1~/10/88 15,155'-175' ' 20' ' 15,185'-~10' ' 25 .... 15,361'-376' Hemlock 15' 4 1~/1~/72 Jumbo Je't 15,382'-397' ])ST 15 .... 15,416'-431' 15 .... 15,446'-461' Per+`ora~clons 15 .... Hemlock per?ore,~lons were Isolated a?~er DST by a cm~. rede,Inet bu~ were never cm~. squeezed. 1~/17/90. Reservoir I)e,~un, 14,800' Sub See, Revision Tl~e, 3/26/91 Revised 9y, TM/erg Reason, Reper~ Lower O Previous RevlslOn~ 12/21/88 Attachment #3 BEAVER CREEK Wireline Lubricator w/Associated BOPE Manually Operated BOP Grease Head (Hydralically Activated) -- Lubricator Tree Cap Swab Valve 2' Wing Valve 3-1/2" 50QO psi Christmas T~ee Master Valves Seal Flange Alaska 0[1 & Gas Cons, Armhoragc Alaska Region Domestic Production ORIGINAL Marathon Oil Company P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 January 7, 1991 Mr. D. W. Johnston Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Johnston: Enclosed is the AOGCC "Report of Sundry Well Operations" reperforating Beaver Creek Well BC-4. Should you have any questions regarding the report, please contact J. J. Burger at (907).564-6436. Sincerely, --)--,~\., L~ ' , ,,, T. J. Kovacevich Operations Engineering Supervisor Attachment \docs\ml\6.doc A subsidiary of USX Corporation STATE OF ALASKA U ALASKA el L AN D GAS CONSERVATION COM MISSION REPORT OF SUNDRY WELL OPERATIONS t6iNAL 1. Operations pedormed: Operation shutdown __ Stimulate __ Plugging __ Pedorate _Z. Pull tubing __ Alter casing __ Repair well __ Other __ 2. Name of Operator Marathon Oil Company 3. Address P. O. Box lg0168 Anchorage, AK 995 [. Type of Well: Development X__ Exploratory __ Stratigraphic __ Service, 6. Datum elevation (DF or KB) ].9' KB above GL feet 7. Unit or Property name Beaver Creek Unit 4. Location of well at surface ].,700' FSL, 660' FWL, Sec. At top of productive interval ' L Ateff~dt~e6~epthFs ' 711' FEL, Sec. 1,492' FSL, 768' FEL, Sec. At total depth 1,553' FSL, 900' FEL, Sec. 33-7N-lOW-SM 34-7N-lOW-SM 34-7N-lOW-SM 34-7N-lOW-SM 12. Present well condition summary Total depth: measured true vertical 15,921 ' feet Plugs (measured) 15,715' feet 8. Well number BC 4 9. Permit number/approval number 90-902 10. APl number 50- 133-20239 11. Field/Pool Beaver Creek Fi el d Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate 20989 ' Production 12,521 ' Liner 3,704' Perforation depth:measured 15,529 ' feet Junk (measured) 15,290' feet Size Cemented Measured depth True vertical depth 13 3/8" 2,000 sx 2,989' 2,890' 9 5/8" 2,868 sx 12,521' 12,445' 7" 1,400 sx 15,921' 15,715' true vertical See Attachment #1 Tubing (size, grade, and measured depth) 3 1/2" 9.3# L-80 EUE, AB Mod Tubing 0 14,482' MD Packers and SSSV (type and measured depth) 0tis XX0 Profile for SSSV (2.813" ID) ~ 250' MD Baker FAB-1 pkr (4.00" ID) @ 14,484', Baker FA-1, p.~r,.~.4,QO~"rI~l~ @ 14,813' MD 13. Stimulation or cement squeeze summary I:: L, Ir, I V E IJ 14. Intervals treated (measured) Treatment description including volumes used and final pressure ",.,~I Representative Daily Average Production or JAN u 8 199! & Cons. c0ma'msll;;l- OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 12/18/90 231 1400 1 580 70 Subsequent to operation 12 / 21/90 402 1500 2 640 100 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X__ Gas__ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Operations Signed , Title Form 10-404 Rev 06/~15~88' Eng. Supervisor 1/4/91 Date SUBMIT IN DUPLICATE Attachment #1 Beaver Creek Well BC-4 Perforations Lower "G" Zone Hemlock 15,040' - 15,100' MD 15,108' - 15,128' MD 15,132' - 15,146' MD 15,155' - 15,175' MD 15,185' - 15,210' MD 15,361' - 15,376' MD 15,382' - 15,397' MD 15,416' - 15,431' MD 15,446' - 15,461' MD 14,840' - 14,900' TVD 14,907' - 14,926' TVD 14,928' - 14,944' TVD 14,950' - 14,972' TVD 14,981' - 15,006' TVD 15,152' - 15,166' TVD 15,172' - 15,187' TVD 15,205' - 15,219' TVD 15,234' - 15,249' TVD (Note: Hemlock zone perforated in 1972 for DST. Hemlock perforations currently covered by fill.) NEF/em/BC-4/BC Attachment #2 Daily Summary of Well Operations Beaver Creek Well #4 12/19/90 RU Wireline, choke well. RIH with 2.70" gauge ring. Tag fill at 15,347'. POH. RD Precision wireline. Open choke 1004 and turn well over to production. 12/20/90 RU E-line o~ BC #4. MU 25' 2-1/8" Enerjet III guns, 14 GM charge, s, 4 SPF, 0° phasing, 30 offset to the ieft looking down the gun. Choke well Pressure test lubricator. RIH. Perforate 15,185' - 15,210' with well flowing. POH. Guns hung up @ 14,437'. Worked guns several times. Cleared obstruction. POH. OOH. All shots fired. Secure well for the night. 12/21/90 MU 20', 2-1/8" Enerjet III guns, 4 SPF0 14 GM charges, 0° phasing, offset 30o to the left looking down the gun. Pressure test. RIH with choke open 100%. Perforate 15,155'-15,175'. POH with well flowing. OOH. All shots fired. RD equipment and turn well over to production to test. \docs\bc\bc4.doc ,. Alaska R~ Domestic .;-, oduction Marathon Oil Company P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 December 20, 1990 Mr. D. W. Johnston Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Johnston: Attached for your approval is an "Application for Sundry Approvals" with appropriate attachments for Beaver Creek Wel 1 #4. Should you have any questions regarding any application or report, please contact J. J. Burger at (907) 564-6436. Sincerely, T. J. Kovacevich Operations Engineering Supervisor Attachment em\docs\m1\6 A subsidiary of USX Corporation · ~' STATE OF ALASKA ALAS,,~ OIL AND GAS CONSERVATION COMMIS , APPLICATION FOR SUNDRY APPROVALS 2. Name of Operator Marathon 0i 1 3. Address P.O. 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubmg __ Variance __ Perforate X Other __ 5. Type of Well: 6. Datum elevation (DF or KB) Comp an y Development _.~ Exploratory__ 19m KB above GL Stratigraphic __ 7. Unit or Property name Box 190168 Anchorage, AK 995 9 Service__ Beaver Creek Unit feet 4. Location of well at surface 1,700' FSL, 660' FWL, Sec. At top of productive interval , , m w AteftJ~iv~epthFSL 711 FEL Sec. 1,492' FSL, 768' FEL, Sec. At total depth 1,553' FSL, 900' FEL, Sec. 33-7N-lOW-SM 34-7N-lOW-SM 34-7N-lOW-SM 34-7N-lOW-SM 8. Well number R£ 4 9. Permit number 72-13 10. APl number 5o- 133-20239 11. Field/Pool Beaver Creek Fi el d 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate 2,989 ' Production 12,521 ' Liner 3,704' Perforation depth: measured 15, g21 ' feet Plugs(measured) 15,715m feet 15,529 ' feet Junk (measured) 15,290' feet Size Cemented DEC 2 4 19 0 ' Measured' 8'b~tb,¢~.;; ~C~0[~e.,~e~ical depth 13 3/8" 2,000 sx 2,989' 2,890' 9 5/8" 2,868 sx 12,521' 12,445' 7" 1,400 sx 15,921' 15,715' true vertical See Attachment #1 Tubing (size, grade, and measured depth) 3 1/2" 9.3# L-80 EUE, AB Mod Tubing ~ 14,482' MD Packers and SSSV (type and measured depth) 0ti$ XX0 Profile for SSSV (2.813" ID) @ 250' MD Baker FAB-1 pkr (4.00" ID) ~ 14,484',. Baker FA-1 pkr (4.00" ID) e !4,813' 13, Attachments 2 (q,. 3Description summary of proposal ~ Detailed operations program __ BOP sketch ~ MD 14. Estimated date for commencing operation December !9, 1990 16. If proposal was verbally approved Lonnie Smith Name of approver 12/18/90 Date approved 15. Status of well classification as: Oil ~ Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true aQd.c, orr,e~ to the best of my knowledge. Signed T. ,1. Kovacevich 1~0__~¢t..-i0~ Tte0peral:ions Engineering SupervisDate 12/19/90 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Approved Copy ORIGINAL SIGNED BY Re, turf)ed the [ C SMITH ~_-,L]_ Approved by order of ,,, , Commissioner [,Approval No. ?~ ..,.,~;;¢ ~ Date/.~.~'7/c?~,' Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment #1 Beaver Creek Well BC-4 Perforations Lower "G" Zone Hemlock 15,040' - 15,100' MD 15,108' - 15,128' MD 15,132' - 15,146' MD 15,155' - 15,175' MD 15,185' - 15,210' MD 15,361' - 15,376' MD 15,382' - 15,397' MD 15,416' - 15,431' MD 15,446' - 15,461' MD e- 14,840' - 14,900' TVD 14,907' - 14,926' TVD 14,928' - 14,944' TVD 14,950' - 14,972' TVD 14,981' - 15,006' TVD 15,152' - 15,166' TVD 15,172' - 15,187' TVD 15,205' - 15,219' TVD 15,234' - 15,249' TVD (Note: Hemlock zone perforated in 1972 for DST. Hemlock perforations currently covered by fill.) NEF/em/BC-4/BC Attachment 2 BC Well #4 Reperforation Procedure AFE 8146-0 · RU slickline. PT to 1500 psi. Run 2.7" GR and tag fill. POH. RD slickline. ® RU E-line unit. PT to 1500 psi. Perforate the lower G-Zone using 2-1/8" strip guns, 4 SPF, 0° phasing, 300 offset, with well flowing at a reduced stabilized rate. Run Interval Footage i 15,185' - 15,210' 25' 2 15,155' - 15,175' 20' 4. RD E-line unit. Be Return well to full production over 24 hours. Maximum gas lift rate = 1500 MCFPD. NOTE: Maximum anticipate SBHP is 3000 psi. \docs\afe\28.doc i 2. ttachment #3 ( BEAVER CREEK Coiled Tubing Lubricator w/Associated BOPE Double BOP w/1 1/4' Rams 5000 psi WP Hydraulic Rams Tree Cap Swab Valve ~ 2' Wing Valve Master Valves 4 1/2' 5000 psi Christmas Tree Seal Flange Marathon Oil Company ~ .~ion Domestic Production RO. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 May 14, 1990 Mr. C. V. Chatterton Alaska Oil & Gas conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed is the AOGCC "Report of Sundry Well Operations" with appropriate attachments for Beaver Creek Well #4. Should you have any questions regarding the report, please contact me at (907) 561-5311. Sincerely, .~-~(ovacevich District Operations Engineer Attachments :ldk\ml\6a A subsidiary of USX Corporation i:' STATE OF ALASKA i :i'i' ALASKA el L AN D GAS CONSERVATION COM MISSION REPORT OF SUNDRY WELL OPERATIONS iN 1. Operations performed: Operation shutdown __ Stimulate __ Plugging Pull tubing __ Alter casing __ Repair well I Perforate X Other 2. Name of Operator Ma~athnn 3. Address I5. Type of Well: Development Exploratory Stratigraphic 99-~ g Service ! Anchoraoe.. AK Sec. 33-7N-lOW-SM F~_, Sec. 34-7N-lOW-SM F~L, Sec. 34-7N-lOW-SM 6. Datum elevation (DF or KB) 1 O' VI~ ~k~,-, ~7." U nii'~'r P~(~e~t~ n~n~ e Beaver ¢r¢.¢_l~ Ilnif 8. Well number feet B~ pe4rmit number/approval number i0.'TA~Fnumber 50- 13~-70239 11. Field/Pool P. O. Box !901§8 4. Location of well at surface i 700' F,,% 660' At top (~f productive ¢~terval , At eff~ect~zl,~lept~.,l--, 711' 1,492' F~L, 768' At total depth 1,553' FSL, 900'F~I_, 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate 2,989 ' Production 12,521 ' Liner 3,704' Perforation depth:measured Sec. :]4-7N-lOW-SM 15,921' feet 15,715' feet 15,529' 15,290' Size 13 3/8" 9 5/8" 7" feet feet ~&eaver, £reek Field Plugs (measured)i'%~ ,','CIA\" 1 $ Junk (measured) . ,,,,,:,,,~,, ¢~1 ~ Gas Cons. C0mmissim~ ' .,~,.~ ~nchora~ ' Cemented Measured depth True ve~ical depth 2,000 sx 2,989' 2,890' 2,868 sx 12,521' 12,445' 1,400 sx 15,921' 15,715' true vertical See Attachment #1 Tubing (size, grade, and measured depth) 3 1/2" 9.3# L-80 EUE, AB Mod Tub'ing La 14,482' ND Packers and SSSV (type and measured depth)0t i s XX0 Profile for $$$V (2.813" ID) La 250' MD R;~L,.¢,~ F&R_I nl,,~ fA nn,, Tn) Ca 14,~, ,~,~,,,,, rA_l pbv. (`4 nn.. Tn~ t~ 1,4 Qi-'ji .... ~ · f ~,.~. , ,1 ~ ,~. ,lvv .i,l.,,/ ~,.- .i. 13. Stimulation~F6~en't ~;~l-ue~ze~]~m'a~'~ - - Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 5/03/90 215 209 0 535 70 Subsequent to operation 5/10/90 15. AttachmentsX #2 Copies of Logs and Surveys run ~ Daily Report of Well Operations ~ 580 385 5 655 90 16. Status of well classification as: Oil X__ Gas ~ Suspended ~ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed-'"~~,, I ~ Title District Operations Engineer Form 10-404 Rev 06/15/88 Date 5/14/90 SUBMIT IN DUPLICATE Attachment #1 Beaver Creek Well BC-4 Perforations Lower 'IGI' Zone Hemlock 15,040' - 15,100' MD 15,108' - 15,128' MD 15,132' - 15,146' MD 15,155' - 15,175' MD 15,185' - 15,210' MD 15,361' - 15,376' MD 15,382' - 15,397' MD 15,416' - 15,431' MD 15,446' - 15,461' MD 14,840' - 14,900' TVD 14,907' - 14,926' I'VD 14,928' - 14,944' TVD 14,950' - 14,972' TVD 14,981' - 15,006' TVD 15,152' - 15,166' TVD 15,172' - 15,187' TVD 15,205' - 15,219' TVD 15,234' - 15,249' TVD (Note: Hemlock zone perforated in 1972 for DST. Hemlock perforations currently covered by fill.) NEF/em/BC-4/BC Attachment #2 Daily Wel 10perati ons Report Beaver Creek Unit Well #4 5/4/90 RU & PT lubricator to 1500 psi OK. MU 2 1/8" Dyna Strip Guns, 4SPF, 0° phasing, offset 300. RIH and perforate the Lower 'G' Zone 15,185'-15,210' DIL. Flow well for 30 min., POOH. 5/5/90 RU & PT lubricator to 1500 psi OK. MU 2 1/8" strip guns as above, RIH and perforate the Lower 'G' Zone 15,155'-15,175' DIL. Flow well for 30 min., POOH. 5/6/90 RU & PT lubricator to 1500 psi OK. Made four perforating runs using same guns as above. RIH and perforated the Lower 'G' Zone 15,132'-15,146'~ 15,108'-15,128'~ 15,070'-15,100'~ 15,040'-15,070' DIL. Flowed well following each run. POOH, RD, put well in test. docs/bc/bc4 Marathon Oil Company Ala~ ,,. o,on Domu~dc Production RO. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 May 14, 1990 Mr. C. V. Ch'atterton Alaska Oil & Gas Conservation Commission 3001 Por~u. pine ~J~O Anchorage, AK 1 Dear Mr. erton: Attached for your approval is an "Application for Sundry Approvals" with appropriate attachments for Beaver Creek Well #4. Verbal approval for this work was given by Mr. Russ Douglass on May 3, 1990. Should you have any questions regarding any application or report, please contact me at (907) 561-5311. Sincerely, District Operations Engineer Attachment :ldk\Ml\6A Anchora~ :' A subsidiary of USX Corporation STATE OF ALASKA i '":~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPRO A LS AL 1. Type of Request: Abandon m Suspend ~ Alter casing __ Repair well Change approved program __ Operation shutdown ~ Re-enter suspended well ~ Plugging ~ Time extension m ,, ~timulate ~ Pull tubing m Variance ~ Perforate AA Other 2. Name of Operator Marathon Oil Company 3. Address P. 0. Box 190168 Anchorage, Al( FWL, Sec. 4. Location of well at surface 1,700' FSL, 660' At top of productive interval ' L At efl~b0v6e7dep~s ' 711' FEL, Sec. 1,492' FSL, 768' FEL, Sec. At total depth 1,553' FSL, gOO' FEL, Sec. 15,921' 15,715' 12. Present well condition summary Total depth: meas'ured true vertical Effective depth: , measured 15,529' true vertical 15,290 ' J 5. Type of Well: Development X._~.X Exploratory m Stratigraphic __ 99519 Service ~ Casing Length Structural Conductor Sudace Intermediate 2,989' 12,521' Production Liner 3,704' Perforation depth: measured 33-7N-lOW-SM 34-7N-lOW-SM 34-7N-lOW-SM 34-7N-lOW-SM feet feet Plugs (measured) Size 6. Datum elevation (DF or KB) 19' KB above 6L 7. Unit or Property name Beaver Creek Unit 8. Well number B£ 4 9. Permit number 72-13 10. APl number 5o- 133-20239 feet feet 11. Field/Pool I~¥e~r~,C.,~eek Field E! V Eib? ,;WIAY 1 6 1990 Junk (measure~¢tSk~ 0]] · .:,.,,,,.,, .. & Gas Cons. Commissi(m '~ gnchora~ ~' Cemented Measured depth True vertical depth 13 3/8" 2,000 sx 2,989' 2,890' 9 5/8" 2,868 sx 12,521' 12,445' feet 7" 1,400 sx 15,921' 15,715' true vertical See Attachment #1 Tubing (size, grade, and measured depth) 3 1/2" 9.3# L-80 EUE, AB Mod Tubing @ 1'4,482' MD PackersandSSSV(ty_peandmeasureddeDth~0tis XX0 Profil, e for SSSV (2.813" ID!, ca 250' MD Baker FAB-1 pkr (4.00'¢ ID) 8 14,484' Baker FA-1 pkr (4.00 ID) Ca 14,813' MD 13. Attachments 2 & 3 Description summary of proposal X Detailed operations program __ BOP sketch X__ 14. Estimated date for commencing operation rvlaiy 4 ~ 1990 16. If proposal was verbally approved Name of approver Russ Douglass 5/3/9O Date approved 15. Status of well classification as: Oil X Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~-. ~,~ , ~ Title District Operations Engineer Date 5/14/90 (~) ' FOR COMMISSION USE ONLY Conditions ofPlug approval:integrityNotify_ Commission BOP Test so__ representatiVe Location may clearance witness __ ]Approval No./~ Mechanical Integrity Test ~ Subsequent form required 10- Approved by order of the Commission Form 10-403 Rev 06/15/88 J~IGINAL Sl!:~!~"'n t:~' ~, .... ~ ,-,, ~u~.~,',n,4 Copy Returned Commissioner Date 5-1 ~ -~(~ SUBMIT IN TRIPLICATE Attachment #1 Beaver Creek Well BC-4 Perforations Lower "GI' Zone Hemlock 15,040' - 15,100' MD 15,108' - 15,128' MD 15,132' - 15,146' MD 15,155' - 15,175' MD 15,185' - 15,210' MD 15,361' - 15,376' MD 15,382' - 15,397' MD 15,416' - 15,431' MD 15,446' - 15,461' MD 14,840' - 14,900' TVD 14,907' - 14,926' TVD 14,928' - 14,944' TVD 14,950' - 14,972' TVD 14,981' - 15,006' TVD 15,152' - 15,166' TVD 15,172' - 15,187' TVD 15,205' - 15,219' TVD 15,234' - 15,249' TVD (Note: Hemlock zone perforated in 1972 for DST. Hemlock perforations currently covered by fill.) %,'t~.'sI~ 9ii .& Gas Co~s. Com~aiS~'~.~ ',, Anchoraoja NEF/em/BC-4/BC Attachment 2 BC Well #4 Reperforation Procedure · RU E-line unit. PT to 1500 psi. Perforate the lower G-Zone using 2-1/8" strip guns, 4 SPF, 0° phasing, 30o offset, with well flowing at a reduced stabilized rate. Run Interval Footage 15,185 - 15,210 15,155 - 15,175 15,132 - 15,146 15,108 - 15,128 15,070 - 15,100 15,040 - 15,070 25 20 14 20 30 30 3. RD E-line unit. · Return well to full production over 24 hours. Maximum gas lift rate = 1500 MCFPD. NOTE: Maximum anticipate SBHP is 3000 psi. \docs\bc\bc4 Attachment #3 ~ BEAVER CREEK Wireline Lubricator w/Associated BOPE Grease Head (Hydralically Activated) Lubricator Manually Operated BOP Tree Cap Swab Valve 2' Wing Valve Master Valves 3-1/2' 5000 psi Christmas Tree Seal Flange Marathon Oil Company Alask~ ~gion Domestic Production RO. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 March 15, 1990 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed is the AOGCC "Report of Sundry Well Operations" with appropriate attachments for Beaver Creek Well #4. Should you have any questions regarding the report, please contact me at (907) 561-5311. Sincerely, 1. d. acevich D/strict Operations [ngineer Attachment \docs\ml\6.doc A subsidiary of USX Corporation STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION FIEPOFIT OF SUNDRY WELL OPEFIATIONS 1. Operations performed: Operation shutdown __ Pull tubing __ Alter casing __ Stimulate __ Plugging __ Perforate ~ Repair well __ Other __ 2. Name of Operator Marathon 0il Company 3. Address P. 0. Box 190168 4. Location of well at surface 1,700' FSL, 660' At top of productive interval i ! i At eff~dt,v~ept~S L 711 1,492' FSL, 768' At total depth 1,553' FSL, 900' 6, Datum elevation (DF or KB) ]9' KB above GL Anchorage, AK 5. Type of Well: Development X Exploratory __ Stratigraphic ~ 995 9 Service __ FWL, Sec. 33-7N-lOW-SM FEL, Sec. 34-7N- FEL, Sec. 34-7N- iOW-SM lOW-SM lOW-SM FEL, Sec. 34-7N- 7. Unit or Property name Beaver Creek Unit 8. Well number ~)."Permit number/approval number 10. APl number 50- 133-20239 11. Field/Pool Beaver Creek Fi el d feet 12. Present well condition summary Total depth: measured true vertical 15,921' feet 15,715' feet Plugs (measured) Effec!ive depth: measured 15,529 ' feet Junk (measured) true vertical 15,290 ' feet Casing Length Size Cemented Measured depth Structural Conductor Surface Intermediate 2,989' 13 3/8" 2,000 sx 2,989' Production 12,521' 9 5/8" 2,868 sx 12,521' Liner 3,704' 7" 1,400 sx 15,921' Perforation depth:measured True vertical depth 2,890' 12,445' 15,715' true vertical See Attachment #1 Tubing (size, grade, and measured depth) 3 1/2" 9.3# L-80 EUE, AB Mod Tubing 0 14,482' MD Packers and SSSV (type and measured depth) 0t i s XX0 Profile for SSSV (2.813" ID) @ 250' MD Baker FAB-1 Dkr (4 00" ID/ [a 14:484' Baker FA-1 nkr.(ZL, flQ".ID~.~ .1.4.R1.~' Mil 13. Stimulation or cement squeeze summary ~q~.,~ ~ (:~, ~:.~ \i? ~ ,,~,-~ ~' 14. Intervals treated (measured) Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data' Ar:mh0ra9,8. .. OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 3/2/90 260 120 3 560 70 Subsequent to operation 3 / 9 / 9 0 5 2 6 2 4 7 0 720 3O 15. Attachment~( #2 Copies of Logs and Surveys run __ Daily Report of Well Operations x__. 16. Status of well classification as: OilX__ Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '-'i--,~N~ 1~42-(~._¢.4~ 2 TitleDistrict Operati°ns Engineer Form 10-404 Rev 0k6/-1~/88 Date 2~"11 I¢ f~ O SUBMIT IN DUPLICATE Attachment #1 Beaver Creek Well BC-4 Perforations Lower "G" Zone Hemlock 15,040' - 15,100' MD 15,108' - 15,128' MD 15,132' - 15,146' MD 15,155' - 15,175' MD 15,185' - 15,210' MD 15,361' - 15,376' MD 15,382' - 15,397' MD 15,416' - 15,431' MD 15,446' - 15,461' MD 14,840' - 14,900' TVD 14,907' - 14,926' TVD 14,928' - 14,944' TVD 14,950' - 14,972' TVD 14,981' - 15,006' TVD 15,152' - 15,166' TVD 15,172' - 15,187' TVD 15,205' - 15,219' TVD 15,234' - 15,249' TVD (Note: Hemlock zone perforated in 1972 for DST. Hemlock perforations currently covered by fill.) NEF/em/BC-4/BC Attachment #2 Daily Summary of Well Operations Beaver Creek Well #4 3/3/90 RU E-line and PT lubricator w/ N2, OK. Ma~e one perforating run using 2-5/8" Jumbo Jet II Hollow Carrier guns, 4 SPF, 0v phasing. Perforated lower G-Zone 15,185' - 15,210' DIL. Flow well 10 min. POH, RD for night. 3/4/90 RU E-line and PT lubricator, OK. Made four perforating runs using same guns as above, flowed well for 10 min. after each run. RIH and perforated the lower G-Zone: Run 1 Run 2 Run 3 Run 4 15,155' - 15,175' and 15,136' - 15,146' 15,132' - 15,136' and 15,108' - 15,128' 15,070' - 15,100' 15,040' - 15,070' Tagged fill on last run @ 15,340'. RD E-line and placed back on production. \docs~bc\bc4.doc t STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~.~. APPLICATION FOR SUNDRY APPROVALS' 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ 2. Name of Operator Marathon Oil Company 3. Address P. 0. Box 190168 Anchorage, AK Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing __ Variance __ Pedorate ~ Other __ 5. Type of Well: Development Exploratory Stratigraphic 995 9 Service 6. Datum elevation (DF or KB) 19' KB above GL 7. Unit or Property name Beaver Creek Unit feet 4. Location of well at surface 1,700' FSL, 660' At top of productive interval 1.467' FSL 711' At effective depth ' 1,492' FSL, 768' At total depth 1,553' FSL, 900' FWL, Sec. 33-7N-lOW-SM FEL, Sec. 34-7N-lOW-SM FEL, Sec. 34-7N-lOW-SM FEL, Sec. 34-7N-lOW-SM 12. Present well condition summary Total depth: meas'ured true vertical 15,921' feet 15,715' feet Effective depth: measured 15,529' true vertical 15,290' Plugs (measured) Casing Length Structural REC 8. Well number BC q 9. Permit number 72-13 10. APl number 5o- 133-20239 11. Field/Pool Beaver Creek Field EIVED Size feet feet JAN 0 8 Junk (measured) Cemented MeaSurbd dept~-" True ve~ical depth Conductor Surface Intermediate 2,989' 13 3/8" 12,521' 9 5/8" Production Liner 3,704' 7" 2,000 sx 2,989' 2,890' 2,868 sx 12,521' 12,445' 1,400 sx 15,921' 15,715' Perforation depth: measured true vertical See Attachment #1 Tubing (size. grade, and measured depth) 3 1/2" 9.3# L-80 EUE, AB Mod Tubing @ 14,482' MD PackersanQ. SSSV(ty~¢gnqlmecsure, d. de..qtll)0t.l.!.,S XX0 Prof-i]e for SSSV (2.813" ID) La 250' MD uaKer rAu-t pKr L~.UU" tU) La 14,484'' Baker FA-1 pkr (4.00" ID) La 14,813' MD 13. Attachments 2 & 3 Description summary of proposal X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation January 11, 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X_~ Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~...~,~-~./..~'~~. Title District Operations Enqineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Date j. Approval No.¢ ~ _. ~/~ Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ~r.~ ,z~ Approved by order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY i i,IltlMil:: ~. ~/IITI-I Returnee j: ,4 Commissioner Date SUBMIT IN TRIPLICATE Attachment #1 Beaver Creek Well BC-4 Perforations Lower "G" Zone Hemlock 15,040' - 15,100' MD 15,108' - 15,128' MD 15,132' - 15,146' MD 15,155' - 15,175' MD 15,185' - 15,210' MD 15,3611 - 15,376' MD 15,3821 - 15,397' MD 15,4161 - 15,431' MD 15,446' - 15,461' MD 14,840' - 14,900' TVD 14,907' - 14,926' TVD 14,928' - 14,944' TVD 14,950' - 14,972' TVD 14,981' - 15,006' TVD 15,152' - 15,166' TVD 15,172' - 15,187' TVD 15,205' - 15,2191 TVD 15,234' - 15,249' TVD (Note: Hemlock zone perforated in 1972 for DST. Hemlock perforations currently covered by fill.) NEF/em/BC-4/BC Attachment # BC #4 Perforation Procedure AFE 8145-0 1. RU E-line unit. PT to 2500 psi. 2. P~rforate the ~)ower G-Zone using 2-1/2" hollow carrier guns, 4 SPF, 0 phasing, 30 offset, with well flowing at a reduced stabilized rate. Run Interval Footage 15,185 - 15,210 15,155 - 15,175 15,132 - 15,146 15,108 - 15,128 15,070 - 15,100 15,040 - 15,070 25' 20~ 14' 20' 30' 30' 3. RD E-line unit. 4. Return well to full production over 24 hours. Maximum gas lift rate = 1500 MCFPD. NOTE: Maximum anticipated SBHP is 3000 psi. ~docs~bc~bc4.doc {,, Attachment #3 i~ BEAVER CREEK Wireline Lubricator w/Associated BOPE Manually Operated BOP Grease Head (Hydralically Activated) Lubricator Tree Cap Swab Valve 2" Wing Valve Master Valves 3-1/2" 5000 psi Christmas Tree Seal Flange . i STATE OF ALASKA ( "'* ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Pull tubing __ Alter casing __ Repair well __ Perforate X__ Other Marathon Oi 1 Company Development ~X Exploratory __ 3. Address Stratigraphic __ P. O. Box 190168 Anchorage, AK 995 Service__ 4. Location of well at sudace 1,700' FSL, 660' FWL, Sec. 33-7N-lOW-SM At top of productive interval 1 4 7' S 711' FEL, Sec 34-7N-lOW-SM At effedtiv§ Uept~' L, . 1,492' FSL, 768' FEL, Sec. 34-7N-lOW-SM At total depth 1,553' FSL, 900' FEL, Sec. 34-7N-lOW-SM 12. Present well condition summary Total depth: measured true vertical 15,921' feet 15,715' feet Plugs (measured) 6. Datum elevation (DF or KB) 19' KB above 6L feet 7. Unit or Property name Beaver Creek Unit 8. Well number R¢, 4 9. Permit numbedapproval number 9-842 10. APl number 5o- 133-20239 11. Field/Pool Beaver Creek Field Effective depth: measured 15,529 ' true vertical 15,290 ' Casing Length StructUral Conductor Surface Intermediate 2,989 ' Production 12,521 ' Liner 3,704' Perforation depth: measured Size feet Junk (measured) feet Cemented Measured depth 13 3/8" 2,000 sx 2,989' 9 5/8" 2,868 sx 12,521' 7" 1,400 sx 15,921' True vertical depth 2,890' 12,445' 15,715' true vertical See Attachment #1 Tubing (size, grade, and measured depth) 3 1/2" 9.3# L-80 EUE, AB Mod Tubing @ 14,482' MD Packers and SSSV (type and measured depth)0t i s XX0 Profile for SSSV Baker FAB-1 pkr (4.00" ID) 0 14,484', Baker FA-1 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure (2.813" ID) pkr (4.00" @ 250' MD ID) (a 14,813' MD. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 9/20/89 333 132 Subsequent to operation 9/25/89 548 171 Anch0ra§<~ Tubing Pressure 3 620 75 0 710 80 15. Attachmen~ #2 Copies of Logs and Surveys run __ Daily Report of Well Operations _~x 16. Status of well classification as: Oil ~ Gas_ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. /%._/ Signed ~(,,)~C~ ~ ~' Title District Form 10-404 Rev 06/15188 Operations Engineer Date /o/~'//$ ~ SUBMIT IN DUPLICATE Attachment #1 Beaver Creek Well BC-4 Perforations Lower "G" Zone Hemlock 15,040' - 15,100' MD 15,108' - 15,128' MD 15,132' - 15,146' MD 15,155' - 15,175' MD 15,185' - 15,210' MD 15,361' - 15,376' MD 15,382' - 15,397' MD 15,416' - 15,431' MD 15,446' - 15,461' MD 14,840' - 14,900' TVD 14,907' - 14,926' TVD 14,928' - 14,944' TVD 14,950' - 14,972' TVD 14,981' - 15,006' TVD 15,152' - 15,166' TVD 15,172' - 15,187' TVD 15,205' - 15,219' TVD 15,234' - 15,249' TVD Attachment #2 Daily Summary of Well Operations Beaver Creek Well #4 9/21/89 U E-line and PT lubricator to 2500 psi, OK. Made four perforating runs using -1/2" hollow carrier, deep penetrating charges, 0° phasing, 30o offset, 4 SPF. RIH, correlate and perforate the Lower G-Zone 15,185' - 15,210'; 15,155' - 15,175'; 15,132' - 15,146' and 15,108' - 15,128' IEL. Flowed well for 10 min. after each run to clean up well. Tagged bottom on last run 0 15,356' WLM. POOH, secure well for the night. 9/22/89 RU E/~!ine and PT lubricator to 2500 psi, OK. Made two perforating runs using 2-1~ hollow carrier, deep penetrating charges, 0° phasing, 30o offset, 4 SPF. RIH, correlate and perforate the Lower G-Zone 15,070' - 15,100' and 15,040' - 15,070' IEL. Flowed well 10 min. after each run to clean up well. Tagged fill at 15,355' WLM on last run. RD and turn well over to Production. ~docs~BC~BC4.doc Marathon Oil Company Alaska~~ .,ion Domest~,.; Production /- P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 September 19, 1989 Alaska Oil & Gas Conservation 3001 Porcupine Dr. Anchorage, AK 99501 Commission Dear Mr. Chatterton: Enclosed is the AOGCC "Report of Sundry Well Operations" with the appropriate attachments for Beaver Creek Well 4 coiled tubing xylene treatment. Should you have any questions regarding the report, please contact me at (907) 561-5311. 'Sincerely, D. K. Corlett District Operations Engineer Attachment \docs\ml\6.doc RECEIVED SEP ]. c)1,989 Alaska 0ii A Gas Cons.C0m[m,,s,~,::. Anchorage A subsidiary of USX Corporation 'i STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMI"~olON REPORT OF SUNDRY WELL OPERATIONS 1. Operations pedormed: Operation shutdown __ Stimulate __ Plugging Pull tubing __ Alter casing ~ Repair well __ 2. Name of Operator Marathon Oil Company 3. Address P. O. Box 190168 Anchorage, AK 4. Location of well at surface Pedorate __ X Other __ 5. lypeofWelk DevelopmentX Exploratory ~ t Stratigraphic __ 995 9 Service _~. 1,700' FSL, 660' FWL, Sec. 33-7N-lOW-SM At top of productive interval i ' FEL Sec 34-7N-lOW-SM . .467 FSL 711' . At effedtive depth ' ' 1,492' FSL, 768' FEL, Sec. 34-TN-10W-SH At total depth 1,553' FSL, 900' FEL, Sec. 34-TN-10W-SM 6. Datum elevation (DF or KB) 19' KB above GL feet 7. Unit or Property name Beaver Creek Unit 8. Well number BC 4 9. Permit number/approval number 9-801 10. APl number 5Q-33-20239-01 11. Field/Pool Beaver Creek Field 12. Present well condition summary Total depth: measured true vertical Effec!ive depth: measured true vertical Casing Length Structural Conductor Sudace Intermediate 2,989 ' Production 12,521 ' Liner 3,704' Perforation depth: measured 15,921' feet 15,715' feet 15,529' feet 15,290' feet Size Plugs (measured) Junk(measured) Cemented Measured depth True vertical depth 13 3/8" 2,000 sx 2,989' 9 5/8" 2,868 sx 12,521' 7" 1,400 sx 15,921' true vertical See Attachment #1 2,890' 12,445' 15,715' 13. Tubing (size, grade, and measured depth) 3 1/2" 9.3# L-80 EUE, AB Mod Tubing 0.14,482' MD Packers and SSSV (type and measured depth) 0t i s XX0 Profile for SSSV (2.813" ID) @ 250' MD Baker FAB-1 pkr (4.00¢' ID) @ 14,484', Baker FA-1 pkr (4.00" ~)r,@#,~l.~,i%t}'rl~l;~ Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure KcLr..I V EIJ SEP 191989 Alaska 0il a Gas Cons. G.ommis i . 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 9/5/89 550 293 2 760 9/16/09 312 154. 8 700 Tubing Pressure 100 75 15. Attachment~, Z Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas__ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~/~/¢'~/~----6/"~ Title District Operations Engineer Date ~'//~//o'=~ Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Attachment #1 Beaver Creek Well BC-4 Perforations Lower "G" Zone Hemlock 15,040' - 15,100' MD 15,108' - 15,128' MD 15,132' - 15,146' MD 15,155' - 15,175' MD 15,185' - 15,210' MD 15,361' - 15,376' MD 15,382' - 15,397' MD 15,416' - 15,431' MD 15,446' - 15,461' MD 14,840' - 14,900' TVD 14,907' - 14,926' TVD 14,928' - 14,944' TVD 14,950' - 14,972' TVD 14,981' - 15,006' TVD 15,152' - 15,166' TVD 15,172' - 15,187' TVD 15,205' - 15,219' TVD 15,234' - 15,249' TVD (Note: Hemlock zone perforated in 1972 for DST. Hemlock perforations currently covered by fill.) NEF/em/BC-4/BC RECEIVED , Gas Cons,, ~omm~s,~, Anchorage Attachment #2 Beaver Creek Unit Well BC #4 Daily Summary of Wel 10perati ons 9/8/89 RU CTU and PT lines to 4500 psig, OK. With well on gas lift, RIH w/ hydroblast tool to 14,000' CTM. Well died. Displace CT w/ xylene. RIH to 15,040' CTM and hydroblast with xylene @ I BPM from 15,040' to 15,210' CTM. Used total of 1900 gals xylene. POOH w/ CT to 14,550' CTM. Start gas lift and flow back 40 bbls. SI gas lift and allow well to die. Fill CT - tbg annulus with lease crude. Pump ~ 4 BPM - 60 bbls to fill while moving CT to perforations. Squeeze xylene @ perfs ~ 3/4 BPM w/ 4000 psig pump pressure. Pump 1100 gals xylene and displace CT w/ lease crude. POOH w/ CT. Allow xylene to soak 12 hours, RD CT. ~docs~BC4~BC.doc RECEIVED s'E 1 1989 ,. GasCons.' ~ms~: Anchorage Marathon Oil Company Ala~, ~ion Domesh~, Production ORiGINA[, P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 September 18, 1989 Alaska Oil & Gas Conservation 3001 Porcupine Dr. Anchorage, AK 99501 Commi ssi on Dear Mr. Chatterton: Attached for your approval is an I'Application for Sundry Approvals" with appropriate attachments for Beaver Creek Well #4. Should you have any questions regarding any application or report, please contact me at (907) 561-5311. Sincerely, D. K. Corlett District Operations Engineer Attachment em\docs\m1\6 RECEIVED ! 1989 Oil & 6as Cons. Cofll~jSsk?, Anchorage A subsidiary of USX Corporation STATE OF ALASKA " ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance __ Pedorate X__ Other __ 2. Name of Operator Marathon Oil Company 3. Address P. 0. Box 190168 Anchorage, AK 4. Location of well at surface ] . Type of Well: Development Exploratory Stratigraphic 995 Service 6. Datum elevation (DF or KB) 1,700' FSL, 660' FWL, Sec. 33-7N-lOW-SM At top of productive interval 1,467' FSL 711' FEL Sec. 34-7N-lOW-SM At effective depth ' ' 1,492' FSL, 768' FEL, Sec. 34-7N-lOW-SM Attot~l,d~.~, FSL, 900' FEL, Sec. 34-TN-10W-SM 12. Present well condition summary Total depth: measured true vertical 15,921' feet 15,715' feet Plugs (measured) Effective depth: measured 15,529' true vertical 15,290 ' feet Junk (measured) feet Casing Length Structural Conductor Surface 2,989' Intermediate 12,521 ' Production Liner 3,704' Size Cemented Measured depth 13 3/8" 2,000 sx 2,989' 9 5/8" 2,868 sx 12,521' 7" 1,400 sx 15,921' Perforation depth: measured 19' KB above GL feet 7. Unit or Property name Beaver Creek Unit 8. Well number B6 4 9. Permit number 72-13 10. APl number 50-- 133-20239-01 .Field/Po~l eaver ~reek Field SEP 191989 Alaska 0ii & Gas Cons, commissi ', Anchorage True vertical depth 2,890' 12,445' 15,715' true vertical See Attachment #1 Tubing (size, grade, and measured depth) 3 1/2" 9.3# L-80 EUE, AB Mod Tubing @ 14,482' MD 0ti " ' Packers and SSSV (type and measured depth) S XX0 Profile for SSSV (2.813 ID) 0 250 MD Baker FAB-1 pkr (4.00" ID) @ 14~484', Baker FA-1 pkr (4.00" TD) ~a 14~813' MD 13. Attachments 2 & 3 Description summary of proposal ~ Detailed operations program I BOP sketch _X. 14. Estimated date for commencing operation 15. Status of well classification as: September' 21, 1989 16. If proposal was verbally approved Oil ~ Gas __ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of m'¢ knowledge. Signed /-~/~ ~--~ Title District Operations Engineer FOR COMMISSION USE ONLY Suspended__ Date Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance i Mechanical Integrity Test I Subsequent form required 10- Approved by order of the Commission Form 10-403 Rev 06/15~88 ORIGINAL SIGNED BY LONNfF fl, S~41TH J Approval No..~).__0¢ Z./",2... Approved Copy Returned Commissioner Date SUBMIT IN TRIPLICATE Attachment #1 Beaver Creek Well BC-4 Perforations Lower "G" Zone Hemlock 15,040' - 15,100' MD 15,108' - 15,128' MD 15,132' - 15,146' MD 15,155' - 15,175' MD 15,185' - 15,210' MD 15,361' - 15,376' MD 15,382' - 15,397' MD 15,416' - 15,431' MD 15,446' - 15,461' MD 14,840' - 14,900' TVD 14,907' - 14,926' TVD 14,928' - 14,944' TVD 14,950' - 14,972' TVD 14,981' - 15,006' TVD 15,152' - 15,166' TVD 15,172' - 15,187' TVD 15,205' - 15,219' TVD 15,234' - 15,249' TVD (Note: Hemlock zone perforated in 1972 for DST. Hemlock perforations currently covered by fill.) RECEIVED S EP 1 91989 Alaska Oil & Gas Cons. L;ommiss~c,, Anchorage NEF/em/BC-4/BC Attachment #2 BC #4 Perforation Procedure 1. RU E-line unit. PT to 2500 psi. 2. P~rforate the ~ower G-Zone using 2-1/2" hollow carrier guns, 4 SPF, 0 phasing, 30v offset, with well flowing at a reduced stabilized rate. Run Interval Footage 15,185 - 15,210 15,155 - 15,175 15,132 - 15,146 15,108 - 15,128 15,070 - 15,100 15,040 - 15,070 25 20 14 20 30 30 3. RD E-line unit. 4. Return well to full production over 24 hours. Maximum gas lift rate = 1200 MCFPD. NOTE: Maximum anticipated SBHP is 3000 psi. ~docs~afe\28.doc RECI IVED 1 g 1989 Alaska Oil & Gas Cons. l;ommissi<:,,.~ Armhorage Attachment #3 ( BEAVER CREEK Wireline Lubricator w/Associated BOPE Manually Operated BOP Grease Head (Hydralically Activated) -- Lubricator ,, Tree Cap Swab Valve Master Valves 3-1/2" 5000 psi Christmas Tree Seal Flange Marathon Oil Company Alask~i lion Domes,,. Production 0 R i 6 i N A L ',/~) P.O. BOX 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 September 7, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: Attached for your approval is an "Application for Sundry Approvals" with appropriate attachments for Beaver Creek Well #4. Should you have any questions regarding any application or report, please contact me at (907) 561-5311. Sincerely, / ~D, K. Corlett '---District Operations Engineer Attachment em\docs\m1\6 A subsidiary of USX Corporation RECEIVED SEP o 8 t989 Alaska Oil & Gas Cons. Commisslort Anchorage i STATE OF ALASKA [ ALASKA OIL AND GAS CONSERVATION COMMIfSSION APPLICATION FOR SUNDRY APPROVALS 0 Ri GIN AL 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing __ Variance __ Perforate __ Other X 2. Name of Operator Marathon Oil Company 3. Address P. 0. Box 190168 Anchorage, AK I 5. Type of Well: Development Exploratory Stratigraphic 995 9 Service ~ 4. Location of well at surface 1,700' FSL, 660' At top of productive interval FWL, Sec. 33-7N-lOW-SM 1,467' FSL 711' FEL Sec. 34-7N-lOW-SM At effective depth 1,492' FSL, 768' FEL, Sec. 34-7N-lOW-SM At total depth ll553' FSL~ 900' FEL~ Sec. 34-7N-lOW-SM 12. Present well condition summary Total depth: measured 15,921 ' feet true vertical 15,715 ' feet Effective depth: measured 15,529 ' feet true vertical 15,290' feet Casing Length Structural Conductor Sudace Intermediate 2,989' Production 12,521' Liner 3,704' Perforation depth: measured 6. Datum elevation (DF or KB) 19' KB above 6L 7, Unit or ~opert,y n,a,m¢, Beaver LreeK unl~ 8. Well number DC-4 9. Permit number 10. APl number 50133-20239-01 11. Field/Pool Beaver Creek Field Size feet Plugs (measured) Junk (measured) Cemented RECEIVED S EP o 8 ]989 Mea~~l~ Gas Cons,~~ll~epth Anchorage 13 3/8" 2,000 sx 2,989' 2,890' 9 5/8" 2,868 sx 12,521' 12,445' 7" 1,400 sx 15,921' 15,715' true vertical See Attachment #1 Tubing (size, grade, and measured depth) 3 1/2" 9.3# L-80 EUE, AB Mod Tubing @ 14,482' MD Packers and SSSV (type and measured depth) Ot i s XXO Profile for SSSV (2.813" ID) @ 250' MD Baker FAB-1 pkr (4.00" ID) @ 14,484', Baker FA-1 pkr (4.00" ID) La 14~813' MD 13. Attachments 2 & 3 Description summary of proposal ~ Detailed operations program __ BOP sketch ~ 14. Estimated date for commencing operati on 9/7/89 16. If proposal was verbally approved R. A. Doug'lass 9/6/89 Name of approver Date approved 15. Status of well classification as: Oil ~ Gas m Suspended Service 17. I here~e~ify that t~e foregoing is true and correct to the best of my knowledge. S igne~t.=~..~~/~-~ ~K'~¢~ Title District Operations Engineer /~/' ' - -// FOR COMMISSION USE ONLY Co¢/ons of approval: Notify Commission so representative may witness Plug integrity __ BOP Test m Location clearance ~ ,: ,; Mechanical Integrity Test __ Subsequent form required 10- ¢/.-~ "t'- ORIGINAL SIGNED BY LONNIE C. SMITH Approved by order of the Commission Commissioner Date ?/~/¢~ J Approval No. 9- 2a// &pproved Copy Returned Form 10-403 Rev 06/15188 SUBMIT IN TRIPLICATE Attachment #1 Beaver Creek Well BC-4 Perforations Lower "G" Zone Hemlock 15,040' - 15,100' MD 15,108' - 15,128' MD 15,132' - 15,146' MD 15,155' - 15,175' MD 15,185' - 15,210' MD 15,361' - 15,376' MD 15,382' - 15,397' MD 15,416' - 15,431' MD 15,446' - 15,461' MD 14,840' - 14,900' TVD 14,907' - 14,926' TVD 14,928' - 14,944' TVD 14,950' - 14,972' TVD 14,981' - 15,006' TVD 15,152' - 15,166' TVD 15,172' - 15,187' TVD 15,205' - 15,219' TVD 15,234' - 15,249' TVD (Note: Hemlock zone perforated in 1972 for DST. Hemlock perforations currently covered by fill.) REC'EiVED SEP o 8 ]989 Alaska Oil & Gas Cons. Commission Anchorage NEF/em/BC-4/BC Attachment #2 ~i Beaver Creek Well #4 Asphaltene Cleanout and Xylene Squeeze Procedure 1. Obtain fluid samle for analysis. 2. RU I 1/4" coiled tubing and pump truck to BC-4RD. PT equipment to 4500 psi. 3. RU Hydroblaster wash tool on coiled tubing. RIH w/ CT with well on gas lift to 15,200' CTM. CHECK PICK-UP WEIGHT EVERY 500' NEAR TD. 4. Hydroblast casing with xylene at as high a pump rate as possible. Wash while moving CT uphole slowly to 15,000' CTM. Repeat until xylene volume of 2000 gals. is depleted. Pull uphole with CT to 12,000'. 5. Shut off gas lift and allow well to die. 6. RIH with CT to 15,200' CTM. Fill tubing with lease crude (60 bbls.) 7. Squeeze 1000 gals. xylene into formation while moving CT up and down perf. interval. MONITOR CASING PRESSURE. MAXIMUM TUBING PRESSURE = 3000PSI. 8. POH w/CT, displace coil w/lease crude. 9. Allow xylene to soak for 12 hours. 10. Bring well on production and test. 11. Obtain second fluid sample after unloading for 12 hours. NOTE: Maximum anticipated SBHP is 3000 psi. Attachment #3 BEAVER CREEK Coiled Tubing Lubricator w/Associated BOPE Double BOP w/1 1/4' Rams 5000 psi WP Hydraulic Rams ~,~~- Tree Cai) Swab Valve / 2' Wing Valve Master Valves 4 1/2' 5000 Christmas Tree Seal Flange Marathon Oil Company Alaska'~, . ~jion Domestic Production P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 January 9, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed is the AOGCC "Report of Sundry Well Operations" with attachments for Beaver Creek Well #4. Should you have any questions regarding the report, please contact me at (907) 561-5311. Sincerely, D. K. Corlett District Operations Engineer At t a chmen t DKC/em/6/mi A subsidiary of USX Corporation .... STATE OF ALASKA "~. AL~,.,XA OIL AND GAS CONSERVATION COMMI ,..ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Pull tubing __ Alter casing __ Repair well __ 2. Name of Operator Marathon Oil Company 3. Address P. O. Box 190168 Anchorage, AK Perforate Pull tubing __ Other I 5. Type of Well: ~ Development ~ Exploratory ! Stratigraphic 9 ~ 519 Service / 6. Datum elevation (DF or KB) 19' KB above GL Unit or Property name Beaver Creek Unit 4. Location of well at surface 1,700' FSL, 660' FWL, Sec. At top of productive interval 1,467' FSL, 711' FEL, Sec. At effective depth 1,492' FSL, 768' FEL, Sec. At total depth 1,553' FSL, 900' FEL, Sec. 12. Present well condition summary Total depth: measured true vertical 15,921' 15,715' Effective depth: measured 15,529 ' true vertical 15,290 ' Casing Length Structural Conductor Surface Intermediate 2,989 ' Production 12,521 ' Liner 3,704' Perforation depth: measured 33-7N-10W-SM 34-7N-10W-SM 34-7N-10W-SM 34-7N-lOW-SM feet Plugs (measured) feet 8. ~/j~ll r~umber 9. Permitnumber/approvalnumber 8-938 10. APInumber 50--133-20239-01 11. Field/Pool Beaver Creek Field feet Junk (measured) feet Size Cemented Measur~'~et~th: ~' True vertical depth 13 3/8" 2,000 Sx 2,989' 2,890' 9 5/8" 2,868 sx 12,521' 12,445' 7" 1,400 sx 15,921' 15,715' true vertical See Attachment feet Tubing (size, grade, and measured depth) 3 1/2" 9.3¢f L-80 EUE, AB Mod Tubing @ 14,482' MD Packers and SSSV (type and measured depth) Otis XXO Profile for SSSV (2.813" ID) @ 250' MD Baker YAB-1 pkr (4.00" ID) @ 14,484', Baker FA-1 pkr (4.00" ID) @ 14,813' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 10/19/88 444 81 23 820 60 Subsequent to operation 12/24/88 535 147 8 720 ' ! 15. Attachments ~2 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations ~ Oil ~ Gas __ Suspended __ 17. I hereby certify thai ihe foregoing is true and 'Correct to the best of my knowledge, ' Signed /~/~/f~'"7/--~ ~ TitleDistrict Service Operations Engineer 5O Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Attachment #1 Beaver Creek Well BC-4 Perforations Lower "G" Zone Hemlock 15,040' - 15,100' MD 15,108' - 15,128' MD 15,132' - 15,146' MD 15,155' - 15,175' MD 15,185' - 15,210' MD 15,361' - 15,376' MD 15,382' - 15,397' MD 15,416' - 15,431' MD 15,446' - 15,461' MD 14,840' - 14,900' TVD 14,907' - 14,926' TVD 14,928' - 14,944' TVD 14,950' - 14,972' TVD 14,981' - 15,006' TVD 15,152' - 15,166' TVD 15,172' - 15,187' TVD 15,205' - 15,219' TVD 15,234' - 15,249' TVD (Note: Hemlock zone perforated in 1972 for DST. Hemlock perforations currently covered by fill.) NEF/em/27A/BC Attachment #2 Beaver Creek Well #4 Daily Well Operations Report 12/8/88 RU wireline, PT lubricator, OK. RIH w/ 2.754" gauge ring and tag bottom @ 15,357" WLM. POOH. 12/lO/88 RU wireline and PT lubricator, OK. RIH w/ 2.25" bailer and tag bottom @ 15,360' WLM. Retrieve bailer full of sand and asphaltine. RD wireline. RU E-line and PT lubricator to 2500 psig, OK. Made two perforating runs using 2.5", 4 SPF, 180° phase Deep Penetrator Carrier guns oriented 90° from lowside. RIH, correlated and perforated @ 15,185' - 15,210' and 15,155' - 15, 175' IEL. POOH, SD for rest. 12/11188 Resume perforating. Made four perforating runs using same guns as before. RIH, correlated and perforated @ 15,132' - 15,146'; 15,108' - 15, 128'; 15,070' - 15,100'; 15,040' - 15,070' IEL. Tagged fill on last perforating run @ 15,352' IEL. POOH, RD. Marathon Oil Company Alaska ~ ..~gion Domestic Production P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 December 7, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: Attached for your approval is an "Application for Sundry Approval" for reperforating Beaver Creek Well BC #4. Should you have any questions regarding any application or report, please contact me at (907) 561-5311. Sincerely, D. K. Corlett District Operations Engineer Attachment DKC/em/6/M1 A subsidiary of USX Corporation '""~ STATE CFA LAS KA "[ AL ~KA OIL AND GAS CONSERVATION COMMI ,.,..ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing ~ Repair well ~ Change approved program __ Pull tubing __ Variance __ I 5. Type of Well: Marathon Oil Company Development x Exploratory __ Stratigraphic __ 9 519 Service__ Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Perforate x Other 2. Name of Operator 3. Address P. O. Box 190168 Anchorage, AK 4. Location of well at surface 1,700' FSL, 660' FWL, Sec. 33-7N-10W-SM At top of productive interval 1,467' FSL, 711' FEL, Sec. 34-7N-10W-SM At effective depth 1,492' FSL, 768' FEL, Sec. 34-TN-10W-SM At total depth 1,553' FSL, 900' FEL, Sec. 34-7N-10W-SM 6. Datum elevation (DF or KB) 19' KB above GL 7. Unit or Property name Beaver Creek Unit 8.BV~ell~umber 9. Permit number 72-13 10. APl number 50--133-20239-01 11. Field/Pool Beaver Creek Field feet 12. Present well condition summary Total depth' measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate 2,989 ' Production 12,521 ' Liner 3,704' Perforation depth: measured 15,921 ' feet 15,715 ' feet 15,529' feet 15,290 ' feet Size 13 9 Plugs (measured) Junk (measured) Cemented Measured depth 3/8" 2,000 sx 2,989' 5/8" 2,868 sx 12,521' 7" 1,400 sx 15,921' 2,890' 12,445' 15,715' true vertical Tubing (size, grade, and measured depth) See Attachment #1 3 1/2" 9.3¢~ L-80 EUE, AB Mod Tubing @ 14,482' MD Packers and SSSV (type and measured depth) Otis XXO Profile for SSSV (2.813" ID) @ 250' MD Bm~.c_r FAB-.1 nkr (4,00" ID] ¢. 14~484', Baker FA-1 pkr (4.00" ID) @ 14~813' MD 13. Attachments 2 & 3 DeSCriptio'n summary of proposal ~ Detailed operations program __ BOP sketch ~ 14. Estimated date for commencing operation t 15. Status of well classification as: December 1988 16. If proposal was verbally approved Oil ~ Name of approver Date approved Service 17. I hereby _certify that the foregoing is true and correct to the best of my knowledge. Signed c/'t Title District Operations Engineer FOR COMMISSION USE ONLY Gas __ Suspended __ Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ORIGINAl. SIGNED BY Approved byorderoftheCommissioner LONNIE C, SMITH '77:' '~."/¢.,iw o r eyed CoPY Returned ~. Commissioner lApprOval NO. Date FOrm 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment #1 Beaver Creek Well BC-4 Perforations Lower "G" Zone Hemlock 15,040' - 15,100' MD 15,108' - 15,128' MD 15,132' - 15,146' MD 15,155' - 15,175' MD 15,185' - 15,210' MD 15,361' - 15,376' MD 15,382' - 15,397' MD 15,416' - 15,431' MD 15,446' - 15,461' MD 14,840' - 14,900' TVD 14,907' - 14,926' TVD 14,928' - 14,944' TVD 14,950' - 14,972' TVD 14,981' - 15,006' TVD 15,152' - 15,166' TYD 15,172' - 15,187' TVD 15,205' - 15,219' TVD 15,234' - 15,249' TVD (Note: Hemlock zone perforated in 1972 for DST) NEF/em/27A/BC Attachment #2 Well Beaver Creek #4 Procedure 1. RU Electric line. PT to 2500 psi. 2. Perforate the following Lower G-Zone intervals underbalanced w/ 2.5" carrier gun, 4 SPF, 180° phasing. Run Interval DIL Footage 1 15,185' - 15,210' 25 2 15,155' - 15,175' 20 3 15,132' - 15,146' 14 4 15,108' - 15,128' 20 5 15,070' - 15,100' 30 6 15,040' - 15,070' 30 3. RD E-line. Note: Maximum anticipated SBHP is 3100 psi. Attachment #3 BEAVER CREEK Wireline Lubricator w/Associated BOPE Grease Head (Hydralically Activated) -- Lubricator Manually Operated BOP .. Tree Cap Swab Valve 2' Wing Valve 3 1/2' 5ooo psi Christmas Tree Master Valve8 Seal Flange Marathon Oil Company Alaska~t, ..-..lion . . Domestic Production P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 November 15, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed is the AOGCC "Report of Sundry Well Operations" with attachments for Beaver Creek Well BC #4. Also enclosed is the "Well Completion or Recompletion Report and Log" Report for Beaver Creek Well BC #4. The proposed reperforation of the Hemlock producing interval has been delayed due to mechanical problems during the workover. As per our conversation with Mike Minder, November 14, 1988, an addendum to the subsequent notice with the appropriate attachments will be submitted when the reperforation of the Hemlock producing interval has been completed. Should you have any questions regarding the report, please contact me at (907) 561-5311. Sincerely, D. K. Corlett District Operations Engineer Attachment DKC/em/6/ml NOV 2 L ~q?'" · - .t,..,, 5 '.'~ ,~taska Oil & Gas Cons. CommisSio[~ Anchorage A subsidiary of USX Corporation ,, STATE OF ALASKA "~ ALASK,( ,'L AND GAS CONSERVATION d. ,iMISSION 'WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAs [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number '- Marathon Oil Company 72-13 3. Address 8. APl Number P. O. Box 190168, Anchorage, AK 99519 50- Beaver Creek Unit 4. Location of well at surface 9. Unit or Lease Name 1700' FSL, 660' FWL, Sec. 33, 7N-10W-SM 133-20239-01 At Top Producing Interval 10. Well Number 1467' FSL, 711' FEL, Sec. 34, 7N-10W-SM BCU-4 At Total Depth 11. Field and Pool 1553' FSL, 900' FEL, 'Sec. 34, 7N-10W-SM Beaver Creek Field .5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 19' KB above GLI A-028083 "G" Zone & Hemlock 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 115. Water Depth, if offshore 116' No. of Completions 6/12/72 11/26/72 10/12/88 I feetMSL i 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey / 20. Depth where SSSV set I 21. Thickness of Permafrost 15,921-15,715' 15,52.9-15,290' YES[] No~3Pr~file @ 250'feetMD I N/A 22. Type Electric or Other Logs Run None 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 0 288' 26" 965 sx Class G None 13-3/8" 72 & 68# N-80 0 29.89' 17.5~ 2300 sx Class G None 9-5/8" 47/53.5#1q-80/S-95 0 -- 12..25~ 3141 sx Class G: 9-5/8" 47/53.5#' P-110 -- 12521' 7" line:- 29/32# P-110 12217' 15921' 1400 sx Class G None 24. Perforations open to Production (MD+TVD of Top and Bottom and .25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 14482' 14484' & ... 14813' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. See ,Attachment #1: .... DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 14731-14743' 125 s× Class G-Cmt · , , 27. '" PRODUCTION TEST Date First Production ' ..I Method of Operation (Flowing, gas lift, etc.) , 10/18/88 Gas Lift I "Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-DEL CHOKE SIZE GAS-OILRATIO 10/19/88 24 TEST PERIOD J~ 444 . 81 23 ., NA 182 , Flow Tubing Casing Pressure CALCULATED OIL-BB.L ... GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 60 820 2.4-HOUR RATE ]~ 444 8.1 23 34 '"28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None .. ,, , .. · Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS ,,, NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Beluga Fm 5,865' 5,865' Tyonek Fm 8,670' 8,670' Hemlock Fm 15,313' 15,106' W. Foreland 15,874' 15,651' , · 31. LIST OF ATTACHMENTS ........ ,,, '~'2, I hereby certify that the foregoing is true and correct to the best of my knowledge __ Title Engineer Date ,, INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. ! Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 Attachment #1 Beaver Creek Well BC-4 Perforations Lower "G" Zone Hemlock 15,040' - 15,100' MD 15,108' - 15,128' MD 15,132' - 15,146' MD 15,150' - 15,175' MD 15,185' - 15,210' MD 15,361' - 15,376' MD 15,382' - 15,397' MD 15,416' - 15,431' MD 15,446' - 15,461' MD 14,840' - 14,900' TVD 14,907' - 14,926' TVD 14,928' - 14,944' TVD 14,950' - 14,972' TVD 14,981' - 15,006' TVD, 15,152' - 15,166' TVD 15,172' - 15,187' TVD 15,205' - 15,219' TVD 15,234' - 15,249' TVD (Note: Hemlock zone perforated in 1972 for DST) NEF/em/27A/BC STATE OF ALASKA COMMI~" AL{ ,A OIL AND GAS CONSERVATION ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging Pull tubing __ Alter casing __ Repair well __ 2. Name of Operator Marathon Oil Company 3. Address P. O. Box 190168 Anchorage, AK 4. Location of well at surface 1,700' FSL, 660' FWL, Sec. At top of productive interval 1,467' FSL, 711' FEL, Sec. At effective depth 1,492' FSL, 768' FEL, Sec. At total depth 1,553' FSL, 900' FEL, Sec. Perforate __ Pull tubing x__ Other __ J5. Type of Well: Development x__ Exploratory __ 9p 519 StratigraphiCservice --__ 33-TN-10W-SM 34-7N-10W-SM 34-7N-10W-SM 34-7N-10W-SM 6. Datum elevation (DF or KB) 19' KB above GL 7. Unit or Property name Beaver Creek Unit 8. ~1 n~mber feet 9. Permit number/approval number 8-440 10. APl number 50-- 133-20239-01 11. Field/Pool Beaver Creek Field 12. Present well condition summary Total depth: measured feet Plugs (measured) feet 15,921' true vertical 15,715 ' Effective depth: measured 15,529 ' true vertical 15,290 ' Casing Length Structural Conductor Surface Intermediate Production feet Junk (measured) feet Size Cemented RECEIVED NOV 2 t Measured dept~$k~,;-.. .0il 2,989' 13 3/8" 2,000 sx 2,989' 2,890' 12,521' 9 5/8" 2,868 sx 12,521' 12,445' Liner 3,704' 7" 1,400 sx 15,921' 15,715' Perforation depth: measured true vertical See Attachment #1 Tubing (size, grade, and measured depth) 3 1/2" 9.3# L-80 EUE, AB Mod Tubing @ 14,482' MD PackersandSSSV(typeandmeasureddepth) Otis XXO Profile for SSSV (2.813" ID) @ 250' MD Baker F_&B-1 pkr (4.00" ID) @ 14,484', Baker FA-1 pkr (4.00" ID) @ 14,813' MD 13. Stimulation or cement squeeze summary .. Intervalstr.eated(measured) See Attachment #2 Daily Summary of Operations 14. Treatment description including volumes used and final pressure RepreSentative Daily Average Production or InjeCtion Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 5/29/88 335 47 73 900 8O Subsequent to operation 10/19/88 444 81 23 15. Attachments 2 & 3 J16. Status of well classification as'. Copies of Logs and Surveys run __ ! Daily Report of Well Operations x__ Oil ~ Gas __ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. _Signed 82O Service Title Region Operations Engineer Form 10-404 Rev 06/15/88 6O Date SUBMIT IN DUPLICATE Attachment #1 Beaver Creek Well BC-4 Perforations Lower "G" Zone Hemlock 15,040' - 15,100' MD 15,108' - 15,128' MD 15,132' - 15,146' MD 15,150' - 15,175' MD 15,185' - 15,210' MD 15,361' - 15,376' MD 15,382' - 15,397' MD 15,416' - 15,431' MD 15,446' - 15,461' MD 14,840' - 14,900' TVD 14,907' - 14,926' TVD 14,928' - 14,944' TVD 14,950' - 14,972' TVD 14,981' - 15,006' TVD 15,152' - 15,166' TVD 15,172' - 15,187' TVD 15,205' - 15,219' TVD 15,234' - 15,249' TVD (Note: Hemlock zone perforated in 1972 for DST) NEF/em/27A/BC Attachment #2 Daily Well Operations Report Beaver Creek Unit Well #4 08/01188 RU filter equip & mixing equip. Mix & filter 970 BBL of 10 ppg CaCi? brine. SI lift gas. Mix 36 BBL of gelled 3% KC1 and 50 sx sand. Pump sand slurry & displace w/ 67.5 BBL of 10 ppg CaC12. TP increased from 0 to 3000 psi. RU to fill annulus. Pumped 120 BBL 10 ppg CaC12 into annulus' Pressure up on tbg to 3000 psi w/ no injection rate. DS to allow sand to settle. 8/02/88 Bled csg press to 0 psi. Filled tbg X csg annulus w/ 710 BBL of 10.0 ppg CaC12. Bled CP 750 to 0 psi. Bled TP 845 to 245 psi. Tbg full of CaCi_. CP build to 140 psi. Bled off to 110 psi. RU E-line. Checked. sand fillup ~ 15,003' w/ CCL/perf gun. Attempted to perf top locator jt @ 12,362'-12,369'. Guns misfired. MU new gun, RIH. Perfed tbg @ 12,362'-12,364'. Set DXX plug bean in SSSV nipple @ 278'. Set BPV in tbg hanger. ! · 8/03/88 Fin mixing 10 ppg CaCI^ brine. Circ 1000 BBL. Monitor well. Tbg had slight trickle. Circ 430 BBL~ 10 ppg'brine bullhead 3 BBL down tbg. Press increased to 2000 psi. Circ. SD well flow increasing. SI well. TP increased to 650 psi. CP increased to 640 psi. 8/04/88 Moved in & RU Roll'n Rig #5. Pulled BPV. RU slickline & pulled DXX plug @ 278' TP=580 psi. Fin filling pits & mixing 10 ppg CaC12. 8/05/88 Continued monitoring pressure. Final pressures TP = 790 psi CP = 680 psi. Bled pressure off. Pressure dropped to zero immediately. Monitored well. Tbg flowed 2" stream (1 bph). Weighted CaCl2 up to 10.5 ppg and circulated hole volume plus 20% (1,035 bbl). Monitored well. Well dead. Set DXX plug bean in SSSV profile at 278'. Set BPV. ND tree. NU BOPE. 8/06/88 Annular to !,500 psi. Ail tests witnessed and approved by Joe Russell with BLM. Casing pressure had built to 575 psi. Bled off pressure. No flow for 10 minutes, then built to 1/8" stream. RU Otis and pull DXX plug bean at 278. Reversed out 6 BF. Recovered 4 BO. Pull seals out of packer at 12,377'. Circ 1,400 bbl at 6BPM. S/D pump no flow for 10 minutes then 0.2 bph flow. SI. Daily Well Opera~ ~s Report ii' Beaver Creek Unit~ well #4 Page 2 Monitor pressure. TP = 395 psi and building at 70 psi/hr. CP = 370 and building at 70 psi/hr. Preparing to change over to mud. 8~07~88 Fin cleaning pits. Mix and condition mud. Mix 57 bbl of HEC-XC polymer pill. Pump 90 bbl water and 57 BBL of polymer pill. Pumped 950 BBL of 11.8 ppg mud. SI. TP and CP = 20 psi. Presently mixing and conditioning mud. 8/08/88 Fin displacing hole w/ 11.8 ppg mud. Circ hole volume. SI & monitor well. TP=20 psi. CP=40 psi. Bled press to zero. Well dead. POH to SSSV. NU pitcher nipple. Had safety meeting w/ crew & tool pusher. POH sideways w/ 3-1/2" tbg. 8/09/88 Fin POH sideways. LD GLM's & seal assembly. Installed wear bushing. PU BHA, RIH, PU 3-1/2" DP~ 8110188 I ' RIH w/ pkr retrieving tool. PU DP. C&C mud. PU 3 its of DP, latch into Baker SC-1L pkr @ 12,377'. Pulled on pkr to shift inner sleeve. No indication of movement. Jarred on pkr w/ 46,000# overpull. Released retrieving tool from pkr. Sting back into.pkr. Jarred w/ 76,000# overpull. Released retrieving tool. POH. LD retrieving tool, bumper sub, & jars. MU milling assembly & RIH. 8111188 RIH w/ burnshoe. Mill Baker SC-IL pkr @ 12,377' DPM. Repair ~ig. Cont milling pkr. Milled a total of 18". Mill quit. POH to check mill. 8/12/88 POH w/ mill #1, had marks 8" inside shoe. RIH w/ burn.shoe #2, burn over pkr. Made total 27"-30" in two runs, CBU, POH. 8/13/88 POH, had marks 1.80' inside shoe, RIH w/ spear, attempt to latch fish. POH, no recovery, RIH w/ burn shoe. 8/14/88 RIH w/ burn'shoe #3, mill on pkr @ 12,378'. Repair rotary table. Mill on pkr, pkr fell down hole to 12,381'. POH. ,,, Daily Well Operati ~ Report Beaver Creek Unit Well #4 Page 3 8115188 POH w/ burn shoe #3, test BOPE 250/5000, portion of stack left to test, leaking test plug O-rings, RIH w/ spear, latch fish & POH. Full recovery, left pkr slips in hole, MU OS BHA. 8/16/88 RIH w/ OS, tag TOF @ 12,410'. Work seal out of pkrs, circ out gas & oil cut mud, monitor well. POH w/ OS. 8/17/88 POH w/ OS. LD fish, recovered 67 jts 3-1/2" tbg, 4 jts 2-7/8" tbg & 2 sets seals. Shuck OS. Run test plug. Attempt to test stack. Leaking past test plug. LD test plug. RIH w/ mill & pkr retieving tool. Repair broken chain on drawworks. 8/18/88 RIH. Mill pkr @ 14,483'. CBU. POH. Recovered pkr, left pkr elements & BTM slips on hole. RIH w/ bit & scraper. ~ · 8/19/88 Fin RIH w/ bit & scraper. Tagged fill 6' on top of pkr. POH. PU mill & pkr retrieving tool & started RIH. 8~20~88 Fin RIH w/ pkr retrieving tool. CO junk on top of pkr. Milled on pkr & pkr fell downhole. Circ hole clean. Attempted to latch pkr & POH' Recovered only top 7" of pkr. Changed out pkr retrieving tool & started RIH. 8/21/88 Fin RIH w/ pkr retrieving tool. Started milling on pkr. Made 1' in first 1-1/2 hrs & stopped making progress. Jarred up to free pkr w/o success. Released grapple & started POH. 8/22/88 Fin POH. Found mill 100% worn. PU new mill. RIH w/ pkr retrieving tool. Milled on pkr for one hour & pkr came free. RIH to 14,700' & circ hole clean. Started POH. 8/23/88 Fin POH w/ pkr retrieving tool. Recovered all of pkr except bottom slips. RU wireline. Ran gauge ring & JB to 14,700'. Recovered 1 slip segment & 1 pkr Daily Well OperatI ~ Report Beaver Creek Unit well #4 Page 4 element. Set cmt retainer @ 14,610'. Perf 14~570'-14,574' w/ 4 SPF. Started RIH w/ pkr & tailpipe. 8~24~88 Fin RIH to 14,543'. Set pkr @ 12,652'. Attempted to break down perfs. Could not break down @ 4750 psi. Spotted 10 BBL diesel. Still could not break down perfs @ 4750 psi. Spotted 500 gal mud acid. Still could not break down perfs @ 4750'. Circ out acid. POH. 8/25/88 Fin POH. Laid down 2-7/8" tbg. PU bit & RIH. Started drlg on retainer @ 14,610' WLM. Rotary table failed. 8/26/88 Repaired rotary table. Fin drlg retainer. Circ hole clean. POH. PU new retainer & started RIH. Hydromatic clutch failed. 8/27/88 Repaired hydromatic clutch. Fin RIH w/ retainer. Spotted 7 BBL CaC12 f/ 14,845'-14,575'. PU & set retainer @ 14,693'. Test DP to 5000 psi. Stung out of retainer & spot 15 BBL CaCi_ @ retainer. Stung into retainer & attempted to pump into perfs 14,731'-14,743g @ 5000 psi w/o success. Stung out of retainer & spotted 500 gals mud acid @ retainer. Stung into retainer & pumped into perfs @ 5700 psi. Established injection rate of .8 BPM @ 5100 psi. Stung out of retainer & started reverse circ to remove contaminated mud. 8/28/88 Fin reversing out 365 BBL contaminated mud. Mixed & spotted 125 sx Class "G" w/ additives. Sting into retainer, squeezed U "G" zone perfs to 5700 psi. RO. POH. 8/29/88 POH, set RBP @ 1400'. Test annular to 1700 psi. Test rams & choke manifold to 3000 psi. Retrieve RBP. MU bit & DC's. RIH, break circ @ 10,000' & 12,000'. RIH. 8/30/88 RIH to 1900'. Break circ. Drill EZSV @ 14,723'-12,728'. Drill hard cmt 14,728'-14,745'. Rotated & pushed junk 14,745'-14,932,. Drill hard fill 14,932'-14,948'. Daily Well Opera~ .s Report Beaver Creek Unit well #4 Page 5 8/31/88 Attempt to CO fill @ 14,948'. CBU. Had to work on pump. POH. 9/01/88 Fin POH, MU & RIH w/ bit & scraper to 14,947'. C&C mud. POH. PU dry test assy. 9~2~88 RIH w/ dry test tools. Filled 185 stds w/ 11 ppg mud fOr 9.5 ppg EMW. Set retrievamatic pkr @ 14,645' DPM. Opened MFE valve. IF=5 min. Had 4" blow in bucket. ISI=60 min. FF=30 min. Had slight flow for 5 min then no indication of flow. FSI=30 min. Released pkr, PU to 14,456 & reset pkr to test both sets of squeeze perforations. IF=5 min had 2" blow in bucket. ISI=60 min. Dropped bar to open reversing sub. RO only mud. RO test lines. POH. 9/3/88 Fin POH w/ DP. LD DST tools. Charts indicate perfs are leaking a small amount. ?U 5-7/8" bit, bit sub, 44 stds of DP, 9-5/8" csg scraper. RIH. ! · 9/4/88 RIH w/ 9-5/8" scraper & stinger to 14,947'. Circ long way. Reverse circ hole Volume. Repair drawworks. POH~ Well dead. POH. -MU TSA BHA. RIH. 9/5/88 Fin RIH w/ JB w/ internal junk catcher to 14,952'. Reverse 10 BBL in attempt to fill JB. Mill on junk, 14,952' to 14,957' pushed junk to 14,981'. Repairing mud pump. 9/6/88 Repair pump. Washover & push junk 15,015'-15,018'. Couldn't go deeper. Reversed 25 BBL, POH. JB 100% worn. Recovered 1 cup fine debris (rubber & metal) & slip lost off pkr retrieving tool. MU new JB & RIH. 9/7/88 Fin RIH w/ junk mill assy #2. Washover junk f/ 15,018'-15,023'. No progress last 3 hrs. Reverse circ 25 BBL & POH. Recd half-cup full chunks & rubber pieces. PU bladed junk mill & RIH. 9/8/88 RIH w/ 6" junk mill to 14,742' (upper "G" zone perfs 14,739'-14,751' DPM). Unable to get past perfs. Attempted to rotate past perfs. Had to jar out of perfs. POH. LD 6" junk mill. MU 5-7/8" junk mill. RIH. Daily Well Opera~ ~s Report Beaver Creek Unit' well #4 Page 6 9/09/88 Fin RIH w/ 5-7/8" mill. No trouble at upper "G" zone perfs. Circ. Cleaned mud pits. Milled junk @ 15,023'. Made 5" in 4 hrs then no progress. Spudded lightly to break up junk. Circ. POH. 9/10/88 Fin POH w/ junk mill. LD junk mill. 100% worn. MU new 5-7/8" junk mill & RIH. Mill junk 15,023'-15,026' total of 39" milled. POH. 9/11/88 Fin POH w/ mill. Mill worn 90% on outside, fine on inside. MU new junk mill. RIH. Milled junk @ 15,025' made 8". 9/12/88 POH. LD junk mill. No wear. Several marks on edge of mill. 'Change out jars & bumper sub. MU reverse circ JB. RIH. Drop ball to reverse circ. Milling @ 15,027' w/ more torque than junk mill. ~ 9/13/88 ,' Milled on junk from 15,026'-15,028'. POH w/ reverse circ JB. Shoe slightly worn, no indication of wear inside. No junk in basket. LD boot baskets, baskets filled w/ fine sand. RU wireline w/ collar, locater and dump bailer. Mix two sx cmt to 15.6 ppg and filled bailer. RIH. w/ 5"' OD bailer. Hit restriction @ 14,800'. POH to check tool. 9/14/88 Dump cmt on top of junk after 3 attempts w/ bailer. MU 5-7/8" bit, RIH. WOC 12 hrs, tag @ 15,015' dpm. Water pump on back-up generator broke shaft. Main generator shaft had broken on 9/12/88 & is still in shop. Pull one stand & repairing generator. 9/15/88 Fin rig repairs on back-up generator. RIH tag top of junk @ 15,028'. Very little cmt on top of junk. Drl on junk f/ 15,028' to 15,130'. Penetration rate increased. Drld & pushed junk 15,130'-15,224'. Bit torqued up, hole took 12 BBL fluid. CBU. Preparing to POH. 9/16/88 Cont circ. POH. Had to repair drive line on rig motor. Fin POH. LD bit. PU JB assy. Daily Well Opera~ .s Report Beaver Creek UniC Well #4 Page 7 9117188 RIH w/ JB assy. Tag top of fish @ 15,221'. Mill on junk to 15,241'. Circ viscous pill. POH w/ apparent junk above fishing assy. 9118188 Cont to wash DP out of hole. DP sticking w/ pump off. DP pulled freely when BHA cleared liner top. POH. LD JB. No recovery inside JB. Ail three boot baskets full of debris from retainers & perforating debris. MU new JB & extension & RIH. 9/19/88 RIH w/ JB. Circ TOL @ 12,219'. RIH to 15,240'. Mill & work JB @ 15,240'. Pump press increasing, torque increasing, try to pull off bottom, pipe stuck. Jar & work pipe free. POH. 9~20~88 Fin POH. SerVice rig. LD JB & boot basket, JB empty. No fingers broken out. Recovered approx 3 gal of sand & metal junk in boot baskets. MU boot baskets & bladed mil!. RIH. Wash 15,189'-15,240'. M~ll on junk 15,240'-15,242'. POH. First 2 stands off bottom tight. POH. 9/21/88 Fin POH. Clean boot baskets, recover 5 gal metal junk. Total wt about 150#, center of mill cored out. String new drlg line. MU BHA, RIH. Change generators, continue RIH. 9~22~88 RIH w/ JB. Tag junk @ 15~,242'. Mill over junk f/ 15,242'-15,245'. CBU. POH. BHA. Recovered 100# junk in boot baskets. JB catcher finger broken, no recovery. Ring cut in bottom of shoe. MU JB head #12 w/ rolling dog catchers. BHA. RIH. 9~23~88 RIH w/ rolling dog OS. Rotate. Washover fish. POH. BHA. Recovered kinley cutter in OS. No recovery in boot baskets. MU JB head #13 w/ finger catchers. RIH. 9~24~88 RIH w/ JB. 'Tag @ 15,245'. Drl to 15,262'. Pump press increased f/ 1700 psi to 2300 psi. CBU. POH. BHA. Recovered rope socket w/ OS & drop bar & perf gun strap in JB. Ail boot baskets full of junk, approximately 5 gals. RIH w/ 5-7/8" bladed mill. RIH. Daily Well Operat! ~ Report Beaver Creek Unit~Well #4 Page 8 9/25/88 Mill on junk to 15,269'. CBU. POH. Mill worn. MU JB head. RIH. 9~26/88 RIH w/ 3B head w/ internal junk catchers. Milled 15,269'-15,321'. POH. BHA. Recovered pieces of rope socket & strip guns. ~3 5-3/8" OD bladed mill. RIH. 9/27/88 RIH w/ junk mill 15,321'-15327'. Broke free. RIH to 15,466'. Milled 15,466'-15,529' . CBU. POH. 9/28/88 BHA. KIH w/ bit & scraper to 15,529'. Reverse circ@ 15,523'. POH. 9/29/88 RIH w/ Model FA-1 pkr on DP. Set @ 14,820'. POH. RU & RIH w/ 5" 18# N-80 FL4S scab liner assy. I ' 9/30/88 MU Baker FAB-1 pkr. RIH w/ 5" 18# N-80 FL4S csg. RIH w/ scab assy. Set scab liner w/ top of pkr @ .14,491'. POH. LD setting tool~ Testing BOPs. 10101188 Complete BOP test. PU 2-3/8" tbg stinger. RIH to 15,529'. C&C mud to change over to CaC12. 10102188 C&C mud. Clean pits & suction lines. Displace mud w/ 10.5 ppg CaC12. Filtering CaC12· 10/03/88 Circ & filter CaCl~ water. POH. LD 2-3/8" tbg stinger. MU Baker 3-3/8" OD TCP z assy and retrievamatic pkr. RIH. Fill first 58 stds w/ 10.4 ppg CaC12 for 2000 psi bottom hole preSs. 10104188 Cont RIH. Correlated perf guns w/ CCL/GR. Set retrtevamatic pkr, perf lower G zone f/ 15,040'-15,100'; 15,108'-15,128'; 15,132'-15,146; 15,155'-15,175', 15,185'-15,210' DIL. Had immediate blow on bubble bucket. Decrease to weak blow, blow got stronger, had strong blow w/ hose @ bottom of bucket for last 90 min of flow. Attempt to release pkr. Pkr would not release, unloader would not Daily Well Operat~ j Report Beaver Creek Unit~wel! #4 Page 9 open. Filled DP w/ 58 bbl CaCI_. Press DP to'2000 psi, PU to 265,000# & pkr pulled loose. Reverse circ thr~ choke manifold to rig pit. Getting oil & gas in returns. Presently filtering CaC12 to fill hole. 10105188 Cont filtering CaCi~. Reverse circ to clear DP. POH. Stand back 13 stds. Guns pulled 20,000-~0,000# over thru liner. POH. LD 3-1/2" DP. LD TCP assy. MU 9-5/8" Baker RBP. RIH. 10/06/88 RIH w/ 9-5/8" RBP set @ 1631' DP measurement. POH. ND BOPs. Install TC-60 adapter spool. NU BOP. Close blind rams, press test flange connection, and BOPs to 4500 psi for 15 min - OK. MU RBP retrieving tool. RIH. Tag RBP @ 1631' DP measurement. Set down 10,000#. Pick up, set down second time. RBP would not take weight. Rotate DP to left w/ 36" pipe wrench. Could not reset RBP. PU 4 its DP, RIH. Unable to locate plug. POH. Found DP backed off 4 jts above running retrieving tool. PU OS & oil jars & bumper sub. RIH chasing bridge plug. Presently have 100 its of DP in hole. · 10/07/88 ! · Fin RIH w/ fishing assy to 11,597' DPM. Latch fish. POH. LD BHA. Recovered fish. RU E-line. RIH w/ 5.75" GR & JB to top of 5" liner @ 14,520' WLM. POH. lO/8/88 Fin POH w/ 5.75" gage ring empty. MU 3.992" gage ring & JB. RIH. Could not work gage ring & JB past 14,500' WLM. POH. JB empty. RU braided line unit. RIH w/ 2 prong grab. Set down @ 14,500' WLM. Work tool string, could not get deeper. POH. MU melon centralizer on bottom of fishing tool ~tring. RIH set down @ 14,500' WLM. Jar down to clear TOL. Jarred tool string & moved rubber down hole. Ran tool string, 50' below bottom of scab liner @ 14,820'. Did not see any sign of rubber. POH. RD Otis unit. MU seal assy on DP. RIH to test pkr. 10/9/88 RIH w/ Baker seal assy on DP. Sting into pkr @ 14,491'. Set down 15,000# on pkr. Press tested backside to 1400 psi for 15 min, OK. PU 10' above pkr. Reverse hole clean. POH. LD 3-1/2" DP. Presently LD BHA. 10/10/88 Fin LD BHA. PU PBR seal assy, locator, K type latching anchor. Press test to 2500 psi. Held safety meeting. Run 3-1/2" 9.3# L-80 tbg w/ 8 rd EUE AB modified couplings & gas lift mandrels. Gator hawk all connections to 5000 psi. Presently have 220 its in hole. Daily Well Operati ~ Report Beaver Creek Unit~'well #4 Page 10 10/11/88 Cont RIH w/ 3-1/2" completion string. CBU. Space out, MU tbg hanger & pup its. Ldg 3-1/2" tbg. 10/12/88 Stab seals into PBR, land tbg in neutral w/ locator landed on PBR. Fin landing tbg. Set XRXX plug bean in SSSV landing nipple. Set back press valve. ND BOP equip. NU tree. Test hanger to 5000 psi, OK. Press test tree to 5000 psi, OK. Release rig from BC #4 @ 2359 hrs 10/12/88 for move to BC #3. FINAL REPORT. em/27A/BC ! ' Spud Date: G/18/72 Original RKB: 19' above GL Top o? 'G' Zone, 14,731' MTI Top o? Hemlock; 15,313' MD Annulus Fluid: 10.3 ppg CaCl~ All depths are RK]3 M~ to top o~ equipment 5 6 7 8 N 10 Attachment #3 MARATHON OIL COMPANY ]~EAVER CREEK UNIT APl ~: 50-133-80839-01 Completion Bate, 10/10/88 Maximum Hole Angle, 18 8 13,780' MD Angle Through 'O': 14 Angle Through Hem: 14 ReFerence Log: OIL 9/11 & 11/83/72 Well Type: 01l Producer New [] ~orkover [] Recomplet;on [] JEWELRY 1, FMC TC-1A-EN Tb9, Hgr. 2. Dtls XXD pro?Re ?or SSSV (8.813' ID), 3-1/2' 9.3¢ L-80, 8RD EUE, AB Mod Th§. 4. Otis X Nipple (2,813' ID). 5. 3-1/2' Baker sent assembly-B040 PBR (17.91' length). 6. 3-1/8' hal?cut Muleshoe. 7. Baker PBR (4.00' ID) w/concentric coupling (4.00' ID) and Baker SBE (18.74' length). 8. Baker FAB-1 pkr, size 83FA47 (4.00' ID). 9. 5' Isolation liner assembly (See Tubing Cas~n9 DetaR). 10. Baker FA-1 pkr, size 83FA47 (4.00" ID). GAS LIFT DATA Depth Size Mandrel ID Valve Type 2737' 3.5' Flopetrol gPM-2 2.867' 1.5' GLV 1.5 OR 4747 ..... 6138 ..... 7800 8079 8862 .... 9586 10,815 ..... 10,837 11,463 12,085' ' Flopetrol SPM-2 ' 1.5' GLV 1.5 DR 18,708 " N/A N/A 1' DUMMy Valve 13,206' " BST 2.867; ' 1' BLV l,O DR 13,730' 14,259' ' BET 2.867' 1' Orl?~ce CASING & TUBING 16' 250' 14,482' 14,428' 14,464' 14,482' 14,464' 14,484' [4,484' 14,813' Latch Port [6/64 · · · · · 16/64 20/64 RK 20/64 OK-2 N/A · 3/8 OK-8 3/8 Size. %/eight' Grode Top Bottom Descrimt` 20' 94 H-40 0 288' ST&C csg 13-3/8' 78 N-BO 0 1942' 8RD csg ~ 68 J-55 1942' 8989' ' 9-5/8' 47 N-80 0 7481' Butt. csg · 47 S-95 7421' 9938' ' ' 53,5 P-IlO 9938' 12,521' ' 7' 29 P-il0 12,817' 12,552' "'"' ' 32 P-Il0 12,558' 15,921' ' 5' 18 N-80 14,487' 14,813' I~ola'tlon Liner· 3-1/2' 9.3 L-BO 0 14,488' 8RD AB Mod Tb9 NOTE, KB to top oF 80' cs9 = 84'. PERFORATION DATA Interval Zone FT SPF Dote Gun Type~ 14,435'-565' Upper 'G' 30' 4 D'73 Squeezed 14,731'-743' 18' 4 8/28/88 Squeezed 15,040'-180' Lower 'G' 60' 4 10/5/88 TCP 15,108'-1P8' ' 20 .... 15,138'-146' ' 14' ' ' · 15,155'-175' ' 20 .... 15,185'-210' · 25' ' 1/24/88 E-Jet II 15,361'-376' Hemlock 15' 4 18/18/72 Jumbo Jet 15,382'-397' 15 15,416'-431' DST 15 .... 15,446'-461' Per?oral;Ions 15 .... NOT~ PBTD = 15,589' TD = 15,921' Hemlock per?orations were Isolated a?ter DST by ~ cml retainer but were never CMl. squeezed. Reservoir Dotum~ 14,800' Sub Sea Revision Date: 10/87/88 Revised By: NEF Reason. ~orkover Previous Revision: 8/24/87 Marathon Oil Company Alaska ~] ~ Domestic ~-. oduction P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 June 1, 1988 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached for your approval is an "Application for Sundry Approvals" for proposed work on Beaver Creek Well #4. Should you have any questions regarding any application or report, please contact me at (907) 561-5311. Sincerely, D. K. Corlett District Operations Engineer Attachments NEF/DKC/dw/766/OE31 'RECEIVED JUN 0 Y~ 1988 ~ 0il & Gas ~ns. Commissio~'~ A~ch0rage A subsidiary of USX Corporation · OIL AND GAS CONSERVATION COM ,,oc~lON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing ~ Amend order [] Perforate ~ Other:~ 2. Name of Operator 5. Marathon Oil Company 3. Address 6. P. O. Box 190168 Anchorage, AK 99519 4. Location of well at surface 7. 1,700' FSL, 660' FWL, Sec. 33-7N-10W-SM At top 6f productive interval 1,467' FSL 711' FEL, Sec. 34-7N-10W-SM At effective depth ' 1,492' FSL, 768' FEL, Sec. 34-7N-10W-SM At total depth 1,553' FSL, 900' FEL, Sec. 34-7N-10W-SM Datum elevation (DF or KB) 19' KB above GL Unit or Property name Beaver Creek Unit Well number BC ¢/4 8. Permit number 72-13 9. APl number 50-- 133-20239-01 10. Pool Beaver Creek 0il Pool feet 11. Present well condition summary Total depth' measured 15,921' feet true vertical 15,715 ' feet Effective depth: measured 15,315' feet true vertical feet 15,107' Length Casing Structural Conductor Surface Intermediate Production Liner Plugs (measured) Junk(measured) Size Cemented 15,315' - 15,921' CMT 15,210' Sand line:cutter Drop bar, rope sockett and overshot Measured depth ~ue Verticaldepth 2,989' 13 3/8" 2,000 sx 2,989' 2,890' 12,521' 9 5/8" 2,868 sx 12,521' 12,445' 3,704' 7" 1,400 sx 15,921' 15,717' Perforation depth: measured true vertical See Attachment #1 Tubing (size, grade and measured depth) 3 1/2" 9.3# N-80 EUE and Buttress Tubing @ 14,498' MD 2 7/8" N-80 EUE Tublng @ 14,498' to 14,644' Packers and SSSV (type and measured depth) SSSV Profile (Otis w/2.81" ID 'x' profile) @ 278' MD 7" Sealbore Packers ¢ 12;376'; 14, AR?' , and 14,615' 12.Attachments 3 & 4 Description summary of proposal 13. Estimated date for commencing operation 3une 1988 14. If proposal was verbally approved Detailed operations program II % t=1,,, a.=. n u h,M, BOP sketch ~3 Attachment # ,5 J U N 0 5 z:oo Subsequent Work Reported on Name of approver Form No.~Dated-/-/-/~~~ 0~J & 6as C011s. C0111[lii$$[~'D, · ' a.,~,,,,~ Date approved 15. I hereby~ertify that the foregoing is true and correct to the best of my knowledge Commission Use Only Date ~"/$ t Conditions of approval Approved by Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test AE~pl~Cc~l~trancel f ¢~7/~ Returned Commissioner Form 10-403 Rev 12-1-85 ORIGINAL SIGNED BY LONNIE O. SMITH by order of ,~the commission Date ~'W ~,,.-- ~/ Attachment #1 Beaver Creek Well BC-4 Perforations Upper "g" Zone 14,731' - 14,743' MD 14,542' - 14,553' TVD Lower "G" Zone 15,040' - 15,100' MD 15,108' - 15,128' MD 15,132' - 15,146' MD 15,155' - 15,175' MD 15,185' - 15,210' MD 14,840' - 14,900' TVD 14,907' - 14,926' TVD 14,928' - 14,944' TVD 14,952' - 14,972' TVD 14,981' - 15,006' TVD ATTACHMENT #2 BEAVER CREEK WELL NO. 4 DESCRIPTION OF PROPOSAL Marathon Oil Company, as Beaver Creek Unit Operator proposes to perform a workover on Beaver Creek Well No. 4 as described below. The proposed workover involves cement squeezing a portion of the existing perforations to eliminate communication with a damaging fresh water interval, reperforating the existing intervals, and perforating new pay to be produced in a single completion with the existing intervals. Beaver Creek No. 4 currently produces from selected intervals in the G-Zone of the currently undefined Beaver Creek Oil Pool. The purpose of this workover is to eliminate suspected communication between the existing intervals and a fresh water sand located approximately 166 feet above the top G-Zone perforations. During the workover, selected intervals in the Hemlock zone of the Beaver Creek Oil Pool will also be perforated. The G-Zone and Hemlock intervals of the undefined Beaver Creek Oil Pool will be produced through a single completion. During and immediately following this workover and recompletion, a reservoir evaluation program will be conducted. The program will likely involve isolation and testing of the Hemlock perforations to adequately evaluate the potential and relative contribution of the zones; extensive testing of combined G-Zone and Hemlock interval production; production logging surveys; and other reasonable well testing as deemed appropriate by the Operator. Concurrent with the workover and reservoir evaluation period, the appropriate action will be taken by the Operator to establish the definition of and the pool rules for the G-Zone/Hemlock Oil Pool of the Beaver Creek Field. A detailed workover procedure with wellbo~e diagrams are provided as Attachments No. 3 and 4. dw/762/OE31 Attachment #3 Beaver Creek #4 Workover Procedure . Shut off lift gas and allow well to die. Fill tubing and casing with filtered KC1 water. MI RU workover rig. Set BPV. ND tree and NU BOPE. Test BOPE to 3000 psi. 0 POH w/tubing. Retrieve SC-iL packer and overshot assembly. Fish tubing and seal assemblies and packers at 14,462' and 14,615'. Scrape 7" liner to 15,210' (approximate top of junk). 0 Set drillable BP at 14,760'. Perforate bottom of fresh water sand from 14,570' to 14,575'. . RIH w/retrievable cementer and 14 joints 2-7/8" tubing tail. Break down perfs w/KC1 water. Lay balanced cement plug from 14,760' to 14,450'. ?U 7 stands (14 joints), set packer, and squeeze. 5. Cleanout and pressure test squeeze. Drill out BP at 14,760'. 6. Cleanout to 15,520'. . RIH w/TCP/DST system and correlate and perforate select Hemlock intervals between 15,290' and 15,470'. Perform DST. Circulate to kill well and POH w/TCP/DST system. Set isolation packer w/plut at ±15'250'. 8. Set retrievable 7" x 4" SB packer above lower G-Zone. . RIH w/TCP/jet pump system and correlate to perforate select lower G-Zone intervals between 15,040' and 15,210'. Stab into SB packer and set mechanical packer above squeezed perforations. Perforate with 1000 psi underbalance. (Lower G-Zone reservoir pressure is 3000 psi.) 10. Jet pump test lower G-Zone and perform PBU. 11. Pull TCP/jet pump assembly and set plug in SB packer. 12. RIH w/TCP assembly. Correlate and perforate upper G-Zone from 14,731' to 14,743' DIL. Test upper G-Zone. Kill well and POOH w/TCP assembly. Note: If fresh water is still being produced from upper G-Zone, place sand plug on top of SB packer and perform cement squeeze on upper G-Zone perfs. If interval produces dry oil, continue with next step. 13. Retrieve plugs from packers above lower G-Zone and Hemlock. 14. RIH with seal assembly/packer to isolate upper G-Zone. Stab into packer at 14,760' and set packer at 14,640'. POH. Attachment #3-2 Beaver Creek Well #4 Workover Procedure (Continued) 15. RIH with seal assembly/packer to isolate squeeze perfs. Stab into packer at ±14,640' and set top packer at 14,500'. POH LD DP. Note: If upper G-Zone is abandoned, eliminate middle packer and sliding sleeve. 16. RIH w/completion string. Space out and land tubing. Set BPV. ND BOPE. NU tree. Release rig. Return well to production. dw/725/OE31 7", 32#, P-Il0 7' X &. Otis Perma-' drill 7" X 3-1/4" Otis Perma- (14,645') Top of Junk {,, 1,5;210' Sandline Cut~ Drop bar shot and socket of 2-1/8" SilverJets AFE 8122-8 Beaver Creek Well Beever Creek Uell $& ~urreot Completion Assembly Z9~9' 13-315", 68 S 721 lt,.,BO & Al.t~ ate 3.5" x 1.5" Side ?ockec (Johnston H acco S~H 2) 'zBgg' ~ ti &?lB' 12 609?' 7292' 8297' 9114' 16 9740' 10,336' 10,954' 11,580' ilo 12,175' ill 12,$21' 9-$/8", &?l, H-SO & $-95, 531 P-II0 12,37&* Baker Tog. Locacor 12,375' co Baker Seal Assembly (G-22 Size 12,~75*Baktr SC-IL Packer, ~,, 321 x ~.0" SB 12,39~'v/l/2 ~le Shoe 12,380*~ker tO* SBE, t.0~ ID (Siz~ 12,390'Baker ~ncencric Coupliu$ 12,391*Baker I0' SBE, ~.0" ID (Size 8~0) 12,4~0'~ver, SBE Box x 3-1/2" 8rd ~ 12,~01'~m~shoc t Pac~fi ~s~ly Equi~en~.L~fC from Original Completion 12,~0~* Stub Joint v/ch~lcal cuc ~de 18 12,~23* 3-1/2' ~.31 Butt, Ii,iii* Otis 2.75" ID ~ sleeve 1~,~45' I JO. 3-1/2" 9.3~ Butt. 14~7~'Otis 2.7}' ID 'X*' 1~,476* Otis ~cacor Sub 1~,t78* Otis S~I Unic 4,0' OD x 3.0" ID 11,49~' X~er 3-1/2", RU 10~d Box x 1~,498* ~ JO. 2-7/8", 6.5~ 8rd ~E ~8. 14,623' X~er 2-7/8", 8cd Box x Z-l/2' ~ lOr~ 14,644' ~le Shoe Cu/de Fresh Water Zone .14,535~ - 65* (Squeezed) 14,711' - l&,?&3' }iD Lo.er "~ ZOne 15,040' - 15,100' HI) 15,132' - l&,l&$' 15,155' * 15,175' 15,315' PBTD (Baker "N" BP) NEF 11/3/87 tS,git' TI) Sliding Sleeve Blast Joi] AFE 8122-8 Beaver Creek ~ell ~4 Proposed Completion Assembly 3-1/2", 9.3#, 8rd EUE AB Hodified Tubing 15,500' 7" x 4" SB Packer Fresh Water Zone 14,535' - 65' Resqueezed 14,570' - 75' Perf and Squeeze 14,640' 7" x 4" SB Packer Upper G-Zone: Squeeze apd Reperforate 14,731' - 743' 14,760' 7" ~ i" SB Packer Lower C-Zone: Intervals Proposed for Perforations 15,040' - 100'~ 15,108' - 128' 15,132' - 146', 15,155' - 175' 15,185' - 210' 15,250' 7" x 4" SB Packer Hemlock: Proposed. C~mpletion Intervals 15,290' - 296', 15,318' - 322' 15,360' - 378', 15,384' - 405' 15,418' - 438', 15,4~4' - 458'- 15,520' PBTD Attachment ¥/5 'i,' ._ARATHON OIL COMPJ~.. ~ BEAVER CREEK WELL NO. 4' 13-5/8' 5000 psi BOP Assembly _1 Mud Pan Drilling Nipple Rotating Head 0 0 0 Clamp Connector 13 5/8' x 5000~ .,Annular Preventer (Hyd'rll), · ... 0 0 0 Clamp Connector 3' x 5000~ Kill 'Lin (Pipe Rams) 13 3/8' Double-Gate-ClW 3' x 5000~ 'Choke Line (Blind Rams) 0 0 1.2' x 300'Oe Casing Head w/Flanged Outlets & Valves Marathon Oil Company Alaska i" Domesti~., ,roduction P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 March 3, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: Attached is the AOGCC Report of Sundry Well Operations and Daily Well Operations Report for Beaver Creek Well BC #4. Should you have any questions regarding the report, please contact me at (907) 561-5311. Sincerely, D. K. Corlett District Operations Engineer Attachment DKC/em/6/ml A subsidiary of USX Corporation STATE OF ALASKA '~' ALAS~.'~ . OIL AND GAS CONSERVATION COMIc, bSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator Marathon Oil Company 3. Address P. O. Box 190168 Anchorage, AK 99519 4. Location of wellatsurface 1,700' FSL, 660' FWL, Sec. 33-7N-10W-SM Attop of productiveinterval 1,467' FSL, 711' FEL, Sec. 34-7N-10W-SM Ateffective depth 1,492' FSL, 768' FEL, Sec. 34-7N-10W-SM Attotaldepth 1,553' FSL, 900' FEL, Sec. 34-7N-10W-SM 5. Datum elevation(DF or KB) 19' KB above GL 6. Unit or Property name Beaver Creek Unit 7. Well number BC 4 8. Approval number 8-10 9. APl number 50-- 133-20239-01 10. Pool Beaver Creek Field Feet 11. Present well condition summary Total depth: measured true vertical 15,9 21 ' feet 15,715 ' feet Effective depth: measured 15,315 ' true vertical 15,107 ' Casing Length Size Structural Conductor Surface Intermediate 2,989 ' 13 3/8" Production 12,521' 9 5/8" Liner 3,704' 7" Perforation depth: measured feet feet Plugs (measured) 15,315 ' Junk (measured) N/A - 15,921' CMT Cemented Measured depth True Vertical depth 2,000 sx 2,989' 2,868 sx 12,521' 1,400 sx 15,921' 2,890' 12,445' 15,717' true vertical See Attachment #1 Tubing (size, grade and measured depth) 3 1/2" 9.3# N-80 EUE and Buttress Tubing @ 14,498' MD 2 7/8" N-80 EUE Tubing @ 14,498' to 14,644' MD Packers and SSSV (type and measured depth) SSSV Profile (Otis w/2.81" ID 'x' profile) @ 278' MI Otis 7" x 4" Permadril Pkr @ 14~462' MD & Otis 7" x 3-1/4" Permadril Pkr @ 14,615' M 12. Stimulation or cement squeeze summary R E,t:;EiV F-O 13. Intervals treated (measured) Treatment description including volumes used and final pressure MAR 0 7 Representative Daily Average Production or Injection Data Anchorage OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1/20/88 292 69 Subsequent to operation 1/30/88 400 100 41 900 psi 80 psi 36 900 psi 80 psi 14. Attachment~ #2 Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /-~/~/~/c./~ Title District Operations Engineer Form 10-404 Rev. 12-1-85 Date.~2/~/~,; Submit in Ddplicate/ Upper "G" Zone Lower "G" Zone Attachment #1 Beaver Creek Well BC-4 Perforations 14,731' - 14,743' MD 14,542' - 14,553' TVD 15,040' - 15,100' MD 15,108' - 15,128' MD 15,132' - 15,146' MD 15,150' - 15,175' MD 15,185' - 15,210' MD 14,840' - 14,900' TVD 14,907' - 14,926' TVD 14,928' - 14,944' TVD 14,950' - i4,972' TVD 14,981' - 15,006' TVD NEF/em/27/Sundr 2 Attachment #2 Daily Well Operations Report Beaver Creek Unit Well #4 1124188 RU E-line, pressure test lubricator to 850 psi, OK. RIH w/15', 1-11/16" sinker bar/I-3/4" CCL/2-1/4" gauge ring, and tag bottom @ 15,209' DIL, POOH. Made two perforating runs using 2-1/8" E-Jet II, 4 SPF, 0° phasing, 16 gm. charge perf guns. RIH, correlated and with well flowing, perf 15,185' to 15,208' on first run and 15,150' to 15,175' on second run. POOH. RD and secure well. ~./25/88 RU E-line and pressure test, OK. MU 2-1/2" gauge ring/knuckle joint/spangs/CCL/sinker bar. RIH and work through tubing tail, POOH. Make two perforating runs using 2-1/8", E-Jet II, 4 SPF, 0° phasing, 16 gm charge perf guns. RIH, correlated and with well flowing, perf 15,132' to 15,146' on first run and 15,108' to 15,128' on second run. POOH, RD and flow well for cleanup. 1/26/88 RU E-line, pressure test, OK. Made two perforating runs using 2-1/8" E-Jet II, 4 SPF, 0° phasing, 16 gm charge perf guns. RIH, correlated and with well flowing, perf 15,070' to 15,100' on first run and 15,040' to 15,070' on second run. POOH, RD and turn well back to production. NEF/em/27A/Sundr2 Marathon Oil Company Doyle L;' ~es Product1 anager Alaskan D~rict Production United States P.O. Box 102380 Anchorage, Alaska 99510 Telephone 907/561-5311 December 29, 1987 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: Attached is the AOGCC Application for sundry Approval for Beaver Creek Well #4. Should you have any questions regarding any application or report, please contact me at (907) 561-5311. Sincerely, D. K. Corlett District Operations Engineer Attachment DKC/em/6/M1 S~ STATE OF ALASKA '":'~, ALA .., OIL AND GAS CONSERVATION COM ,, .,ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [~ Other [] 2. Name of Operator Marathon Oil Company 3. Address P. O. Box 102380 Anchorage, AK 99510 4. Location of well at surface 1,700' FSL, 660' FWL, Sec. 33-7N-10W-SM At top of productive interval 1,467' FSL, 711' FEL, Sec. 34-7N-10W-SM At effective depth 1,492' FSL, 768' FEL, Sec. 34-7N-10W-SM At total depth 1,553' FSL, 900' FEL, Sec. 34-7N-10W-SM 5. Datum elevation (DF or KB) 19' KB above GL 6. Unit or Property name Beaver Creek Unit 7. W~I~: n~mber 8. Permit number 72-13 9. APl number 50-- 133-20239-01 10. Pool Beaver Creek Field feet 11. Present well condition summary Total depth: measured true vertical 15,921 ' feet 15,715 ' feet Plugs (measured) 15,315' - 15,921' CMT Effective depth: measured 15,315' true vertical 15,107 ' feet Junk (measured) N/A feet Casing Length Structural Conductor Surface Intermediate 2,989 ' Production 12,521 ' Liner 3,704' Perforation depth: measured true vertical Tubing (size, grade and measured depth) Size Cemented Measured depth True Vertical depth 13 3/8" 9 5/8" 2,000 sx 2,989' 2,890' 2,868 sx 12,52]' 12,445' 7" 1,400 sx 15,92~'~*~JV~.U' 15,717' See Attachment A~ch0mg~ 3 1/2" 9.3~f N-80 EUE.and Buttress Tubing 2 7/8" N-80 EUE Tubing @ 14,498' to 14,644' MD Packers and SSSV (type and measured depth) SSSV Profile (Otis w/2.81" ID 'x' profile) @ 278' MD Otis 7" x 4" Permadril Pkr @ 14,462' MD & Otis 7" x 3-1/4" Permadril Pkr @ 14,615' ~ 12.Attachment~×xxx2 Description summary of proposal ~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation January 1988 14. If proposal was verbally approved Name of approver Date approved 15. I hereb,~ certify that th, e foregoing is true and correct to the best of my knowledge Signed ~ ~ ~c.~ l/~'-- Conditions of approval II Title District Operations Engineer Date Commission Use Only Notify commission so representative may witness I Approval No.,.~:~ /~' [] Plug integrity [] BOP Test [] Location clearancej ........ -~.----.-- Approved Copy em;l~]lll~~,Olitll~..~~"~-~ ~-~/'~-'-~- .... ' - Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 12-1-85 Returned ..~/~ Commissioner by order of the commission Date /'-,,~---' Submit in triplicate/,~,, Attachment #1 Beaver Creek Well BC-4 Perforations Upper "G" Zone Lower "G" Zone 14,731' - 14,743' MD 15,040' - 15,100' MD 15,108' - 15,128' MD 15,132' - 15,146' MD 15,155' - 15,175' MD 15,185' - 15,210' MD 14,542' - 14,553' TVD 14,840' - 14,900' TVD 14,907' - 14,926' TVD 14,928' - 14,944' TVD 14,952' - 14,972' TVD 14,981' - 15,006' TVD NEF/em/27/Sundr2 Attachment #2 Beaver Creek Well #4 Procedure It is Marathon's intention to enter Well BC #4 and reperforate the current perforated intervals as listed on Attachment #1 using the following procedure: 1. Rig up electric line over BC #4. 2. Pressure test lubricator to 2,500 psi. 3. Reperforate the current perforated zones underbalanced with 2-1/8" Silver Jet strip guns, 4 SPF, 0° phasing. Tag fill on first gun run. 4. Rig down electric line and place well on test. em/NEF/27/Sundr2 Marathon Oil Company Alasl~'--.., ict Production United States RO. Box 102380 Anchorage, Alaska 99510 Telephone 907/561-5311 November 17, 1987 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: Attached is the. AOGCC Report of Sundry Well Operations and Daily Well Operations Report for Beaver Creek Well BC #4 Should you have any questions regarding the report, please contact me at (907) 561-5311. Sincerely, District Operations Emgtneer Attachment DKC/em/107/Sundr3 STATE OF ALASKA .r ALAL../-, ~IL AND GAS CONSERVATION CO~, .... ,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) Marathon Oil Company 19' KB above GL Feet 3. Address 6. Unit or Property name P. O. Box 102380 Anchorage, AK 99510 Beaver Creek Unit 4. Location of well at surface 1,700' FSL, 660' FWL, Sec. 33-7N-lOW-SM At top of productive interval 1,467' FSL, 71I' YEL, Sec. 34-7N-10W-SM At effective depth 1,492' FSL, 768' FEL, Sec. 34-7N-10W-SM At total depth 1,553' FSL, 900' FEL, Sec. 34-7N-10W-SM 8. Approval number 72-13 9. APl number 50-- 133-20239-01 10. Pool Beaver Creek Field 11. Present well condition summary Total depth: measured true vertical 15,921' feet Plugs (measured) 15,715' feet 15,315' - 15,921' CMT Effective depth: measured 15,315 ' feet Junk (measured) N/A true vertical 15,107 ' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True Vertical depth 2 989 , ' 13 3/8" 2,000 sx 2,~'A 1, 00 sx 1 3,704 ' 7 4 ~,2~ ' measured true vertical See Attachment Tubing (size, grade and measured depth) 3-1/2" 9.3¢f N-80 EUE and Buttress Tubing ~ 14, 2-7/8" N-80 EUE Tubing ~ 14,498' to 14,644' ~ 2,890' 12,445' 15,717' 498' MD Packers and SSSV(type and measured depth) SSSV Profile (Otis w/2.81" ID 'x' profile) @ 278' MI Otis 7" x 4" Permadril Pkr @ 14,462' MD & Otis 7" x 3-1/4" ?ermadril Pkr @ 14,615' ~ 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment,,,,.description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data Prior to well operation 8/9/87 Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Subsequent to operation 1 l/1/87 14. Attachments ~'r~2 & Daily Report of Well Operations 272 69 777 147 0 1070 psig 60 psig 0 640 psig 75 psig Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ]~'~~ Form 10-404 Rev. 12-1-85 District Operations Engineer Title Submit in Duplicate Upper "G" Zone Lower "G" Zone Attachment #i Beaver Creek Well BC-4 Perforations 14,731' - 14,743' MD 14,542' - 14,553' TVD 15,040' - 15,100' MD 15,108' - 15,128' MD 15,132' - 15,146' MD 15,155' - 15,175' MD 15,185' - 15,210' MD 14,840' - 14,900' TVD 14,907' - 14,926' TVD 14,928' - 14,944' TVD 14,952' - 14,972' TVD 14,981' - 15,006' TVD NEF/em/27/Sundr2 Attachment #2 Daily Well Operations Report Beaver Creek Unit Well #4 8/].4/87 Move in & rig up Roll'n Rig #5. Fill annulus & tbg w/ diesel. ND xmas tree. NU BOPE. 8115187 Finish NU BOPE. Test BOPE to 3000 psi & Hydrill to 1500 psi. RU wireline & backed off 3-1/2" tbg @ 8483' (2 its below #9 GLM). RD wireline & POH. 8/16/87 "Finish POH w/3-1/2" tbg. MU overshot bumper sub & jars. RIH, Latch fish. RU wireline to run GR-CCL correlation log. Couldn't get past 8450'. RD wireline. Release overshot. POH w/3-1/2" tbg. 8117187 Finished POH w/3-1/2" tbg. Found bottom jt plugged w/piece of GLM packoff. RIH w/fishing assembly. Latch fish. Ran GR/CCL. RU & ran CCL & chemical cutter. Attempt to cut @ 12,371 TM. No cut. Redress chemical cutter. Cut tbg @ 12,401'. Presently POH w/chemical cutter. 8118187 R/D wireline POH w/tbg & fish. Well started flowing. Pumped diesel POH w/10 more stands. Checked well. Well started flowing. RIH to 12000'. 8119187 RIH to 12,200'. Circ diesel. Diesel still gas cut. Shut down pump. Well gassey. Mix 3% KCL brine. Presently pumping 3% KCL. 8/20/87 Mix & pump 3% KCL to kill well. POH. LD fishing tools & GLM's. 8121187 POH w/ fish & LD GLM's. RU wireline & run 5.875" gauge ring & junk basket to 12,350'. PU packer & overshot assembly. Presently RIH. 8/22/87 RIH w/ packer & overshot assembly. Swallow tbg stub. Set 8000# @ overshot. Run CCL-GR correlation. Drop ball & set packer. Test tbg/csg annulus to 1900 psi for 30 minutes OK. POH. LD tbg. Moving new production tbg onto racks. 8/23/87 Ran tbg & GLM's. 8/24/87 RIH w/ SSSV & central line. Sting into packer. Run CCL/GR space out. Land tbg & set BPV. LD substructure & nippld down. NU Xmas tree & test to 3000 psi. Did not retrieve BPV. RELEASED RIG @ 2330 hfs 8/23/87. em/27A/Sundr2 Attachment #2 Daily Well Operations Report Beaver Creek Unit Well #4 (Continued) 8/24/87 Hook up flow line and remove BPV. Hook up gas lift line and begin unloading well. 8/~_5/87 - 918187 9/9/87 Testing well. RU wireline, test lubricator, and RIH w/CCL and 2-1/8", 4 SPF, Silver Jet steel strip perforating guns. Made 7 perforating runs and perforated the following intervals (all measurements DIL): 15,185' - 15,210', 15,155' - 15,175', 15,132' - 15,146', 15,108' - 15,128', 15,070' - 15,100', 15,040' - 15,070'. 9/10/87 - 10/12/87 Testing well. 10/13/87 10/15/87 Run pressure buildup survey. RIH w/2-1/8" Enerjet strip charges and perforate 2' intervals from 14,736' - 14,738'. Ran pressure and temp gradient surveys before and after perforating. RU wireline. Pressure test lubricator and RIH w/12', 2-1/8" Silver Jet guns, 4 SPF, 0° phasing. Perforate from 14,731' - 14,743' DIL. POOH and RD WL. 10/16/87 - 10/20/87 10/21/87 Testing well. RU Wireline. Pressure test lubricator and RIH w/Silver Jet steel strip charges, 4 SPF, 0° phasing, and perforate 14,731' - 14,743'. POOH. RD WL. Put well back on production. NEF/em/27A/Sundr2 Attachment # 3 Beaver Creek Uell Current Completion Assembly 3-1/2" FMC Tbg. Hanger 278' 3-1/2" SSSV Profile w/2 'lOs 3-1/2", 9.3#, 8rd EUE, AB Mod. Completion String 2989' 13-3/8", 68 & 72# N-80 & J-55 Ail GLMs are 3.5" x 1.5" Side Pocket (Johnston Macco SPM 2) '2899' GLM #1 4718' #2 6097' #3 7292' #4 8297' #5 9114' #6 9740' #7 10,336' #8 10,954' #9 11,580' #10 12,175' #11 12,521' 9-5/8", 47#, N-80 & S-95, 53# P-110 12,374' Baker Tbg. Locator 12,375' to Baker Seal Assembly (G-22 Size 80-40) 12,376' Baker SC-IL Packer, 7", 32# x 4.0" SB (Size 70A-40} 12,395' w/l/2 Mule Shoe 12,380' Baker 10' SBE, 4.0" ID (Size 80-40) 12,390' Baker Concentric Coupling 12,391' Baker 10' SBE, 4.0" ID (Size 80-40) 12,400' XOver, SBE Box x 3-1/2" 8rd EUE Pin 12,401' Overshot 1Packoff Assembly Equipment Left from Orisinal Completion 12,405' 12,423' 14,441' 14,445' 14,475'i 14,476' 14,478' 14,497' 14,498' 14,623' 14,624' 14,644' Stub joint w/chemical cut made 18' above collar. 3-1/2" 9.3# Butt. Tbg. Otis 2.75" ID XO sleeve 1 Jr. 3-1/2" 9.3# Butt. Tbg. Otis 2.75" ID "X" Nipple Otis Locator Sub Otis Seal Unit 4.0" OD x 3.0" ID X-Over 3-1/2", NU 10rd Box x 2-7/8" 8rd EUE pin 4 Jr. 2-7/8", 6.5# 8rd EUE Tbg. X-Over 2-7/8", 8rd Box x 2-1/2" NU 10rd pin Otis Seal Unit 3.25" OD x 2.38" ID Mule Shoe Guide Perforations DIL Upper "G" Zone 14,731' - 14,743' MD Lower "G" Zone 15,040' - 15,100' MD 15,108' -.15,128' 15,132' - 14,146' 15,155' - 15,175' 15,185' - 15,210' 15,315' PBTD' 15,921' TD NEF 11/3/87 STATE OF ALASKA ALAS(' OIL AND GAS CONSERVATION COM~~ ;SION APPLICA ION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing ~ Amend order [] Perforate ~ Other [] 2. Name of Operator 5. Datum elevation (DF or KB) Marathon Oil Company 164' KB 3. Address P. O. Box 102380 Anchorage, AK 99510 4. Location of well at surface 1,700' FSL, 660' ~L, Sec. 33-7N-10W-SM At top of productive interval 1,467' FSL, 711' FEL, Sec. 34-7N-10W-SM At effective depth 1,492' PSL, 768' FEL, Sec. 34-7N-10W-SM At total depth 1,553' FSL, 900' FEL, Sec. 34-7N-10W-SM 6. Unit or Property name Beaver Creek Unit 7. W~,l~ n~mber 8. Permit number 72-13 9. APl number 50-- 133-202391 10. Pool Beaver Creek Field 11. Present well condition summary Total depth: measured true vertical 15,921 ' feet Plugs (measured) 15,715 ' feet 15,315' - 15,921' CMT Effective depth: measured 15,315 ' feet Junk (measured) true vertical 15,107' feet N/A Casing Length Size Cemented Structural Conductor Surface Intermediate 2,989' 13 3/8" 2,000' sx Production 12,521' 9 5/8" 2,868' sx Liner 3,704' 7" 1,400 sx Perforation depth: measured true vertical See Attachment #1 Measured depth 2,989' 12,521' 15,921' ~ueVerticaldepth 2,890' 12,445' 15,717' RECEIVED Tubi.~g ts)~e~, grade..and measured depth) 9.3# N-80 EUE andButtress Tubing @ 14,462' (MD) 2 7/8" N-80 EUE Tubing @ 14,636' (MD) Packers and SSSV (type and measured depth) Otis 7" x 4" Permadrill Packers @ 14,462' MD & 14,605 MD Alaska. 0il & Gas Cons. CommiSsion Anchorage 12.Attachment~ 2 & 3 Description summary of proposal'[~ Detailed operations program [] BOP sketch ~ Attachment #4 13. Estimated date for commencing operation June, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~[.J/("~o?~/~ Title District Operations Engineer Date 5/13/87 Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI ~..,, ~,., ..,'~ ,': ..,:, Approved by Commissioner by order of the commission Date ,,,~--~ ,/~,,~'~-. ¢<~' feelf(~ Form 10-403 Rev 12-1-85 Submit in triplicate Attachment #1 Beaver Creek Well BC-4 Perforations Lower "G" Zone 15,040' - 15,100' MD 15,108' - 15,128' MD 15,132' - 15,146' MD 15,155' - 15,175' MD 15,185' - 15,210' MD 14,840' - 14,900' TVD 14,907' - 14,926' TVD 14,928' - 14,944' TVD 14,952' - 14,972' TVD 14,981' - 15,006' TVD NEF/em/27/Sundr2 RECEIVED Cons. Commission Aachorage Attachment #2 Beaver Creek #4 Workover Procedure 1. Shut off lift gas and allow well to die. Bleed tubing and casing pressure to zero. Fill tubing w/75 bbls diesel and fill casing w/250 bbls diesel. The SBHP = 3070 psi on 2/16/87, which is a 3.94 lb/gal, equivalent mud weight. 2. MI RU workover rig. 3. Set BPV. ND tree. NU BOPE and rotating head. Test BOPE to 3000 psi. 4. Cut tubing @ 12,350'. POH w/tubing and stand in derrick. 5. Gatorhawk in hole w/the following packer assembly and..,~.!ow the ~~'sh. (Exact packer assembly may change slightly.) a) 4.30" ID x 5.75" OD x 30' wash pipe w/muleshoe guide and compression packoff. b) 20' SBE (4" ID). c) 7", 32#, permanent packer (4" bore). d) Hydraulic setting tool; right hand rotational release. e) RA Tag ± one stand above packer. 6. RU W.L. Run GR correlation to ensure the assembly is over the tubing fish. RD W.L. 7. Set packer. PU to ensure packer is set. Release setting tool and POH laying down tubing. 8. RIH w/new completion assy. as detailed below; tubing to be Gaterhawked. a) 20' seal assy. b) Locator. c) 3-1/2" 9.3# L-80 EUE tubing. d) 3-1/2" x 1" GLMs. e) 3-1/2" wireline retrievable ball valve profile. 9. Set BPV ND BOPE NU and test tree. Release rig. 10. Gas lift and test well. Cons, 11. Reperforate existing perforated intervals and test well. Lower "G" Zone 15,040' - 15,100' DIL 15,108' - 15,128' DIL 15,132' - 15,146' DIL 15,155' - 15,175' DIL 15,185' - 15,210' DIL 12. Evaluate a solvent treatment of the existing perforations. 13. Fill tubing with diesel and perforate new interval in the Upper "G" Zone from 14,731' to 14,743' DIL. 14. Test well and run GL Survey and production logs after one month minimum. PMS/em/27/NEF ATTACHHENT it: 3' Beaver Creek Well #4 Proposed Completion Schematic Beaver Creek ~ Complec ion Schematic (~x:Lsc ~ng) pepch (TH) I.O. Oescriotion 3-1/2" Wirellne Retrievable Bell Va~ · -1/2~ tbS. 3215 ~118 5408 6213 680~ · 7212 7S~7 · 79~0 83~5 8800 ~205 ~577 ~981 10,385 9-5/8" 12,217 12,521 14,432 2.3~" · 1~,535' - 1&,5~5' Iq,605' 14,636 7" P-II0 Liner o. 15,0~0' - 15,100~ IS,108' - ~,128' 15,132' - 15,166'' 15,155' - 15,175' 15,18S' - 15,210( · . IS,315 PBTO GLV :1 GLV :2 GLV 13 GLV ~S GLV :6 GLV d7 GLV :8 GLV #9 Packed off w/ Baker BFC Mode' K~3 StraddSe Packoff i-7/16" I.D. (6,19.1975) ~ GLV #1o · GLV ~I1 GLV ~|2 GLV Circulating Shoe Seal As$¥. (¥' X 20') v/ Locator, X-Nipple HtBh pressure racer zone; squeezed bug still leaking Seal Assy (3-l/q" x 20'} Hule Shoe Guide Otis 7" x 4" Permadrill Packer 2-7/8" EUE tubing (125' 4 jts) Otis 7" x 3-1/4" Permadrill Packer ~300' WL Bali Valve Profile '-248' 20", 94#, H-40 -2989' 13-3/8", 68 & 72# N-80 & J-55 3-I/2", 9.3#, L-80, EUE Modified Tubing Approx 15 3-I/2" x 1" GLHs 12,217' TOL 12,521' 9-5/8", 47#, N-80 & S-95, 53.5# P-110 Pac~er.:.~;.~2,300' Overshot over cut tubing @ 12,350' Locator was landed 1-i/2' above packer 14,462' 14,535' - 14,565' Leaking p~ that were squeeze~ 14,605' 14,731' - 14,743' Upper G-Z~ perforations (proI 15,040' - 15,100' 15,108' - 15,12g' Lower 15,132' - 15,146' G-Zone 15,155' - 15,175' Perforacic 15,185' - 15,210' 15,315' PBTD 15,921" 7", 32::. P-Il0 P.'.; S 3 Attachment #4 ( ARATHON OIL COMP/[' Y BEAVER CREEK WELL NO~-4' 13-5/8' 5000 psi BOP Assembly Mud Pan Flowline Drilling Nipple .,r'/" 2 , ,k h · . Rotating Heed Clamp Connector U 13 .,.Annular 5/8' x 5000* Preventer (Hy d'ril) 0] f' , !~0 (~] Clamp Connector -- ~ (Pipe~ems)' ~ 13 3/8' Oouble-Oate-ClW 3' x 5000. Kill 'Line U (Blind Rems) I I/ x 5000. Choke Line 0 0 0 ~ 1.2' x 300'0* Casing Heed · ~ t r._~ollllw/Flanged Outlet8 & valves , ,,~ 13 3/8 Surfac,_ 30' Conductor Alaskan District Production United States Marathon Oil Company March 20, 1 P.O. Box 102380 Anchorage, Alaska 99510 Telephone 907/561-5311 Mr. Russ Douglas Alaska Oil and Gas Conservation Commission 3001 Porcupine DriVe Anchorage, AK 99510' Dear Russ: Flash Vaporization Calculations for Determination of Separator Gas/Oil Ratio, Beaver Creek #4 As you requested during our March 19, 198~ telephone conversation, I am attaching the flash vaporization calculations used to estimate the separator GOR for the Beaver Creek G-Zone producers. PleaSe contact me at 564-6407 if you have any questions or require additional information. Sincerely, P' M. O'Dell Reservoir Engineer lb/RE12/20 RECEIVED MAR 2 z, 1987 Ataska 011 ,& Gas Cons. Commissio~ BEAVER CREEK #4 -- FLASH VAPORIZATION CALCULATIONS CONDITIONS: SEPT = 100 SEP P = 45 MOLE EQUIL. COMPONENT FRACTION RATIO XJ C1 0.1593 94.000 0.0054 C2 0.041'3 15.000 0.0078 C3 0.0740 4.350 0.0364 i-C4 0.0215 1.950 0.0167 n-C4 0.0515 1.500 0.0447 i-C5 0.0310 0.650 0.0348 n-C5 0.0323 0.510 0.0381 C6 0.0403 0.185 0.0538 C7+ 0.5487 0.088 0.7624 NOTE: 0.506~ 225.000 0.0014 0.1169 27.500 0.0058 0.1585 7.100 0.0337 0.0325 3.200 0.016~ 0.0670 ~.300 0.0439 0.0226 0.930 0.0348 0.0194 0.720 0.0382 0.0100 0.220 0.0543 0.0671 0.094 0.7717 1.0000 1.0000 1.0000 1.0000 ~ F~*~-~ND (1) = 0.3074 Li~Z~ ;~,'-- ~N1 ( 1 ) = 0.69E6 NQ (~) = N1 (2) = o. O133 0.9867 I EQUILIBRIUM RATIOS FOR O~LAHOMA CITY CRUDE AFTER KATZ AND HACr~MUTI-I I ! · Yj (2) MW Xj (2)*NW DENSITY 0.6/L~,~ (LB/FT3) ~ i <'r2,'~.'~r~,; I 0.3051 16.0 0.1585 30.1 0.~ 0.~393 44.1 1..5 0.0518 58.1 0.,9 0.1010 58,1 0.0324 72.2 0.0275 72.2 ~.'8 0.0120 86.2 0.0725 216.0 166.,7 LIQUID VOLUME (FT3/LB-MOLE) 31.66 35.12 36.45 38.96 39.35 41.30 53.88 0.0470 0.0268 0.0700 0.0645 0.0701 0.1134 3.0938 1.0000 C3+= 181.6247 C2+= 181.7982 ~o, = uO~~= 181.8~@0 DENSITY OF C3+ · = WT% OF C2 IN C2~ = WT% OF C1 IN C1~ = SPEC. GRAVITY ~ = API = ~ 3. 4855 52.11~ 0.0001J 0. 835 37.9 PRODUCING GOR = 275 ' -'- 8 STOCK TANK GOR TOTAL GOR ' = RECEIVED MAR2 4 1987 Alaska Oil & Gas Cons. Commission Anchorage Ms--r o GTt~ IVlarathoi~ Oil Company January 29, 1976 Mr. Rodney A. Smith Oil & Gas Supervisor, Alaska Area U.S.G.S. P.O. Box 259 Anchorage, Alaska 99510 Al Mecl,~, "Jr Managt{ ~chorage Division Canad~ Product".,.,,', Operations US & ..... Telephone 907/274 1511 ..... ~.~-,~-. Dear Mr. Smith: As you requested in your letter of December 17, 1975, enclosed is a schematic drawing of our production facili- ties at Beaver Creek Field. All oil and gas metering points are shown on the drawing° A list of the meters and abbreviations 'to be used in the following discussion are: Beaver Creek #4 Separator Gas . o o #4 S.G. Beaver Creek ~5 Heater Treater Gas ............... #5 H.T.G. Beaver Creek ~4 Gas Lift Gas .... #4 G.L.G. Beaver Creek #5 Gas Lift Gas.. ~. · 95 G.L.G. Beaver Creek #lA Makeup Gas .... #lA M.G.. Beaver Creek 9lA Injection Gas .......... ~ ..... #lA I.G. Fuel Gas. . F,G. BeaVer Creek'~ ~e~a;a;o; 6ii ' ' ' Turbine Meter ........... #4 T.M. Beaver Creek #5 Heater Treater Oil Turbine Meter ........ 95 T.M. The disposition of all gas at.Be'aver Creek as reported on your Form 9-329 is as follows: Beaver Creek #lA Injected Gas = #lA I..G., Metered Beaver Creek #lA Produced Gas = #lA M.G., Metered Mr. Rodney A. Smith January 29, 1976 Page 2 Beaver Creek #4 Produced Gas = #4 P.G. = #4 S.G. - #4 G.L.G. Beaver Creek #5 Produced Gas = #5 P.G. = #5 H.T.G. - #5 G.L.G. Fuel Gas = F.G., Metered Total Produced Gas = T.P.G. = #iA M.G. + #4 P.G. + #5 P.G. Shrinkage = (#4 G.LoG. + #5 G.L.G.) x 0.021452 Flared Gas = T.P.G. - F.G. - #lA I.G. - Shrinkage The shrinkage shown above is to allow for condensation of liquids in the compressor after coolers and scrubbers. As shown on the diagram, this liquid is blended with the oil and sold as oil. The small amount of liquids involved would be difficult to meter with any degree of.accuracy. Instead, the shrinkage was calculated with the NGPA flash program utilizing observed pressures and .temperatures on each scrubber and a known gas composition. Please advise if you need additional information. Very truly yours, ~1 ~4echl~ , Jr. Division Operations Manager AM/pr Enclosure cc: Mr. O. K. Gilbreth, Director Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99504 ~ur£~cm ya~llit~ ~col~ : ll~n~ MARATHON OIL COMPANY PRODUCTION - UNITED STAI'ES AND CANADA Decamber 18, 1973 /v~O"~A T HO~,~ I L COMPANY AN~FiAGE, ALASKA M, L. Lowma ,.- ~ ~ !!i73 Mr. R. T. Anderson Union Oil Company of California 909 West Ninth Avenue · Anchorage, Alaska 99501 Beaver Creak Unit Dear Bob: Attached is a copy of letter of notice to State of Alaska, Division of Oil and Gas, advising them of our contemplated injection of excess solution gas at Beaver Creek. If you have no objection to this proposed operation, please acknowledge on the carbon copy of this letter and return. Ve~.~truly your~~ Morris L. Senior Landh~an MLL/smy Enclosure APPROVED: ' MARATHON OIL COMPANY PRODUCTION-UNITED STATES AND CANADA ANCHOI~AGE OIVIglON P.O. I:lOX ~390 ANGHORAGE , ALASKA 99510 January 21, 1973 Mr. O. K. Gilbreth State of Alaska Division of Oil and Gas Conservation Committee 3001 Porcupine Anchorage, Alaska 99504 Dear Sir: As Mr. Vonderay requested during our telephone con- versation on January 21, I am enclosing copies of five letters that should complete your file on Beaver Creek Well No. 4. If you need further information, please let me know. Yours very~ truly~ C. F. Ferguson Division Petroleum Engineer .CFF/rp Enc. (5) Letter of 1-2-74 from MarathOn Oil to Divn. of Oil & Gas Letter of 11-26-73 from Dept. of Interior to Marathon Oil Letter of 11-20-73 from Marathon Oil to U.S.Geological Survey Letter of 10-25-73 to Marathon Oil from U.S.Geological Survey Letter of 10-19-73 from Marathon Oil to U.S.Geological Survey 5 I974 MARATHON OIL COMPANY PRODUCTION-UNITED STATES AND CANADA ANGHOF=IAGE DIVISION B.G. HOWARD DImERATIONS MANAGER ANCHOF:IAGI: , ALASKA lB ~1 ~ 10 January 2, 1974 State of Alaska Division of Oi. 1 aJ~d. (]as Conservation Committee 3001 Porcupine ~mchorage, Alaska 99504 Gentlemen · E.[ ,:f C il' L_.,.,. '" I.)IVISION .. "' "" 'r,',', ;' :.., Beaver C'reek Unit Pursuant to Section. 2228 of tl~e State of Alaska Oil and Gas Conserva. t~ion Regulations, Marathon Oil Company, as Unit Opera- t°r, hereby gi. ves ~otice of its intention to inject excess solution gas froln Beaver Creek Un. it Well No. 4 (and. from Well No. 2 after recompletion) into the Sterling Formation of the Beaver Creek Unit Well No. IA, whose surface location is in the SW% SE¼ Section 3, T6N, R10W, SM and the subsurface loca- tion is in the SE~ SE¼ of said Section 3. The interval in which injection is to be made is from 5,430 to 5,675 feet, measured depth. For your information following is a casing record for Well No. iA' Casing Size Weight Depth Set Hole Size Cementing LB./FT. (MD) Record 20" 94 526.29 26" 1,000 sx 13-3/8" 61 2,209.05 18-5/8" 2,025 sx 9-5/8" 4.0 & 43.5 5,101.27 ].2-1/4" 1,500 sx 7" 26 & 29 ' 9,697.83 8-1/2" 730 sx ,. , It is antic'i, pated that the injection p'rogramwi]l commence on or about January 15, ].974, or as soon thereafter as equipment is received and installed. J 2 1974 ,January 2, 1974 olll v t~l'l~t:i' ll)ey l~ave ;~l'lc'cted p;.trLy is U~i. oli (.)il (:Oml~:lliy of (:;~l[l'orliiit, ;lJ)l)l'ovcd l:11o l)rOpOSed oj)c'ratiOll. Very trttly yot~z's, X (.i ' l~,odll ¢:y A. Sm i tl~ '1~~' ' Divi. s.i. on Ol)erati. ons Manager bcc: Co Fo C. J. D. L. Ferguson Diver Jones J A J'! 2, ,)~ I974 UNITED STATES u~ ~ I~. DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY :P.O. :Box 259 Anchorage, Alaska 99510 Marathon Oil Company P.O. Box 2360 Anchorage, Alaska 99510 Attention: Mr. W. L. Kinney Acting Division Operations Manager Gentlemen: The subject of your November 20, 1973, letter and our meeting on that day was the present status of operations in the Beaver Cr'eek Unit and your plans for further operations at this time. You advised us that you plan to inject excess solution gas into the Sterling gas sand in Beaver Creek Unit Well 1-A as soon as a compressor modification can .be made. Delivery of necessary parts is expected in'early January with injection operations commencing soon thereafter. You also advised us of the delay in recompletion of Beaver Creek Well No. 2 and the mechanical problems experienced in producing well No. 4. In view of plans and preparations underway to inject excess solution gas as soon as possible, we have no objection to your continued production test of Beaver Creek Unit Well No. 4 and the flaring of excess solution gas until the injection is commenced or for an additional two month period ending January 22, 1974. If it appears that the injection cannot be commenced prior to that date, we believe you should make plans to shut-in the well or cut back production to reduce the unnecessary loss of gas. Your November 20 letter also requested approval of a safety flare using up to 300 MCFD. Before considering this request for a safety flare, we ask that you furnish complete justification for the safety flare including a discussion of alternatives. If and when you furnish justification for the safety flare, -2- include a detailed description of the flaring system proposed including the type of pilot flare, a diagram of the system, design pressures and volumes and method of measurement. Please l<eep us currently posted on the progress toward commencing injection of the excess solution gas; and .if you have any questions on the contents of this letter, please contact me. Sincerely yours, Rodney AI. Smith Oil and Gas Supervisor Alaska Area Ii,Iii,, MARATHON OIL COMPANY PRODUCTION-UNITED STATES AND CANADA ANCHORAGE DIVISION I~.O. BOX ANCHORAGE,ALASKA November 20, 1973 U. S. Geological Survey P. O. Box 259 Anchorage, Alaska 99510 Attention: Mr. Rodney A. Smith Oil & Gas Supervisor Alaska Area Gentlemen: ~s you requested in your letter of October 25, 1973, I am attaching a schedule of our proposed test program for Beaver Creek Wells $2 and #4. After recompletion of BC #2, about 36 days will be needed for production and buildup tests on BC #2. If these tests show a pulse test to be needed and feasible, an additional period of at least 30 days will be required to generate the pulses in BC #2 and detect them in the shut-in BC $4 well. For the reasons given in my letter dated October 19, 1973, we believe it is desirable to continue producing BC #4 until BC #2 is recompleted and tested. However, at the time that letter was written, we expected to have BC #2 recompleted by December. The strike by the Alaska Drillers and Roughnecks Association has delayed the recompletion for an indefinite period. Even if the strike would end tomorrow, it would probably be mid-January before the workover can be completed. At that time of the year, we anticipate that the frac job might have ~.to be delayed because of extreme cold weather. To be realistic, the strike and the weather could delay the recompletion and testing until next spring. U. S. Geological Survey Attention: Mr. Rodney A. Smith November 20, 1973 Page 2 As you are aware, we have been investigating the feasi- bility of injecting excess solution gas into the Sterling gas sand in BC #lA. Although our study is not yet completed, the results to date are encouraging. Core Lab has run a dew point test on a Bea~er Creek gas sample. The test showed no liquid dropout at reservoir conditions. The question still remains as to whether this was a representative gas sample or if variations in operating conditions might at times result in liquid dropout. We feel certain enough that injection will prove to be feasible that we have already ordered the required compressor cylinder. Delivery was originally promised for December, 1973. We~called the manufacturer today in an attempt to expedite delivery. We were told that due to an unusually heavy work load, the delivery date has slipped to early 1974. We have asked our central purchasing department to try in every way possible to accelerate the delivery and also to try to find a suitable used cylinder. If we can obtain a cylinder by mid-January, we will be able to inject the excess gas within a week to ten days later. We request permission to continue producing BC #4 and flaring the excess solution gas until the gas injection facilities are completed. I assure you that we will make every effort to complete the installation as soon as possible. After injection is started, a minimum safety pilot flare will be necessary. We request ~permission to use up to 300 MCFD for that purpose. We have not yet obtained the final pressure buildup test that you requested. We had planned to run the test about two weeks ago but the compressor went down ahead of schedule due to a seized third stage cylinder. The compressor was repaired and the well placed on reduced flow on November 14 after being shut in for eight days. After the well was returned to service, paraffin deposits were cut out of the tubing over an interval from 7,600 to 10,379 feet. Paraffin cutting was completed and the well placed on maximum producing rate on November 19. The producing rate has not yet stabilized so the ef the paraffin removal can not yet be · W.L. Kinney Acting Division Operations Manager TIME-DAYS CUM T~T I I $ I 4 I 18 14 22. 4 26 4 37 I 127 67 137 I 0 77 142 BE~ -.R CREEK 2. :>4-HR ORIGINAL PRESSURE RECORD 2.4.-HR FLOW TEST I24-HR BUILDUP TEST FRAC AS PER FRAC DESIGN I PRODUCE FOR 2 WEEKS1 ,,, 4 -DAY BUILDUP TEST DRAWDOWN TEST ' 4-DAY JKEEP WELL FLOWING J IANALYZE.ALL TESTS YES PURPOSE OF T~ -(S_.) CONDUCT PULSE TEST LOW Kh HIGH Kh OBSERVE ORIGINAL ; RES. PRESSURE .... ~ INTERFERENCE BEAVER CREEK 4. ,L IKEEP WELL FLOWING WELL FLOWIN(} ANALYZE ALL TESTS PRE-FRAC EVALUATION I I ! I FRAC EVALUA~ON , , , ! .~SE.VOIR P"OPE~rlESN---~----J WELL INTERFERENCE AFTER FRAC' EVALU AT I 0 N SHUT'IN I-WEEK BEFORE I~"~ PULSE IN 2 ~ I:~CORO I PRESSURE-TIME 'DATA I ' , RESERVOIR CONTINUITY__ --! ', R, ~----~---..-.] PULSE TEST INTER-WELL PROPERTIEE~ IPRESSURE-TIME DATA IANALYZE TEST DATAI · J-coNclUsioNs ~ ~..~ ,-~ ..,,, RECOMMENDATIONS ' A l'!' ,~; ,:i I~ ~,~ , , , A TESTING PROGRAM FOR BEAVER CREEK OIL FIELD C CORE LABORATORIES, INC. Petroleum Re~'~..-Enzi. rl~rin,/ ~ ~74 ' ~ January 14, ,. ~ . rea Engineers . chorage Divisio RESERVOIR FLUID DIVISION Marathon Oil Company P. O. Box 2380 Anchorage, Alaska 99501 Attention: Mr. Harold D. Lee Subject: Reservoir Fluid Study Beaver Creek No. 4 Well Beaver Creek Field Kenai Borough, Alaska Our File Number' RFL 73550 Gentlemen: Duplicate subsurface fluid samples from the subject well were delivered to our laboratory in Dallas, and were used in the reservoir fluid study. The. results of this study are presented on the following pages. Upon receipt, the bubble point pressures of the samples were determined to be 733 and 738 psig at 74"F., which is considered to be very good agree- ment. A small amount of fluid was flashed to atmospheric conditions, and the liquid was mailed t° your Denver research center. The reservoir fluid study we performed was in accordance with your letter of November 26 and our telephone conversation of December 17. At the reservoir temperature of 211°F., the bubble poin,t pressure of the fluid was determined to be 1012 psig. This is considerably below the reported reservoir pressure of 4620 psig, indicating that ~he fluid is highly undersaturated in the formation. During differential pressure depletion at Z!i~F. , the fluid evolved 38Z standard cubic feet of gas per barrel of residual oil. The formation volume factor was determined to be 1o 33Z barrels of fluid at the bubble Marathon Oil Company Beaver Creek No. 4 Well Page Two point per barrel of residual oil. The viscosity of the liquid phase was also measured during differential pressure depletion, and increased from 0. 698 centipoise at the bubble point pressure to 1. 436 centipoises at at- mospheric pressure. The composition of the fluid was measured by low temperature, fractional distillation. The fluid is very rich in intermediate components (approx-.. imately 29 mol percent), which accounts for the extreme changes in the fluid properties near atmospheric pressure during the differential depletion. It was a pleasure to cooperate with you by performing this reservoir fluid study, and we hope you will call on us again in the near future. If you have any questions or comments concerning the data, please let us know. Very truly yours, PLM:JB:vs 7 cc. - Addressee Core Laboratories, Inc. Reservoir Fluid Analysis P. L. Moses Manager Company Well Field CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALI-AS, T£XAS Marathon Oil Company Beaver Creek No. 4 Beaver Creek Page 1 of. 9 File RFL 73550 November 13, 197.3 Date Sampled County Kenai Peninsula Borough State Alaska Formation Name Date First Well Completed Original Reservoir Pressure Original Produced Gas-Oil Ratio Production Rate Separator Pressure and Temperature Oil Gravity at 60° F. Datum Original Gas Cap Elevation Total Depth Producing Interval Tubing Size and Depth Productivity Index Last Reservoir Pressure · Date Reservoir Temperature Status of Well Pressure Gauge Normal Production Rate Gas-Oil Ratio Sel~arator Pressure and Temperature Base Pressure Well Making Water FORMATION CHARACTERISTICS G ~ Z one Ja n,za ry 12 , 19. 73 7500 PSIG@. -!4800 .Ft. 2 80 SCF/Bbl Z 600 Bbl/Day PSIG. °F. 38 o API 14800 Ft. Subsea WELL CHARACTERISTICS 145 15940 15040-15210 3-1/2 OD In. to 14469 .Ft. Ft. Ft. Ft. Bbl/D/PSI @ Bbl/Day 4620 PSIG (~ -14800 Ft. Novembe.r 10 ., 19 73 220* oF.@ 1,5850 Ft. PSIG, Bbl/Day SCF/Bbl °F. PSIA Cut SAMPLING CONDITIONS Sampled at Status of Well Gas-Oil Ratio Separator Pressure .and Temperature Tubing Pressure Samping Pressure Core Laboratories Engineer Type Sampler Ft. Flowing 328 Bbl/Dav 400 SCF/Bbl 55 PSIG, 60 OF. 57 PSIG 2630 PSIG North Star .Engineering REMARKS: *Temperature interpolated to 15125 Ft. = 21!°F. CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS. TEXAS Page File Well 2 of, 9 RFL 73550 Beaver Creek No. 4 VOLUMETRIC DATA OF Reservoir Fluid SAMPLE 1. Saturation pressure (bubble-point pressure) ! 012. ' V@ Zll oF 2. Thermal expansion of saturated oil @ 5000 ,PSI ---- V@ 71 oF -- 3. Compressibility of saturated °ii @ reservoir temperature' Vol/Vol/PSI' PSIG@ Zll OF. 1. 06972 From 7500 From 5000 From 2500 PSI to 5000 PSI -- PSI toZS00 PSI-- PSI tol012 PSI-- 7.28 x 1016 '-6 8.86x 10 -6 10~ 95 x l0 4. Specific volume at saturation pressure: ft a/lb 0.02188 @ 211 OF. Th~ analyse~, opinions or interpretations are. based on observations and material supplied by the client to whom. and for whose exclusive and confidential use. this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories. Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations as to the productivity, l~roper opera- tion, or profitablene~ of any oil, gas or other mineral well or sand in connection with which such reoort is used or relied u~on. , . CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS. TEXAS 75207 Page 3 of 9 File. RFL 73550 Well Beaver Creek No, 4 Reservoir Fluid SAMPLE TABULAR DATA DIFFERENTIAL LIBERATION @ 211 'F. PRESSURE-VOLUME VISCOSITY RELATION OF OIL o GAS/OIL RATIO GAS/OIL RATIO RELATIVE OIL PRESSURE PSI GAUGE ' ' LISERATED IN SOLUTION VOLUME. RELATIVE VOLUME OF CENTIPOISES PER BARREL OF PER BARREL OF V/VR OIL AND GAS, V/VsAT. RESIDUAL OIL RESIDUAL OIL 7500 7000 650O 6000 5500 5000 4500 4000 3500 3000 2500 2000 1500 ,1200 1100 1012 1000 981 938 9OO 878 812 8OO 736 7OO 657 6OO 57O 5OO 487 407 0.9444 1.221 1.258 0.9475 1.262 O. 9509 1. 267 O. 9543 1. 100 1. 271 O. 9580 1o 276 O. 9619 1. 019 1.281 0.9658 1.287 0.9699 0.940 1.292 0.9743 1.298 0.9788 0.859 1.304 0.9837 0.818 1.310 0.9888 0.777 1.317 0.9943 0.737 1.324 0.9978 1.329 , O. 999O 1. 331 1. 0000 O. 698 0 382 1. 332 1.0059 1.0129 1.0328 1.0627 i1.1025' 1.1624 1.2423 1. 3620 1. 5221 .1. 7418 0.722 21 361 1.322 O. 742 42 340 1. 313 0.762 62 320 1.304 O. 782 83 299 10 294 O. 810 105 277 1. 283 v -- Volume at given pressure v,^,. = Volume at saturation pressure and the specified temperature. v, -- Residual oil volume at 14.65 PSI absolute and 60° F. These analTses, opinions or interpretations are based on observations and material supplied by the client to whom, and for' whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent t.h,e..b~, st judgment of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responmbflxty and make no warranty or representations as to the productivity, proper opera- tion, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. . CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS 75207 Page 4 of 9 File. RFL 73550 Well Reservoir Fluid SAMPLE TABULAR DATA Beaver Creek No. 4 PRESSURE-VOLUME VISCOSITY DIFFERENTIAL LIBERATION @ 21 ! °F. RELATION OF OIL PRESSURE (~ 211 °F GAS/OIL RATIO GAS/OIL RATIO RELATIVE OIL PBI GAUGE '' @ 2 11 °F., LIBERATED IN SOLUTION VOLUME, RELATIVE VOLUME OF CENTIPOISES PER BARREL OF PER BARREL OF V/VR OIL AND GAS, V/VSAT. RESIDUAL OIL RESIDUAL OIL , 400 323 300 248 200 182 112 0 2. 1236 2.72 36 3. 7124 0.845 129 253 1.272 0.878 155 227 1.258 O. 935 186 196 1. 240 0.995 225 157 1.212 1. 436 382 0 1. 070 @ 60°F. = l. O00 Gravity of residual oil = 34.0© APl v = Volume at given pressure v,^,. -- Volume at saturation pressure and the specified temperature. v, -- Residual oil volume at 14.65 PSI absolute and 60° F. These analy~ea, opinions or interpretations are based on observations and material supplied by the client to whom. and for who~e exclusive and confidential u~e, this rei~ort is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories. Inc. (all errors and omissione excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations as to the productivity, proper opera- tion, or profitableness of any oil, gas or other mineral well or ~and in connection with which such report is used or relied upon. CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS. TEXAS ..¢ Page File Well 5 .of 9 RFL 73550 Beaver Creek No. 4 Differential Pressure Depletion at Z 1 1 o F. Pressure Oil 'Density Gas PSIG Gms/Cc Gravity 1012 O. 7322 900 O. 7349 O. 797 800 O. 7372 O. 803 700 O. 7398 O. 814 600 O. 7423 O. 830 500 O. 7453 O. 855 400 O. 7486 O. 891 300 O. 7527 O. 954 200 O. 7579 1. 071 li2 0. 7658 1. 378 0 0. 7982 2. 155 Deviation Factor Z O. 921 O. 928 0.935 O. 941 Oo 954 O. 959 O. 970 O. 978 O. 987 These analyses, opinions or interpretations are based on observations and material supplied by the client to whom, and for whose exclusive and confidential use. this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted): but Core Laboratories, Inc. ami its officers and employees, assume no responsibility and make no warranty or representations as to the productivity, proper opera- tion, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. Company Well Field CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS. TF-XAS Marathon Oil Comoany Beaver Creek No. 4 Page 6 of 9 Beaver Creek File RFL 73550 Formation G .- Z on e County State Kenai Peninsula Borough Alas ka HYDROCARBON ANALYSIS OF I MOL I WEIGHT ' COMPONENT PER CENT PER CENT Reservoir Fluid SAMPLE D~ENSITY (~ 60e F. GRAMS PER CUBIC CENTIMETER APl MOLECULAR 60e F. WEIGHT Hydrogen Sulfide Nil Nil Carboh Dioxide 0.05 .. 0.02 Nitrogen 0.97 ,0.20 Methane 15.77 1.85 Ethane 4.09 0.90 P.ropane ' 7.3Z Z. 36 iso-Butane 2.1 3 0.90 n-Butane 5.10 2.17 iso-Pentane 3.07 !. 6 Z n-Pentane 3. Z 0 1.69, Hexanes 3.99 2.50' Heptanes plus 5__4.3___~1 85.79 100.00 100.00 O. 8634 32.2 216 Core Laboratories~ [nc. Reservoir Fluid Analysis P. L. Moses Manager These analyses, opinions or interpretations are based on observations and material supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted); but · Core Laboratories. Inc. and its officers and employees, assume no responsibility and make no warranty or representations as to the productivity, lproper opera- tion, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. CORE LABORATORIES, INC. Petroleum Reservoir Enginec. dng Pcge ~ DALLAS. TEXAS File PRESSURE-VOLUME RELATIONS OF RESERVOIR FLUID 7 __ of__9_ RFL 73550 4.0 Comlc~n y __ Well Field Marathon Oil Company Beaver Creek No. 4 Beaver Creek Formation County_ State G- Z one Kenai Peninsula Borough Alas ka 3.0 o 2.0 :> :> 1.0 0.0 0 500 1000 1500 2000 PRESSURE: POUNDS PER SQUARE INCH GAUGE 2500 3000 8OO 700 600 500 400 300 200 I00 CORE LABORATORIES. INC. Pem~leum Re,era,oil' Eng/necnng DALLAS. TEXAS DIFFERENTIAL VAPORIZATiO?i OF RE.EERVOIR FLUID Page 8 of 9 File RFL 73550 (.'c,,m p~n y ._lki_aj:.a__l;_hon__Oil.__Gompan¥ Formation _._.~,,-_Z. one.._ Well ........ ~._l~.¥~r. (~_r,__e_ek..l'",Io,_4__ ..................... County'_ Kenai Peninsula,___~o. zlo__ugh_ Field ........ .__~_e._av_e._r...._C_ re e k State Alaska 0 500 1000 1500 ZOO0 g500 3000 PRESSURE: POUNDS PER SQUARE INCH GAUGE 1.8 1.7 1.6 1.5 1.4 1.3 1.Z 1.1 1.0 1.6 CORE LABORATORIES. INC. Pe~'oleum Re~er~o~ Enl~meering DALLAS. TEXAS VISCOSITY OF RESERVOIR FLUID Well Beaver Creek No. 4 Field Beaver Creek __ Formation County State Page 9 of ~ File RFL 73550 G-Z one Kenai Peninsula Borough_ Alaska 1.4 1.0 0.6 0.4 O.Z 0.0 . 500 1000 1500 ZOO0 PRESSURE. POUNDS PER SQUARE INCH GAUGE Z500 3000 UNITED STATES DEPARTMENT OF 'I'HE INTERIOR GEOLOGICAL SURVEY P.O. Box 259 Anchorage, Alaska 99510 Marathon Oil Company P.O. Box 2380 Anchorage, Alaska 99510 October{ 25,~ ~]197~3~)~'3~/ ~ ? ~.. ~ .3 r' P . . Attn: Mr. W. L. Kinney Acting Division Operations Manager Gentlemen: Attached is an approved copy of your plan to recomplete and test Beaver Creek Unit well No. 2. In addition to the proposed work on well No. 2,. your'October 12 and October 19, ].973 letters request approval to continue producing Beaver Creek Unit well No. 4 until the No. 2 well is completed, 'to 'test well No. 2 for a reasonable period of time and to further produce No. 4 for pressure interference tests. Excess solution gas would be flared. As we understand your plan, we see no objection to the continued pro- duction of Unit well No. 4 for an additional limited period, a reason- able test period for well No. 2 and limited production for pressure interference tests. However, we ask that you furnish the detailed program for testing well No. 2, continued testing of well No. 4, and the pressure interference tests as soon as possible for our review and final consideration of your proposal. So as to prevent the shut-in of well No. 4 while you are finalizing your plans, the producing test period for well No. 4 is hereby extended until November 22, 1973. As you know, we are much concerned about the flaring and waste of excess solution gas and we cannot allow the was~ of gas over and above that necessary for initial well evaluation tests. It now appears that the added production history from well No. 4 and initial test data from well No. 2 should furnish sufficient information for a reasonably reliable evaluation. We are hopeful that your investigation into the feasibility of injection of the excess solution gas shows that reinjection is a workable solution. We urge you to initiate studies and plans necessary for beneficial utili- zation or conservation of the excess gas since continued flaring beyond that deemed necessary for initial testing and evaluation will not be permitted. If you have any questions on the above, please contact me. Sincerely yours, Attachment Rodney Al, Smith Oil and Gas Supervisor Alaska Area · R.~THONy' MARATHON OIL COMPANY PRODUCTION-UNITED STATES AND CANADA AN CHOI::IA G E DIVISION P.O. BOX AN~I.,I OI~A~ F , ALA SI< A October 19, 1973 Mr. Rodney Smith U. S. Geological Survey P. O. Box 259 Anchorage, Alaska 99510 Dear Sir: As we discussed in our letter dated October 12, 1973, and during the meeting on the same date, we have received enough encouragement from the production test on Beaver Creek Well #4 to be willing to proceed with further devel- opment of the field by recompleting Beaver Creek Well #2 from a shut-in gas well to an oil producer in the G Zone. The recompletion would be followed by a sand fracture stimulation.of the tight portions of the reservoir. We estimate the cost of the recompletion, frac job and additional surface equipment to be about $750,000. We are hopeful the performance of.Beaver Creek Wells #2~ and #4 will justify further development of the field. Our analysis shows that each new well must recover some 1,500,000 to 2,000,000 barrels of oil to be economically feasible. Further, any additional development will require the installation of pipelines to transport the oil and gas. Thus, further development must support not only the approximate $1,500,000 cost of each well but also the estimated $1,600,000 cost of the pipelines. The sooner we can acquire sufficient data to reliably determine recover- able oil reserves per well, the sooner we can justify the very substantial investment required. During the meeting on October 12, you asked how continued production from BC #4 could aid in determining the economic feasibility of further development. Continued production from BC #4 would be helpful in two ways: Mr. Rodney Smith U. S. Geological Survey October 19, 1973 Page 2 (1) The graph, attached to our letter of October 12, showing rate vs. cumulatiVe production, gives some indication that the decline may be leveling off. Additional production could verify the decline rate. (2) At the end of the four-month test period for BC #4, the pressure in the reservoir will be drawn down over an areal extent that is dependent on continuity, permeability and thickness of the producing sands. If production can be continued until completion of the proposed BC #2 workover, valuable information on reservoir continuity, communication between sands, and pressure inter- ference between wells can possibly be gained by observing reservoir pressure drawdown in BC ~2. If BC #4 is shut in at the end of the current four-month test period, the reservoir pressure will have equalized in the one to two months. required for completion of BC #2. We are in the process of preparing a detailed program for (1) testing performance of BC #2 before and after the frac job and (2) testing reservoir characteristics through a series of pulse tests on BC #2 and/or BC #4. We expect to have the test program completed in about two to three weeks. At that time we will be able to determine how much BC #4 should be produced in conjunction'with BC #2 to obtain a' reliable interference test. Tentative calculations show an optimum pulse interval of 3 to 7'days, a lag time of 5 to 25 days,' and a pressure response of 0.05 to 0.5 psi - all depending on average reservoir properties between the wells. We can visualize that BC #4 might need to be produced for any~'here from 7 to 30 days. We will supply you with the detailed test program as soon as it is completed. As you requested, we are investigating further the feasibility of reinjecting excess solution gas. Our main concern is that the fairly rich gas might drop out liquids in the reservoir and cause an irreversible loss of permeability, around the, wellbore. Within the next few days we will obtain a sample of the gas and send it to Core Lab for determination of dewpoint temperature at reservoir pressure. Further, with the aid of a wellbore computer model, we will attempt to determine if a series of injectivity tests can detect liquid dropout before irreparable damage occurs. J t4 '""',' ' ,. ,.'.:, t-,9. f4 '~ ~ ' I"~ I '"~ ~',l'~" ,,...I~' ,~'~ ~ '~',, Mr. Rodney Smith U. S. Geological Survey October 19, 1973 Page 3 In summary, we respectfully request permission to recomplete Beaver Creek Well ~2 and to subsequently production test the well for a reasonable period of time - perhaps 45 days. In addition we request permission to continue producing BC #4 until BC #2 is completed and for a reasonable test period after completion. It will be necessary to flare the result- ing solution gas in excess of fuel requirements unless the aforementioned study shows gas reinjection to be feasible. As you have requested, I am enclosing: (1) All production test data currently available from the four-month test on BC #4. (2) An analysis of the casinghead gas from BC #4. (3) A copy of the contract for sale of Oil from the Beaver Creek Field. Enclosures Yours very tr~y, w. L. Kinney Acting Div. Operations Manag.er .a, For.?, 9-331 IMay 1963) O,L [] WELL SUNDRY NOTICES AND REPORT~ UNITED S'FATES " r~"(Other I.struct[ol}''~ on r~ BudKot Bur.au Nh. 42-R142.1. DEPAR~M~~ r OF THE INTE~..IOx..,.,.r~,~d~.. GEOLOGICAL SURVE~, ~. ' '¢' A-028Z18 ~ IF I~DIAN, ALLOTTE~ 0~ ~RIB~ NAME not use this f.rm D,r hr-! .... al~ t., drill nc t,, d.,,,pen or I,lu~: hack to n different reservoir.. . Use "APPLICATION FOR PEI4MIT--" for such propo.mlm) ~.,. .... - " "' ~.'~ ~ ,O~ ''~ .... . CAS WEI.T, ~ ;_. · ,7' NAME OF' OPER&TOR Marathon Oil Company 7. UNIT ^GREEMENT NAME Bcaver Creek Unit S, FARM OR LEASE NAME Beaver Creek Unit ADDRESS OF OPERATOR 9. WELL NO. P. O. Box 2380, Anchorage, Alaska 9.9510 2 'LOCATION OF WEt, L IliepOrt location clearly and in accordance with any State requirements.* See also space 17 below.) At surface , NE Corner, T6N, R10W, SM 590'S, 1979'W Straight tlole Et. EVATION5 (Show whether DF. RI, (ill etc,) GR 140.3' 14. PER.MIT NO. I 15. State 67-26 . 10. FIELD AND POOL, OR WILDCAT Beaver Creek-G Zone 11. I/tEC., T., R., .~., OR BLK. AND SURVEY OR AREA Sec. 3, T6N, 12. COUNTY OR.PAKIStI/I~. STATE Kenai Boroug¢ AK 16. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data ' NOTICE OF INTENTION TO: TEST WATER SHUT-OFF [ ] PULL OR ALTER CASING FRACTURE TREAT MULTIPLE CO,MPI,ETE 8HOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Test New Zone SUBSEQUENT REPORT OF: WATE~R SHUT-OFF REPAIRINO WELL FRACTURE TREATMENT ALTERING CASIN(I SHOOTING OR ACIDIZING ABANDONMENT* (Other) (~NOT~,: Report results of multiple completloa on Well Completion or U. ecompletion Itelmrt and Lo~ form.) 1'~. DESCRIBE I'P, OI'OSED ¢)g CO.MPLETED OPERATIONS /Clearly state all Imrtinent details, and ,'zive pertinent dates,,lncluding estim~tted date of starting ariy proposed work. If well is directiona, ll¥ drilled, give subsurface locations ~tnd measured and true vertical depths for all markers and ~ones perti- nent to this work.) * I " · It is proposed to initiate operations approximately November l, 1973, to temporarily abandon the existing Beaver Creek gas sand completion using a tie-back 7" liner. The well will then be cleaned out to 14,950' and the G Zone oil sands tested and stimulated by a sand fracturing treatment. ,.:, :. A detailed workover procedure, proposed blow out equipment assembly and schematic diagrams of existing and proposed completion assemblys are attached. · : ,7 _. '-':' '~ :' .". (This space /or F~,c]zl~ or ~tat~ CONDITIONS OF APPROVAL, true and correct ";?'LZ'"?-Z--'~ TITLE Area Superintendent 10-12-73 M .. ~TLE , DATE . ~Se~ Imtr~ctions Reverie Side on ( V.... (""...L ..J,..I..,.J;..I . . . ....;). L. ""'J.. "'I ( Test Data: Company Lease Well No. Field State ð.l¿.I T~/l4I Test Date /~~/b¡l73 Producing Formation G 2t1tYF . Casing Size (I. D. Inches) 7 "3d (~.()lJ¥".£./)) Cum. Prod. Np (bbl) . Stabilized Daily Prod.t¡(B/D) /37.2 .ß,Ø Effective Prod. List t (hr) = 24Np/9 ðEÁ t/ EL C/¡! Olt. -# ¥ !t//L/)C4 r I. Calculation of kh. (md-ft) an~ k (md): It" = "2.l;9~B . m II. t?,? cp " 30 fI: B ~. /,:JD @ ð.p. ~ /.I? ({ / :;, r;2- BID ?n 90 psi / eye-Ie kh = 16,2.~ X 1392- X (tJ, ý' = ?37'1 md. fl.; If - _b.37Y l- 79 rnd. . 9()., - (~o) - Calculation of Skin Effect, s; and Pressure Loss Due töÂP skin (psi): f$ = . S(I?~Ií':m-:-: .1>,., -,of( (~ L:,.~~)t-. 3. 2~ APs/(¡,.,= (mJx O.S7{s) . k rnø t/> p.- I) II. I'w P,h~ Pwf m fI. psig pslg , psi/aydé . cp p!SÎ -I 8 - /.151 let f APISHitt == ()X ( } - 109 ------L- . -1 ( J( )()( )+ a.2~= } = psi III. Càlculation of Productivity Index (BID-psi) and Flow Efficiency: . ~ ~ t¡ J(e.ctl!ot) = P"'*""PwF AP6HltJ . . ---- pSI BID . q "(ideal) = . (P*-Pw9 )-APs/fin .,.,"" . r - ~'9 ~P .~~ c¡ ( . ) J(acfllÞl} = ( ) - ( ) = ( ) cT (¡dlled) =( l - ( ) -= - SIp psi . J(uc'UÞfj Flow Effløltlncy =- .r .. , = " v Oâee.t) BID plsl =. Note: 1. Compressibility is obtained from Ct=So Cø + Swcw+ cf 3~, '7DAf r ~ =.;);)J,(¡F Golt :=; 3t)() IV. Calculation of Average Pressure in Drainage Area A = a~re~ = ,sr.,9. Z = Then from Figur~ 4.3 page 40 in Monograph Vol. 1 read valve ,~ ( ) _ .zo.~ ~'1~ ~/,~ = zeo,~ -= ~;eoe - Ce) )-( )= (c) ~..MARATHON] MARATHON OIL COMPANY PI:::IODUCTION-UNITED STATES AND CANADA ANCHORAGE (DIVISION BOX 2380 ANCHOFIA(~E , ALASKA October 12, 1973 Mr. Rodney Smith U. S. Geological Survey P. O. Box 259 Anchorage, Alaska 99510 Dear Sir: In your letter dated May 15, 1973, you granted permission, subject to certain limitations, to conduct a four-month production testing program on Beaver Creek Well 94 in order to determine the economic feasibility of further development. The attached graph of cumulative production versus daily production rate indicates recoverable reserves from BC #4 of about 1,300,000 barrels at an assumed economic limit of 500 BOPD. The reserves would be increased further if operating exPenses can be reduced to permit a lower economic limit. In comparison, the limited production data prior to the present test showed that recoverable reserves could be as low as 420,000 barrels. Even though the four-month .test period is not yet~.~completed, we have received sufficient encouragement from theY'd<results to date to be willing to proceed with the next step ~f the development program. . We propose to recomplete Beaver Creek Well 92, presently a shut-in gas well comple%e.d in the Sterling Gas Sands, to an oil producer in the G Zon~'~ .............. Furthers, a.s-part of the workover we plan a sand fracture stimulation on the tight portions of the reservoir. A~ detailed workover procedure, proposed blow- out equipment assembly and schematic diagrams of existing and proposed completion assemblies are shown on the attached Sundry Notice, Form 9-331. The purpose of the proposed recompletion is two-fold: I~. ~'~ Mr. Rodney Smith U. S. Geological Survey October 12, 1973 Page 2 (1) The limited test data to date indicates that the tight sands in BC ~4 are making only a minor contribution to production. If these sands can be effectively fracture stimulated, economically recoverable reserves could be increased significantly. (2) Production and testing of BC #2, coupled with continued production of BC #4, will aid in determining reservoir continuity and pressure interference between BC #2 and 94. Production testing of BC #2 and continued testing of BC #4 will hopefully indicate sufficient reserves to justify the drilling of new wells. The decision to drill a new well will be a major one. We must justify not only the approximate $1,500,000 cost per well for one or more new wells, but also the estimated $1,600,000 cost of pipelines to transport the oil and gas. We respectfully request 'permission to continue producing BC 94 and to produce BC #2 for a period of time not to exceed six months following recompletion, until adequate production data has been obtained to confirm the reserves necessary to justify this major investment. We also request permission to flare the resulting solution gas in excess of fuel requirements. during this test period. YO__w.~L. Kinney ~/ Acting Division Operations Manager Attachments MAF:IATH©N OIL C©MPANY APR 2,"1 1973 i*.,/.~.,\!t"t[);.~ OIL f.,~. Anchor c~gt~, Alaska PRODUCTION-UNITED STATES AND CANADA A N C H O I::t A (.~ E B.G. 0 ~ F::: F::I AT I 0 N S M A N A G E F::::1 April 27, 1973 P.O BOX 23~0 ANCHORAGE,ALASKA 9B§I0 Mr. Rodnoy Smith U. S. Geological Survey P. O. Box 259 Anchorage, Alaska 99510 'Re: Permission to Flare Solu~%~r 12 Months from Beaver Creek Unit~/¢ ¥~11 No. 4.? Dear Sir: Reference is made to our letter of April 16, 1973 requesting permission to flare excess solution gas from Beaver Creek Unit, Well No. 4. Pursuant to our telephone conversation of.April 26, attached please find Table I that gives an itemized list of future operating costs and Table 2 containing the details of how we arrived at an economic Ilmit of 500 BOPD. In addition to the test data included in our report of April 16, we have taken two more spot reservoir pressure readings. A static reservoir pressure reading of 66?5 psi ~as recorded on March 20 after 19 days shut in and another reading of 6?78 psi ~as recorded on April I0 after 40 days shut'in. As you know, our plans are to install a rotative gas lift system on this well to prevent flaring of gas well lift 9as. However, it will be necessary to flare the excess solution gas. We have considered various alternatives to flaring the excess 'solution gas' I. Injection of the solution gas into one of the Beaver Creek gas wells has been considered. However, since the excess solution gas will he extremely rlch in liquids, there is a good possibility that the hoavy ends may saturate the formation causing permeability damage in the immediate vicinity of the wellbore. 2. The possibility of using the solution gas as comoressor fuel was also s'fudied. However, the BTU content of the solution gas is much higher than that required for the proper operation of this engine. We have not been able to operate our compressors success- fully with caslnghead gas because of its higher BTU content. There'fore, the solution gas can not be used as fuel. Also, fuel requirements will be only a fraction of the excess solution gas. Mr. Rodney Smith -2- April 27, 1973 3. We have also considered the possibility of laying a pipeline and connecting Beaver Creek to Standard's Nikiskl-Swanson River pipe- line. However, this will involve an investment of about $1.1 mill ion to $1.4 mill ion. Performance to date indicates very limited reserves and we are not able to justify pipeline investment of this magnitude. The pressure data indicates that the remaining recoverable reserves maybe as Iow as 340,000 STB. The remaining life of these reserves is estimated to be about 12 months~ Installation of a rotative gas lift system and other surface facilities will require an investment of about $375,000. Considering the limited amount of recoverable reserves and the high operating costs, this additional investment in compression and other surface facilities can be justi- fied only if the well is produced for 12 months or more. Also, we believe that from 3 to 12 months additional production history is required to fully evaluate the reserve potential of the Beaver Creek Field. Since there is no other alternative, it will be necessary to flare the excess solution gas and we hereby request permission to do so for a period of 12 months. If theYe are any questions, we would be pleased to discuss them at your convenience. .. Very truly yours, Attachments Division Operations Manager TABLE I BEAVER CREEK # 4 MONTHLY OPERATING COSTS Renta Is Tra i l er Portable Air Compressor Test Un It 75 K~I Generator 2 - I000 Gallon Fuel Tanks ~ $25 Fi re Extinguishers Mobile Unit Labor ! 3 Shift Operators and I Roustabout Miscellaneous Fuel Cost ~ 26~/gal Road Maintenance Supervision - Direct - Indirect Compressor Maintenance ~ $3.00/HP/Month (Materials & Labor on 500 HP) DO L LARS/IVO NT ~ t 200 88 3,100 1,100 5O 45 775 7,600 350 10,000 1,860 3,500 1,500 $ 30, 168 TAULE 2 BEAVER CREEK # 4 ECONOMIC LIMIT FOR FLOWRAIE I. Operating Costs/Day 2. Revenues 3. Transportation Cost 4. Override, Ad Valorem Taxes and Severance Taxes $O.16/bbl 5. Net Revenue [$3.20 - ($0.71 + $0.16)] $3.20/bbl $0.71/bbl $ 1,006 $ 2.33/bbl Al lowing for 12.5% royalty, the economic limit for daily flowrate = = zig3 BOPD = 500 BOPD ~0 O · lO X 1{0 TO THE: INCH 46 0703 ~ ~"~'"~' 7 x io INCHES MADE IN UoSoA. e '~' KEUFFEL & ESSER CO. k. 2Zo z_io 2-00 I~0 q~__, .... ~'___~u._ _~_. ........... _------ -----~- ~ r---c- ~ c --_-:zz_-:_-_-- z_-_- -c~__-_-z __-___---~_-:____--: :_-: :': : :_--:---_--:-_-: :: ..... ZZZZZ zZ_~-.3i i Z i ZT~ZZZZZZZ ZEE 1-44 ~Z Z Z Z Z_ F---i ZZZZZZZZZ~EZZ ............ _- Z-'Z ::::::::::::::::::::::::::::::::: _-__-_-__-:::_:__-:: :_:::':~-: ~:::::-::_::: ...... -____::::::: ...... ,, , / " JJ~H III I - _ ...... ~,__- ................. ~.~ ...... ~_- ......... ~ ........... ~.~'-:_----~ ...... _-__ ........ ~ ----_.~ ................. IZ-~.~...._~ .... :____'n ....... ..p .......... ~..-____ p~:_-_-----: :-~z~_-::::::::: :_--:-:~:: .......................... 7-~- zz-z-z ~-- z-_-- :- :::::::::::::::::::::: -~-' --- ---'-- ---~ ----. _ _:_ ......... - .... - .... ' 0 I 7D3~ 7,5/0 ~ ~3,o0 7%cD / 2,2 ?~,od'- ~o,o~ //.off- .33 2__.) /.S . //.2 J ~.. aC' -/4JYV2 [o 1 / ~ t/q.o ,:po · ~ %0o /o~,.~z. 223Cqz 2_, 11 ~? 7 f 1578' :oK MARATHON OIL COMPANY PF:IOI_-)UCTION-UNITED STATES AND CANADA ANCHORAGE OPERATION lB MAN~,GER r~,O. BOX 2380 ANOHORAGE . ALASKA I~ 19 ~ 10 April 16, 1973 Mr. Rodney Smith U.S. Geological Survey P. O. Box 259 Anchorage, AK 99510 Re: Permission to Flare Solution Gas · ' from Beaver Creek Unit, Well No. 4 Dear Sir: Reference is made to your letter of January 15 granting Marathon Oil Company, as operator, permission to flare gas well lift gas and solution gas from Beaver Creek No. 4 well for a period of 30 producing days and subsequently extended by three additional days in your letter of February 26, 1973. We produced the well a total of 33 days after January 15. During that time we conducted a three-day buildup test followed by a 10-day drawdown test and then a 9-day buildup test for the purpose of evaluating the well and reservoir. A report contain- ing all the test data, analysis of the data and our conclusions is enclosed for your information. The pressure data shows layer- ing effects and indicates remaining recoverable reserves may be as low as 340,000 STB. Additional production history is required to establish a more reliable reserve estimate. We expect the well will have to be produced at maximum rate for at least three more months to achieve any significant improvement in the accuracy of prediction of recoverable reserves. .We and the other participants have invested over $2 million in this exploratory well and based on its performance to date have no hopes of recovering the cost. However, since we feel that further production is required to fully evaluate the potential of Beaver Creek Field oil reserves, we plan to install a rotative gas lift system on this well to prevent flaring of gas well lift gas even though the economics of this installation would normally be unacceptable. Prior to resuming full production from the well, we plan to per- forate approximately 70-90 feet of additional section of the G-zone. It will be necessary to flow the well at moderate rates Mr. Rodney Smith Aprill6, 1973 during perforation operations and for one or two days after per- forating for cleanup. We then expect to shut the well in until installation of the gas lift compressor and other necessary surface facilities are completed; we estimate we will be prepared to'open the well for production on about May 1.5, 1973. It will be necessary to flare the excess solution gas as there are no disposal facilities available and we hereby request per- mission to do so. We would be pleased to discuss the attached report at your convenience. ~,' Very truly yours, Enclosure B ."-' G. Howard Division Operations Manager REPORT ON THE EVALUATION OF BEAVER CREEK UNIT ~;'ELL NO. 4 TO U. 8. GEOLOGICAL' SURVEY ANCHORAGE, ALASKA PREPARED BY iVIARATHON 0 IL COMPANY APR IL 16, 1973 BEAVER CREEK UNIT WELL NO. 4 MARATHON OIL COMPANY Marathon Oil Company's Beaver Creek Unit Well No. 4 was spudded on June 12, 1972, and it was completed on January 14, 1973, as an oil producer. A total of 6 drill stem tests were conducted on this well during the month of December 1972; 3 in the Hemlock, . . and 3 in the G Zone. DST's 4 and 5 in the G Zone were oil tn~ wellbore productive and are the only intervals now open into ~ = . All of the DST data has been forwarded to the U.S.G.S. Appendix A shows a summary of our analysis of DST's 4 and 5. The analysis shows that the average reservoir pressure calculated during DST 4 was about 7500 psi and the average reservoir pressure determined from DST 5 was about 7650 psi. This reversed pressure gradient' is evidence that the intervals are not in communication or the pressure would have equalized over geologic time. The DST 4 interval has a much higher permeability (80 md) than the DST 5 interval which has a permeability of only about 2 to 3 md. It was noted that DST 4 data showed a decreasing reservoir pressure during the DST suggesting a limited reservoir. After producing a total of about 9000 STB of oil, the well was shut in for a week in January. The measured static reservoir pressure after shut in was 7225 psi or 275 psi less than the original reservoir pressure in the DST 4 interval. This reduction was further indication of a limited size reservoir. In an effort to evaluate the extent of the reservoir, a series of transient tests were conducted on the well. A 3-day buildup test was conducted in February 1973, followed by a 10-day drawdown test · at a producing rate of about 2500 BOPD, and then a 9-day buildup test. Appendix B shows the data for the 3-day buildup test, Appendix C shows the data for the drawdown test, and Appendix D shows the data obtained during the 9-day buildup test. · . Both the 3-day and 9-day buildup tests show that at least' two layers are contributing to production and that the layers are not communicating in the reservoir. The layering effect makes it impossible to determine an accurate average reservoir pressure that can be used for the determination of recoverable reserves. Data from the 10-day drawdown 'test show that the reservoir had not reached pseudo-steady state at the end of the drawdown period. This does not necessarily indicate a large reservoir, but instead may merely reflect the longer time required to achieve pseudo- steady state in a layered reservoir with a high ratio of permea- bility between layers. Assuming that the well is producing from the center of a circular area, our analysis of the data shows that at the termination of the drawdown test, the area of drainage for the well was only 350 acres; for a non-circular area or an off-, center location, the area would be less. In short, the series of transient tests do not provide sufficient data to allow us to determine recoverable reserves with any reason- able degree of accuracy. The drawdown test does give an indication of the minimum areal extent of the reservoir from which oil in place can be estimated; however, the important question of recovery effi- ciency cannot be answered. The recovery efficiency in the low permeability zone will probably be very low. We feel that the best method of determining a reliable .estimate of ultimate oil recovery from Beaver Creek Well No. 4 is to obtain sufficient pro- duction history to allow a reasonable extrapolation of the cumulative production vs. rate curve to abandonment rate. £~.~ }~i? ~ '~ ~o,?~ At present we are limited to the prediction of reserves by applying an approximate barrels/psi figure to the estimated ultimate draw- downs. Our economic analysis shows that the economic limit on this well will be about 500 BOPD, which corresponds to a reservoir pressure of some 2500 psig for an ultimate drawdown of approximately 5000 psig. Probably the best method of calculating recovery per psi of drawdown is to compare the 7-day shut-in pressure obt'ained in January and February. In January, with a cUmulative production of 9280 barrels, the 7-day shut-in pressure was 7225 psig. 'In Feb- ruary, with a cumulative production of 80,091 barrels, the corres- ponding pressure was 6385 psig. Thus production of 70,820 barrels resulted in a pressure decline of 840 psi or about 84 barrels/psi. Ultimate recovery would then be 420,000 barrels of which 80,000 has already been produced leaving a future recovery of 340,000 barrels. We estimate that the remaining life would then be about 12 months. Since we feel that additional production is required to fully evaluate the potential Beaver Creek reserves, we plan to install a 5000 barrel storage tank and an ACT unit to reduce transporta- tion costs and to install a rotative gas lift system to prevent flaring of gas well lift gas. Following is a brief economic analysis of the proposed plan. Investment 1 - 5000 Bbl. tank $ 50,000 1 - 500 HP compressor 300,000 1 - ACT unit 25,000 Total $ 375,000 Operating Cost/12 months $ 360,000 Transportation Cost @ $0.65/bbl. $ 221,000 Provision for royalty and tax payments brings the total cost to $1,105,500. Gross income at $3.20 per barrel will total $1,088,000 for an overall loss of $17,500. We believe the need for evaluation of this well is sufficient to justify the operation outlined even though it is not expected to generate a profit. A somewhat more optimistic figure for barrels/psi can be obtained by using data from the 3-day and 9-day buildup tests run during February: The difference in cumulative production between the two tests is 32,300 barrels. At corresponding times after shut-in, the tests show about 300 psi difference in pressure. The extra- polated ultimate pressure difference is 335 psi, which calculates to be 96 barrels/psi. This would increase recoverable reservo~ to 480,000 barrels, but the overall economic analysis would not be cha~ged appreciably. APPENDIX k APPENDIX A SUMMARY DST'S 4 & 5 DST #4 DST #5 Reservoir Perforated Intervals G-Zone 15155-175 15190-200 G-Zone 15060-72 15082-100 Total Fluid Prod., Bbl. Est. @/D Rate Gauge Depth Ft; I FP FFP FSIP P k DR bPs rd · . (30') ., 1244 (Mostly Oil) 1392 BO 4636 (I hr) 7493 (2) 5908 (21.3) 7385 (15) ~415 8O 2.42 885 1300' (30') 5O Bbl/ 9 hr. Oil &O & GCM .. .133 BO 15021 1392 (I hr) 7565 (2) 1724 (9.3) 7629 (16) 7670 3.2 5.3 4825 200' APPENDIX B · " 272-5966 / Reservoir Pressure & Temperature Data Individual Well Data Sheet Company. , Well BC -4 \ MARATHON OIL COMPANY Platform // Field 487 Southampton Dr. Anchorage, Alaska Borough Formation BEAVER CREEK WI LDCAT State_. ALASKA Date 11-14 FEB 1973 CHRONOLOGICAL DATA GAUGE GAUGE #25519-N #25518-N DATE TIME REMARKS FEB 11 1973 09:00 WELL IN TEST 10:00 RIGGING ON WELL 11: O0 " 12: 00 PRESS TEST LUBR. 13: 00 " BHPD BHP~ BHP~ BHP~ ELAPSED OIL H20 GAS GAS FOP~M TBG CSG R.D. R.D.M.P. DATUA~ TIME PROD PROD OUT VOL GOR PRESS PRESS TVD .TVD TVD HR. MIN BOPD BWPD MCFD MCFD.SCF/B T~IG PSIG 14908 14914 14930 -148C · 00:00 01:00 02:00 03:00 04:00 14:00 STARRED G.L. CHECK 05:00 15:00 RUNNING G.L. CHECK 06:00 16:00 " 07:00 17:00 FINISHED G.L. CHECK 08:00 18:00 CHANGED TO 72 HR. CLOCK 09:00 19:00 RUN,DEPTH 15114 10:00 20:00 ON BTM. FOR FLOWING PSI 11:00 21:00 FLOWING PRESS. 12:00 O. 2542 1881 0 2542 1902 0 2555 1892 0 . 2555 1892 0 2569 1913 0 2269 1913 0 2269 1913 0 2555 1925 0 2555 1914 118 1378 118 1378 118 1378 118 1378 118 1378 118 1378 118 1378 118 1378 118 1378 3280 3285 3297 3280 3285 3297 0 2633 1892 0 2605 1913 118 1345 118 1345 3273 3281 3286 3299 0 2528 1913 0 2528 1913 11.8 1345 3273 3281 3286 3299 125 1345 3273 3281 3286 3299 (12) HR. AVERAGE 2450 '2562 1906 267 118 1368. 3273 3281 3287 3298 21:40 SH~T IN GAS LIFT '22:00 SHUT IN WELL 22: 06 BUI ID-UP 22:12 '" 22 18 " 22: 24 · " 22:30 ~ "' 22:36 " . 22: 42 " 22:48 " 22: 54 " 23: O0 23:15 " ' 23:30 " 23:45 " 24: O0 " FEB 12 1973 00:15 " 00:30 " 00:45 " 12:40 0 0 13:00 2450 0 2~01 0 00:06 ' 00:12 O0:J8 00:2/+ 00:30 00:36 O0: 42 00:48 O0: 54 01: O0 01:15 O1:30 01:45 02: O0 02:15 02:30 02:45 3293 3301 3306 3318 106 1355 , 3154 31,65 3170 3187 1312 3245 3254 3259 3271 1312. 3388 3399 3404 3394 131,2 3670 3679 3684 3696 1312 3913 3924 3929~ 3941' 1312 4276 4286 4291' 4303 1312 4515 4526 4531 2+543 1321 4726 4735 4740 4753 1312 4942 4951 4956 4968 1312 5115 5126 5131 5143 1312 5259 5269 5274 5286 1312 5470 5481 5486 '5498 1312 5556 5565 5570 5582 1312 5599 5610 5615 5627 1312 5623 5633 5638 5650 1312 5647 5658 5663 5675 1312 5666 5676 5681 5693 1312 5681 5691 5696 5708 " 272-5966 \./ Reservoir Pressure & Temperature Da v Individual Well Data Sheet 487 Southampton Dr. Anchorage, Alaska / Company. Well., MARATHON OIL COMPANT BC -4 Field WI LDCAT Platform . BEAVER CREEK .State_.. ALASKA Borough , .. Formation__ __Date.. 11-14 FEB 1973 CHRONOLOGICAL DATA GAUGE GAUGE #25519-N //25518-N DATE TIME P~[ARKS 01: O0 BUI ID-UP 01: 30 " 02: 0O ', 03: O0 " 04: O0 ,, 05: O0 ,, 06: O0 " O?: O0 " 08: OO " 09: O0 " 10: O0 " 11:00 " 12:00 " 13: O0 ' " 14: O0 " 15: O0 " 16: O0 " 17:00 '" 18:00 " 19: O0 " 20: O0 ' " 21: O0 " 22: O0 " 23: O0 " 24i00 . " FEB 13 1973 01: 00 ,, 02:00 ,, 03: O0 ,, 04: O0 " 05: O0 " 06:O0 "' ,. 0'7: O0 " 08: O0 " 09:00 " , i 0: O0 " 11: O0 ,, 12: O0 " 13:00 " 14:00 ." BHP~ BHP~ BHP~ BHP~ ELAPSED OIL H20 GAS GAS FOP~M TBG CSG R.D. R.D. R.D. DATUM TIME PROD PROD OUT VOL GOR PRESS PRESS TVD TVD TVD HR. MIN BOPD BWPD MCFD MCFD SCF'B~IG PSIG 1L,~08 i 1 1, 0 -1 80C . 03:00 03:30 04: O0 05: OO 06: OO '07: O0 08: O0 09': O0 10:00 11:00 12:00 13:00 14:00 15:00 16i00 17:00 18:00 19:00 20: O0 21:00 , 22: O0 23:00 24: O0 25:00 26:00 27:00 28:00 29:00 30:00 31:00 32:00 33:00 34:00 35:00 36:00 37:00 38:00 39:00 40:00' 1312 5690 5701 5706 5118 1312 5709 5720 5725 5737 1312 5729 5739 5744 5756 1312 5753 5752 5757 5769 1312 5777 5788 5793 5805 1312 5801 5812 5817 5829 1312 5815 5827 5832 5844 1312 5834 5845 '5850 5862 1312 5853 5863 5868 5880 1312 5872 5881 5886 5898 1312 5887 5898 5903 5915 1312 5906 5916 5921 5938 1312 5920 5929 5934 5946 1312 5930 5939 5944 5956 1312 5944 5943 5948 5960 1312 5954 5962 5967 5979 1312 5968 5977 5987 5994 1312 5978 5987 5992 6004 1312 5988 5998 6003 6015 1312 5997 6006 6011 6023 1312 6007 6015-6020 6032' 1312 6016 6025 6030 6042 1312 6026 6035 6040 6052 1312 6036 6046 6051 6063 1312 6045 6054 6059 6071 1312 6055 6065 6070 62+82 1312 6064 6075 6080 6092 1312 6074 6084 6089 6101 1312 6084 6095' 6100 61i2 1312 6093 6103 6108 6120 1312 6103 6113 6118 6130 1312 6112 6121 6126. 6138 1312 6117 6126 6131 6143 1312 6127 6137 6142 6154 1312 6136 .6145 6150 6162 1312 6146 6154 6159 6171 1312 6151 6160. 6165 6177 1312 6155 6164 6169 6181 1312 6165 6174 6'179 6191 Area Code 907 ~.~[...J ',, ~qi, lt.~ ~;~ \ Reservoir Pressure & Temperature Data 272-5966 ~.,'" Individual Well Data Sheet 487 Southampton Dr. Anchorage, Alaska Company MARATHON OIL COMPANY Well BC -4 Borough Field Formation Platform WI IDCAT BEAVER CREEK State A[ASKA Date 11-14 FEB 1973 DATE TIME .,. Rt~, ~ P~S 15:00 16:00 17:00 18:00 19:00 20: O0 21:00' 22: O0 23: O0 24:00 FEB 14 1973 ,01: 00 " 02: O0 " 03:00 " 04: O0 " 05: O0 " 06: O0 " O?: O0 " 08: O0 " 09:00 "' 10:00 '" 11:00 ' " 12: O0 " 13:00 ' " 14: 00 " 1 5:00 " 16: O0 " 17: O0 " 18: 00 " 19: 00 " 20: O0 " 21: 00 " · 22: 00 " BUIlD-UP I! II I! II 1! CHRONOLOGICAL DATA ELAPSED OIL H20 GAS FAS. FORM TBG CSG TIME PROD PROD OUT VOL GOR PRESS PRESS HR. MIN, BOPD BWPD MCFD ~CF~D S,CF/'B PSIG, PSIG 41:00 42:00 43:00 44:00 45:00 46:00 47:00 48:00 49:00 50:00 51:00 52:00 53:00 54:00 55:00 56:00 57:00 58:00 59:00 60:00 61:00 62:00 63:00 64:00 65:00 66:00 6?:00 68:00 '69:00 ?0:00 71:00 7Z:O0 1352 i312 1312 1312 1312 1312 1312 1312 1312 1312 1312 · GAUGE #25519-N GAUGE //25518-N BHB~ R.D. TVD 147o8 BHB~ BHP~ BHY~ R.D. R.D. DATUM TVD TVD 1,491414930-14800 6170 6178 6183 6195 6175 6183 6188 6200 6184 6193 6198 6210 6194 6203 6208 6220 6203 6212 6217 6229 6208 6217 6222 6234 6213 6221 '6226 6238 6218 6226 6231 6243 6223 6231 6236 6248 6227 6234 6239 6251 1312 6232 6240 6245 6257 1312 6237 6245 6250 6262 '1312 6242 6250 6255. 6267 1312 6247 6254 6259 6271 1312 6251 6259 6264 6276 1312 6256 6264 6269 6271 1312 6261 6269 6274 6286 1312 6271 6279 6284 6296 1312 6275 6285' 6290 6302 1312 6285 6294 6299 6311 1312 6290 ' 6299 6304 6316 1312, 6295' 6304 6309 6321 1312 6299 6308 6313 6375 1312 6304 6312 6317 6329 1312 6309 6318 6323 6335 1312 6314 6322 6327 6339 '1312 6319 6329 6334 6346 1312 6328 6338 6342 6354 1312 6343 6344 6349 6361 1312 6352 6362 6367 6379 1312 6362 6372 6377 6389 1312 6371 6380 6385 6397 APP Area Code 907 ~-"-'"'----~__ ( 272-5966 \/, Reservoir"~ Pressure & Temperature Dalai · Individual Well Data Sheet 487 Southampton Dr. Anchorage. Alaska Company, MARATHON OIL COMP.~NY ,Platform Well BEAVER CREEK NO. 4 Field WILDCAT Borough Formation BEAV~ CREEK State. __ ALASKA ~.Date ' 17 FEB 1973 C H R O N O LO G I C A L D A T_A GAUGE · GAUGE #25519-N #25518-N DATE TIME ' RF~MA RKS BHF~ BHB~ BHP~ ELAPSED PROD GAS INJECTED TBG CSG R.D. DATUM M.P. TIME tLATE VOL VOL GOR PRESS PRESS TVD -1480OTVD TVD HH.~N ~O?D M¢?P MOFD SCF/~ ?Sm ?S%S 1~957 ~47~) ~4930 17 FEB 1973 07:00 GAS LIFTING,IN TEST 00:00 2420 '2408 1849 231 08:00 SHUT IN GAS LIFT,WELL FLOWING 01:00 1450 714 S.I. 492 09:00 WELL FLOWING 02:00 1433 313 " 218 10: O0 " 03: O0 lf+67 313 " 213 11:00 RIG LUBR. ON WELL 04:00 1700 313 " 184 12: O0 PRESS TEST. LUBR. 2500 PSI 05:00 1594 329 " ° 206 13: O0 WELL FLOWING 06: O0 1630 329 " 202 14:00 " 07:00 1607 329 " 205 15:00 " 08: O0 1638 329 " 201 16: O0 RAN TANDEM GAUGES TO R.D. 14965 T.V.D.,15167 M.D. 09: O0 1628 329 " 17:00 GAUGE ON BTM. 72 HR. CLOCK 10:00 1617 313 " 194 18:00 S.I. IN //2 FLOW LINE11:00 1609 313 " 195 19:00 WELL FLOWING 36.7 GRAV. 12:00 1613 313 " 20:00 STARTED ADJ. CHOKE 13:00 1408 313 . " 21:00 WELL FLOWING 14:00 1535 313 " 22:00 " 15: O0 1537 297 " 23: O0 " 16: O0 1537 280 " 24:00 "., 36.7 GRAV. 17 :bo 1524 264 " · 18 FEB 1973" 01: O0 " 18: O0 1517 115 " 02:00 " 19:00 1391 115 " 03:00(FORMATION GAS & GOR INACCURATE 20:O0 1510 812 " 04:00 DUE TO PAt~IALLY FROZHN FLARE LINE) 21:00 1410, 1003 II 22:00 1570 1003 " 23: O0 126~ 1003 " '24:00 . 1292 1.003 " 25:00 1312 1003 "' 26:00 1335 1003 " 27:00 1277 1003 " 28:00 1307 1003 " 29:00 1307 1003 " 30:00 .1'-3-17% 1003 " 05: O0 WELL FLOWING 06: O0 " 07: 00 ' " : 08: 00 '" 09: O0 " 10:00 " 11: O0 " 12: O0 " 13:00 " "'"' 115 1378 20 1328 39 1312 39 1328 39 1328 39 1345 39 1345 39 1345 39 1348 202. 39 1348 194 222 204' 193 182 173':" 51 39 1348 4419 4428 39 1348 4490 4498 · 39 1348 4505 4512 39 1348 4505 4512 45 1312 4505 45t2 45 1312 4509 45i7 51 1312 4514 4522 1312 4519 4527 76 80 1345 4532 4541 83 135 1312 4555 4564 538 135 1312 5011 5020 711 88 1312 4674 4682 639 80 1345 4590 4597 793 125 1345 4711 4719 776 125 '1345 4763 4771 .764 125 1345 4768 4776 751 125 1345 4768 4776 785 125 1345 4772 4780 767. '125 1345 4772 4780 767 125 1345 4772 4780 762 125. 1345 4772 4780 ; 4416 4486 4500 45OO 45OO 4505 4510 4515 4529 4552 5008 4670 4585 4707 4759 4764 4764 4768 4768 4768 4768 272-5966 \./ Reservoir Pressure & Temperature Data lndi¥iduol Well Data Sheet 487 Southampton Dr, Anchorage, Alaska Company, MARATHON OIL COMPANY Platform Well.. BEAVER CREF~K NO. 4, Borough .... , Field. .~/Z LDCAT Formati~ BEAVER CREEK State .... ALASKA Date 17 FF.F~ 19'73 CHRONO LOGI CA L DAT'A GAUGE GAUGE #25519-N //25518-N DATE .TI.ME RE~t~RKS 14:00 WELL FLOWING .15: 00 " 16: O0 " 17: 00 " 06 07 08 ELAPSED PROD TIME RATE HR. NIN BOP,,D 31:00 32:00 33:00 34:00 35:00 36:00 37:00 38:00 39!00 40:00 41:00 18:00 " 19; O0 " 20: O0 " 21: 00 " 22: 00 " 23: O0 " 24: OO " 19 FEB 1973 01: O0 " 42: O0 02:00 ' " 43:00 03: O0 " 44: O0 04:00 " 45: O0 05:00 PINCHED WELL BACK TO 1400 B/D 46: O0 : O0 WELL FLOWING 47: O0 : O0 " 48: O0 :00 " 49:00 GAS . INJECTED VOL VOL GOR , MCFD ,,MCFD SCF/B BHP~ BH?~ BHP~ TB('~ CSG R.D. DATUM M.P. PRESS PRY_SS TVD -14800TVD TVD PSIG PSIG 14959 14965 14930 1309 1003 S.I. 766 125 1314 1027 " 782 125 1316 1027 " 780 i25 1316 1027 " 780 125 1312 1027 " 783 125 1324 992 " 749 125 1303 992 "i 761 125 1318 992 "° 753 125 ; 1320 992 " 751, 125 1320 1038 " 786 125 1358 1038 " 764 , 125 " 788 125 " 713 125 " 733 125 ' " 744 125 · " 811 125 " 778 1 25 " 760 125 " 770 125 " 705 125 O9 10 11 12:00 13:00 :00 " 50 :00 OPENED UP #2 FLOW LINE 51 :00 STAI~ED' GAS LIFTING OO :00 GAS LIFTING 01 " 02 " 03 1347 1061 1488 1061 1447 1061 1457 1084 1336 1084 1394 1084 1427 1084 1407 1084 14:00 15:00 16:00 17:00 18:00 19:00 20: O0 " 21:00 " 22: O0 '" 23:00 ' " 24:00 . " 20, FEB 1973 : O0 1538 1084 :00 1321 1084 '" 821 :00 :00 1751 189 108 :00' 2?8? 28?0 1153 616 :00 2452 2175 1254 3?6 04:00 2424 2147 1254 368 05;00 2520 2623 1657 383 06:00 2530 28?6 1902 385 07:00 2509 2906 1924 391 08:00 2491 29O6 1924 394 09:0O 2498 2906 1935 389 10:00 2-448 2906 1935 39? 11:00 2452 2906 1935 396 12:00 2441 2906 1935 398 13:00 2452 2936 1935 408 14:00 2409 2936 1935 416 · 1345 4777 1345 4777 1345 4777 1345 4777 1345 4777 1345 4777 1345 4777 1345 4777 1345 4777 1345 4777 1345 4777 4785 4773 4785 4773 4785 4773 4785 4773 4785 4773 4785 4773 4785 4773 4785 4773 4785 4773 4785 4773 4785 4773 1345 4777. 4785 4773 1345 4777 4785 4773 1345 4777 4785 4773' 1345 4777 4785 4773 1345 · 4829 1345 4829 1345 4829 1345 4829 1345 4829 4837 4825 4837 4825 4837 4825 4837 4825 4837 4825 125 1345 4829 4837 4825 80 1378 4682 4691 4679 157 1378 3503 3512 3500 80 1361 3474 3483~ 3471 80 , 1361 3479 3488 3476 97 1361 3427 .3436 3424 97 1361 3399 3408 3396 97 1361 3381 3390 3378 97 1361 3365 3375 3363 97 1361' 3362 3371 3359 115 1378 3350 3361 3349 115 1378 3342 3352 3340 115 1378 3337 3347 3335 125 1378 3334 3343 3331 125 1378 3329 3338 3326 ""\ / 'Reservoir Pressure & Temperature Data 272-5966 Individual Well Data Sheet 487 Southampton Dr. Anchorage, Alaska Company. Well Borough · . · MARATHON Ol L COMPANY BEAVER CREEK NO. 4 Field Formation, Platform BEAVER CRE~K State ALASKA Date 17 FEB 1973 C H RO N 0 L,,O G I C A L D A T A GAUGE #25519-N GAUGE //25518-N DATE TIME RL-MARKS ELAPSED PROD GAS INJECTED TIME RATE VOL VOL HR. MIN,, BQPD MCFD .... MCFD O2:00 GAS LIFTING, 03: O0 " 04: O0 " 05: OO " , 06: O0 '" O?: O0 " 08: O0 " 09:00 " 10: O0 " 16:00 2666 2921 1935 17:00 2659 2876 1935 18:00 2515 2876 1935 19:00 2676 2921 1935 20:00 26,35 2921. 193.5 21:00 2647 2921 1935 22:00 2673 2876 1828! 23:00 2594 2847; ,1828' 24:00 2702 2847 182~ ' 11:00 RECALIBRATE TURBINE METER ON SEP. 25: O0 12: O0 " 26: 00 13: O0 GAS LIFTING 27: O0 14: O0 " 28: O0 1 5: O0 " 29: 00 i6:00' PULLED ~RESS. GAUGES 30:00 17: O0 ON BTM. WITH PRESS. GAUGES 31:00 18: O0 GAS LIFTING 19:00 " 20: O0 " 21:00 ' i, 22: OO " 23: O0 " 24: O0 " 21 FEB 1973 01: OO " 02: O0 " 03: O0 " 04: O0 "' 05:00 " 06: OO " 07: O0 " 08: OO "' 09:00 " 10: O0 " 11 :O " 12: O0 " 13:00' "' 32: O0 33;O0 34:00 35:00 36 :OO 37:00 38:00 39:00 .. 40:00 41: 00' 42:00 43:00 44:00 ,45: O0 6:oo · 47: O0 48:00 49:00 50:00 .51:00' 2558, 2817 1828 2570 2817 1828 2160 2817 1828 2378 2817 1828 2376 1817 1828 2395 2871 2383 2774 2362 2832 2369 2832 2371 2832 2369 2832 2371'! 2832 236]'~ 2862 2371 2876 BHR~ BHP~ TBG CSG R.D. DATUM GOR PRESS PRESS TVD -14800TVD SCF/B .... P~.IG PSIG, 1A959, .14965 370 115 1378 3324 3333 354 115 1361 3324 3333 374 125 1378 3319 3328 368 125 1378 .3319 3328 374 125 1378 3319 3328 372 115 1378 3315 3324 392 1061 1361 3309. 3319 593 106 1361' 3309 3319 377 106 1361 3309 3319 Bt{P~ M.P. TVD 1~930 3321 3321 3316 3316 3316 3312 3307 3307 3307 386 106 1361 3309 3319 3307 384 106 1361 3309 3319 3307 457 106 1361 3309 3319 3307 415 106 1361 3309 3319 3307 416 106 1361 3309 3319 3307 1828 412 106 136'1 3309 3319 3307 1828 1839 1839 1839 1839 1839 189'2 1892 106 1361 3307. 3316 3304 106. 1361 3305 3314 3302 106 1361 3303 3311 3299 115 1361 3303 3310 3298 106 1361 '3302 3309 3297 106I' 1361. 3302 3309 3297 115. 1361 3302 3309 3297 115 1361 3299 3307 3295 125 1378 3296 3304 115 1378 3295 3302 115 1378 3293 3300 115 1378 3292 '3299 115 1378 3290 3297 115 1378 3287 3295 115 1378 3286 3294 115 1361 3286 3294 115 1361' 3284 3293 115 1361' 3282 3290 115 1361 3282 3290' 11 5 1361 3280 ,3289 115 1361 3279 3288 396 420 419 418 419 418 41o 415 2404 2876 1892 409 2Z,.02 2876 1892 409 24.02 2876 1892 409 2397 1847 1892 398 2399 2862 1892 404 2397 2862' 1892 404 2404 2862 1892 403 '2402 2862 1892 403 2402 2862 1892 403 2404 2862 1892 403 2402 2862 1892 403' 2397 2876 1892 410 2390 2862 1892 405 3292 329O 3288 3287 3285 3283 3282 3282 3281 3278 3278 3277 3276 272-5966 Reservoir Pressure & Temperature Data Individual Well Data Shc-e! 487 Soulhampton Dr. Anchorage, Alaska Company., MARATHON 0IL COMPANY Platform . Well ...... _ BO_ -4 ' Field WILDCAT Borough ..... ' . Formation . . ... BEAVER CREEK . State_ ALASKA Date .... 17 FEB 1972 C H RO NO LO G ILC. A.,,L' D A T A GAUGE GAUGE #25519-N #25518-N ELAPSED PROD' GAS INJECTED .TZ..~ _ . P~,,. P~S ........ HR. MIS B.O..PD , MCED ,,, __ 14:00 GAS LIFTING 15: O0 ,, 16:00 ,. ,, 17: 00 ,,' 18: O0 ,, 19: O0 , 20: 00 ,, 2'1: 00 ,, 22:00 ,, ' 23: O0 ,, 24: O0 22 FEB 1973 · 01: O0 " 02: O0 ', 03: O0 " · b, 04: 00 " .' 05:00 ." .. 06: O0 ' ', 07: O0. " 06: O0 ' . " 09:00 '" ' 10 !O0 " 11: O0 ', 12: O0 " ,. 13:00 " 14: O0 " , 1 5: O0 ' " 1.6: O0 " 17: O0 ,, 18:00 ,, 19:O0 ' ,' 20: O0 ' . " 21: O0 " 22: 00 ,, 23: 00 " 24:00 " 23 FEB 1973 52:00 2395' 2862 53:00 '2384 2862 54:00 2380 , 2862 55:00 2385 ~ 2817 56:00 2407 2787 57:00 2351 2811 58:00 2370 . 284.7 59:00 2373 2847. 60:00 2368 2847 61: O0 2370 2847 62:00 2368 284? 63:00 2358 2847 64:00 2354 2862 65:00 ~2356 2862 66:00 .. 2354' 2862 67:00 2358 2847 68:00 2358 2847 69: oo .2358 2847 BHP~ BHY~ BHK TBG CSG R.D. DATUN M. P, VOL GOR PBZSS PRESS TVD-lZ+SOOTVI) TV]3 MCFD SCF/B... PSIG_ PSIG 14959 J49.6>. 14930 1892 1892 1892 1892 1892 1881 1892 892 , 892 1892 1892 1892 1892 1892 1892 1892 1892 405 115 1361 3278 3287 3275 406 115 1378 3276 3285 3273 407 115 1378 3276 32~5 3273 387. 115 1~78 3276 3265 3273 371 115 '1378 3274 3283 3271 395 ' 115 1378 3272 3281 3269 402. 115 1378 ' 3271 3280 3268 462. 125 1361 3270 3279 3267 402. 115 1361 3270 3279 3267 402 125 1361 3269 3277 3265 403 125 1361 3267 3275 3263 405 125 1379 3265 3273 3261 412 125 1379 3265 3272 '3260 '411 125 1379 3265 3272 3260 412 125 1379 3262 3269 '3257 405 115 1361 3262 3269 3257 405 115 1361 3262 3269 3257 1892 405 115 1361' 3260 3268 3256 70:00 2361 2847. .1892' 404 115 1361 3259-3267 3255 71:00 2395 2847 1892 398 115 1361 3259 3267 3255 72:00. 2356 2847 73:00 2356 2862 74:00 · 2356 2876 75:00 2356 2876 76:00 23/J+ 2876 77:00 2334 2876 78:00 2334 2847 79:00 2327 2773 1892 1892 1892 1892' 1892 1892 1892 1892 80:00 2307 2862 1892 81:00 2320 2781' 1892 82:00 2322 2766 1892 83:00 2322 2766: 1892 84:00 2322 2743 , 1892 85:00 2320 2773 1892 86:00 2332 2773 1849 405 115 1361 3258 3265 3253 411 115 1361 3258 3265 3253 .417" 115 1361 325.5. 3261 3249 417 115 1361 3251 3259 3247 419 115 1361 3251 3259 3247 421 115 1361 3249 3257 3245 409 115 1361 3249 3257 3245 378 115 1361 3249 3257 3245 /+20 115 1361 ' 3248' 3256 32~A 383 115 1361 3248 3256 3244 376 115 1361 3248 3256 32~ 376 115 1361 · 3246 3254 3242 366 115 1361 3246 3254 3242 279 115 1361 3244 3253 3241 396 115 1361, 3244 3253. 3241 ,... Area Code 907 V' 272-5966 Reservoir Pressure & Temperature DoIo Individual Well D~ta Sheet 487 Soulhampton Dr. Anchorage, Alaska Company Well Borough ,.. MARATHON OiL COMPANY BC -A Field Formation Platform, WI LDCAT BEAVER CREL-K State_.___AlASKA Date , 17 FEB 1973 .,,C,H R 0 N,O_..L O,G..I, C A L D A T,A GAUGE GAUGE #25519-N #25518-N DATE TIME ,, REMARKS . BHB~ BH~ BItE ELAPSED PROD GAS INJECTED TBG CSG R.D. DATUM M. P, TIME RATE VOL VOL GOR PRESS PRESS TVD-148OOTVD TVD HR.,MIN BOPD ,, MCF.D . MCF,D ~,. S,C,F/B ,, PS, IG PSiG 14959 _ 14965 14930 ,. 23 FEB 1973 01:00 GAS LIFTING. 02: O0 ,, 03: O0 ,, 04: O0 ,, 05: O0 ", 06 :od " 07: O0 ·" 08: O0 " 09:00 ' " 10:00 " 11: O0 " 12: O0 " 87:00 2276¢~ 2832 .88:O0 2276 2832 89:00' 2274 2,832 90: 00 2281 2832 91: O0 2279 '2832 1'892 413 115 1361 3241 3250 3238 1892 ' 413 115 1361 3240 3248 3236 1892 413 115 '1361 3240 3248 3236 1892 412 115 1361 3238 3246 3234 11892 412 115 1361 3238. 3246 3234 '92:00 2276 2.832 '1892' 413 115 1361 3238 3246 3234 93:00 2283' 2817 11892 405 115 1361 3238 3246 3234 94:00 2329 2870 ' ,'1892 419 115 1361 3236 32A3 3231 95:00 2253 2832 1902 412 115 1378 3236 3243 3231 96:00 2281 2832 1902 407 11.5 1378 3233 3242 3230 97:00. 2317 2832 ~ 1902 '401 115 1378 3233 32A2 3230 98:00 2312 2832 1902 402 115 1378 3231 323,0 3228 -..13:00 " 99:00 2281 2847. 1914 409 115 1378 3231 3240 3228 13:15 CHANGE 0HFICE PLATE IN SEP. FROM (82.37) TO (121.65) 14:00 100.00. 2286 2858 1914 412 115 1378 3231 3240 3228 15:00 PULL PRESS GAUGES 101.00 2272 2836 16: O0 102. O0 2374 2825 '16:35.0N BTM. WITH pRF-Ss GAUGES 17:O0 GAS LIFTING 1'8: O0 '" 19: O0 " 20: O0 " 21: O0 " 22: O0 " 103:00 2262 282¢ 104:00 2246 2825 105:00' 2248 2825 106:00 2238 2803 107:00 2246 2803 108:00 2248 2803 1914 405 115 1378 3231 3240 3228 1914 383 115 1361' 1914 402 115 1361 3231 3240 3228 1914 405 115 1378 3231 3240 3228 1914 405.. 115 1378 3231 3240 3228 1914 ':. 397 115 1345 3231 3239 3227 1892 405 155 1345 3231 3239 3227 1892 405 155 1345 3230 3239 3227 23:00 " 24: O0 " 2/+ FEB 1973 01: O0 " 02: O0 " 03:00 · " 0/+: O0 " 05: O0 " 06:00' . ",. 07: O0 " 08: 00 " 09:00 " 10: O0 " 11:90 " 12; O0 " 109:00 2267 2803 1871 411 155 1345 3230 3239 3227 11.0:00 2264 ' 2825' 1871 421 155 1345 3230 3239 3227 111:00 2041 2825' , 1871 112: O0 2090 2941 113:00 2088 2941 1.14:00 2112 2941 · 115:00 2155 29t2 116: O0 2172 2836 117:00 '2183 2974 118:00 21 89 2974 467 115 1345 . 3230 3239 3227 1871 511.. 155 1345 3230 3239 3227 1871 512. 155 1345. 3230 3239 3227 1871 506 ' 155 1345. 3230 3238 3226 1871 483. 155 1345 3229 3237 3225 1871 444 155 1345 3229 3236 3224 1871 505 155 1345. 3228 3236 3224 1871 503' 155 1345. 3228 3235 3223 119:00 2248 2775 '..1871 402 106 1361 3227 3234 3222 ,120:00 2248 2781 ' 1870 405 106 1361 3227 3234 .3222 ,:.121 :bo 2241 ' 2781 1870' 406 106 1361 3227 3235 3223 272-5966 ~./; Reservoir Pressure 8, Temperature Data In~[~,idual Well Data Sheet 487 Southampton Dr. Anchorage, Alask. Company. ..... MARATHON OIL COMPANY Well Borough ,, BEAW R CP EK NO. 4 Field L, Formation Platform .. BEAVER C REEIi .~tate_ ALASKA Date 17 FEB 1973 C H.R 0 N O,,,,LO G..I C,A,L D.. A.,T.,,,,A GAUGE #25519-N GAUGE //25518-N · . DATE 13:O0 GAS 14:00 · 15:00 16:00 · 17 O0 18:00 19:00 20: 00 21: 00 · 22: O0 23: O0 24:00 25 FEB 1973 01: 00' 02: OO 03:00 ' 04: OO 05: O0 ,06:00 07:00 , 08: O0 · 09:00 10:00 11:00 12:00 13:00 14:00 15:00 16:.00 17:00 18:00 19:00 20:.00 21: O0 22: 00 23: O0 24:00 26 FEB 1973 01:00 LIFTING Il II Il !1 ., Il t! 11 · ti ti I! I1 · II .' II , , ,,I.; II 11 II II , II II II II II !! · .. II II !1 II .. ELAPSED PROD GAS TIME RATE VOL HR. MZN, BOPD MCFD,. 123:00 2i51 2791 124:00 2209 2813 125:00 2220 2781 126:00 2217 '28.03' 127:00 .2215 2803 128:00 2228 2803' 129:00 2224 2842 130:00 2215 2842 131:00 2217 2842' 132:00 229? 2842 133:00 226? 2803 134:00 2288' ' 2803 '; '135:00 2240 2803 136:00 2234 2803 137;00 2223 2803 138:00 2226 2803. 139:00 2452 2?59 140:00 2284 2?59 141:00 2289 2?59. 142:00 2291 2?59 143:00, 2314 2?3? 144:00 2314 2781 1,45:00 2310 2781 146:00 2309 2781 147:00 2295 2?59 148:00 23O4 2?59 149:00 2321 2?59 150:00 2312 2?59 151:00 2318 2?59 152:00 2306 2?59' 153:00 2310 2?59 154:00 2291 2?59 155:00 2312 2?59 156:00 2329 .2?59 157:00 2333 2?59 158:00 2325 2?59 INJECTED VOL MCFD BtIF~ BHF~ TBG CSG R.D. DATUM GOR ?HESS TVP -148oorvD SCF/B,, PSIG ,, PSlG .14957 _ 14965 1859 433 106 '1361 1849 436 106 1378 1849- 419 106 1378 1849 430 106 1378 1849 430. 106 1378 1849 428 106 1378 1849. 446 106 1378 1849/ 448 106 1378 1849 447 106 1378 1849 432 106 1378 1849 420'106 1378 1849 416 106 1378 3227 3235 3226 3234 3226 3233 3225 3231 '3224 ,3230 3223'3229 3223 3229 · . 3223, 3229 3221 3226 .3220 3226 3220 3226 3219 3225 1849 1849 1849 1849 1849 1849 1849 '1849 1849 1860 1860 18'60 1838 1838 1827 1827 1838 1838 ' 182? 1827 182? 1838 1838 1828 425 427 429 428 371 398 297 297 .383 398 398 398 401 399 401 403 397 403 403 406 403 395 394 4OO 106 106 106 lO6 lO6 106 ' 106 106 106. 106 106 106 106' 106 106 106 106 106 106 106 106 106 106 106 1378 1378 1378 1378 1378 1378 1378 1378 1361 1361 !361 · 1361 .1378 1378 1378 1378 1378 1378 .1378 1378 ' 1378 1378 1361 1361 3219 3218 3217 3216 3215 · 3214 3214 3213 3213 3212 .3212 3211" 3210 3209 3208 3208 3207 3207 3206 3206 3206 3205 3205 3204 3225 3224 3223 3222 3222 3221 3221 3220 3220 3219 3218 3217 3216 3215 3215 3214 3214 3213 3212 3212 3212 3211 3211 3210 ~59:00 %. 2167 2715 1828 429 106 1378 · , 3203 3210 M.P. TVD 14 9.3.0 3223 3222 3221 3219 3218 3217 3217 3217 3214 3214 3214 3213 3213 3212 3211 3210 '3210 3209 3209 32O8 32O8 3207 3206 3205 3204 3203 3203 3202 3202 3201 320O 32O0 3200 3199 3199 3198 3198 Area C I',i ~.. ~.., ~,~ ~ ~' 272-5966 \/' Reservoir Pressure & Temperaturo Dala Individual Well Data Sheot 487 Soulhampton Dr. Anchorage, Alaska · Company. MARATHON OiL COMPANY _Platform , .. Well BC ',,¢ Field, WI LDCAT Formation Borough .... , ..... BEAVER CREFX State__.__AZ~S_'KA Date ~ 17 FEB 19'73 _C H RO N.Q LO G I.~C A,.L .... D AT A GAUGE GAUGE #25519-N #25518-N ELAPSED PROD ' GAS INJECTED DATE TIME RATE VOL VOL GOR TIME _ ILl, ARKS ..... HR..MIN BOPD MCFD , MCFD.. .. SCF/B . 02:00 ,. 03:00 04:00 '05:00 ' 06:00 07:00 03:00 09:00 10:00 11:00 12:00 13:O0 14:00 15:00 PULL PRESS GAUGES GAS ,.LIFTING I! II II I! 160:00 2169 271 5 161:00 2203 2715 162: O0 2122 271 5 163:00 2197 2715 164:00 2199 2715 165:00 2219 2715 166:00 2221 2759 '.167:O0 2219 2759 168:00 2258 2759 169:00 2290 2737 170:00 2252 2714 171: 00. 2244 271 5 172: O0 2230 2671 173:O0 2236 2715 2167 2953 16:00 , 174:00 16:45 ON BT. WITH PRF~S GAUGES 17: 00 WAS LIFTING 18:00 ', 1.9: O0 · " 20: O0 " 21:00 !' ' ' 22: O0 ' " 23: O0 " 24: O0 "' 27 FEB 1973 ', " 01: O0 " 02: O0 " 03: O0 " 04: O0 " 05: O0 " 06: 00 ', ,i 07: 03 " 08: OO 09:00 " 10: 00 " 11: 00 " 12:00 ,, 13: O0 ', 14: O0 " 1828 408 1828 . 402 1828 418 1828 403 1828 403 1828 399 / 1817 424 1817 424 1817 417 18O6 406 1806 403 1828 395 1828 378 1828 396 1828 519 175:00 2191 2759 1828. 424 176:00 2195 2759 1828 424 177:00 2098 2?59 1828 443 178:00 2128 2759 1828 437 179:00 2167 2759 1828 429 180:00 2165 2759 1828 430 181:00 2193 2737 1828 414 182: O0 2197 273 7 1828 413 183: O0 2i 20 2737 184: O0 2.126 2737 185:00 2129 2737 186:00 2135 2737 187: O0 2172 2671 188:00 2191 2737 189:00 2~8 2737 190:O0 22~~49L9 2693 191: O0 22_~J~ 2693 192:00 2.258 2737 .193:00 2.:~ 51 2759 · 194:00 22.32 2737 195:00 '2234 2737 ,:. 196~00 2230 2737 1828 /+28 1828 427 1828 426 1828 425 1817 393 1828 414 1828 411 1817 389 1817 390 1838 398 1838 409 1849 392 1827 /jO7 1827 4O8 BHP~ BHP$ BH5 TBG CSG R.D. DATUM M.P. PRESS PRZSS TVD -148OOTVD TVD PSIG PSIG. _14959 14965 14930. , 106 1361 3203 3210 106 1361 3202 3209 106 1361 3202 3209 106 '~'1361 3202 3209 106 1361 3201 3208 106 1361 3201 3208 106 1361 3201 3208 106 1361 3200 3207 106 1361 3200 3207 106 1378 3200 3206 106 137~ 3199 3206 106 1361 3199 3206 106 1361 3198 3205 106 1361 3198 3205 115 1361 3198 3197 3197 3197 3196 3196 3196 3195 3195 3194 3194 3194 3193 3193 115 1.36.1 115 .1361 3198 3205 3193 .. 115 1361 3198. 3205 3193 115 1361 3198 3205 3193 115 1361. 3197 3204 3192 115 1,361 3197 3204 3192 115 1361 3197 3204 3192 115 1361 3197 3204 3194 115 1361 3196 3203 115 1361 3196 3203 115 1361 3196 3203 1.15 1361. 3196. 3203 115 1361 3196 3203 115 1361 3195 3202 115 1361 3195 3202 155 1361 3194 3201 115 1361 3193 3200 115 1378 3195 3202 115 1378 3194 3201 115 1361 3193 3200 1'06 1378 3192 3199 106 1378 3190 3197 3191 3191 3191 3191 3191 3190 3190 3189 3188 3190 3189 3188 3187 3185 272-5966 ~/: 'Rose.air Prossuro & Temporoluro Data' Individual Well Dala Sh~t 487 Sou~hamplon Dr. Anchorage, Alaska Company. · Wail, ;Borough · , . DATE MARATHON OIL COMPANY Platform Field Wi II)CAT Formation ..... BEAVER CREE~ State_- ALA~K~A _ Date .... 17 F. EB ~1973 ..C....H R O. N 0 L._O G_I C A__L D___A T A GAUGE GAUGE #25519-N #25518-~N B}IF~ BII Fr~ ELAPSED PROD · GAS INJECTED TBG CSG R.D, DATUM M. P, TIME RATE. VOL VOL C, OR PRF2S PRESS TVD-1AS00TVD TVD ~.%.~E _ REMA...RKS .... HR. MIN BO..PD MCFD MCFD , SCF/B,,L PSIG ,PSIG 34959 1/,965_ 14930 .:.: ...' .15:00 '"' . 16':00 ~', '17:00 , '' 18:00 19:00 .,' .20:00 · 21: O0 22: 00 · 23: 00 " 24:00' 28 FEB 1973 01: O0 02: 00 03: O0 04: O0 05: O0 06: O0 07: O0 08: O0 · 09:00· 1'0:00 11:00 · 12: 00 13:00 l&:O0 15:00 ' , 16:00 , , , .17:00 ,',, .18:00 19:.00.,. 20:00 · " 21:00 ' ""'. 22:00 "' .- , 23: O0 " ,. 24:00 "'. · 1 MARCH 1.973' ... 01: O0 " · ,02:O0 " ' ., 03: 00' "' 04:00 ' ',, , , GAS LIFTING 197:00 2225 2737 .: 1827 40~ ' 106 1378 3190 3197 3185 "',' ' 198:00 2227. 2737 1817 413 106. 1361 3189 3196 3184 ":' '. 199:00 2225 2737 ' 1839 403 '115 1361 3189 3196 318/.,,. I! ']' , 200:00 2219 2737 1839 404 115 "1361 3189 3196 3184 "' 201:00 2214 2737 1839 405 115 1361 3189 3196 3184 "'" - 202:00 .2189 ' 2737 "~,839 410 115 1361 3188 3195 3183 "", 203:00 2187 2737 ".1839' 410 115 1361 3187 3194 3182 "' '204:00 2208 2737 /'1839 406 115 1361 3186 3193 3181 205:00. 2223 2737 /'1839. 403 ' 115 '1361 3186 3193 3181 ",'.,. 206:00. 2219 2737 :1839 404 115 1361 3186 3193 3181 · ' "". 207:00. 22.,~9 2737 '"' 1838 399 106 1361 3186 3193 3181 '' ", . 208:00 2t65 2737 .1838 414' 106. 1361 3185. 3192 3180 "'!" 209:00 2254 2737 "1838 . 398 106 1361 3185' 3192 3180 ' "~' 210:00 2262 2737 1838 396 125 1378' 3185 3i92 3180 "':" 211:00 2303 , 2737 1838 398 125 1378 3185 3192 3180 ",i. 212:00 2268' 2737 1838 395 125 1378 3184 3191 3179 "':,. 213:00 2273 2737 1838 395 ' 1'25 1378 3184 3191 3179 " 21~ :00 , 2271,7 2737. ' 1838' 395 "125 1378 3184' 3191 3i79 "...,. , · . 215:00 22¢~'¢Z~2715 '1838 381 125 1378 3184 3191 3179 ".:,:" 216:00 2266 2715 1817 .396 125 1378 '3184 3191 3179 · . 217:00 2256 2715 '- 1817 398 125 '1378 3183 3190 3178 ...., 218:00 2264. 2715 1817.' 396'125 1378 3184 3191 3179 If, ,.' ',,'4" 219:00. 2230 2?04 " 179,5 40? 125 1378 ' 3185 3192 3180' ,, .. 220:00 2128 2681 1796 415 125 1378 3186 3193 3181 · " 221:00 2128 2681 '1796 415 125 1378 3186" 3193 3181 "' 222:00 21"/.7 2704 1796 422 125 1378 3188 3195 3183 " 223:00 2141 2704 1796 424 125 1378 3188 3195 3183 ".,, 224:00 2135 2704' 1796. 425 125 1378 '3187 .3194 3182 ""' 225:00 2179 2704 1796' .416 125 1378 3187 3194. 3182 .226:00 2156 2704 1796 421 125 1378 3186 3193 3181 .227:00 2158~2704 1796 420 125 1378 3186 3193 3181 228:00 2156 2704 1796 421 125 1378 3186' 3193 3181 229:00 2167 2704 1796 419 125 13.78 3185 3192 3180 230:00 2175' 2704 1796' 417 125 1378 3185" 3192 3180 · '231:00 2222 2704 1796 408 125 .1378 .3185 3192 3180 232:00 2225 2704 .'1796 408 . 125 1378' 3185' 3192 3180 · ,:: 233:00 2264' 2704 '1796 401 125 '1378'. 3185 3192 3180 ' ' 23Z.:00 o~an. 270/,. ' '1706 on,, 10~ !~."7~ qlO/ ~1c~! 3170 · 72.5966 "'Reservoir Pros'~uro & eraturo 2 ' ~/ Temp Data{;' Individual Well Data Sheet 487 Soulhamplon Dr. Anchorage, Alaska Company. MARATHON OIL COMPANY DATE t , ' '.05: 00 ' "" ". 0o·:; O0 · " ':: 07:00 .' :" 08:00 ..'..'09:00 .... .10:00. ; 11:00' ,', :12:00 ,' ,.'.,'. 1.3:00 5 '14:00' ' 15:00 .. : '16':00 16:30 17 :oo ,18:00 ' BO ..,4 ... Field ,,, Formation Platform , . BEAVER CREEK WI LDCAT State_: Oat.; 17 FI S.. !.973 C H RO N 0 L O,,G, I C A L D AT A GAUGE GAUGE #25519-N #25518-N 18:15 18:30 GAS LIFTING II; . ,. II II , . II II II II FULL PRES'S GAUGES PARgFFIN VEi:~ BAD ELAPSED PROD . GAS TIME RATE. VOL . _ HR. HI.N,_ BOPI], , MCFD ... 235:00 2303. 236:00' 2285 237:00 .2247 238:00 2254 239:00 2239. 240:00 2268 '241:00 '2299 . 242:00 2256 243:00 2212 244:00. 2231 245:00 2229 246:00 2183'. s. x, WELL' FOH $/U . , ', ON BTM. WITH PRESS GAUGES ." 246:.30 "· .. 247:00 2196 · 248:00 21"f.¢01 'S.I. GAS INJECTION 248:15 248:30 18:36 ' SHUT WELi" IN · '18:36 BUILD.UP.,' .f, II II Il Il' Il Il Il Il Il Il Il Il Il ,Il Il: Il Il Il ' I 18:42 ", 18:48 ' 18:54 · ' 19:00 · 19:06 · 19:12 19:18 19:24 19:30 19:36- 19:42 19:48 19:54.. 20: O0 20:15 20:30 " 21: OO 21:30 .. O0: O0 00:06 00:12 .00:18 00:24 00:30 00:36 .00:42 00:48 OO: 54 O1: O0 01: 06 01:12 01:18 01:24 01: 30 01:45 02: O0 ' 02:30 03] O0 2704 2704 ' 2704 2704 2'713 2713 27.13 . 2704 2681 2681 2681 2728'.' ., 2657 2739 ' . · ,. .. INJECTED VOL GOR ~ CFDI I S.CF/B 1796 3,94' 1796 397 1796 404 1796 : 4O2 1796 4O9 · ,.1817 395 817 389 f~1817'' 393 ' i, 1806 395 "! 1796 396 1796 397 1796 426 1796. 1796 392 448 . · BH~ BiIP~ TBG CSG R.D. DATUM M. P, PRESS PRESS TVD -148OOTVD TVD PSIG_ PSIO 14959 14965 125 1378 3184 3191 125 1378 3184 3191 ,125 1378 3184 3191 125 ~]378 3184 3191 106 1345 3184 3191 106 1345 3184 3191 106 1345 3183 3190 106 1345 3183 3190 106 13.45 3183 3~90 106 1'361 3182 3189 106 1361 3182 3189 115' 1361 . 317q 317c) 317c) 3179 317g 3179 3178 .3178 3178 3177 3177 , 1361 3268 ·3276 115'1361 3196 3204 .1.15. 1361 3194 3202 .... 3194 3202 . 3086 3O93 . . 326,4 3192 319C, 319G 3081 3180 3187 3394 3403 3683 3671 3905 3914 4145 4155 · 435o 4357 45~7 4545 4689 4696 4824 4832 4938 4946 5022 5031 5131 5139 5202 5212 5257 5266 5304 5312 5364 5372 5400 5409 5434 5442 5460 5468 3199 368..i 3926 4167' 4369 4551' 4708 48z4 4958 5043 5151 522 5278 53Z 53S$ 5421 545 548O APPENOIX D · ~rea Code 907 ~' "'' . 272-5966 Rose~oir Pressure & Iemporaluro Dala Individual Well Dala Sheet 487 Soull~ampton Dr. Anchorage, Alaska Company. ., . MARATHON OIL COMPAN"f · Well , _ B0,-,4 ' Field . i~muoh ............ Formation · , ,. . .. .! .' DATE 'TIME _ Platform WI II)CAT BEAVER CRE~ Oa~_. - 17 FEB 1973 _C H R.O.,N QLO G I C A L D.AT~A · ".05: O0 ,,: 06': O0 · ',:: 07:00 :"':08: O0 '. ,...' 09: O0 10:00. '.. 11:00 :12:00 :,". 13:00' .. ~ 1'14:00' '15:00 ,. 16':00 16:30 ~. . ' GAs LIFTING · . , II · II . . I! PULL PRES'S GAUGES PARgFFIN VEi~ BgD GAUGE #25519-N 7:oo ,18.:00 18:i5 18:30 . ~. · 18:30 SHUT WEL~ IN · .. 48:36 BUILD-UP..' ' '. 18:42 · , 18:48 ' 18:54 "'19:00 19:06 · 19:12 19:18 19:24 19:30 19:36. 19:42 19:48 19:54, 20:00 20:15 20:30 21: 00 21:30 GAUGE //25518-N BHP~ ELAPSED P?~0D ' GAS INJECTED TBG CSG R.D. TIME RATE VOL VOL GOR PRESS PKESS,TVD-14800TVD TVD H.R. MIN , BQPD MCFD_ ,. MCF,D. "SCF/.B PSI_G, PSI_G _14959 _ 14965 14930 235:00 2303 . 236:00 ' 2285 237:00 2247 238:00 2254 239:00 2239 27+0: O0 2268 ~241:00 '2299 , 27+2:00 2256 243:00 2212 244:00 2231 245:00 2229 246:00 2183 . 2196 2704 . 1796 2704 .1796 27C4 1796 , 2704 1796 2713 1796 2713 , 1817 2704 t~ 1817' 2681 i' 18O6 2681 ".! 1796 2681 1 ?96 2?28 '"1796 , ,, 2657" 2739" ,, 3,94 397 4O4 402 4O9 395 389 393 ' 395 396 397 426 1796. 392 1796 448 S.I. ! .o 125 1378 125 1378 ,125 1378 125 ,]378 106 1345 106 1345 106 ~1345 106 , 1345 106 1355 1'06' 1361 106 1361 115' 1361 115 ' 115 · DATUK BI{ M.P. 3180 3187 3199 3394 3403 3415 3683 3671 '3683 3905 3914 3926 4145 4155 4167 · 4350 4357 4369' 4537 4545 4557 4689 4696 4708 4824 4832 484/+ 4938 4946 4958 5022 5031 5043 5131 5139 5151 5202 5212 5224 5257 5266 5278 5304 5312 , 532% 5364 5372 5384 57+00 5409 5421 5434 5442 5454 5460 5468 5480 O0: O0 00:06 00:12 ·00:18 00:24 00:30 00:36 P0:42 00:48 00:54 01:00 01: 06 01:12 01:18 01:24 . 01:30 01:45 02: 00 ' 02:30 03': O0 ON BTM. WITH PRY_SS GAUGES ,'., 246:30 .. ,. 247: O0 248:00 'S.I. GAS INJECTION 248:15 S. I .,WELL' FOR B/U 248: 30 1361 3268 ·3276 3264 1361 3196 3204 3192 1361 3194 3202 3190 ., 3194 3202 3190 3086 3093 3081 , 3184 3i91 3179 3184 3191 3179 3184 3191 3179 3184 3191 3179 3184 3191 3179 3184 3191 3179, 3t83 3190 3178 3183 3190 .3178 3183 3190 3178 3182 3189 3177 3182 3189 3177 · Area Code 907~'"~.~'' · , ~u~;li~'¢bh~,~,~'~',.4 .. Reservoir Pressure & Temperature Data 272-5966 /' Individual Well Data Sheet 487 $outhamplon Dr. Anchorage° Alaska Company. MARATHON 0IL COMPANY Platform Well BFAVER CREEK NO. 4 Field . WILD.CAT . .Borough .... Formation__ , BEAVER C REEIf. State___.A LASKA ~,Date 17 FEB. 1973 CHRONOLOGICAL DATA INJECTED DATE VOL GOR TIME REMS..RKS ..... MCFD, S. CF/.B BUILD-UP" I! II Il' !I II . 1I II , , , , II I! I! II · . I! II l! . · ii1.. 1~.., II I! !I 22:30 23:30 2 MARCH 1973 00:30 01: 30 02:30 03:30 04:30 05:30 06:30 07:30 08:30 09:30 10:30 11:30 12:30 13:30 · 14:30 15:30 16:30 17:30 18:30 , 19:30 20:30 21: 30 22:30 23:30 3 MARCH 1973 , 00':30 " 01:30 " 02:30 .... " 03: 30 " · 04: 30 " 05:30 " 06:30 -" 07:30 " 08:30 " 09: 30 " 10:30 '" 11:30 " GAUGE · GAUGE 11255184; ELAPSED PROD GAS TIME RATE VOL HR. MIY BO~D,, ,MCFD · 04: O0 05:00 TBG CSG PRESS PRESS PSIG PSIG BIIB~ BHRD R. D. DATU]M TVD -14800TVD .. 1A959 . 14965 , 5495 5503 5519 5527 BHP~ 14. P. TVD 1493_o 5515 5539 06:00 07: O0 08: O0 09: O0 10:00 11:00 12i00 13:00 14:00 15:00 16:00 17:00 18:00 ' 19:00 20: O0 21: O0 22:00 23: O0 24:00 25: O0 26:00" 27: O0 28: O0 29: O0 'l . ,5538 5547 5552 '5562 5569 5579 5583 5593 5595' 5604 5607 5616 '5632 5631 5634 5643 5642 5652 5654 5664 5665 5675 5677' 5687 5688 5697 5698 57O7 · 5707 5717 5715 5725 5725 5735 5734 5744 5742 5751 · 5753 5762 5762 5771 5772 578o 5781 5788 5790 5798 5559 5574 5591 5605 5616 5628 5643 5655 5664 5676 5687 5699 5709 5719 5729 5737 5747 5756 5763 5765 5783 5792 58OO 5810. 30:00 31:00 32:00 33:00 34:00 35:0o 36:00 37:00 38:00 39:00 40:00 ;41:00 5797 5805 5817 5806 5815 5827 5811 5821 5833 5817 . 5827 5839 5826 5836 5848 5835 5845 5857 · 5841 5850 5862 5849 5859 5871 5857 5867 5879 5867 5876 5888 5874 5883 5895 5882 5891 5903 ........ ~ I ,-.' r-,,'--, ~ ¢'r~I 0 272-5966 Reservoir Pressure & Temperature Data Individual Well Data Sheet 487 Southampton Dr. Anchorage, Alaska Company. Well MARATHON OIL COMPANY .Platform , , BEAVER CRE?~z( NO. 4. Field . WI LDOAT · BEAVER CRE?_~ State .... ALASKA Borough ... Formation , . ' Date 17,.FEB 1973 ,, _ C H R 0 N,,O L,O G I C A L D A T.,.A GAUGE GAUGE #25519-N #25518-N DATE 13:30 14:30 15:30 16:30 17:30 18:30 19:30 20:30 21:30 '22:30 23:30 4 MJ~'~CH 1973 00:30' O1: OO 02:30 03:30" 04:30 05:¢0, ' ' 06:30' 07:30 08:00 09:30 10:,30 11,:.30 12:30 13:30 14:30 'BUILD-UP ': !I , ! II I! II , I! II II II Il · I! ' II I! " Il, . . l.i Ir II ELAPSED PROD GAS TIME RATE VOL 'HR,,.KIN BOPD , MCFD 43: OO 44:00 45:00 46:00 47: OO 48:00 49:00 50: O0 51:00 52: O0 53:00 54:00 55:00 56:00 57:00 58:00, 59:00 60:00 61:00 62:00 63:00 64:00 65:00, 66:00 67:00 68:00 15:OO 16:00 16:30 17:30 18:30 19:30 20:30 21: 30 22:30 23:30 PULL PRESS.GAUGES (68:30) 69:30 PRESS. GAUGES' ON 'BTM. 70:O0 , BUILD-UP 71:00 " 72: O0 ' " 73:00 " 7~: O0 ·" 75: O0 " 76: O0 " 77:00 e · INJECTED TBG CSG VOL P ESS SCFO. SCF/ .... mZ0 .... SZ,0 ¢ 1221 BHP~ BI[Pg~ BHP~ R.D. DAT~,I M.P. TVD -14800TVD TVD 1A959 J47~5_ 14930 · 5.897 '5906 5918 5903 5912 5924 5910 5919 5931 5915 5925 5937 5934 '5933 5945 5931 '5940 5952 5936 5945 5957 5943 5952 5964 5950 5958 5970 5956 5964 '5976 5963 5971 5983 5969, 5977 5989 5976 5985 5997 5981 5990 6002 5989 5997 6009 5994 6002 6014 '5999 6007 6019 6004 6013 6025 6009 6018 6030 6025 6024 6036 6020 6030 6042 ,6025 6035 6047 6032 6042 6054 6037 6046 6058 6042 6051 6063 6048 6057 6069 6051' 6060 6072 6061 · 60~0 6082 60?9 608? 6099 6083 ":[6_~1ili) 6103 6088 6096 6108 6094 6102 6114 6100 6107 6119 6101 6109 6121 6106 6114 6126 · Are,~ Code 907 ~~.~""' ;" Reservoir Pressure & Temperature Data 272-5966 In~vidual Well Data Sheet 487 Southempton Dr. Anchorage, Alask,~ / Company. - MAHATHON OIL COMPANY Wel~ . ~EA~.C~ ~0~, ,4. Field __ . WILDCAT , Borough · .., Formation .. . Platform, , BEAVER CREE~ A LAS lA Date .. ,17 FEB 1973 DATE TZ _. ,., 5 Y~RCH 1973 00:30 BUILD-UP 01: 30 " 02:30 03':30 04:30 05:30 06:30 07:30 ' 08:30 09:30 10:30 1,1':30 ' 12:30. 13:30 , 14:30~ 15:30. 16:30 . 17:30 18:30 · 19:30 20:30 " 21:30 ." 22i30 " 23:30 " 6 MARCH 1973 00:30 " 01: 30. 02:.30 03: 30 04:30, 05:30 06:30 07:30 08: 30 09:30 10:30 11 II II II I! II ,. II II II ' I1 ' ti · · II II II I! II II I1 II !I II , I.I C_._H. RO N 0 LO G I C A L ELAPSED PROD GAS INJECTED TIME RATE VOL VOL GOR HR. MIN. ,BQ.P,D MCED ..... MCF..D.,. SOF/.B · 78:00 79:'00 80:00 81:00 82:00 ,83:00 84:00 85:00 86:00 87:00 88:00 89:00 90:00 91:00 92:00 93:00 94:00 95:00 96:00 97:00 98:00' 99:00 100:00,~ 101:00 102:00. 103:00 104:OO '105:00 106:OO 107:00 108:00' 109:O0 110~00 111:OO 112:00 D A T A GAUGE GAUGE //25519-N //255i 8-N BHI~ BHF(~ BHP~ TBG CSG R~ D. DATOq-I M.P. PiRF~S PRESS TVD -1480OTVD. TVD .PSIG PSIG _. 14959__._1.4965' 14930 ..... ! 6110 6118 6130 6115 6123 6135 . 6120 . ,,6128 6140 6123 6131 6143 6127'6136 6148 6132 '. 6141 6153 6137 6146 6158 6141 6150 6162 6141 6150 6162 6143 61.54 616/) 6147' 6156 6168 6152 6162 6174 6159 6169 6181 6162 6172 6184 6165 6175 6187 6169 6179 '6191 6173 6183 6195 6177 6187 6199 6181 61.90 6202 6183 6193 6205 6186 6196 6208 '.6191 6200 6212 6193. 6202 6214 6198 6207 6219 6209 6210 6222 6203 6212 6224 6207 6216 6228 6210 6219 6231' 6213 ,6223 6235 . 6216 6226 6238 6220 6229 6241 6222 6231 6243 6224'"'-. 6234 ' 6246 6228 6238" 6250 6232 6241 6253 ' Are'a Code 907 ~:,., ":' 272-5966 ~,/' Resorvoir Pressure & Temperaturo Data Individual Well Data Sheo! 487 Soulhamplon Dr. Anchorage, Alaska Company. Well_ · Borough ... MARATHON OIL COMPANY BEAVER CREEK NO. 4 _Field__ _Formation Platform: WI LDgAT BEAVER CREEK_ ,State_ ALASKA _Date_ 17 FEB 1973 C H RO N 0 L.O G I C A L D A T.A GAUGE GAUGE //25519-N //255184~. ELAPSED PROD GAS DATE TIME RATE VOL TIME RLMARKS ' HR. MIN BOPD MCFD .-- · . · 11:30 12:30 13:30 14:30 15:30 16:30, ' 17:30 18:30 . 19:30 · 20:30 21:30 22:30 23:30 7 MARCH 1973 00:30 01:30 02:00 · 03:00 04:30 05:30 06:30 07:30 08;30 09:30 .10:30 11:30 12:30 13:30 14:30 15:00 16:30 BUI ID-U P. -', II I! II · II II II II · II II II II fl II Il Il II II I! Il I! · · , II II II 113:00 114:00 115:00 116:00 117:00 118:00 119:00 120: 00 121:00 ; 122: O0 123: O0 124:00 ., 125: O0 126 127 128 ,, 129 , 130 13i 132 ; 133 , , :" 134 135 ' 136 137 138 139 " 140 :00 :00 :00 :00 :00 :00 :00 :00 :00 :00 :00 :00 :00 :00 :00 PULI2D PRESS,GAUGE 140:00 ON 'BTM, WITH PRESS, GAUGES r . INJECTED VOL GOR / BH~ BHBD BHP~ TBG . CSG R.D. DATU/,I M.P. PRESS PRESS TVD -14800TVD TVD PSIG 1 6 1 0 1453 $ ! 6235 6245 6257 6237 62/+7 6259 6241 6250 6262 6241 ,.6250 6262 6249 6259 6271 6251' 6261 6273 6254 6264 6276 6257 6267 6279 6238 6268 6280 6262 6271 6283 6263 6273 6285 6267 6276 6288 6269 6278 6290 6272 6281 6293 6276 6285 6297 '6277 6287 6299 6280 6290 6302 6282 6292 6304 6287 6297 6309 6288 6298 6310 .6292 6301 6313 6293 6302 6314 6297 6306 6318 6297 6306 6318 6302 6311 ,, 6323 6310 6312 6324 6307 6316 6328 6309 6318 6330 6311 '6320 6332 ' ~ 272-5966e U ~." ?.'i"~'~ Res'r¥oire Pressure & Temperature Data Individual Well Data Sheet 487 Southampton Dr. Anchorage, Alaska Company. Well~ Borough , MARATHON OIL COMPANY BEAVER NO. 4 Field WI LDCAT Formation~ Platform BEAVER C REEji .State ..... _A_LASKA Date. 17 FEB 1973 CHRONO LOG I CA L DATA GAUGE GAUGE #25519-N //25518-N DATE ,, 19:30 BUILD-UP CONT'D 145:O0 8 MARCH 1973 O0: 30 " 05:30 " 10:30 " 15:30 " 20:30 " 9 MARCH 1973 01:30 " 06:30 " 11:30 " 16:30 " 21:30 " 10 MARCH 1973 02 :'30 " 07:30 " 12:30 " BIID~ BIIF~ BI[P~ ELAPSED PROD GAS INJECTED TBG CSG R.D. DATUM 14. P. TIME P~TE VOL VOL GOR PKE~S PRESS TVD-14800TVD TVD , RLV~ARKS, HR. MIN BOPD MC, FD, MC.FD, SC,F/B PSIG PSIG .14959 14.965., 14930_. ,6325 6334 6346 150:O0 155:O0 160:00 165:00 170: O0 175:00 180:00 185:00 190:OO 195:O0 200:00 205:00 210:00 634O 6348 636O 6350 6360 6372 6361 6371 6383 6370 6381 6393 6380 6390 6402 6395 64O4 6316 6412 6422, ~. 6434 6z,2o 643 '/> 6428 6438" ' 6450 /.(~ ' /~.--'C'J - . ___ ....... '/~;~rea' ~-, ' uouu:ode 901~t,z /'~"-272-5966 r" -' ' Individual Well Data Sheet 487 Southampton Dr.' Anchorage'. Alaska :ompony: , ~/ell_ Bc -4 MARATHON OIL COMPANY ·Platform,' BEAVER CREEK .' ... Field WI LDCAT State A L~SKA mrough Formation .... Date 11'-14 FEB 1973 CHRONOLOGICAL DATA GAUGE GAUGE #25519-N #25518-N DATE TIME FEB 11 1973 09:00 WELL IN TEST 10:00 RIGGING ON WELL 11: O0 " 12: O0 PRF~S TEST LUBR. 13: O0 " BHPD BHB~ BHP~ BHP~ ELAPSED OIL H20 GAS GAS FOP~q TBG CSG R.D. R.D.M.P. DATUM TIME PROD PROD OUT VOL GOR PRESS PRESS TVD . TVD TVD HR. MIN BOPD BWP. D. MCFD...MCFD.SCF/B. DSIG:. pSIG 1490,8 14914_14.93.O .-1/.80, · · OO: OO 01: O0 02: O0 03: O0 04: O0 14:00 STAR~ED G.L. CHECK 05:00 15:00 HNNNING G.L. CHECK 06:00 16: O0 " 07: O0 17:00 FINISHED G. LCHECK 08:00. 18: O0 CHANGED TO 72 HR. CLOCK 09: 00 19:00 l~3N DEPTH 15114 10:00' 20:00 ON BTM. FOR FLOWING PSI 11:00 21:00 FLOWING PRF~S. 12:00 O. 2542 1881 0 2542 1902 0 2555 1892 O . 2555 1892 0 2569 1913 0 2269 1913 0 2269 1913 0 2555 1925 O 2555 1914 0 2633 1892 0 2605 1913 118 1378 118 1378 118 1378 118 1378 118 1378 118 1378 118 1378 118 1378 . 118 1378 · 3280 3285 3297 3280 3285 3297 , 118 1345 118 '1345 3273 3281 3286, 3299 0 2528 1913 0 2528 1913 118 '1345 3273 3281 3286' 3299 125 1345 3273 3281 3286 3299 (12) HR. AVERAGE 21:40 Sh'~JT IN GAS LIFT 22:00 SHUT IN WELL 22: 06 BUI LD-UP 22:12 '" '22 18 " 22:24 · " 22:30 "' 22:36 " 22: 42 " 22:48 " 22: 54 " 23:00 23:15 " ' 23:30 " 23:45 " 24: O0 " FEB 12 1973 00:15 " 00:30 " 00:45 " 2450 '2562 1906 267 118 1368. 3273 3281 3287 3298 12:40 0 0 3293 3301 3306 3318 o o ....... ,--.,~:.-~ 106 1355 3154 3165 3170 3187 00:_0.6_: ......................................... ' .. ..... ................. ...... 00:12 .................................................. : ......... _/_z&~ .............. 1312. 3388 3399 3~4 3394 ............ ~- ............................................... : ................... , 0,0_;._24.~ ......................... ~/ 1312 3913 3924 3929 3941 __o_.0_:3~...'.._... 7~ f i3 i'2 ......... Z2~6-"Z'2 00'~ ~< 1312 4515 &526 ~531 ...................... , ...... 0~i~ ................ ,. ~4~'/ 1312 49~2 A95~ 495'6 4968 ~0:5~ ............ ~/~ ..................................... 1312 5~q5 5126 5t51 51~3 01 '30 .. :¢~ 1312 5556 5565 5570 5582 . ~__.:..~.5 .................. ~ 1312 5599 5610 5615 562? 0~.:.!.5... 02:30 02:45 /~J- · ...... 1312 5647 5658 5663 567.= ,,%:: 1312 '5666 5676 5'68'1 5~93 /'-// ' 1312 5681 5691 5696 570~ ~ ',~r~'a Code 907 ~-'"'"'~..~ ....... .'"' ' '-' · ./ ~" Individual Well Da,a Sheet / Company-, Well .MARATHON OIL COMPA~f BC -4 Field WI II)CAT Platform Borough ... Formation. CHRONOLOGICAL DATA 487 Southampton Dr. Anchorage, Alaska BEAVER CREEK State_ ALASKA Date 11-14 FEB 1..973 GAUGE GAUGE #25519-N #25518-N DATE TIME ~RKS O1: O0 O1:30 02: O0 03:00 04:00 05: O0 06:00 O7: O0 08:00 09:00 10:00 1'~: O0 12:00 13:00 14:00 15:00 16:00 17:00 '" 18: O0 " 19: O0 " 20: O0 " 21: O0 " 22: O0 " 23: O0 " 24 '00 · " FEB 13 1973 01: O0 " 02:00 " 03: O0 " 04: O0 " 05: O0 " 06: 00 '!.' 0'7: O0 " 08: 00 " 09:00 " i 0: O0 " 11: O0 " 12:00 " 13: O0 " 14:00 ." BUILD-UP. BHF~ BHF~ BHPO BHP$~ , ELAPSED OIL H20 GAS GAS FORUM TBG CSG R.D. R.D. R.D. DATUM TIME PROD PROD OUT VOL GOR PRESS PRESS TVD . TVD TVD HR. MIN BOPD BWPD MCFD MCFD S,CFj~B..__ PSIG ~SIG 1Z?O8 i~91& 14930 -14800 I _~r~--, , 93:00 · /~ ' l~_~L_.j~701_~.206 04:0a ~~z J~2 5729 57~9 57~_3Z~6. 05:00 zz . ~2 575~ 5?52 'E%Lg.9 ...................................~ ....................... 3_.~!2 ....... 5.80J .......... ~.~J.~..' ..... 58!2.. 5.8~9 ~, 1312 5815 582? 5832 58~4 09:00 "' ~z '~3~a'~' ~83~ '58'~5"'.'-'5"S'~ Jo:oo ' ' . ' '~? ~_ ...... Z_j~J2 5853 586~ 5868. 5sso . ~ ~ :oo · ,~;~. ~ ................... !~.!..8 ....... 5.~Z8 ....... 58.~1 ......... 5.~s_~ ........ 5,898. ~2:oo ............. ss. ~ ............... 1.~J.8 ......... 5~SS? 5s~$ 5.90~ ........ ~.~...5 ........ 14:00 pz,~. ~3~2 5920 5929 593~ 5946 ~'-~-~;'~O-f Z;"/Z;2-2 ;'~ ~' '2 'Z 'ii ~'Z "2 ;' '"'2 "-'/ ........ ~. f 2f"2 ~ ~ ~ .f'_ 7' :' "';" '-'_ '_ ~' '_ ;~ ~2i_ ~ ...... '. '~Z~ & C.. '~'?~_~ ....... 1.?:00 .......... .~s,~ 1312 5954 5962 5967 59?9 18:00 ................................................................................................................................................................ .......................................................................................... ;,~,~ .... 131'~' 5968 ~5"9~? ' 598? '"599~ ..... 19:00 20: O0 21: O0 . 22:00 23: O0 _24__:p0 ..... 25: O0 26:00 ,~/~' 1312 59?8.. 57~.7 ...... ..5,9..9,,2 .... 6004 ~',2- '. 1312 5988 5998 6003 6015 . /~,~ ..................... !_3J2_ .... 5_.9,.976006 6011 6023 /,~',~ .. 13!2 6007 '66:i"~'~ ....... ~-2~"' 6032' · .,"27 1312 6016 6025 6030 61042 · ?,~,,?U.,.Uiii'i3)'i~"Li.'ii.~'~i~i'61...L~'..O.-~_i~'_ ....... i~io~.o/_i..L~E-i~'.a .......... ......................... __z~,_Y ............ _!._3J_.g___6_03_6__ ~6 04_6_. __6 g_~_ j_ _ ~6p~,~_. /~,~/ 1312 6045 6054 6059 6071 27: O0 28: O0 29: O0 30:00 31:00 ~.3.g.,'_ OO 33:00 /2, ~ 34: O0 _ 3 5: O0 ~,0 .36: O0 /:,c 7 37: O0 /,:'. 'i..38 :oo /// 39: O0 ,.::~.,..?' 40:00' /~;2.-. 1.3.!2 6055 6065 6070 6482 . _ ?/. z ................ ~._)J_2 ..... .6_g_q_& ......... 6.o..7.5 . 60_8_.9 .......... 69.9~. /~,.~- .............. ~_.~.!_2 .6..02~ ..... _6.~.S._& ......... 6..o_~?_ ..... _6_!0_! ........ /~j- 1112 608-4 6095' 6100 61 i2 /~,%' .1].12 6093 610..3 6108 6120 /,~,~ 1 ]12 . 6103... 6! _1,_.3_ .... 6!!8 ....... ~,.'!~.0. _, 31.2 6112 6121 6126 6138 312 6127 6137 6142 6154 312 6136 6145 6150 -6162 312 6146 6154 '6159' 617i' 312 6151 6160, 6165 6177 312 6155 616/, 6169 6181 1312 6165 6174 6'179 6191 272-5966 "~,/ Rese.?oir Pressure & Temperature Data ' Individual Well Data Sheet 487 Southampton Dr. Anchorage, Alaska Company MC,~%THON OI T, COH?ANY Platform. Well ;BO ..--4 Field Wf LDOAT Borough . Formation ~EAVER_C~EEK State--.. . ALASKA ' __ ..Date 11 -14 FEB 1973 CHRONOLOGICAL DATA GAUGE GAUGE #25519-N #25518-N DATE TIME RF24A RKS 15: 00 BUI ID-UP 16:00 " 17:00 " 18: 00 " 19: 00 " 20: O0 " 21: 00' " 22: 00 " 23: 00 " 2/+: 00 '" FEB 14 1973 ,01: O0 " 02: O0 " 03: 00 " O&: O0 " 05: O0 " 05: 00 " 07: O0 " 08:00 " 09:O0 "· 10:00 '" , 11:00 ' " 12: 00 " 13:00 ' " 1/+: 00 ' " 15:00 ' " 16: 00 " 17: 00 " 18:00 " 19:00 " 20: O0 " 21: O0 " 22: O0 " BHP~ BHI~ BHP~ BHF~ ELAPSED OIL H20 GAS FAS.; FORM. TBG CSG R.D. R.D. R.D. DATUM TIME PROD PROD OUT VOL GOR PRESS PRESS TVD TVD TVD, HR. MIN BOPD BWPD MCFD MCFD SCF/B PSIG PSIG 1A908 1A91~ 1A930 -1A800 ~ 1:00 , /~, ~2 ........... ] 3~_~15~ .... .~.]._~.~__.,~..~ .......... ~_]9_~ ..... ~~__'i '..~, ~ ~.~_.~ .......... ~...9_~ ........ ~9_~ ......... 6_~.~. ........... ~.0.. ~ :oo . .~..~ ....... ] !~2. ~9.3 6~..~2 ....... 62.~_~ .......... ~2~?... .... ¢~-~· ....... 3._3_.~_.~ ........... ~_~.~ .~.z~ ......... ........ ~.~ ........... ~3.~ A.?:oo '../ ' ~ :..~.~_~.~ ...... 6~3._.~ ........ ~_~!._L6~ ......... ~_~.~.~. _~_..:~ ~ ~..~ .!3.~_.2......'....~2.~..S 62.~6 6~.~.~_ .......... ~2.~ ........ '~:90 ~ , ~.~'~. 1312 622~ 62~ 623& 62&~ ~ ~_ z.O..Q · ~? :~, ;~' :~ ;': 11. ~...!~ ..... _6..2_ ~ ~_ ..... .6_ ~ ~_0__ _62~.. %.__ .._6 _2~ .......... 54:00 2.// · . 1312 6247 6254 6259 6271 5~.0_~ ............................................................ . : ................ Z?~. !,.,~.~_~ ...... :,.~.~_5.,~. ......... 6..~_~? ....... .62~ ............ ~'i~.~i'i.- ,56.:_o__0 ................. ' _. : ~..F.¢ '.1~12 62~6 626& 6269 6271 _~?:oo_ ..................................................... i_i.'.i._Zi.k~' .... .._...5_8_~_0_Q ............................... : ................ ~ ............... Z~c~.. .... 1~12 6271 6279 6284 6296 i~.~_;....0.~ .... ' .....' . z~-'/' - -': ...................... i)'~--2 ..... -~'~'~'~ ....... ~'2-~-'~-:-'-"-6~-9-0 ..... %302- ..... : .................... . ........................ .: ............. ........ ............................. ............ ........ ............ ....... .' ......... :'-'-0 , ~,? ..... ~': ...... ~' ........ -6~'~""':'-~'~V ...... ~-~- ....... -6)'i'-~ ....... ~doo · . z/F ~3~. 629~.. 63o~ 630~ ...... '6~2i' '-~'~'Z ~ ..~ '[. '. :...:~ .~..,~:~ .'. '~.'..~.."~.)~'-~'2 ~"~'~ ....... ~'~S- .... ~'~')' ......... ~'~'~"~ ~ ~'~-;a8'"' .... "."2[.:..Z.__.LJ[.[ .'~:~'~ ............ ~'~'~ ~o~':'..' ~"~::"~)-~-': ...... .... :~, 0-o- ~ ~ T-~ ............... : ....... ~'~'~-~---'~'~-J ~--'t-~-~'-];-~-~-z~ _.~o., oo .. ~':'~ ..... : ............ ~ ~~'s~-6'~ ~'[ '~'~6%-"-s~'~9~':~ ,Arc~ ,,.gee Yu/ ~~ ..' ~/ Rose.elf Pressure & Temperature Data · ~" ~i.~,~ ..~" ~ Individual Well Dola Sheol :omi,any. Nell · ,. · .: ! .. · MARATHON OI L COMPAN3f Platform - BO -4., ' Field . WI LDCAT · _ _ _ Formation ....... ;.C H RO N 0 LO.Gl C A L DATE . "[.05.:00' G~S ~ING ·. Oo: O0 " · ,,, ',.07: O0 ":'. ' ~'J O~: O0 "" .!'O?:O0 " 2,10:00. · ,. . ~. 11: O0 ' " ' ;12:00 '" '.. 13:00' "" "1~: 00' ". "1 ~ :00 '16;00 16:30 ,' [ . . .l&:O0 , . ,. 18:42 .,.. ', 18=~8 " " ' 18=5& " ;" ' '19=00 . " " .. ~9=06 " ... ' 19~12 " ':" 19 = 2& " ' 19:30 " : 19:36- " . 19:42 " 19:48 " " II . 19:54. 20: OD ,'"' 20:1 5 "' 20: 30 " 21: O0 ." .. 21: 30 " ELAPSED PROD · GAS TIME RATE VOL H,R.. MIN ~ BOPD ..... MCF_D _ ~ , 235:00 236: 00 237:00 238:00 239:00 240: O0 PULL PRESS GAUGES PARAFFIN VERY BAD ON BTM. WITH PRF~S GAUGES 2303. 2285 2247 2254 2239, 2268 '241: O0 '2299 . 242:00 2256 243:00 2212 244: 00. 2231 2.45:00 2229 246:00 2183 . 246:30 247:00 2196 248: O0 21 '$'~0 ! 248:15 .. , , 248: 30 ., 'S.I. GAS INJECTION S. I ..WELL· FOR B/U .; ,. SHUT WEL~ IN · BUILD-UP., i !1 'f' · O0: O0 00:06 00:12 .00:18 00:24 00:30 00:36 90:42 00:48 O0: 54 01:00 01:06 01:12 01:18 01:2/+ 01: 30 01:45 · 02: O0 ' 02:30 03': O0 2704 27O4 ' 2704 2704 2713 ' · 2713 · 27O4 2681 2681 2681 2728," · BEAVER CREF4f 487 Southampton Dr. Anchorage, Alaska _ Rtate=.'-. /b[~S?~ ... Date - 17 FEB 1973 INJECTED. D. A T_A_ _ GAUGE GAUGE f/25519-N //25518-N · · 1.796 ~796 ~ 796 1796, l817 817 3,94 397 404 - 402 4O9 395 389 393 · 395 396 397 '426 1493o · · · 125 1378 3184 3i91 3179 125 1378 3184 3191 3179 .125 1378 3184 3i91 3179 125 ~378 3184 3191 3179 106 1345 3184 3191 3179 106 1345 3184 3191 3179, 106 '1345 3183 3190 3178 106 . 1345 3183 3190 .3178 106 13.45 3183 3190 3178 1'06' ,'1361 3182 3189~ 3177 106 1361 3182 3189 3177 115' 1361 1¢1817' ! i. 1806 · ! 1796 ' 1796 1796 1796. 1796 S.I. · . ' . 1361 392 115 ' 1361 448 115 1361 · · · · · . ~ 3268 .3276 3196 3204 3194 3202 3194 3202 3086 3093 · , 3264 3192 3190 3190 3081 3180 3187 3199 3394 3403 3415 3683 3671 .'3683 3905 3914 3926 .4145 4155 4167 4350 4357 4369' 4537 4545 4557 4689 4696 4708 4824 4832 4844 .~¢~ 4938 4946 4958 : 5131 51'39 5151 · · . 5202 5212 5224 5257 5266 5278 · ". .5304 53!2 ........ 53.. · · 5364 5372 5384 ........ :.. 5.4..9.0_ ....... 540,9. .. .~-¢~,¢ . 5434 5442 5454 ' .... .... 5- 'S-S 54's0 272-5966 \/' Reservoir Pressure & Temperature Data Individual Well Data Sheet ~ompany. MARATHON OIL COMPANY · ,Platform BEAVER C KEK~- 487 Southampton Dr. Anchorage, Alask8 Well BEAVE~R CREF_,K NO. 4 .Borough .... .... Field., ~ Jr..z) c A~ Formation _State_- · Date ALASKA 7 FEB 1973 C H H o N O._L_O~G ! C A _L D_A T__A ~ . GAUGE #25519-N GAUGE //255184; DATE BUIlD-UP "' 1! I! BHB~ BHB3 E~APSED PROD GAS INJECTED TBG CSG R.D. DAT~,I TINE i~TE VOL VOL GOR PRESS P~S T~ -1~800T~ 'HR. MIN. BOPD _MCFD~ MCFD SCF/B ~IG PSIG 14959.. 14965 " Qg;O° .......................... /zF 5495 55o~ 05:00 /;¢ 5519 552? ..................... ,. ............. BHP~ M. P. TVD 1493o,. 5515 5539 0.6:00 · . '/-%' . .5538 5547 5559 0_7 :..0R ' ' . /~ 7 ..... 5.5,52. 5.562 . 5574 08:00 9¥. 5569 5579 5591 .... I 22:30 23:30 00:30 · 01: 30 " 02: 30 " 03: 30 " 0~.' 3_0 .............. "' 05: 30 " 06:30 . '" 07: 30 " 08:30 · " 09: 30 . ," ' 10:30 ' '",. 11:30 " 12:30 " %,¢ 5595' 5604 5616 · 11:oo ........... ' .... /' · . ............... ~6'07 561~ .... ~-~ ........... 12'00. ' .................................................. .-~t ........ , ........................ · . ...................................... c~,¢ ]~.~.~.2 ........ ~63~ .......... 5643 13:00 . .. 5634 5643 5655 14:00 5642 5652 5664 15:00 "' ;-'~'" 5654 5664 5676 16:00 5665 5675 568? 17:00 '. 567?' 5687 ' 5699 18:00' 5688 5697 5709 13:30 " ' 19:00 ' 1_~_.:.3.Q ......... : ............. J!_:. ....................... ] ....... 2__0 LO_P__..j ......... ' ....... ' ..................... 15:30 ' " 16:30 ' '" 17:30 " 18:30 " · 19:30 "' 20:30 · '"" '~',' . 21:30 " 22:30 "' 23: 30 " 3 MARCH 1973 o0'_:_3_0_ ............ ', O1:30 " 02: 30 .... " 03: 30 " · 04: 30 " 05:30 " 06:30 " 07: 30 " OS :30 " 09:30 " 10:30 '" II 11:30 21:00 22: O0 23 24:00 25: O0 26:00 27: O0 28: O0 29: O0 30:00 31:00 32:00 33:00 34:00 35:00 36:00 37:00 38:00 39:00 40:0.0. ;41: GO .................... i ii iiiii i ii 5698 5707 5719 : '¢,¢, ~ · 5707 5717 5729 5715 5725' 5737 5725 5~35 5747 5734 5744. 5756 5742 5751 5763 · 5753 5762 5765 5762 5771 5783 5772 5780 5792 5781 5788 5800 5790 5798 5810 · ....... 57.92 ~8o5_ ........... ~817 5806 5815 5827 5811 5821 583'3 5817 .5827 5839 5826 5836 5848 · 5835 5845 5857 .5841 5850 5862 5849 5859 587~ 5857 5867 5879 5867 5876 5888 5874 5883 5895 5882 589~ 59o3 ~fompany. Borough ... Code 907 ~:.., t 272-5966 \,/' Reservoir' Pret, sure& Temperature Data Individual Well Dale Sheet 487 Southampton Dr, Anchorage, Alask,~ MARATHON OIL CObiPANY BEAVER CREF~K NO. 4 _ Field _ WI LDOAT Formation Platform_ BEAVER CRE~ _ Stot._-_~s~ ..... ~.Oate 17 FEB !973 C H R 0 N..O L 0 G I C A...L...D A T..,A, ,, GAUGE //25519-N GAUGE tt25518-N DATE .T.~.~ . ~ R~.~.g~S,,' ELAPSED PROD GAS T~XE m~. YOn YOU .... ',HR. bLI,N BOpD ,, MCFD ..... MCFD, 13:30 'BUILD-UP 14:30 " 15:30 ." 16:30 17:30 " 18:30 .. " 19:30 " .. 2_0_~: 30 ...." 21:30 ,i 22:30 " 23:30 " ' · 4 MA'<CH 1973 ' 00:30' ", ":. ' 01 :OO " . 02: 30 "' 03: 30 " 04: 30 " 05 :,30 ' " 06:30 ' '" 07: 30 " ' 08:00 ' " 09: 3 0 " ' · 10 :.30 " ' '11,~30 ". ,, ,.~ 12:30 13:30 " 14:30 " 15: O0 PULL PRESS. GAUGES (68 16:00. 69 16:30 PRESS. GAUGES ON BTM. 43: OO 44:00 45:00 46:00 47: OO 48: O0 49,: O0 50..:00 . 51: O0 52:00 · 53:00 · 17:30 BuILD-uP 18:30 " 19:30 " 20:30 " 21:30 ·" 22:30 " 23:30 " 54:00 55:00 56:00 57:00 '58:00. 59:00 60:00 61: O0 62:00 63:00 64:00 65: OO . 66: OO 67: O0 68: O0 :30) :30 -, 70: O0 71:00 72: O0 73:00 ~7A:O0 75: O0 76: O0 77:00 , I'1 e INJECTED · GOR s,_cE/~ · e BHB~ BIIP~ TBG CSG R.D. DAT~.I PRESS PRESS TVD -14800TVD PSI~G .... P, SIG ,,14,9.59 !49~5; //'(,'- 1221 BHP~ M.P. TVD ,!493,0 _ , '5897 '5906 5918 5903 5912 : 5924 5910 5919 5931 5915 5925 5937 5934 '5933 5945 5931 '5940 5952 5936 5945 5957 ...... 5943/. ........ 5_9~_Z ......... 5964 5950 5958 5970 5956 5964 '5976 5963 5971 5983 I. . 5969. 5977 5989 5976 5985 5997 5981 ' 5990 6002 5989 5997 6009 5994 6002 6014 · 5999~ 6007 6019 6004 6013 6025 6009 6018 6030 6025 6024 6036 6020 6030 6042 6025 6035 6047 6032 6042 6054 6037 6046 6058 6042 6051 6063 6048 6057 6069 605J 6060 6072 6061 -60~0 6082 '-6079 6087 6099 6o8 6-,o 6os 6o9 , 6 o8 6094 6102 6114 6100 6107 6119 6101 6109 6121 6106 6114 6126 · 272-5966 ~ Rose.elf Pressure & Temperature Data In~vidual Well Data Sheet 487 Soulhamplon Dr. Anchorage, Al~,sko ~'~ompany. Well i~rough MARATHON OIL COMPANY ~EAVER CRE~ NO, 4, , Platform ;. Field _ . WILDCAT Formation ,., BEAVER CREEK_ Sta~e ALASKA ~.Date 17 FEB 1973 CHRONOLOGICAL DATA GAUGE GAUGE #25519-N //25518-II DATE ,, 5 MARCH '1973· ' 00:30 BUILD-UP ' 01: 30 , " 02:30 " · 03"i'~0 ' ,, 04:30 .. " 05:30 ,. " 06: 30 " .. 07:30 ," 08: 30 " · 09: 30 , " 10:30 "' 1.1':30 ' " · ' I! , 12:30. . ·. 13:30 ' " 14:30 ~' "' 15:30. ,i 16:30 . " 17:30 '" " 18:30 · 19:30 " 20: 30 " 21: 30 ." 2 AO__ ................ " 23:30' " 5 biARCH 1973 30: 3 0 " . 31:30. " 32:.30 " 33:30 " 34: 30. " 35:30 " 35:30 " D7:30 " 38:30 " D9:30 " 10:30 " BHB~ BHi~ BHB9 ELAPSED PROD GAS INJECTED TBG CSG R; D, DATb~.I M, P, TIME RATE VOL VOL GOR PRESS PRESS TVD-1480OTVD~ TVD HE. MIN._ .BO. PD ._MCFD .._MCFD .,, S.CF/.B PS. lQ P. SIG, 1495.9 .,1.4965;_ 1A930 .... 78: OO 79 :'00 80: O0 81:00 82:00 .83:00 84:0o 85:00 86:00 87:00 "88:00 89:00 '. 90:00 ,. 91:00 92:00 93: O0 94: O0 : , 95:0o 96: 00 9?:00 ., 98:00 ; 99:00 , : i ..... ,.,: ! 9_O;PO,)~ , i i, . 101:00 102:00. 103:00 104:'00 '105:00 106:00 107:00 108:00' '109:00 110~00 111:00 112:00 · /0,6' · . I' .1:, 611o 6118 6130 6115 6123 6135 . 6120 . ,,6128 6140 6123 6131 6143 6127'6136 6148 · 6132 '.6141 6153 6137 6146 6158 6141 6150 6162 6141 6150 6162 '. 6143 61.54 6166 · ' 6147' 61 56 6168 6152 6162 6174 61 59 6.!6.9 '. 6.18.1 6162 6172 6184 6165 6175 6187 6169 6179 6191 6173 6183 6195 6177. 6187 6199 6181 61.90 6202 6183 6193 6205 6186 6196 6208 6191 6200 6212 6193. 6202 6214 619~ 6207 6219 6209 6210 6222 6203 6212 6224 6207 6216 6228 6210 6219 6231' 6213 ' 6223 6235 6216 6226 6238 6220 6229 6241 6222 6231 6243 6224'"-6234' 6246 6228 6238' 6250 6232 6241 6253 'ornpan¥. ~'WelL ~rough ,t Re~ervoir Pressure & Temperature Data Individual Well Data Sheet MARATHON OIL COMPANY BEAVER CREEK NO. 4 Field Platform BEAVER CREEK State. 487 Soulhampton Dr. AnChorage, Absk~ , Formation G H RO N 0 LO G I C A.L. D A T A .. ALISKA Date_ .17 FEB 1973 GAUGE GAUGE '#25519-N #25518-N. D TE FI_ME 11:30 12:30 13:30 14:30 1~:3o 16:3o. ~ 17:30 " : 18:30 . " lC~-.,"3'0 .' ,i · 20:30 ' " 21:30 "' 22: 30 " 23: 30 " 7 MARCH 1973 · 00:30 ' " ' 01: 30 "' 02:00 .' " ~3: O0 " P4.:. 3_0 " ~5: 30 " ]6: 30 " )7: 30 " )8; 30 " )9:30 " 10:30 ,. · fl :30 " 2:30. " 3:30 " ~%MAP~S i i ii , i BUI LD-U P.... !! I! . II · . . . , I , I ' ELAPSED PROD GAS INJECTED TIME RATE VOL VOL GOR _ HR. MIN .BOPD MCFD MCFD, SCF/B 113:00 114:00 -: 115:00 116:00 117:00. 118:00 119:00 . . . 120: O0 121:00 122: O0 123:00 ,. 124:00 125:00 BHF8 BHK~ BHP~ TBG .CSG R.D. DATUM M.P. PRESS PRESS TVD -14800TVD TVD .PSIG PSIG 1495.9 _, 1.4965 '. 14930. 6235 6245 6237 6247 6241 6250 6241 ,. 625O 6249 6259 6251'6261 6254 6264 : . ,I ': 6257 ........ 6267 6258 6268 6262 6271 6263 '6273 6267 6276 6269 6278 6257 6259 6262 6262 6271 6273 6276 6279 6280 6283 6285 6288 6290 126:00 127:00 128:00 ' " 129:00 . . 130:00 13i:00 ,. 132:00 .,'' 133:00 · 134:00'~ 135:00 136:00 · 137:00 138:00 . 139:00 6272 6281 . 6276 6285 ' ' '6277 6287 · 6280 6290 · . , 6287 .6297 · 6288 6298 · 6292 6301 · 6293 6302 6297 6306 6297 63O6 6302 6311 6310 ·6312 6307 6316 6~18 '6320 ; I , I - I t 5:00 lULLED PRESS.GAUGE 140:00 1453 6311 6:30 ON'BTM. WITH PKESS. GAUGES · · '6293 6297 6299 6302 .6304 6309 6310 6313 6314 6318 6318 6323 6324 6328 6330 6332 ' ~L 90~'~... ~ ,. ~l' '~¥'" ':. { Reservoir Pressure & Temperature Data' ~iI 272-5966 ~": Individual Well Data' Sheet [-': ~,,,,. 'ell. MARATHON OIL COMPANY BEAVER CRE~K NO. 4 Field WZ LDCAT Platform Borough_ Formolion ~C. 487 Southampton Dr. Anchorage, Alaska BEAVER CREEK State_. ALASKA Date 17 FEB !973 CHRONO LOG I GA L DATA GAUGE GAUGE #25519-N /725518-N ELAPSED' PROD GAS INJECTED TBG CSG R.D. DATUM M.P. DATE TIME RATE VOL VOL GO_R.. PRESS PRESS TVD-14800TVD TVD ~rIME : _ R~,J~RKS, HR..MIN BO,,PD, MCFD MCFD 'S,C,F/B_ PSIG PSIG ,14959 14965 . 1A930 ........ 19:30 BUILD-UP CONT,D 145:00 ' ~' ..6325 6334 6346 8 MARCH 1973 00:30 " 05:30 " 10:30 " 15:30 " 20:30 " 9 MARCH 1973 01:30 " 06: 30 " 11:30 " 16:30 " 21:30 " 10 ¥~RCH 1973 02:'30 " 07: 30 " 12:30 " 150:00 6340 6348 6360 155:OO 6350 6360 '6372 _%~_n____n_n_ ......... ' ' ~;'~'-~- '' 6 61 63_.71 6383. 165:00 ' 6370 6381 6393 170:00 .~ 6380 6390 6402 175:00 .. 6395 6404 6316 180:00 6404 6414 6426. 18~_:00 ' ' ' 1~, ~ ) ~...... ' 6412 6422t~. 6434 195:00 I · ' ' 6428 6438 ' ' 6450 200: O0 205: O0 210:00 6436 6446/.~. 6458 . 6443 645~/,,~ 6464 6450 6460' 6472 · ~ lllll Il I II 'llll ' 'llll I I II IIII I I I I Ill I 111I I I I I Ut_ MARATHON OIL (COMPANY PRODUCTION-UNITF:O STATES ANE) (CANAnA ANCHORAGE OIVISION I~,0. BOX 2~3B0 ANCHOF::IAGE . ALASKA 9~)510 February 12, 1973 State of Alaska Oil and Gas Conservation Committee 3001 Porcupine Anchorage, Alaska Re' USL A-028083 Beaver Creek Unit #4 Gentlemen: Forwarded herewith, in duplicate, is Form P-7 Well Completion Report, for the referenced oil and gas well. Attached to this report are the following: Attachment #1, page 1 - Perforating Record Attachment #1, page 2 - Cementing Record Eastman Subsurface Directional Survey Formation Test Data as follows' Test A 15,732-875' Dated 12-1-72 Test B-2 15,510-740' " 12-8-72 Test 3 15,313-520' " 12-12-72 Test D-4 15,096-315' " 12-16-72 Test E-5 15,005-130' " 12-21-72 Test 6 14,478-625' " 12-28-72 Test 7 14,443-600' " 1-1-73 History of Oil and Gas Well, dated January 29, 1973 One sepia and one blue-line copy of the following listed logs- Dual Induction Laterolog (DIL) Composite 2" scale Runs 1 thru 4- 5" scale Sidewall Neutron Por. osity Run 1 - 2" and 5"- log interval 2,986-5,752' Formation Density Log (compensated) (FDL) Run 1 - 2" and 5" - log interval 2,986-5,748' Run 2 - 5" - log interval 4,900-12,540 Run 3 - 2" and 5" - log interval 12,504-15,934' State of Alaska Oil and Gas Conservation Committee Page 2 February 1 2, 1973 Compensated Neutron Log (CNL) Run 1 - 5" - log interval 4,900-12,540' Run 2- 5" - log interval 12,503-15,926' Borehole Compensated Sonic Log (BCS) Run 1 - 2" and 5" - log interval 12,986-5,742' Run 2- 2" and 5" - log interval 5,688-12,528' Run 3 - 5" - log interval 12,503-15,926 Cement Bond Log - log interval 4,500-1 5,874' Composite Mud Log We respectfully request this data be held confidential in accordance with your regulations. Very truly yours Landman MLL- kb cc: Well File Engineering Form P--? SUBMIT IN'DUPL': '" .TATE OF ALASKA 's,-.. :n.,-.:,. ~Tru.; ,r- on OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* TYPE OF WELL; un. ~ ,.~ ~ ~ wznc w~nz. ~ D~ ~ Other TYPE OF COMPLE~ON: WELL OVHR ~N ~ ~C~ ~ ~EN%'R. ~ Other ~ .NAME OF 0PrRATOR Marathon Oil Company 3. ADDR£S~, OF OPERATOR P. O. Box 2380- Anchorage, Alaska 99510 4'. LOCATION OF ~'ELL (Report location clearly and in accordance with any .State requircmenta) ° At surface 1700' S, 660' W from NE corner protracted Sec. 33 T7AI, 1K10W, SM ProD. At top prod. interval reported beloW' 1467' S, 711' E from l~V corner Sec. 34, TTN, P~10W, SM At total depth 1553' S, 900' E from Nlff corner Sec. 34, T7AI, I{10W, S~°p APl NUQ. LE/i/C.k/, COOW- 6.LF_A_~E DF-~',GN,kTION A-ND ~EI%L~j_ .NO. , A-028083 7.iF I,%,qDIA.,\'. AJ-,LOTTF_~ OR TRIBE 8.UNIT,F~%I OR ~-~SE B emver Creek 9. W~L ~'O. 10. F~ ~ND POOL, OR %VI~C~T Wildcat O~ECTIVE) Sec. 34, TTN, ~10W S~ 12. PERAIIT NO. Prop. 72-13 6/12/72 11/26/72 1/14/73 !144.8' Gr 164' KB 145' , 15 107 TVD ingle Compl. X PRODUCING I~-r~V~(S), OF ~IS COMP~TIO~--TOP, BO~OM, N~E (MD A~D ~)- .r %.j~. ~. WAS 15,060 - 15,100 MD ~'' 14,861 - 14,898 TVD ':'7 ,'.' . , susvs~ns ~ Yes 15, 155 - 15, 200 MD~'. 14,952 - 14,900 TVD ,~ ,' ...... j 24. TYPE ~.r.~.;r~-tlC A_ND OTI-ua{ LOGS RUN DILr BHC-GP,., FDC- CNL-GI{, Hi{D, CBL ! ~m~ CASLIN'G RECORD (Report all strings set in well) CASING SIZE WEIGI-IT, LB,'FT. DEPTFI SET (iVLD) HOLE SIZE [ CEAILNTING RECOi~D H-40 " See Attachment ....... 9-5/8" &53 521 12-1/4" None 2~. LIi~/E~ I:~COI:~D 27. TUBIi~G RECOP,,D 7" ' 469' ~ f~ 2-7/8 14,469-14,6 5 14 15 See Attachment ~ 0~0-15,072 000 gal mud clean out acid ~. , .- . .~' ~ jA.~7 . , 1/13-14/73[ 24 I 3/8 . . ~%V, '~'BING [C~{G P~SSU~ [CAL~~ OI~BSL. GA~?~. WA~BBL. tOIL GRAVITY-~I (CO~.) ~. [ 143 psi~ 13zo ~sig [ ~ 1196 I 215.7 I 0 ] 37° 31. DISPOSITION OF GAS (,%'01d, USed /0r f~el, vented, etc.) '" Flared ITEST WITNESSED II. D. Lee do.. L[.qT OF ATTACII.ME.N'TM . oDzes of all logs - perforation record - cernentin~ record, DST data, directional 33. I he~oy certify that the furegoing and attaciled informath,n Is completo and correct as determu~eu from all available recoras 1/Z9/73 SXC~'F.D TITLEArea Drilling Supt.. ~^'r~: *(See Instructions and Spaces For Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submilling a complete: and correct well complelion ~eporl end log -.~ all types of lan~Js and leases in Alaska. Item: 16: tndicale which elevalion is use.d as reference (where hal otherwise shown) fat depth measure- ments given in clher spaces on this form and in any atlachmenls. Itoms :20, and 22:: If this well is completed for separ0tc, produclion {rom more than one inlerva} zone (mulliple complelion), so stole in item 20, and in ilem 22 show the p~oJucing inlerval, or inle~vals, ~op(s), bottom(s) and name (s) (ii any) for only the interval.reported in item 30. Submit a separate repor~ (page) on Ibis form, adequalely idenlified, for each adc[ilional inle~val Io be separately produced, show- lng the acktitional data pertinenl Io such I1om26: "Sacks CemenW: Attached supplemental records, {or this well shou}.zl show the detail, at any mul- tiple stage cementing and lhe location of the cementing tobl.,.: Item 28: Submit ~ separate completion report on this fo~'m for each iqterwl to be separately produced. (See inslruclion for items 20 and 22 above). ,. - · .. _ , , .. DST data aktached. ~' ' ...... ' ' Beluga Fn'~. 5,865' 5,865' ryonek Fro. 8,670~ 8,670' Memlock Fro. 15, 313 ' ~ ~est Foreland ~ ~. 15, g74* 15,651~ . ........... ~ ,, , ~ ........ 30. 1'~11}: DATA. A'i'I'At'li l]l{IEb' DF. qCIIIPI'FIONfi OF LITIIUDOGY. POI1OSITY. FI1AC'~ll~, APP~NT D{PS Gore []1: 15, 350-15,380~: Recovered 10~ of silt and Z0~ of spo~ty oil- stained sand. Gore [[Z: 15,430-15,460': Recovered 30' of sp0~y oil-stained sand and conglome rate. . _ _~ ~l_ -._ .... ATTACHMENT #1 Perforating Record Forma ti on Internal Hemlock .~, ./ 15,795-15,855 (60') 1 5,560-15,580) - 15,600-15,610) 60' 15,640-15,660) 15,685-15,695) 15,446-15,461) 6o' 15,361-15,376) Gun Size No. of Holes 4" 4 Jets/Ft 240 · 4" Jumbo Jets 4/Ft 4" Jumbo Jets 4/Ft 240 240 Status Isolated w/bridge plug at 15,750' Isolated w/bridge plug at 15,530' Isolated w/bridge plug at 15,315 T_y. onek 15'190-15'200) 15,155-., 5,17E)' 30'. · ~ , 15,082 15,1,OQ 30 14,535-14,565 (30') 2" Tubing Gun 4/Ft 4" Casing Gun 4/F~ Casing Gun 4/Ft 120 120 120 Producing Producing ~-. Cement squeezed and isolated w/packers i'4,615' and 14,469. at Cementing Record 30" Conductor - 60 SX. Class "G" w/ 4% Ca.C1. 20" Casing String - 965 SX Class "G" w/ 2% CaC1 13-3/8" Surface Casing - 2000 SX Class "G" w/ 4% get followed by 300 SX Class "G" w/ 2% CaC1. 9-5/8" Intermediate Casing: Casing landed @ 12,521' KB. FIRST STAGE - Cemented with 696 sks "G", 1/2 cubic/ft Perlite, 4% Gel, 1% D-19, 0.8% R-5 tailed in with 300 sks "G", 0.5% R-5, 1% D-19 from 12,521-8,546'. Started mixing @ 9:15 p.m., completed @ 9:50 p.m., 13.4# gal on blend, 15.5#/gal on neat. Pumped plug down with rig pump @ 2,000#, held OK @ 11:00 p.m. 9-15-72. Dropped DV bomb & circulated second stage. Trace of cement to surface. SECOND STAGE - Cemented w/760 sks "G", 1/2 cu ft Perlite, 4% Get, 1% D-19, 0 5% R-5 tailed in with 200 sks "G" 1% D-19 0 5% R-5 from 8,546' to · I , · 4,604'. Started mixing @ 1:10 a.m., completed @ 1:50 a.m. 13.2#/gal on slurry tailed in with 15.3#/gal on neat· Plug down with 3,000# @2:30 a.m. 9-16-72. Dropped DV bomb and circulated cement to surface. THIRD STAGE - Cemented with 912 sks "G", 1/2 cu ft Perlite, 4% Gel, 1% D-31 from 4,604' to surface. Started mixing @ 8:15 a.m., completed .@~8:45a~ 13.3#/gal on slurry blend. Pumped plug down with 3,000# @9:10 a.m. 9-16-72. Cement to surface. Set casing slips and changed spools. Tested slip seals to 3,000#, held OK. Changed pump lines to 6". Pressure tested Hydril to 1,500#, rams to 4,500#. Picking up drill collars and preparing to drill out plugs. 7" Liner - 1400 SX Class "G" w/ 1% D-31, 1% D-19, 2% R-5 & 18% Salt. FORM '484~ REV, 3--63 DATE January 29~ 1973 HiStORY OF OIL OR gas WELL FIELD Beaver Creek WELL NO., 4 LEASE STATE MEASUREMENTS TAKEN FROM Alaska Beaver Creek Unit BLOCK SEC., 34 PARISH COUNTY. Kenai l~eninsula Borough TWP 7N r 1 OW KB ELEV. ~ TOP OF Oil STRING .. ELEV.. TOP OF ROTARY TABLE~ ELEV. GRD. OR MAT ELEV. 164' · HISTORY PREPARED BY TITLE O. W. Akins Drilling Sup e rint endent DATE 1972 5/5- 6/11 6/12 6/13 6/14 6/15 6/16 6/17 6/18 It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. Moved in equipment and started rigging up May 5, 1972. F~ 1 D!'/;'S!C- ~.-i · ..,..,,. AHD GAS TD 76~ - Spudded at 9:00 PM 6/l]/72. Drilled 12~~ hole to 76~ and surveyed. Opened 12~' hole to'17~~ to 40~. TD TD TD TD TD TD 296' - Opened 17~' hole to 26" to 40'. Drove 30" pipe to 35' KB. Cemented with 60 sx Class G with 4% CaC1. Cut of~ drive pipe. Welded floTM line. WOC. Started drilling at 9:30 PM. Losing mud over shaker--screen mask too small. Drilled and surveyed 1Z~' hole to 296'. Pulled out of hole. Waiting on shaker screens. 296' - 17~'. clean. Changed shaker screens. Built up mud volume. Opened 12~' hole to Pulled out of hole. Opened 17~' hole to 26" to 296'. Circulated h°le Pulled out of hole. 296' - Ran 7 jts 20" H-40 8rd ST&C R-3 casing and landed at 288' KB. Ran Baker guide shoe and Baker duplex float collar. Circulated Z hrs. Cemented with 740 sx type G with 2% CaC1z. Maximum pressure 250#. Displaced with 25 cuft water. Job completed at 4:30 PM. Pulled drill pipe out of casing and cleaned out cellar. Waiting on cement. 296' - Top of cement at Z0'. Cemented outside job with 125 sx Class G with 2% CaC1. Cut off Z0" casing and welded 20'~ casing head housing. Tested with 250#, OK. Flanged up Z0" Hydril. Installed 'Baroid double screen shale shaker. Installed two 4" lines for blowdown lines from BOPs. Z0" Casing Detail Elf From To KB to top of casing 6 jts 20", 94#, H-40, 8rdST&C csg 1 Baker float collar 1 jt Z0", 94#, H-40, 8rd ST&C csg 1 Baker float shoe 24.00' 0 24.00' 223.66' 24.00' 247.66' 2.65' 247.66' 250.31' 33<12' 250. 31' 286.4a' z. 05' 286.43' 288.48' 296' - Drilled mouse hole. Drilled hard cement from 177' to 243'. Drilled at 243' for 1½hrs. Pulled out of hole to check bit; bit had deep cut in shank and circle-cut pattern on bottom. Ran impression block--showed float collar with stinger hole in center and 1" gouge out of side of impression block. 1, 329' - Ran 15" magnet and recovered Z lbs junk. Ran 1Z~' bit and drilled 3' hole on junk. Pulled out of hole. Ran 1ZQ' bit and drilled 8' hole. Ran 17~' bit and drilled cement to 266'. Circulated hole clean. Pressured casing 1 to 1,000# for yhr., OBi. 1Kan magnet and recovered Z pieces iron 1~' long, 1~' wide, and 1' round. Hole clean. Ran 17~' bit on 6 - 9" drill collars & drilled hard cement in shoe joint and hard cement 5' below guide shoe. Drilled from 296' to 1, 329' and surveyed every 150'. FC~RM 484 DATE REV. 3--63 HISTOF Y OF OIl OR GAS WELL FIELD Page Z Beaver Creek WELL NO. 4 LEASE STATE MEASUREMENTS TAKEN From ftoP OF OIL STRING ~ TOP OF ROTARY TABLE__ GRD. or MAT Beaver Creek Unit PARISH COUNTY __ ELEV._ ELEV.-- EIEV. __ bLOCK SEC. TWP. R HISTORY PREPARED BY TITLE ELEV. __ It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1972 6/19 6/20 6/21 6/22 6/23 6/24 TD TD TD TD TD TD 2,452' - Drilled and surveyed 17~' hole from 1,329' to 2,452'. 2,996' - Drilled 17~' hole from 2,452' to 2,462'. Tripped for bit change. Drilled 12~' hole from 2,462' to 2,996'. Opened hole from 12~' to 17~' from 2,462' to 2, 986'. 2,996' - Started out of hole. Pulled 3 stands tight. Swabbing hole, ran back to bottom. Circulated 1½hrs. 1Kan in h~le with 17~' bit. Broke circulation @ 2,145-2,427'. Reamed 2,427-2,660'. Circulated. 1leamed 2,660-2,996'. Circulated and conditioned mud. Made wiper trip. No fill. Circulated hole clean. Added walnut hulls to mud system. POH. Hole in good condition. Running 13-3/8" casing. 2,996' - Ran 27 jts 68#, J-55, Buttress csg (1,042.64') and 47 jts 72#, N-80 8rd csg (1,947. 10') with Baker' shoe and float and set at 2,989'. Centralizers 10' above shoe, 10' above float collar, w/one centralizer on every Other collar for 10 jts. One centralizer 120' down from top in 20r' csg. Circulated csg 1½ hrs. Pumped 15 BBLS water ahead of cement. Cementedw/Z, 000 sx Class "G" w/4% gel, 14# slurry, and 300 sx class "G" w/2% CaC1z, 15# slurry. 10 BBLS water behind plug. Displaced cement w/425 BBLS mud. Good returns all thru job. Good cement to surface. Started mixing at 3:40 PM. Completed at 4:40 PM. Maximum pressure 1,500#. Plug down w/Z, 000# pressure. Job completed 5:20 PM. Landed 13-3/8r' csg on OCT slips and seal assembly. Cut off 13-3/8" csg. Tested seal assembly w/Z, 000 psi, held OI~i. lXlippling up BOP. . 13-3/8" Casing Detail Elf. From To KB to top of casing 47 jts 13-3/8", 72#, N-80, 8rd Csg 26 jts 13-3/8", 68#, J-55, 8rd Csg 1 Baker float collar 1 jt 13-3/8", 68#, J-55, 8rd Csg 1 Baker guide shoe 25.50' 25.50' 1,916. 17' 25.50' 1,941.67' 1,005.72' 1,941.67' Z, 947.39' 1. 98' 2,947.39' 2,949.37' 36.92' 2,949.37' 2,986.29' Zo 71' Z, 986.29' 2,989.00' 2,996' - Installed 13-5/8" hydril. Built drlg nipple. Hooked up flow lines. Set choke manifold on rig floor. Set mud gas separator on mud shaker tank. In- stalled choke line from BOP to choke manifold. Installed lines from choke manifold to mud gas separator. Installed flow lines to downhole shale shaker. Cleaned out mud tanks. Installed 5" pipe rams. 2,996' - Installed choke manifold and kill line. Changed pipe rams. Installed flow line to shale shaker. Tested 13-3/8" casing and blind rams to 3,000 psi, held for 1/Z hr. , OI4. Ran test plug and pressured up pipe rams to 5,000 psi. Check valve leaked. Need new gasket. Accumulator for BOP to small closing time on pipe rams 4 min. Will install another accumulator for BOP. FORM 484 DATE REV. 3--63 HISTORY OF OIL OR GAS WELL FIELD ~'a~e 3 Beaver Creek WELL NO. STATE BLOCK 4 LEASE Beaver Creek Unit SEC. i PARISH COUNTY, __ ELEV..~ ~ToP OF Oil STRING__ ELEV.__ HISTORY PREPARED BY MEASUREMENTS TOP OF ROTARY TAbLE~ ELEV. TITLE TAKEN FROM LGRD. OR MAT. ELEV. TWP. R It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1972 6/25 6/26 6/27 6/28 6/29 6/30 7/1 7/2 7/3 7/4 7/5 TD TD TD TD TD TD TD TD TD TD TD 2,996' - Installed new BOP accumulator and remote control panel. Tested BOP and choke manifold to 5,000 psi. Check valve flange leaked. Re-tightened flange. Retested BOP and choke manifold, held O14. Closing time on pipe rams 6 seconds, h.eld pressure for 5 minutes. Tested hydril-to 1,000 psi, held for 5 minutes. Closing time 25 seconds. Picking up 7" drill collars. Preparing to drill out shoe. 3,886' - Completed picking up drill collars. Installed casing protectors on 1,000' of drill pipe. Drilled plug and float at Z, 94?'. Drilled and surveyed from Z, 996' to 3,886'. 4,765' - Tripped at 4, 175' for bit and drilling assembly. Reamed 90' to bottom. Drilled and surveyed from 3,886' to 4,765', 5,602' - Drilled 12~' hole from 4,765' to 5,324'. Tripped for bit change. 1 Down 7hr to change seals in clutch. Washed 35' to bottom. Drilled and surveyed from 5,324' to 5,602'. 5,761' - Drilled 12Q' hole from 5,602' to 5,743'. Circulated bottoms up and pulled 20 stands. Ran back to bottom and circulated and conditioned mud. Pulled up to 13-3/8" shoe - OI~l. ILan back in hole and had 29' of fill. Washed to bottom. Circulated hole clean. Strapped drill pipe out of hole. Corrected from 5,743' to 5,761'. Hole in good condition. Started rigging up Schlumberger at 0600 hrs. 5,761' - Ran Dual Induction Log from 5,747' t0 Z, 989' - two runs. Ran Sonic Log from 5,747' to 2,800'. Ran ClXlL FDC Log from 5,747' to 2, 989'--did not work. Ran FDC from 5,448' to 2, 989'. Logging time 12½hrs. Ran in hole to bottom of 13-3/8" casing and circulated bottoms up. Completed going in hole. Had 15' of fill. POH. Rigged up Schlumberger. Logging. 6, 115' - Continued running SNP Log from 5,752' to 2,989'. Ran Dipmeter Log from 5,752' to Z, 989'. Completed logging at Z:30 PM. Ran in hole and broke circulation' at 13-3/8" shoe. Drilled from 5,761' to 6,115'. 6,472' - Drilled 12~' hole from 6,115' to 6,162'. Checked BOP. Drilled and surveyed 1gQ' hole from 6, 162' to 6,472'. 6,658' - Drilled 12Q' hole from 6,472' to 6,488' and tripped for bit Change. Checked BOP. Hole in good condition. Drilled 12Q' hole from 6,488' to 6,658' 6,825' - Completed trip for bit #10. Reamed 30' to bottom, no fill. Drilled lZQ' hole from 6,658' to 6,788' & tripped for bit #11. Drilled 6,788-6,825'. 6,975' - Drilled 12~' hole from 6,825' to 6,873'. Tripped for bit change. Hole in good condition. Checked BOPs. Drilled lZQ' hole from 6,873' to 6, 975'. Tripping for bit change. FORM ~84 DATE REV. 3--63 HISTORY OF OIL OR' GAS WELL Page 4 FIELD Beaver Creek WELL NO. 4 STATE LEASE ]Beaver Creek PARISH COUNTY. BLOCK SEC. ~WP R. ~ ELEV. fToP OF OiL STRiNg ELEV.- HiSTOrY PREPARED BY / MEASUREMENTS LTop OF ROTARY Table ELEV. TITLE TAKEN FROM l GRD. OR MATi ELEV. It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 197Z 7/6 7/7 7/8 7/9 7/10 7/11 7/1Z 7/13 7/14 7/15 7/16 7/17 7/18 7/19 7/2,0 TD TD TD TD TD TD TD TD TD TD TD TD TD TD TD 7, llZ' - Completed trip for bit #13. Kan test plug and testedhydril to 1,500 psi, held OK. Tested BOP to 4, 700 psi, held OK. Drilled 1g~' hole from 6,975' to 7, 1 la'. Tripping for bit #14. 7,333' - Tripped in'hole and washed 20' to bottom. Drilled 12~' hole from 7, 112' to 7, 333'. POH.. Hole in good condition. Tripping for bit change. 7,548' - Completed trip for bit #15. Drilled 17.~' hole from 7,333' to 7,548'. Tripping for bit. 7,745' - Completed trip for bit #16. Tripping for bit. Drilled 1Z~' hole from 7,548' to 7,745' 7,952' - Completed trip for bit #17. , from 7,745' to 7, 952'. Hole in good condition. Drilled 1Z~" hole 8, 105' - Drilled 1Z~' hole from 7,95Z' to 7,995'. Tripped for bit #18. Drilled 1Z~' hole from 7,995' to 8, 105'. 8, Z88' - Drilled 12~' hole from 8,105' to 8, 163'. Tripped for bit #19. Checked_ BOPs. Drilled 1Z~' hole from 8, 163' to 8, Z88'. 8,469' - Drilled 1g~' hole from 8, Z88' to 8,336'. Tripped for bit #Z0. Hole in good condition. Drilled 1Z~' hole from 8,336' to 8,469'. 8,580' - Drilled 1Z~' hole from 8,469' to 8,516'. Tripped for bit #Z1. Drilled 1Z~' hole from 8,516' to 8,580'. 8,680' - Drilled 1Z~' hole from 8,580' to 8,680'. Tripped for bit #ZZ. Hole in good condition. Picked up 3 - 8" drill collars. 8,801' - Drilled 1g~' hole from 8,680' to 8,801'. Tripped for bit #23. Hole in good condition. Picked up 3 - 8" drill collars. Tripping in hole. 8,905' - Completed trip in hole. Drilled 12~' hole from 8,801' to 8,905' - shale and coal. Built mud weight up to 11.4#. Tripping for bit #24. 9,044' - Completed trip for bit. Drilled 12~' hole from 8,905' to 9,044' Tripping for bit change. Strapped pipe out of hole - no change. 9, 196' - Completed trip for bit #25. Hole in good condition. from 9,044' to 9, 196'. Tripping for bit #Z6. Drilled 1Z~' hole 9,356' - Completed tripping for bit #26. Pumped thru choke manifold, OBi. Back on bottom at 1:30 PM. Had 110 units of. trip gas. Circulated out drilling break at 9, Z58' - 25 units of gas. Had 180 units of gas and coal from 9,330' to 9,350'. Drilled ahead to 9,356'. Preparing to circulate for trip. FORM 484 REV. 3--63 DATE ~~~tI~:Ci~ C:~I~L ~~~~Y HIS'TOI~Y OF OIL OR GAS WELL FIELD i-'age 5 Beaver Creek BLOCK ' WELL NO. 4 LEASE Beaver Creek Unit SEC. STATE PARISH COUNTY __ ELEV. __ IToP OF OIL STRing ElEV.__ HISTORY PRePareD BY MEASUREMENTS I TAKEN FROM tTOP OF ROTARY TABLE ~ EIEV.__ Title: / [GRD. or MAT, ElEV._ TWP R. It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1972 7/Z1 7/22 7/23 7/24 7/25 7/26 7/27 7/28 TD TD TD TD TD TD TD TD 9,465r - Tripped for bit #27. Tested BOP stack with 1,500# on hydril, 4, 500# on pkpe rams, tested OK. Test witnessed by Bill Wanike of USGS. llole in good condition. Drilled 12~r hole from 9, 356' to 9,465'. 9,595' - Drilled 1Z~' hole from 9,465' to 9,515'. Tripped for bit #28. Drilled 12~' hole from 9,515' to 9,595'. Hole in good condition. 9,716' - Drilled 12~' hole from 9,595' to 9,650'. Tripped for bit #Z9. Checked BOPs. Hole in good condition. Drilled 12~' hole from 9,650' to 9,716'. 9,754' - Drilled 12~' hole from 9,716' to 9,754'. One jet in bit plugged. Driller picked pipe up 60' off bottom at 12:30 PM. Opened bleeder valve lowering pipe to open jet. Drill line parted 142' above rig floor, on dead line side. Kelly fell to rotary table and broke swivel and kelly bushings. Traveling block did not fall to floor due to fouling of drilling line in blocks. 1Kepaired block guards in crown. 2estrung 10 lines. Changed swivel. Drilling string weighed 2.30,000# when drilling stopped. W-hen picked up after being dropped, string weighed 162, 000#, loss of 68,000#. Circulating hole. 9,754' - Circulated hole clean. Pulled 44 stands of straight drill pipe. Laid down 153 its of crooked drill pipe and 15.7' piece of 5" drill pipe. Left approximately 16' of 5" drill pipe and 1 jt 5" drill pipe on top of drill collars. Total fish - 787.64'. Top of fish at 8,967'. Broke down 4~' kelly. Picked up 5~' kelly. Picked up 7' 8" drill collars. Tested BOP with 4, 500# on pipe rams and 1,500# on hydril, OK. 1Keplaced pins in rotary table beams. Picking up 5" drill pipe and going in hole with'mill shoe. 9,754' - Strapped in hole. Tagged top of fish at 8,971', corrected depth'. Circulated and milled on top of fish with' Tri-State cone mill with 11" OD with cone into 5/8" ID center. Milled from 8,971' to 8,974'. Circulated and con- ditioned mud. POll. l~an in with Bowen overshot dressed with 5" basket grapple and 12" guide shoe. Attempted to engage drill pipe. Could not get over pipe. Pipe appeared to be bent over in hole. Circulating and conditioning mud. Preparing 'to pull out of hole. 9,754' - Pulled out of hole and laid down fishing tools. Ran in hole with open- ended drill pipe to 8,960'. Cemented with 180 sacks type G cement with 1% D-31. Five BBLS of water ahead of cement. Displaced with 860 cuft mud. Estimated top of cement at 8,710'. Pulled 4 stands, circulated and conditioned mud. Cement in place at 7:50 PM. Pulled out of hole. 9 754' PBTD 8 790' Picked up monel drill collar. Ran in hole to 4, 500' circulated and V¢OC. 1Kan in hole to 8,700', circulated and ~WOC. Set down on cement plug at 9:00 PM. Top of hard cement at 8,785'. Drilled 5' of hard cement to 8,790'. Circulated to condition mud. Dropped multishot and pulled out of hole. Multishot did not work. FOR~ DATE REV. 3--63 HISTORY OF OIL OR GAS WELL FIELD Beaver Creek WELL NO. STATE MEASUREMENTS TAKEN FROM LEASE Beaver Creek Unit PARISH COUNTY BLOCK SEC. TWP. R ELEV. __ IToP Of OIL STRING EIEV.__ TOP OF ROTARY TaBLE~ ELEV. GRD. OR MAT. ELEV.__ HISTORY PREPARED BY TITLE It is of the greatest importance to have a complete history of the well. Use this fOrm in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1972 7/29 7/30 7/31 8/1 8/2 8/3 8/4 8/5 8/6 8/7 8/8 PBTD 8,790' - Tripped in hole for #Z multi-shot. Circulated and conditioned mud for turbo drill. Surveyed with multi-shot every 180' out of hole. Ran Eastman Gyro survey on 13-3/8" surface casing with survey every 200'. Welded dog on rotary table. Picked up turbo drill and ran in hole. Oriented turbo drill N 80° E. Drilling shoulder with turbo drill. TD 8,931' - Drilled 8 hrs with turbo drill#1 from 8,788' to 8,911'. POH. Laid down turbo drill and ran in with drilling assembly. Reamed from 8, ?90' to 8, 911'. Drilled from 8,911' to 8,931'. Ran survey - showed bit too close to fish. POH. Going in hole with open-ended drill pipe. TD 8, 931' - Ran open-ended drill pipe to 8,926'. Cemented with 180 sacks type G cement with 1% D-31 and 13 sacks of 10-20 sand, 15.8#/gal slurry. Dis- placed with 86? cuft mud. Cli° at 1:00 PM. WOC. Picked up 30 jts heavy wall drill pipe. Ran in to 13-3/8[' shoe. WOC. TD 8,815' - Ran in hole to 8 500'. Circulated and conditioned mud. Top of cement at 8,772'. Drilled 5' to 8,777' With 5 to 20,000#, 3 mtn/foot. Circulated bottoms up. POH. Picked up turbo drill #Z with Z½° kick sub and ran in hole. Faced turbo drill S 80° E at 8,777'. Drilled 9-7/8" hole from 8,777' to 8,815'. TD 8,840' - Drilled with turbo drill #Z to 8,833'. POH. Picked up 1Z~' hole opener. Opened hole from 8, ?7?' to 8,833'. POH. Ran in With drilling assembly. Drilled 1ZQ' hole from 8,833' to 8,840'. TD 8,878' - Drilled 1Z~' hole from 8,840' to 8,863' at rate of 10'/hr. Drilled from 8,863' to 8,878' at rate of 70'/hr. Ran survey at 8,878' - 1¼°. 1Keran survey at 8,878' - lyX°. Pulled up to 8,833' and checked survey at 8,833'.. Showed 4°. POH. Ran in with open-ended drill pipe to 8, 8?4'. Cemented with 255 sax class "Gr' With 1% D-31 and 10% coarse walnut hulls - 16#/gal. CIP at 4:20 AM. Estimated top of cement to be 8,540'. WOC. TD 8,661' - Cleaned out soft cement 8,637-8,654'. WOC until 4:30 AM. Drld cement to 8,661'.. Cement would not pump off With Z5, 00-0# weight. POH. TD TD 8,735' - Picked up monel drill collar and turbo drill #3 with 2½° kick sub. Faced turbo drill #3 S 10° E and drilled 8,661-8,735'. POH & laid down turbo drill. Picked up 12Q' hole opener and opened hole from 9-7/8" to 1Z~" from 8,661' to 8,690'. 8, 735' - Finished opening 9-7/8" hole to 12Q' from 8,661' to 8,735'. Surveyed and POH. Ran 12Q' bit and reamed 8,547-8,735'. Dropped survey & POH. TD 8,808' - Ran in with turbo drill #4-; Faced turbo drill S 20 ° E and drilled 8,735-8,808'. POH for bit change. TD 8, 858' - Ran in with turbo drill #5 and oriented drill due east. Drilled 13' and checked orientation. Still due east. Drilled to 8,858'. Ran survey and POH. Changed drilling assembly and ran in hole. Now reaming. FORM ~84 DATE REV. 3--63 HISTORY OF OIL OR' GAS WELL FIELD Page 7 Beaver. Creek WELL NO STATE MEaSUREmENtS TAKEN FROM 4 LEASE IToP Of OIL STRING __ TOP OF ROTARY TABLE~ GRD. OR MAT, Beaver Creek Unit PARISH COUNTY __ ELEV._ ELEV. ,. ELEV._ BLOCK SEC. TWP Roi HISTORY PREPARED BY. TITLE ELEV. __ It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1972 8/9 8/10 8/11 8/12 8/13 8/14 8/15 8/16 8/17 8/18 8/19 8/20 8/21 8/ZZ 8/23 TD 8,982' - Worked pipe to bottom and reamed to 8, 858'. Drilled 12~' hole 8, 858-8,982I. Ran survey. POH. TD 9, 068' - Completed pulling out of hole. Tested Hydril with 1,.500#, OK and pipe rams with 4,500#, OK. l~an in to shoe and circulated, l~epaired master clutch. Cut 90' and slipped 45r of drilling line. -Finished strapping in hole, no correction. TD 9,290' - Drilled 12~' hole to 9, 185'. Dropped survey and POH to change bit. Checked BOPs. Drilled from 9, 185' to 9,290'. TD 9,428' - Drilled to 9,360' and POH. Laid down 18 jts "G" drill pipe. tlan 6 stands from derrick. Ran in hole and circulated 15 minutes. Drilled from 9, 360' to 9,428'. TD 9, 540' - Drilled 9,428-9,522' and dropped survey. POH. Changed-bottom hole assembly, iR,an in hole to 3,000', slipped drilling line and repaired compount chain. Ran in hole to 9,522', circulated, and drilled to 9,540', TD 9,650' - Drilled 12~' hole 9,540-9,636' and dropped survey. POH for new bit. Ran in hole and drilled 9, 636-9,650'. TD 9,778' - Drilled 1Z~' hole 9,650-9,778'. POH for bit change. Ran in to shoe and changed out make-up cathead. Hole in good condition. TD 9,902' - Finished going in hole with bit #42. Drilled 1Z~' hole 9,778-9,902' and dropped survey. POH. Going in hole with new bit. TD 10,070' - Finished going in hole with bit #43. Drilled 1-Z~' hole 9,902-10,070' Dropped survey and now POH. TD 10,110' - Picked up 16 - 8" drill collars and ran in hole to shoe. Cut 90' of drilling line and slipped 45'. Drilled 1Z~' hole 10,070-10, 110'. Dropped survey and POH.. Ran in to shoe and now picking up new kelly and swivel. TD 10,258' - Drilled 1Z~' hole 10, 110-10,258'. Dropped survey and POH. TD 10,330' - Ran in hole to 2,800' and slipped drilling line. Drilled to 10,321', dropped survey, and t~OH. Ran in with bit #47 and drilled to 10,330'. TD 10,500' - Drilled 1Z~' hole 10,321'-10,446'. Dropped survey and POH to change bits. Hole in good condition. Ran in to bottom of surface casing, slipped and cut drilling line. Drilled 10,446-10, 500'. TD TD 10,602' - Drilled 10,500-10,542'. Tripped for bit. Cut and slipped drilling line. Drilled 10,543-10,602'. 10,738' - Drilled 1Z~' hole 10,602-10,664'. to 1,500# and pipe rams to 4,500#, test OK. Tripped for bit. Tested Hydril Drilled 10,664-10,738'. FORM 484 DATE REV. :)--63 H,$TORY OF OIL OR GAS WELL FIELD Page 8 Beaver Creek WELL NO.. STATE BLOCK 4 LEASE Beaver Creek Unit SEC. PARISH COUNTY. ELEV. ~ TWP R fToP of OIL STRing ELEV.. HISTORY PREPARED BY MEASUREMENTS iTOp Of ROtarY TablE~ EIEV. TITLE TAKEN FROM LORD. OR MAT, ELEV. It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of ali important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1972 8/24 8/25 8/Z6 8/Z7 8/Z8 8/Z9 8/30 8/31 9/1 9/z 9/3 9/4 9/5 TD TD TD TD TD TD TD TD TD TD TD TD TD 10,828' - Drilled 1Z~' hole 10,738-10,782' and dropped survey. POH. Ran in to shoe and slipped drilling Line. Drilled 10,782-10,828' and dropped survey. Pulling out of hole for bit change. 10,932' - Completgd trip at 10,828'. Drilled 1Z~' hole 10,828-10,932' and dropped survey. Tripped for bit change. Ran in to bottom of 13-3/8" casing and slipped drilling line. 11,041' - Completed trip in hole. Drilled 12~' hole 10,932-11,039' and rotary began to torque while drilling. Dropped survey and POH. Had 3" broke off of lead cone on bit. Ran in hole and now drilling with no indication o f junk. 11,082' - Drilled 1Z~' hole ll,041-11,065'and POH. Bit showed junk marks on shank and cones. Ran in with bit and junk sub - drilled 17' in 5 hrs. Bit in good condition, recovered approx. 1 lb junk from cone and 3'pieces of drill collar slip segment. Ran in hole with bit #56 11, 198' - Ran in to bottom of surface casing and slipped drilLing line. Drilled 1Z~' hole ll,08Z-11, 198'. Tripping for bit change. 11,289' - Completed trip out of hole. Recovered some junk out of junk sub. Pulled ware bushing - in good shape. Tested Hydril to 1,500# and pipe rams to 4,500#, test OI4. Ran in hole and drilled 1Z~' hole 11,198-11,289. Tripping for bit change. 11,420' - Completed trip. Ran in to surface casing shoe and slipped and cut drilling line. Ran to bottom and drilled 1Z~' hole 11,289-11,420'. 11,500' - Drilled 1Z~' hole 11,420-11;437'. POH for bit change. Hole in good condition. No junk in junk sub. Ran in and drilled 11,437-11,500'. 11,562' - Drilled 11, 500-11,506' and bit started torquing up. POH. Ran in to bottom of surface casing and slipped drilling line. Drilled 1Z~' hole 11, 506- 11, 562'. Tripping for bit. 11,662' - Completed trip. Hole in good condition. Drilled 1Z~' hole 11,562- 11,662'. 11,761' - Drilled 1Z~' hole 11,662-11,666'. Tripped for bit change. Drilled 1Z~' hole 11,662-11,761'. Tripping for bit change. 11, 835' - Completed trip for bit. Checked BOPs. 1Kan in and drilled 1Z~' hole 11,761-11,835'. POH for bit change. 11,929' - Completed trip for bit. Drilled 1Z~' hole 11,835-11, 9Z9'. Tripping for bit change. FORM 484 DATE REV. 3--63 =il HISTORY OF Oil Or GAS WELL FIELD Page 9 Beaver Creek WELL NO. STATE MEASUREMENTS TakEN FROM 4 LEASE Beaver Creek Unit PARISH COUNTY, BLOCK SEC. ToP Of OIL STRING_ ELEV. ~ ELEV.. ELEV. ELEV. HISTORY PREPARED BY TITle TWP R.. It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all 'completion operations and procedure, etc. DATE 1972 9/6 9/7 9/8 9/9 9/10 9/ll 9/12 9/13 9/14 9/15 9/16 TD TD TD TD TD TD TD TD TD TD TD 12,015' - Completed trip. Hole in good condition. Drilled 12~' hole 11,929- 12,015'. Dropped survey. POH. 12, 142' -Complete. d trip. Drilled 12~' hole 12,015-12, 142'.' Tripping for bit. 1Z, 236' - Completed trip. Slipped and cut drilling line. Hole in good con- dition. Drilled 1Z~' hole IZ, 142-12,236'. 12, 321' - Drilled 12~' hole 12,236-12,251'. Tripped for bit. Hole in good condition. Drilled 1Z~' hole 12,251-12,321'. 12,444' - Drilled 1ZQ' hole 12,321-12,341' of hole; corrected drill pipe measurement. Tripping for bit change. · Tripped for bit. Measured out Drilled 12Q' hole 12, 341-12,.444'. 12, 542' - Completed trip for bit. Drilled 1Z~' hole 1Z, 444-12,542" Making wiper trip prior to running logs. 1Z, 542' - Completed wiper trip. Circulated and conditioned mud for logs. Dropped survey and POH. Rigged up and tested 7' lubricator to 2,000#, test OK. Ran DIL 12, 536-5,700'. Running Sonic Log. 12,542' - Logging unit broke down. Pulled Sonic Log go shoe of 13-3/8" csg. Let motor on Schlumberger unit cool down. Pulled log out of hole and rigged down Schlumberger. Ran in with drill pipe and conditioned mud. POH. Rerunning Sonic Log. 12, 542' - Ran Sonic Log 10,000-5,688'. Ran FDC/CNL 12,540-4,900'. Ran Dipmeter Log 12, 540-5,700'. Completed logging at 3 30 AM. Going in hole to condition mud for 9-5/8" casing. Made 2 trips with Sonic and FDC/CNL Logs. 12, 542' - Ran in and conditioned mud to run 9-5/8" casing. POH and laid down 94 its drill pipe and 6 drill collars. Changed pipe rams and tested Hydril to 1,500#, held OK. 1{unning casing. 12,542' - Completed running 9-5/8" casing. Ran 65 jts 9-5/8" P-110, 53.5#, 61 jts 9-5/8" 1{.S. 95#, and 197 jts 47#, N-80. Landed shoe at 1.2,521' KB. Circulated hole clean· Cemented 1st stage with 696 sax Class "G", ¥cu'ft Perlite, 4% gel, 1% D-19, 0.8% 1{-5 tailed in with 300 sax Class "G", 0.5% R-5, 1% D-19 from 12,521-8,546'. Started mixing @ 9:15 PM, completed at 9:50 PM - 13.4#/gal on blend, 15.5#/gal on neat. Pumped plug down with rig pump at 2,000#, held OK at 11:00 PM 9-15-72. Dropped DY bomb & circulated 2nd stage. Trace of cement to surface· Cemented 2nd stage with 760 sax Class "G", ¥cu ft Perlite, 4% gel, 1% D-19, 0.5% 1{-5 tailed in with 200 sax Class "G", 1% D-19, 0.5% 1{-5 from 8,546' to 4,604'. Started mixing at 1:10 AM, completed at 1:50 AM, 1'3.2#/gal on slurry tailed in with 15.3#/gal on neat. Plug down with 3,000# at 2:30 AM 9-16-7Z. Dropped DV bomb and circulated cement to surface. FORM 484 DATE REV. 3--63 ' mAtH m HISTORY OF OIl OR GAS WELL FIELD Page 10 Beaver Creek WELL NO.. STATE MEASUREMENTS TAKEN FROM 4 LEASE Beaver Creek Unit PARISH COUNTY. BLOCK SEC. ELEV. ~ IToP Of OIL STRING ELEV. ItoP OF ROTARY TABLE~ ELEV. GRD. OR MAT ELEV. HISTORY PREPARED BY TITLE TWP R It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1972 9/17 9/18 9/19 9/20 TD TD TD TD 1 1Z, 54Z' - Cemented 3rd stage with 912 sax Class "G", ¥cu ft Perlite, 4% gel, 1% D-31 from 4,604' to surface. Started mixing at 8:15 AM, completed at 8:45 AM, 13.3#/gal on slurry blend. Pumped plug down with 3,000# @ 9:10 AM 9-16-72. Cement to surface. Set casing slips and changed spools. Tested slip seals to 3,000'#, held OI~. Changed pump lines to 6". Pressure tested Hydril to 1,500#, rams to 4,500#, OK. Preparing to drill out plugs. lZ, 54Z' - Tagged DV collar and plug at ~i, 613" Drilled plug at 4,613' and tested to 2,500~ for 1 hr., test Ot{. Ran in to 8,545' and drilled DV collar and plug at 8, 55Z'. Tested with 2,500# for 1 hr. , test OK. Ran in to float collar at 12,438'. Drilled plug and float and soft cement to 12,510'. POll to change drilling assembly. 9-5/8" Casing Detail Eff. From To KB to top of casing 18.35' 0 18.35' 122 jts 9-5/8", 47#, N-80, Buttress LT&C casing 4,584.81' 18.35' 4,603. 16' 1 DV Collar 1.70' 4,603. 16' 4,604.86' 75 jts 9-5/8", 47#, N-80, Buttress LT&C casing 2,816.73' 4,604.86' 7, 4Z1.59' Z7 jts 9-5/8", 47#, S-95, Buttress LT&C casing 1, 124.03' 7,421.59" 8,545.62' 1 DV Collar 1.70' 8,545.62' 8,547.32' 34 jts 9-5/8", 47#, S-95, Buttress t,390.41' 8,547.32' 9,937.73' LT&C casing 63 jts 9-5/8r', 53.5#, P-110, Buttress LT&C casing 2,500.55' 9,937.73' 12,438.28' 1 Baker float collar 1.96' 12,438.28' 1g, 440.24' 2 jts 9-5/8", 53.5#, P-110, Buttress LT&C casing 78. Z7' 1Z,440.24' 12,518. 51' 1 Baker float shoe 2.49' 12,518.51' 1Z,521. 00' All casing Range 3 12,521.00' 12, 542' - Picked up new bit and ran in hole to bottom of surface casing. Slipped drilling line. Tested 9-5/8" casing with 1,600#--would not hold, bled back to 800#. Cleaned out soft cement to shoe of 9-5/8" casing. Drilled out shoe at 12, 521' and ran to bottom at 12,542'. POll. 1Kan in with Baker Model t~ cement retainer to squeeze bottom of 9-5/8"' casing. 12, 542' - Set cement retainer at 1Z, 450'. Tested drill pipe and casing with 2,000#, broke down at 3,200#. Pumped 330 cuft water ahead of ZOO sax Class *'G" cement with 1% D-19. Slurry 14.5#/gal. Pumped 20 cuft water and 162 cuft mud behind cement and closed tools. Pressure increased to 3,600# and held. Approximately 50 sax cement in formation. 1Keversed out excess cement. Job completed at 11:30 AM 9/19/72. Dumped mud and cleaned mud pits. FORM 484' DaTE REV. 3--63 HISTORY OF OIL Or GAS WELL FIELD Page 11 Beaver Creek WELL NO. STATE MEASUREMeNtS TAKEN FROM 4 LEASE ToP Of OIL STRING ~ TOP OF ROtarY Table GRD. OR MaT. Beaver Creek Unit PARISH COUNTY, __ ELEV. __ ELEV._ EIEV. ELEV. bLOCK SEC. TWP. HISTORY PREPARED BY TITLE It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, ali completion operations and procedure, etc. DATE 1972 9/21 9/22 9/23 9/24 9/25 9/26 9/27 9/28 9/Z9 9/30 10/1 10/2 10/3 TD TD TD TD TD TD TD TD TD TD TD TD TD 1Z, 542' - Continued cleaning mud pits. Displaced water base mud with oil base mud. Completed at 8:00 PM. Tripped out of hole for bit. Ran in and started drilling on cement retainer. 12,549' - Gontinue'd drilling cement retainer at 12,450'. Drilled hard cement to 12, 526' and cleaned out to 12,542'. Drilled on junk from cement retainer 12,54Z-12,549'. Tested 9-5/8" casing to 2, 000#, test Ot(. Started trip for bit. Pulled Z0 stands and hole was swat~bing--would not take mud. 1Kan back to bottom, circulated and raised mud weight from 9.8#/gal to 10. l#/gal. Had 180 units of gas when circulated bottoms up after going back to bottom. Tripping for bit. Hole taking proper amount of mud. 12,650' - Completed trip for bit. Drilled 12,549-12,577'. Measured out of hole and corrected 5'. Drilled to 12,650'. condition. Tripped for bit. Hole in good 12, 775' - Drilled 12,650-12,738' and tripped for bit. Hole in good condition. Drilled 12,738-12,775'. 12, 942' - Drilled 8-3/8" hole 12, 775-12, 942' and dropped survey. POH. Hole in good condition. 13, 093' - Completed trip. Cut and slipped drilling line. Hole in good con- dition. Drilled 8-3/8" hole 12,942-13,093'. 13, 336' - Drilled 8-3/8" hole 13,093-13,336"andmade short trip after drilling 30 hours. Hole in good condition. Drilling ahead. 13,530' - Drilled 8-3/8" hole 13,336-13,400'. Had c0al stringers 13,400- 13,439'. Coal started sloughing, had to work pipe to keep free. Raised mud weight from 10. 1 to 10. 3#/gal. Hole cleaned up. Drilled 13,439-13,530'. Dropped survey. Now making wiper trip. 13,770' survey. 13,770' - Continued wiper trip to bottom of 9-5/8" casing. Made 2 trips for Ran back to bottom and had 12' of fill. Drilled 8-3/8" hole 13,530- 13,790' - Drilled 1 hr and ran directional survey at 13,780'. Tripped for bit change. Tested BOP stack, Ot{. 1Kan bit #77. Picked up lead drill collar. Changed bottom hole assembly. 1R~an in hole and encountered restriction at 13,430'. Raised mud weight and viscosity, tKeamed to 13,780'. Drilled 13,780-13,790'. 13,884' - Drilled 8-3/8" hole 13,790-13,884'. Tripping for bit change. 14,079' - Drilled 8-3/8" hole 13,884-14,079'. Had Z5' of fill on trip. 14, 131' - Drilled 8-3/8r' hole 14,079-14,103' and dropped survey. Tripped for bit. Picked up junk basket. Drilled 14,103-14, 131'. FORm 484 DATE REV. 3--63 HiStORY OF OIL OR GAS WELL [Page FIELD Beaver Greek WELL NO. STATE MEASUREMENTS TAKEN FROm BLOCK 4 LEASE Beaver Creek Unit SEC. TWP. r.i PARISH COUNTY __ ELEV. __ · ELEV.. HISTORY PREPARED BY ~ ELEV. TITLE f ToP Of OIL STRING TOP OF ROTARY TAblE GRD. OR MAT. ELEV. It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1977. 10/4 10/5 10/6 10/7 10/8 10/9 ~O/lO lo/]1 lO/lZ 10/13 10/14 lO/15 10/16 TD TD TD TD TD TD TD TD TD TD TD TD TD 14,299' - Drilled 8-3/8" hole 14,131-14, Z99'. Pulling out for short trip to bottom of 9-5/8" casing. 14,344' - Drilled 8-3/8" hole 14, 299-14,305' and dropped su~rvey. Tripped for bit change. D~illed 14, 305-14,344'. Down 3½hrs repairing compound chain and guard. 14,458' - Pulled into 9-5/8" casing to repair compound chain and guard. Completed repairs. Ran to bottom, had 20' fill. Drilled 8-3/8" hole 14,344- 14, 458' and dropped survey. Tripping for bit. 14, 61Z' - Changed drilling assembly and bit. Ran in hole, hole in good con- dition. Cleaned out 40~ fill 14,418-14,458'. Drilled 14,458-14,612'. 14,664' - Drilled 8-3/8" hole 14, 612-14,625' and dropped survey. POH. Hole in good condition. Ran to casing shoe and installed new compbund chain. Ran in to 14,595' and cleaned out 30' of fill. Had 450 units of gas while circulating bottoms up. Drilled ~o 14,664'. 14,762' - Drilled 8-3/8" hole 14,664-14,762'. Had break @ 14,738-14,752! - 3' coal, 11' sand @ 100'/hr rate, clay & shale 14,752-14,762' @ 10'/hr. Stopped @ 0110 hrs due to gas increase to 800 units and cut mud from 10.9 to 10.7#/gal with 3 BBL pit gain. Built mud up from 10.7 to 11.5#/gal in 6 hrs circulating and adding weight material. Started drilling @ 0700 hrs. 14, 862' - Drilled 8-3/8" hole 14,762-14,862'; Raised mud weight from 11.5 to 12.3#/gal. 14,897' - Drilled 8-3/8" hole 14,86Z-14;897'. Raised mud weight from 12.3# to 1Z. 7#/gal. Made short trip, ran back to bottom and had increase in gas of 160 units. Raised mud weight from 12.7 to 13#/gal. Circulating before making trip. 14,924' - Tripped for bit change. Tested Hydril to 1,800~ and pipe rams to 4,200#, test OK. Ran to bottom of 9-5/8" casing and cut drilling line. Ran to bottom and circulated bottoms up. Had 45 units of gas above base line. 14,995' - Drilled from 14, 924' to 14,995'. 15,078' - Drilled 14, 995-15,018'. Made short wiper trip, hole in good condition. Had 2' of fill. Trip gas 85 units, 40 units above base line. Drilled to 15,038' and had drilling break @ Z0-40'/hr. Circulated bottoms up - no gas. 15, 132' - Drilled 8-3/8" hole 15,078-15, 13Z'. Tripping for bit. Hole in good condition. 15,222' - Completed trip for bit #83. Slipped drilling line. Had 20' of fill after trip. Had drilling break 15,198-15,205'. Very slight show. Drilled 15,205-15,222'. fORM 484 DATE REV. 3--63 HISTORY OF OIL OR GAS WELL Page 13 FIELD Beaver Creek BLOCK WELL NO. 4 LEASE Beaver Creek Unit SEC STATE PARISH COUNTY. ELEV. ~ {/TOP OF OiL STRING. ELEV.. History PREPARED BY MEASUREMENTS [ToP OF ROTARY TABLE~ ELEV. TITLE TAKEN FROM [GRD. Or MAT. ELEV. TWP R.. It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, Cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1972 lO/17 10/18 10/19 10/20 lO/Z:t lo/mm 10/23 10/24 lO/Z5 10/z6 10/z7 lO/Z8 TD TD TD TD TD TD TD TD TD TD TD TD 15, Z51' - Drilled 15,222-15, Z5l' and lost 600 to 700# pump pressure. leaks in surface equipment. POFI. Ran in hole with new bit and pumped 50 strokes/min, every Z5 stands. Found hole in 6th jt from top. Laid down joint and ran to bottom. Circulating to check pressure,. . 15, 350' - Drilled 8-3/8" hole 15,251-15,340'. Circulated bottoms up. Drilled 15, 340-15,350'. 15, 350' - Circulated bottoms.up from 15, 350'. Measured out of hole - no correction. Rigged up Schlumberger and lubricator. Pressure tested to 1,500~, held OBi. Ran Dual Induction Log with Gamma Ray from 15, 338'. to casing shoe. Picked up core barrel and new jars and going in hole to cut core ~ 1. 15,380' - Completed trip in hdle with core barrel. Washed Z0' to bottom. Cut core #1 from 15,350' to 15,380'. Four hours working core barrel out of core hole. Pulled barrel out of hole. 15,420' - Completed trip out with core #1 from 15,350' to 15,380'. recovery. Laid down core barrel and picked up drilling assembly. to bottom and drilled ahead to 15,420'. Had 100% l~eamed Drilled 8-3/8" hole 15,4Z0-15,430'. Circulated bottoms up. picked up core barrel to cut core #Z. Washed Z0' to bottom. from 15,430' to 15,460' (30'). POH with core #Z. POH and Cut core #Z 15,505' - Completed trip out of hole with core #2 from 15,430' to 15,460'. Cut 30', recovered 30'. Laid down core barrel. Tested Flydril to 1,500# and pipe rams to 4, g00#, test OBi. Drilled 15,460-15', 505'. 15, 556' - Drilled 8-3/8" hole 15,505-15,556'. Dropped survey. Tripping for bit change. 15,600' - Completed trip for bit. Drilled 8-3/8" hole 15,556-15,600'. Circu- lated 2½hrs. POH to pick up core barrel to cut core #3. 15,630' - Cut core ~3 from 15,600' to 15,630'. Started off bottom and core barrel stuck @ approx. 15,609'. Jarred and worked drill pipe with no results. Ran free point with Dia-log and found free point @ 15,594', top of core barrel. Everything free to that point. Backed off @ 15, 508'. Left in hole: 1 core barrel, 1 XO sub, 1 DC, 1 stabilizer, & 1 DC. Top of fish ~ 15,508'. Circu- lated 1½ hrs. l~ow POFI. 15, 630' - POH. Picked up 12 DC and Bowen overshot with bumper sub and oil jars. Ran in hole and latched onto fish. Jarred 1 hr. Overshot pulled off fish. POH. Grapple in overshot was broken. Now going in with screw-in sub, bumper sub, oil jars, and accelerator jars. 15,630' - Tripped in hole with screw-in sub. Screwed into fish @ 15,508' Jarred 9 hfs with no results. Tried backing off safety jt on top of core barrel. Now PO/-/. FORM 484 DATE REV. 3--63 HISTOF Y OF OIL Or GAS WELL FIELD Page 14 Beaver Creek BLOCK- WELL NO. 4 LEASE Beaver Creek Unit SEC.. PARISH STATE COUNTY. __ ELEV. ~ · IToP OF OIL STRING ELEV.. HISTORY PREPARED BY MEASUREMENTS TOP OF RoTarY TABIE~ EIEV. TitLE TAKEn From GRD. OR Mat. EIEV. TWP R It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and. procedure, etc. DATE 1972 10/29 10/30 10/31 ll/l ll/Z 11/3 11/4 11/5 TD TD TD TD TD TD TD TD 15,630' - POH. Safety jt on top of core barrel did not break. Broke ~ screw- in sub. Tested BOPs. Ran in hole and screwed into fish @ 15,508'. Ran Dia-log free point and found fish stuck to top of drill collar @ 15,508'. Jarred on fish 2 hrs and ran Znd free point. Fish still stuck-in same place. Backed off with sc'few-in sub @ 15,508'. POH. Left in hole: 1 corehead, 1 core barrel, 1 DC, stabilizer, 1 DC. Top of fish @ 15,508'. Preparing to run open-ended drill pipe and plug back. 15, 630' - Ran open-ended drill pipe to 15,490'. Circulated 2½hrs, con- ditioning mud for cementing. Halliburton cemented with 100 sax type "G" with 10% sand, 18% salt, & 1% CFR?.. Slurry weight 17#/gal. Preceded cement with 10 BBLS unweighted Invermul followed by 10 BBLS diesel with 5 gals Hyflo, followed by 10 BBLS water with surfactant. Displaced cement with g BBLS water with surfactant and 269 BBLS mud. Pulled Z stands and 1 single of drill pipe (?.10'). II~versed out with water and diesel ahead of cement, plus approx. Z BBLS cement. After reversing out, drill pipe was stuck @ 15,271'. Worked pipe and circulated with no results. 1Kan Dia-log free point, drill pipe free @ 15, 132', stuck completely below this point. Backed off @ 15, 132' (wireline measurement). Top of fish @ 15, 132'. POH. Left 5 jts 5" drill pipe in hole. Top of fish @ 15, 1Z0'. Changed Hydril rubber. Tested Hydril to 1,500# and pipe rams to 4, ZOO#, test OK. Con- ditioned mud and hole. Circulating. 15,630' - POH. Ran open-ended drill pipe to 15,117.'. Circulated hole before cementing. Pumped l0 BBLS diesel and 10 BBLS water with surfactant. Cemented with 100 sax type "G", 10% sand, 18% salt, 1% CFIK2. Displaced with ?. BBLS water with surfactant and 1,445 cuft mud. [[ob completed 4:00 AM. POH. 15,630' - Ran in with bit and stopped at shoe. WOC until 4:00 AM. Ran in to 14, 150' and circulated bottoms up. Ran' in to 14,700'. Circulating and preparing to wash to bottom. 15,010' - Circulated bottoms up @ 14,700'. Washed to top of plug @ 14,907'. Tagged firm cement and drilled ahead to 15,010' in good cement. Circulated hole and conditioned mud. POH and picked up turbodrill. Going in hole. 15,016' - Tripped in hole with turbodrill #1. Oriented turbodrill and started building shoulder to kick off@ 15,010'. Drilled 6' of new hole to 15,016'. POFI. 15, 016' - Finished pulling out of hole. Found turbodrill #1 had failed. Ran in with turbodrill #2 with same bit and bottom hole assembly. Installed circu- lating head. Started running directional survey, and while moving and circu- lating drilling string, the 2" steel mud line broke out of circulating head, knocking driller off brake. Drilling string dropped 10' when elevators hit rotary table and held drilling string. Traveling blocks dropped to floor with drilling line completely unspooling from drum and jumping one sheave on crown FORM 484 DATE REV. 3--63 HISTORY OF OIL OR GAS WELL Page 15 FiELD]Beaver Creek WELL NO, STATE BLOCK 4 LEASE Beaver Creek Unit SEC. TWP r PARISH COUNTY. __ ELEV. ~ ffToP OF Oil STRING ELEV.. HiStORY PREPARED BY MEASUREMENTS I~ToP OF ROTARY TABLE ~ ELEV. TITLE TAKEN FROM /grD. OR MAT ELEV. It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of ali important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1972 11/5 (Cont'd) 11/6 11/7 11/8 11/9 11/lO 11/11 11/1Z 11/13 11/14 11/15 11/16 TD TD TD TD TD TD TD TD TD TD TD block. Restrung drilling line. Picked up drilling string and was free. Pulled survey line out of hole. Rotary clutch .caught. fire and flame put. out immediately. Drilled received cut on forehead but he was released from hospital after wound was treated. · 15,016' - Pulled up to 1Z, 300' and cut off ZOO' of drilling line. Changed out rotary clutch. Repaired line guide and crown-o-matic. Cleaned up rig and POH. Found no damage to drilling string. Cha{~ged turbodrill and checked BOPs. Ran back in hole with same bottom hole assembly and turbodrill ~3. Found Z5' fill on bottom. Hole in good condition. 15,085' - Orientedturbodrill S 30° W and drilled 15,016-15,085'. Circulated & tripped out of hole. Some tight spots in new rat hole. 15, 111' - Tripped out of hole &' laid down turbodrill. Tested BOPs with 1,500# on Hydril & 4,200# on pipe rams, held OI4. Ran into shoe & slipped drilling line. Ran 8 stands & motors stopped. Water in fuel. Got motors running & pulled up into casing. Cleaned out lines, fuel filters, & tanks. Reamed & washed to bottom. Ran survey on wireline. Started out of hole with survey and wireline broke. Repaired wireline & started out of hole. lVireline broke again. Pulled one stand & found wireline. Pulled survey out of hole. Drilled 15,085- 15,111'. 15, 164' - Drilled & surveyed 15, 111-15, 164'. Tripping for new bit. 15,279' - Completed trip. Drilled 8-3/8" hole 15, 164-15, Z79'. 15,355' - Drilled 8-3/8~' hole 15, Z79-15,315' & dropped survey. Made wiper trip. Retrieved survey w/sand line--no picture. Drilled 15,315-15,355'. 15,445' - Drilled 8-3/8" hole 15,355-15,366' & dropped survey. Made wiper trip. Retrieved survey w/sand line--no picture. Ran to bottom. Drilled 15,366-15,445' & dropped tandem survey tool. Pulled up into casing. Retrieved survey w/sand line. POH for new bit. 15,471' - Completed trip out of hole. Changed bit, 1 roller reamer, picked up junk sub and 1 stabilizer. Ran into shoe & slipped drilling line. Reamed 30' to bottom. Drilled 15,445-15,471'. 15,549' - Drilled 8-3/8" hole 15,471-15,549'. 15,603' - Drilled 8-3/8" hole 15,549-15,554' & made wiper trip· Drilled 15,554-15, 549'. POH for new bit. 15,630' - Completed trip out of hole. Tested BOPs. Repaired roller reamer & stabilizers. Ran in w/bit #93 to 1Z, 300' & changed drilling line. Drilled 15,603-15,630'. Bit #92 had Z pieces of cone end left in hole.. No iron was detected on bottom w/bit #93. FORm 484 DATE REV. 3--63 C ,L HIS'TOFfY OF OIL Or GaS WELL Page 16 FIELD Beaver Creek WELL NO. STATE bLOCK 4 LEASE Beaver Creek Unit SEC. TWP. r PARISH COUNTY. __ ELEV. __ top OF OIL STRING elEV.~ HiStORY PREPARED bY MEASUREMENTS ~toP Of ROTARY TABLE ~ ElEV._ TITLE TAKEN FROM / LGRD. Or MAT. ELEV.__ It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of ali important operations at the well, together with the dates thereof, including size of hole,.size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1972 11/17 11/18 1~/19 11/Z0 11/Z1 li/ZZ 11/24 11/Z5 11/26 TD TD TD TD TD TD TD TD TD TD 15,720r - Drilled 8-3/8rrhole 15,630-15,720' & dropped survey, t~OH for bit. 15, 7'35' - Completed trip out of hole for bit. Started in hole & shut rig down to repair jack shaft. Repaired shaft & ran to bottom. Drilled 15,, 720-15,735'. . 15,774' - Drilled to 15,739' @ Ir/hr in siltsione. Tripped for new bit. Drilled 15,739-15,774'. 15,820' - Drilled 8-3/8rr hole 15,774-15, 8Z0r & dropped survey. Measured out of hole. Ran to bottom of 9-5/8rr casing. Now cutting drilling line. 15,863' - Drilled 8-3/8rrhole 15,820-15,863'. Tripping for new bit. 15,937' - POH for new bit & ran back to bottom. Had 140 units trip gas 25 minutes early (C-3 & C-4 show). Drilled 15,863-15,937'. 15,940' - Drilled 15,937-15,940' & made wiper trip. Hole knotty. Ran to bottom & circulated bottoms up. I~OH. Hole in good conditiono Rigged up lubricator & Schlumberger & pressure tested to 1,500#, OK. 1Kan Dig W/Gamma Ray 15,938-14,700'. 15,940' - Ran Gamma 1Kay-Density & Dipmeter Logs 15,926-12,504'. Ran sidewall core gun & attempted 30 cores, t~ecovered 1 core & 7 partial cores. Rigged down lubricator. Now preparing to go in hole to condition hole and mud for 7" liner. 15,940' - Circulated bottoms up & had 800 units of trip gas. Made wiper trip. Circulated bottoms up & had 340 units of trip gas. Dropped survey. POH. Laid down heavy wall drill pipe. Now laying down drill collars. 15,940' - Completed laying down drill collars. 1Kan 88 jts of 7" liner on 5" drill pipe w/T.I.W, liner hanger w/bottom of liner @ 15,921' and top @ 12, 217' Circulated bottoms up & cemented liner w/l, 400 sacks Class r'G" cement w/l% D-31, 1% D-19, Z% R-5 and 18% salt. 1Kan 15 BBLS dieselw/l% Hy-flo & 15 BBLS mud flush ahead of cement, l~lug down ~ 5:15 AM 11/26/72. Ileversed out approximately 120 sacks of cement. W.O.C. 7r' Line-r Detail Eff. From To KB to top of casing T.I.W. Liner hanger & tieback sleeve 7 its., 7", Z9#, X-Line, l~ll0 casing 80 its., 7", 3Z#, X-line, 1~110 casing T. I.W. I~lug landing collar 1 jr., 7", 32#, X-Line, Pl l0 casing T. I.W. fill-up shoe -0- 12, 217.00 32.. 17' 12, Z17.00' 12, 249. 17 302.45' 12., 2.49. 17' 12., 551.62 3,323.64' 1Z, 551. 62.' 15,875.26 1. 04' 15,875. 26' 15,876.30 4Z. 43' 15,876. 30' 15,918.73 2.40' 15,918.73' 15, 92.1. 13 Total liner 3,704. 13' FORM 484 DATE REV. 3--63 HISTOIRY OF OIL OR GAS WELL FIELD Page 17 Beaver Creek WELL NO BLOCK 4 LEASE Beaver Creek Unit SEC. TWP PARISH STATE COUNTY __ ELEV. · I ToP OF OIL STRING __ ELEV._ HISTORY PREPARED BY, MeasureMENtS ~Top OF ROTARY TABLE ELEV. TITLE TAKEN FROM L GRO. OR MAT ELEV. R It is of the greatest importance to have a complete history of lhe well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 197Z 11/27 ll/Z8 11/29 ll/30 1Z/1 lZ/Z 12/3 lZ/4 il/5 I~BTD 15,875' - POH. ILanin w/8-3/8tr bit & 9-5/8tr casing scraper to top of liner @ 1Z, 217'. Hole was clean, loOH. l~icked up 5-7/8r' bit & 7'r casing scraper on 3,774' of~aaDr drill pipe, Going in hole. PBTD 15,875' - Completed trip in hole w/5-7/8r' bit & 7~' casing scraper. Found 200' fill on bottom. Washed 1Z0' & drilled 80' good cement to 15,875'. Circulated bottoms up. Tested 7~' liner to 2,260 psi for 30 min. , test OK. POH. 1Kigged up Dresser-Atlas & now running Gamma tLay& CBL Log. PBTD 15,875' - Ran G1K-CBL & Collar Locator Log from 15,875' to 4,5.00'. Picked up Halliburton 9-5/8TM drill stem test tool. Set packer @ 12, 167' & ran 2,000' of water cushion. Now testing liner lap. PBTD 15,875' - Completed 1-hr open flow and 1-hr shut-in on liner lap test. Reversed out water cushion. POH. Charts in drill stem test tool improperly loaded--no test. Ran in w/Halliburton test tool to 12, 167' w/Z, 500" of water cushion. Ran 35-min. open flow & 1-hr shut-in. Reversed out water cushion. POH. Liner lap test was dry. Now rigging up lubricator in preparation for DST #1. PBTD 15,875' - 1Kigged up Dresser-Atlas & perforated 15,795-15,855' w/4 jets/ft. Picked up Halliburton drill stem test tools. Ran 4, 500' water.cushion. Drill string took weight going in liner. ILan 1,700# gas cushion on top of water cushion. Now preparing to set packer @ 15,73Z' and open DST #1. PBTD 15,875' - Set Halliburton 7" packer @ 15,73Z' for DST #1. Opened test tool @ 7:15 AM for 1-hr initial flow. No pressure increase @ surface. Bled off 1,700# gas cushion. Closed tool in @ 8:15 AM for Z-hr initial shut-in period. Opened tool for final flow period @ 10:15 AM and.had very weak blow at surface throughout final flow. Final flow period 15 hrs. Closed tool @ 1:15 AM 1Z/Z/72 for final shut-in. Tool shut in for Z5-hr shut-in period. PBTD 15,875' - Continued final buildup on DST #1 to 2:35 AM 12/3/7Z. Opened circulating ports & reverse circulated out. Recovered 20 BBLS water cushion, 1Z BBLS mud, 20 BBLS oil and gas-cut mud. Released packer @ 5:45 AM. POH. PBTD 15,875' - Completed trip out of hole w/DST #1. Recovered total of 74 BBLS fluid consisting of 41 BBLS water cushion, 12 BBLS drilling mud, & 21 BBLS oil and gas-cut mud. Opened tool for 1 hr. Initial shut-in - 2 hrs, final flow - 15 hrs, final shut-in - 25 hrs. Pressures recorded: IHMP - 11,035 psi, IFP (1 hr) - 4,327 psi, ISIP (2 hfs) - 8, 172 psi, FFP (15 hrs) - 4,371 psi, & i~SIP (25 hrs) - 8,205 psi. Ran in w/5-7/8" bit & now conditioning mud to lower mud weight. PBTD 15,875' - Centrifuging & desilting mud to lower weight; also, diluting w/diesel & water--adding approximately 7 BBLS diesel & 7 - 8 BBLS water/hr. FORM 484 DATE REV. 3--63 HISTORY OF Oil OR GAS WELL Page 18 FIELD Beaver Creek WELL NO. 4 LeaSE STATE Beaver Creek Unit PARISH COUNTY. BLOCK SEC. - TWP R ELEV. ~ I top OF OIL STRING . ELEV.__ MEASUREMENTS LTop OF ROTARY TablE~ ElEV. TakEN FROM [Gro. OR MAT ELEV.__ HISTORY PREPARED BY TItlE It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 197Z lZ/6 lZ/7 lZ/8 12/9 12,/10 lZ/11 12/12, 12`/13 PBTD 15,875' - Circulated and conditioned mud, lowering weight from 12.2# to 11. l#/gal. POH to pick up bridge plug. PBTD 15,875' - Completed trip out of hole. Rigged up lubricator & tested to 1,500#, OK, Ran in w/Baker Model lq wireline bridge plug-to top of liner @ 12., 217'. Clutch on wireline unit failed. Now repairing clutch. PBTD 15,740' - Completed repairs to Dresser-Atlas wireline unit. tlan in with Baker Model N 7" bridge plug. Plug would not set. Pulled out of hole and found plug unscrewed from setting assembly. Plug went to bottom. Ran in w/a second Baker ModelN bridge plug and set @ 15,750'. Pressure tested bridge plug to Z, 000#, OK. tLan dump bailer with 1½ sacks Class "G" cement w/l% D-31 and filled. 10' in 7" liner. Perforated with Dresser-Atlas 4 HPFw/jumbo jets: 15,560-15,580', 15,600-15,610', 15,640-15,660', 15,685-15,695'. Rigged down lubricator & picked up Halliburton 7" DST tools. Now going in hole for DST #2. PBTD 15,740' - Completed trip in hole w/DST tools. Ran 3,500' water cushion. Tools @ 15,510'. Pressured up w/1,700# gas cushion. Opened tool @ 5:55 PM 12-8-72 for 1-hr IFP. Had weak, constant blow. Closed tool for 2`-hr ISIP. Opened tool @ 8:55 PM for FFP. Had slow, constant blow. Tool now open. PBTD 15,740' - Completed 15-hr FFP. Closed tool @ 11:55 AM 12/9/72. Had slow, constant blow throughout FFP. Closed tool for Z5-hr FSIP. DST #Z now closed in for final shut-in period. PBTD 15,740' - Completed DST #Z @ 12:25 AM 12/10/72. Reversed out 2.6 BBLS water cushion, 56 BBLS formation water w/some oil- and gas'-cut mud. POH. Ran in w/5-7/8" bit and now circulating to condition mud. Pressures recorded on DST #2: IHMP - 9,226#, IFP (1-hr) - 1,905#, ISIP (2-hr) - 7,637#, FFP (15 hrs) - 3,092#', FSIP (25 hfs) - 7, 663#, & FHMP - 9, 150#. Had 15 gals free oil below circulating sub. PBTD 15,520' - Circulated to condition mud. POH. Rigged up lubricator & ran Baker Model "lq" bridge plug. Set BP @ 15,530'. Ran 10' cement plug w/dump bailer (1½ sax Class "G" w/l% D-31). Perforated w/Dresser AtlaS Jumbo Jets 4SPF: 15,446-15,461', 15,416-15,431', 15,382-15,397', & 15,361-15,376' (60' total), lqow rigging down lubricator. PBTD 15, 52`0' - Picked up DST tools, ran in hole & set packer @ 15,313'. Top perforation @ 15, 361'. Ran 3,500' water cushion & 1,475# gas cushion. Opened tool @ 8:15 PM 12/12/72 & had 25# pressure increase. Bled off gas cushion. Shut tool in @ 9:15 PM 1Z/1Z/7Z after 1 hr initial flow. Opened tool @ 11:15 PM 1Z/1Z/TZ after Z-hr initial buildup. Weak blow to surface increased from 4~' to 5" and now slowing down to 3" blow. , FORM 484 DATE REV. 3--63 HiStORY OF OiL Or Gas WELL Page 19 FIELD Beaver Creek -. BLOCK WELL NO. 4 LEASE Beaver Creek Unit SEC. TWP. R. STATE PARISH COUNTY ELEV. ~ MEASUREMENTS ITM OF OIL STRiNg ELEV.-- HiStOrY PREPARED BY TOP of RotaRY TABLE EIEV. TITLE TAKEN FROM · [GRD. OR MAT, ELEV._ It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1972 12/14 1z/is lZ/16 1Z/17 lz/]8 12/19 PBTD 15,5Z0' - Continued Znd flow period. Blow decreased slowly. Closed tool for final pressure buildup @ 9:22 AM. Opened tool @ 12:22 AM and reversed out 55 BBLS total fluid, including Z6 BBLS water cushion w/show of oil- and gas-cut mud, 29 BBLS total formation fluid, 15 BBLS oil, and 14 BBLS oil- and gas-cut mud. Now POHw/DST tools. PBTD 15,315' - Completed POHw/DST tools. I~igged up Dresser Atlas and ran 7" Model "IWr' bridge plug, set @ 15, 315% Tested BP to Z, 000~, held OI~i. Rigged down lubricator. Now going in hole w/5TM drill pipe open ended. ~' - recorded on DST #3: IHMP - 9, 186#, IFP (1 hr) - 1,771#, ISIP (Z hfs) - 7,382#, FFP (10hrs) - Z, 105#, FSIP (15 hfs) - 7,398#, & FHMP - 9, 190#. PBTD 15,315' - Finished going in hole to 1Z, 190'. Circulated bottoms up. POll. Picked up lubricator & pressure tested to 1,500 psi, OI4. Dresser Atlas' perforated 15, 190-15,200' w/4. SPFw/tubing gun. Perforated 15, 155-15, 175' w/4 SPF w/tubing gun and.gun misfired. Ran back in and perforated 15, 155- 15, 175'. Rigged down Dresser Atlas and tripped out of hole. Now picking' up DST tools. PBTD 15,315' - Ran in w/DST tools for DST #4. Set packer @ 15,096'. 2,300' water cushion and 1,700# gas cushion. Opened tool@ 2:55 PM 1Z/16/7Z and had pressure increase of approximately 50#. Began bleeding off gas cushion @ 3:09 PM. Pressure bled to Z0 psi @ 3:55 PM when tool wa s closed for initial buildup. Bled gas off to Z psi during Z-hour initial buildup. Open. ed tool@ 5:55 PM for final flow period. Pressure increased to 50# w/fluid to surface @ 6:41 PM w/pressure increase to 500 psi. Recovered water cushion & oil- and gas-cut mud. Surface flowing pressure increased to 1, 100 psi on 1/4" choke. Closed well in at surface @ 9:13 PM to rig up separator. Opened tool@ 2:57 AM 12/17/72 and gas vent froze up. Closed well in @ 3:04 AM. Opened @ 3:26 AM and oil dump line froze up. Closed well in @ 3:45 AM. Opened well @ 4:20 AM flowing thru separator ~ 1,100 psi on 1/4" choke, holding 95# on gas separator. At 7:00 AM had flowing rate of approximately 40 BBLS/hr. , APl gravity 34.5 @ 64°, 1/2" bottom hole choke in DST tools. PBTD 15, 315' - Flowing well on 1/4" choke to 8:00 AM~ Estimated rate of 40 BBLS/hr w/drill pipe pressure of 1,088#. Changed choke to 1/2" @ 8:00 AM and flowed well @ rate of 65 BBLS/hr w/flowing pressure of 364 psi. Changed choke to 3/8" @ 12:00 Noon and flowed.well ~ approximate rate of 6Z+ BBLS/hr w/flowing pressure of 595 psi until 10:00 PM. Closed well in @ 10:00 PM for final buildup. Now closed in for final buildup. Total fluid from 7:00 AM to 10:00 PM - 848 BBLS. Total fluid recovery: 1,045 BBLS w/17 BBLS water, approximately l0 BBLS mud. PBTD 15,315' - Continued final buildup on DST #4 to 1:00 PM 12/18/72. Opened tool & reversed out 155 BBLS oil. Released packer @ 3:45 PM. Circulated to condition mud. Ran in hole w/teSt tool and tagged bridge plug @ 15,315'. Tripped out of hole and laid down DST tools. FOR~4 ~84 DATE REV. 3--63 HISTORY OF OIL Or' GAS WELL Page ZO FIELD Beaver Creek BLOCK WELL NO. 4 LEASE Beaver Creek Unit SEC. STATE PARISH COUNTY, ELEV. __ TWP R (Top OF OIL STRING ELEV.__ HISTORY PREPARED BY / MEASUREMENTS LTOP Of ROTARY TabLE~ ELEV.__ TITLE TAKEN FROM / ' GRD. OR MAT ELEV,__ It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1972 lZ/ZO 12/z]. lz/zz lZ/13 12/24 12/25 12/:2-6 lZ/17 PBTD 15, 130' - Tested BOPs, held OK. Ran Halliburton 7r' RBP and set @ 15, 130' Tested RBP, OK. Displaced drill pipe with diesel and set Halliburton RTTS tool @ 14,994'. Rigged up lubricator and attempted to perforate. Perforating gun would not pass thru RTTS tool. Reversed out diesel and released packer. . POH. PBTD 15, 130' - Rigged up and tested lubricator. Perforated w/casing gun: 15,060- 15,072' (12') and 15,082-15, 100' (18') w/4 shots per foot. Picked up Halliburton 7" DST tools, ran in hole and set packer @ 15,005'. Ran 2,300' water cushion and 1,700 psi gas cushion. Opened tool@ Z:17. AM 1Z/ZI'/7Z. Bled off gas cushion, shut tool in @ 3:12 AM after 1 hour initial flow. Opened tool @ 5:12 AM 1Z/Z1/TZ after Z-hour initial buildup. Very weak blow slowly increasing through test. ~ PBTD 15, 130' - Closed toOl for final shut-in@ 2:Z0 PM 12/21/72. Reversed out @ 4:40 AM 1Z/ZZ/7Z, recovered 13 BBLS water cushion, 44 BBLS gas- and water- cut mud and ZZ BBLS clean oil. CirCulated ½'hour and POH. PBTD 15, 130' - Pressures from DST #5 charts." IHMP 9, 063# FFP (9 hrs) - 1,724# IFP (1 hr) - 1,392# FSIP (14 hrs) - 7,627# ISIP (Z hrs) - 7,565# FHMP - 9, 108# Ran in hole w/bridge plug retrieving tool and conditioned mud. POH. Picked up Halliburton RTTS packer w/90' of Z-7/8~' tubing for tail pipe and ran in hole. PBTD 15, 130' - Pumped 20 BBLS diesel, Z, 000 gals mud clean-out acid and dis- placed with diesel. Spotted 10 BBLS acid across perforations (15,060-15,072', 15, 082-15, 100') and shut down for 10 minutes. Pumped 20 BBLS in 4-BBL stages, 5 minutes apart. Set RTTS packer @.15,012' w/tail pipe @ 15, 111'. Pressured up to 4,500 psi. Bled off and repressured to 3,800 psi. Formation did not break down. Opened well to flow .on 1/4t' choke @ Z:00 AM 12/24/72. Flowing pressure 550 psi from 2:00 AM to 6:00 AM. Flowed 206 BBLS diesel, pressure increased to 675 psi. At 6:00 AM started flowing acid w/pressure increasing to 1,000 psi. At 7:10 AM, placed well on test thru separator to test tank w/l, 000 psi flowing pressure. PBTD 15, 130' - Well flowed 387 BBLS oil from 7:10 AM to 11:30 AM 12/24/72. Reversed out ZZ7 BBLS oil and circulated 1 hour to condition mud. Ran in hole and'retrieved bridge plug @ 15,128'. Pulled up and set BP @ 14,625'. Pressure tested OK. Closed well in and shut down for Christmas. PBTD 15,315' - Rig down for Christmas until 1Z:00Noon 12/26/72. Circulated out on top of bridge plug. Now POH w/bridge plug. PBTD 14,629' - Completed trip out of hole--did not recover bridg% plug. Ran in and tagged bridge plug @ 15, 315'. Latched onto and reset BP. Reversed mud out of hole. Tripped out with BP. Ran Halliburton "N" Quick 7" bridge.Plug and set @ 14, 629'. Preparing to trip out of hole to perforate for DST #6. frcRM 484 DATE REV. 3--63 [~ISTOR¥ OF OIL OR GAS WELL Page Z 1 FIELD Beaver Creek WELL NO STATE BLOCK 4 LEASE Beaver Creek Unit SEC. TWP ~:~.l PARISH COUNTY. ELEV. ~ I ToP OF Oil STrINg. ELEV.__ HiSTOrY PrEParED MEASUREMENTS TOP OF ROTARY TAble ~ EIEV. Title TAKEN FRom [GRD. or MaT ELEV. It is of the greatest importance to have a complete history of the well. Use this form. in reporting the history of all important operations al' the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1972 12,/2_,8 1Z/Z9 lZ/3O 1Z/31 1973 1/1 l/Z 1/3' PBTD 14,629' - Tripped out of hole after setting BP ~ 14,629'. Tested BP w/2000~, OI4. Rigged up lubricator & tested to 3,000#. Two-inch Nipple blew out of Z" collar on 7" lubricator. Laid down lubricator & welded in new 2" collar. Pressure tested lubricator to 3,000#, held Olxl. Ran Dresser Atlas 4" perfo- rating gun--did not fire. Reran gun and perforated from 14, 535' to 14,565' w/4 shots/ft. Picked up Halliburton DST tools. Now going in hole. PBTD 14,629' - Completed running in hole w/DST #6 test tools. 1Kan g, 300' water cushion and 1,700# gas cushion. Set packer @ 14,478'. Opened tool @ 1Z:57 PM 1Z-ZS-7Z. Open for 1/Z hour. Closed tool for 1½hours for initial buildup. Opened tool ~ Z:57 PM for final ~ow. Left tool open for 8 hrs. Had strong blow at surface throughout flow period. Closed tool~ 11:00 PM 1Z/ZS/7Z for final buildup. Will leave tool closed in for 16 hours on final buildup. PBTD 14,629' - Continued final buildup on DST #6 until 3:00 PM 1Z/Z9/7Z. Reversed out 80 BBLS total fluid, 17 BBLS water cushion, trace of mud, and 63 BBLS formation water. POH w/DST tools. Picked up bridge plug retrieving tool and ran in to 14,600'. Now conditioning mud. Pressures recorded on DST #6: 1 IHMP - 8,866#, IFP (½hr) - 3,268#, ISIP (lyhrs) - 8,964#, FFP (8 hrs) - Z, 941#, FSIP (16 hrs) - 9,095#, FHMP - 8,866#. PBTD 14,600' - Conditioned mud to 11.6#. Spotted Z0 BBLS diesel across perfo- rations from 14, 535-14, 565'. Latched onto retrievable bridge plug @ 14,6Z9' and POH. Rigged up Dresser Atlas and lubricator. Ran gauge ring and junk basket to 14, 700'. Set Baker Model Kbridge plug ~ 14,600' and Baker Model K retainer @ 14, 515'. Rigged down Dresser Atlas and lubricator. PBTD 14, 515' - Ran in hole w/Baker stinger and broke down perforations w/4,500 psi and 4 BPM using 15 BBLS diesel and 7½ gals Hyflo. Mixed 150 sax"G" cement w/l% CFR?. and 0.7% HR-7. Pumped 10 BBLS diesel ahead and 10 BBLS diesel behind cement. Pumped cement into perforations @ 3,600 psi. Shut down for 3-minute stages and pressure increased to 4, 500#, 5,000#, and 5, 500#. Time since mixing 1 hr 15 min. Pulled out retainer, unable to reverse out. POH and found l, 0?.3' of 3~' drill pipe filled w/cement. PBTD - 14,600' - Completed POHw/Baker cement retainer stinger. Picked up 3 - 4-3/4" DC and 3~' drill pipe and ran in hole. Conditioned mud while W.O.C. Tagged cement retainer @ 14,515'. Drilled retainer and good cement to 14, 578' Circulated & conditioned mud. Preparing to pull out of hole to run dry test on pe rfo rations. PBTD 14,600' - Tripped out of hole w/5-7/8" bit. Pressured to Z, 500# on perfo- rations and casing held Olxl. Picked up Halliburton DST tools for dry test on perforations 14,535-14,565'. Ran 5, 000' water cushion. Set packer ~ 14,443'. Opened tool@ Z:10 AM and had very weak blow (~' increased to 3"). Closed to°l @ 3:10 AM for Z-hour shut-in. Blow continued during shut-in period. Reversed out 56 BBLS water and 1 BBL mud. POHw/DST tools. FORM 484 DATE REV, 3--83 HISTORY OF OIL OR GAS WELL FIELD Page 22 Beaver Creek WELL NO. STATE MEASUREMENTS TAKEN FROM 4 LEASE IToP of Oil STRING__ ITOP OF ROTARY Table (GRD. Or MaT Beaver Creek Unit PARISH COUNT¥i BLOCK SEC., TWP. __ ELeV..~ · ELEV.-- HISTORY PREPARED BY, EIEV. __ TITLE ELEV. __ It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1973 1/4 1/5 1/6 1/7 1/8 1/9 1/10 1/11 PBTD 15, 315' - Completed POH w/DST tools. Pressure charts indicated some fluid entry from perforations. Picked up 5-7/8" bit, ran in hole and drilled out bridge plug @ 14,600'. Ran in and tagged bridge plug @ 15,315'. Circu- lated to condition mud. Now POH. Pressures recorded on dry test of perfo- rations @ 14, 535-14,565': IHMP - 8,833#, IFP (1 hr) - 2, 157#, FFP - 2, 190#, FSIP (2 hrs) - 8,931#, FHMP - 8,898#. PBTD 15, 315' - POH w/bit and picked up casing scraper, tLanin to 15,315'. Conditioned mud. Pulling out of hole laying down drill pipe. PBTD 15,315' - Finished laying down drill pipe. Rigged up lubricator & tested to Z, 500 psig, OK. Dresser-Atlas ran gauge ring & junk basket to bottom, OBI. Ran Otis 7r' x 3~'r Permadrill packer w/wireline & set @ 14,615'. Set gnd Otis 7" x 4" Permadrill packer @ I4,469'. Rigged up to run tubing. Changed rams in BOPs. Picked up seal assembly for bottom packer & pressure teste& Found leaks. Tore down sealassembly & made back up. Pressure tested OBI. PBTD 15, 315' - Tested Znd seal assembly. Started running tubing @ 1Z:00 Noon 1/6/73. PBTD 15, 315' - Ran production tubing string as follows: Guide shoe, 3Q' x 20' seal assembly, 4 jts Z-7/8rr EUE 81t tubing (125.01'), 4~' x 20' seal assembly w/locator, X-nipple, 1 jt 3{r Buttress, circulating sleeve @ 14,43Z', 367 jts 3~' Buttress w/gas lift valves @ 10 385' 9,981' 9 577', 9,205' 8 800' , , I~ , ' ' ' 8,395', 7,990', 7,617',' 7, Z12', 6,804', 6,213', 5,408', 4,118', & 3, Z15' (14 gas lift valves), ball valve, 129 its 3~' S.L. tubing, 1 - 6' pup. Landed seal assembly locator 1½' above packer. Pressure tested tubing couplings to 8,000 psig externally & mandrels to 5,000 psig internally, OBi. Installed Oct back pressure valve in tubing head. Rigged down BOPs. Installed Oct X-mas tree & pressure tested to 5,000 psig, OBi. PBTD 15,315' - Rigged up Halliburton to displace mud from well w/diesel. Pressure tested lines to 5,000 psig. Circulated down tubing @ 4 BPM rate ~ 4,000 psig maximum. Displaced mud w/950 BBLS diesel. Rigged up Otis lubricator & pressure tested to Z, 500 psig. Otis ran in & attempted to close circulating sleeve without success in Z runs. Tubing pressure Z, Z00#, casing pressure 2,200 psig. PBTD 15,315' - Ran in w/sleeve to blank off Otis circulating sleeve--tool would not set. Attempted to jar sleeve ~hut without success. Sleeve still communi- cating w/annulus. Ran in w/X-nipple blanking plug--could not set. POH and found plug filled w/weight material. Rigged down Otis. PBTD 15,315' - Opened well to separator & produced well from 10:30 AM to 1g:00 Midnight in attempt to clean circulating sleeve. Shut well in & rigged up Otis.' Ran wire brushes & brushed Otis circulating sleeve. POH & rigged down Otis. Started producing well to clean tubing string @ 4:00 AM 1/11/73. FORM 484 DATE REV. 3--63 F,i'S'FORY OF OIL OR GAS WELL Page 23 FIELD Beaver Creek WELL NO BLOCK 4 LEASE Beaver Creek Unit SEC. TWP R.i PARISH STATE COUNTY EleV. · I TOP OF Oil STRING i EIEV.~ HiStORY PREPARED BY MEASUREMENTS l, ToP OF ROTARY TABLE ElEV. TITLE Taken From L GrD. OR Mat EIEV. It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1973 1/12, 1/13 1/14 thru 1/19 PBTD 15,315' - Flowed well to clean circulating sleeve. Shut vSell in ~ 8:00 AM. Rigged up Otis and closed circulating sleeve. Bled casing pressure @ 11:00 AM and determined that tubing was not communicating with casing. Opened well to production ~ 1:30 PM. Started unloading well with gas lift @ 5:30 PM. Total production (d{esel & oil) was 1,284 BBLS for last 24 hours. PBTD 15,315' - Unloaded well to separator with gas lift' Produced 1,662 BBLS of oil and diesel· PBTD 15,315' - Unloaded well With gas lift to 11:00 AM. Blew down casing and stabilized well. Commenced flow test on well @ 2:00 PM 1/13/73. 1Keleased rig to standby with partial crews @ 12:00 Noon 1/13/73. Rig taken off standby and released @ 5:00 PM 1/19/73. Test Data: Test Date . ~ ~.////?-~ L/?.~/ff, z~'Zz~-~'d) Producing Formation ~ ~ Casing Size (I. D. Inches) ,,, ~.,0F~z Cum. Prod. ND (bbl) Stabilized Daily Prod.~(B/D) Effective Prod. List t (hr) = 24Np/~ Company Lease Well No. Field State II. Calculation of kb, (md-ft) and k (md): ~ ~/,~ / ~/D ~/~ = i~.~ x p~;/ ) x (?7) ~, ( x/~ ) Calculation of Skin Effect, s; and Pressure Loss Due toAPskin (psi): ~ = (/~)= ~/ (~o) ) -I-8.2~---- · k , =- 1,151F( )-- ( - ) -- Io~ ' ( $ L III. Note: C~lculation of Productivity Index'(B/D-psi) and Flow Efficiency: 1. Compressibility is obtained from ¢~ = So co + Sw~w+c9 ' , " Ticket ' ~cJ,. U i O SAMPLE A Date 12-16-72 .Number 308499 ,r~ ' ' I' 5c~pler Pressure P.S.I.G. ot SuHace Kind Halliburton R~ery: Cu. Ft. Gas of Job HOOK WALL District ANCHO~.G-~ cc. Oil ' cc. Water Tester ~o' MA. DTN .Witness. . ~. ~u~ cc. Mud Drilling. " Tot. Liquid cc. .' Contractor R.BADING ~ BAS'ES IC S . , ,,, C,,m-~i~. "APl ~ "F. EQUIPMENT & HOLE' DATA ~Oil Ratio cu. ft./bbl. Formation Tested ~'G'" Zone Elevation 164 m 3t. RESISTIVIR CHLORIDE Net P~uctive Inte~al 30~ . 3t. CONTENT All Depths M~su,ed From Kelly Bushin~ ... ~~ Water __, ~ 'F. ppm Total Depth 1 5; 3~ 5" _Ft. A~e~ Mud ' ~ ~ "F. Main Hole/Casing Siz- ~ 5/~"" - 7~ A~e~ Mud Filtrate ~ __"F. ppm Drill Collar Length - ,. I.D, - ~ Pit ~mple ~ , 'F.' Drill Pipe Length 36~8~ ~8~39" I.D, 2.76~"-~.276" · ~ Pit ~mple Filtrate , , ~ ~ 'F. ppm PackerDepth(s) 3 ~;~9~~ , Ft. ~ Weight , . ~[.~. , vis ' cp Depth.,T~teF Valve ' ~ ~ ;'~79~' Ft. TYPE AMOUNT Depth Back Surface BoSom ~ F~SH WA~R 2300' (17 FBB~. Valve Choke 1/4" Choke 1/2" ~S CUSHION 1700 PSI ~ .. " ~ered 2300 Feetof Water cushion ......... PSI . a~,,~ 1440 ~o~ Oil .. '.. ~ . ...' , ~er~ ,380 .. ~of G~ .. '"' . . ' . ...... ...... . Depth: ~5;0~31 Ft. Depth: ~5~08~I Ft.t Depth: ~5 ~1 ..... ~ ' Ft. ~, ,,, ,,,,, 2~ Hour Clock 72 Ho,r C~oc~ ~2 Hou~ Cl~ Tool ~ 2; ~ 6 A.~.' ~t. "F. Blanked~f ~0 Blan~edO~f NO .. BlaD~edOH~S .. Opened ~: 55 P.M. 15,117' R T~I i 2-'1"8 A.M. ~~ ,..=~=1 223 °F. Pressures , Pressures,., Pressures .C,osed .)5:45p:M Field Office' Field Office Field Office Reported Computed Initial Hydrostatic 9068 ' ' 9125 9036 9109 909~ 9115 Minutes Minutes i-- ~-~,~ 4285' 4161 4262 4143 ~ 44~% 4190 ~ Flow ~'~ Final 4633 4627 4561 4575 4~75 4630 62 61 ~C Closed in 7504 7517 ~ 745~ 7480 7493 7493 120 113 == Initial4759" 4788 4661 . 4724 4806 4807 ~.~ F3ow ~' ~ S Final - 6372 5860 6328 '5888 6357 1685 195 ' Dosed ~n - 7495 7318 7~7 ..... 7395 7480 1060 333 Initial - 6~Q5 - 6fk~ - 6495 M~ F~ow .... ~ Final 6404 6379 - 5887 - 5911 .... - 1108 - Closedin ~RT TI~E EXpI~D' - 7371 "'- - 1033 F~I Hydrostatic AFaR 19~ MI~S CLOCK ~TOPmD ... 9127 ~2 . .- , 1' , , "' , ..... FORMATION TEST DATA """"'""°""°"'/"/2,-.C Ticket · F L U ! D S A M P L E 'A Date t2-16-72 ' Number 308499 Sampler Pressure P_~.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of Job HOOK WALL District cc. Oil cc. Water Tester ~,~c~. ~.~bl' Witness- ~R.. cc. Mud Drilling · Tot. Liquid cc. " Contractor READING & BA~,$ iC $ ,_ · Gravity. ' APl ~ °F. EQ U I PM E NT & H OL, E DA'T^ , Gas/Oil Ratio ~u. ft./bbl. Formation Tested ..] Elevation . RESISTIVITY CHLORIDE Net Productive Interval J=t. CONTENT All Depths Meosured From Recovery Water @ -- °F. ' ppm Total Depth . . Ft. Recovery Mud ° @ , 'F..' Main Hole/Casing Size Recovery Mud Filtrate __ @ °F. ppm Drill Collar Length _ I.D__ Mud Pit Sample , @ 'F.' Drill Pipe, Length I.D · Mud Pit Sample Filtrate @ °F. ppm Packer Depth(s) Ft. Mud Weight , ,, vis" cp Depth .Tester' Valve ' ' , , Ft. TYPE AMOUNT Depth Back Surface Bottom " Cushion Ft. Pres. Valve ~ Choke ' Oaoke ' · , .., , - . . Recovered ' Feet of ' . , : : .:..¥~?':; .::~., . · _ ., Recovered Feet of .... '. ,, ' .... , , , ,. Recovered Feet'of ''' ' ' Recovered Feet of .vi"' . ,, Recovered Feet of . '. Remarks ' ,, , , , , FOURTH GAUGE , · ~ Gauge' ' J i Gauge No. "138 !'Gauge No'. No. , TEMPERATURE , . TI,ME ,, Depth: , 15~1!6t Ft. Depth: Ft, I Depth: ,, Ft. . ,, , , , 72 Hour Clock j Hour Clock Hour Clock.j T°°l ,, ~,st. ,, , 'F. ' B!a~nk~ed Off .'Y~S , j 'Bl'an.l~ed Off Blanked Off Opened P.M. jToo, . Actual °F. Pressures Pressures Pressures Closed P.M. Field Office Field Office Field Office RelxuCed -C=z~m~uted l Initial Hydrostatic 9093 9126 . Minutes ~.~inutes Initial 4342 4194 · ~o Flow · '-': Final 4664 46~'5 Closed in 7508 7511 '' Initial 4826 4'813 " :o Flow 6366 J °u'c Final - , j Closed in - 7502 t I .. Initial - 6511 J ]~ Flow- ' ' J -c ~, Finol 15922 5945CS Closed in CS Final Hydrostatic CS=CLOC~ STOPPED .. , ] .. , /t"lll NTI~O IN · FORMATION TEST DATA --,,',-,,,,,-.,,',, /:z.. C~sing '0er/s._l,5, 190-15. 200'8ot~ ~oke Surf. ~emp_~ 4 'F Ticket No 30.8499 Gas gravity ..Oil gravity ,., GOR , Spec. gravity . .Chloride,~ . , ppm Res .... @ Dote Choke Surface Gas L;quid Time -a.m. Size Pressure Rate Rate Remarks psi MCF BPD ' iz_~6 ,,, 14:00 " On bottom - rigged up gas cushion 14:30 OPEN 1" 0 Gas cushion , , , 14:45 1250 Gas cushion ·, , /~'.5%~ . Opened. tool .. 15:00 Gas rise · :. 15:09 1900 , ' ,,'Bled pressure to trap. · 20 .......... Closed for closed in,-?ressure ,':~7:5~~,, 2 ' ' Reopened to°l for 'second 18:15 ,. ' ll , On bubble hose-opened tq. flow line .,. · 18:31 ' 1/4" choke , . .. 18:41 500 "..., Fluid to surface · · 18,,:53 , 1/4" . ,, 900 ...... ,, 1/4"., choke - still fluid 19:15 1/4" 1000 Oil.,,&,,gas to surface ..... 19:44 1/4'' .... 1100 , ,Gas..~ oil .,, , · . 2'1:13 1/4" ,,1!.00 Clos,ed..,manifold at surface .... . · , 2200 . ,, 12=17- 7,2 ....... 02:57 . 2350 ,, Opened, to flow to separator ,., · . 1200 .... ,Closed tool for clos,ed in pres.sure .... 0~ . 2350 Opened to flow 03:49 1300 , Closed at surface 04:30 2350 J 180 ,. 120_0 .Opened to fl0,,w., ., 04:35 1100 .... 290 900 .,34.5° AP1 Gravity 08: 02 550 ..!/2"- flow 08: 20 .375 .... F10w, .... 08:58 355 380 i440 Flowed gas & oil - oil cut .. _ 09:.00 1/2" 355 380 _ 1440 Small fluid .over_ Shalker. prjpba,~lv "' ..... i', ....... expanded volume & heat: in dri. l.i pipe PRODUCTION TEST DATA '"'"""' /.z Casing,perfs. ' Bert'S'" hake , , Surf. temp-.-~" ~°F Ticket ~ 308f~99 Gas gravih/ Oil gravity .. · GaR ~ .,, ,Spec, gr.a, vity , . Chloride~ ., , . ppm Res Date . Choke Surface I Gas Liquid Time a.m. Size Pressure I Rate Rate Remarks psi MCi: BPD 12:00 1/2" 355 " 1/2" choke-ready t:o change t:0 3[$" cho 12:02 3/8" 355 On 3/8h choke· 12:40 3/8" 600 Had a gradual increase 22:04 _3[8" ., 600 .., .... Gas Ii. ne froze up-pressure 'increased- 7~ closed surface mnifold · 3/$" , 2000 ... Closed tool .... 13:10 3/8" 0 .... 'Started, .reversing., , -' /% Pulled loose 16:00 ,., CircUlated & ¢.ondieion ...mud long way 20:45 ,', ' ~ ... ' .stepped circulating'broke down head., & equipmen~ 21:30 ' _ Ta~ged bottom depth at 15,315' " Came out: of.hole . . PRODUCTION TEST DATA , , ,, ,, ,, ,,, Coauge. No.: ..... 1238 . .. D.ep!h 15,083' Clock N°. 8422 ,. 24 hour No. . 3Q8499. First I Third Flow Period Clc;sed First Second . Second Third In Pressure Flow Period Closed In Pressure Flow Period Closed In Pressure ,, Time Deft. PSIG Time Deft. t -[- ~ PSIG Time Deft. PSI(; Time Dell. t~0 PSIG Time Dell. PSIG Time Deft. j~ P? IG Temp. Log Temp. Temp. Log Temp. ~ Temp. Log Temp. .000" Corr. .000" 0 Corr. .000" Corr. .000'~ ~ Corr. .000" Corr. .000" Corr. o .000 4161 .000 4627 .000 "J~788 .000' 6372 .00~) 6505 1 .209 .4627 .0494 7382*-- .1336.. 5535 .0207 .. 7298 (.101 7483S~] -" 2 .08-~3 7436 (.161 5680Pc .0414 .7361- (o311 -'7476SC~ ' 3 .1271. 7464 .2672 6331 ,0621 7389 °376 .... 6426**: 4 ,1660 7480 ,4008 '6379 .o 08__28 . 7408 · 668 6379 . 5 ,. ,2048 7492 .5344 -6375 . _~1035 7420 ' 6 2436 .7498 6680 6372 1242 ., ~ :7429 CHART ';Ibm EXPi .RED , · · ....... ,' , . · 7 .... 2825 7505 .1449- 7439 ~FTER .94 MINLK. JES _ 8 .3213 7511 ,16~_6__ ' : 7445 OF THI~LD FLOW 9 ..3602 7514 ,, ,1863 7448 PERIOD. io o3990 7517 . _--2_070 7455 · . ... 11 ~i_,3796' " 7473 '- '"' · . 12 _._~5__2_.1 748 6 ..... 13I - . .7_2_4L6 . '7489 14 ,, J ~. 89_71 ._7_492 ~5 ...............I ]_, ]_49_h '. _ '7495 .... .. Gauge No. 1237 Depth 15,088" ' Clock No. 98§.§ 72'h(~ur 0 ,000 4143J 000 j 4575 ,000 4724 ,000 6328 ,000 6467 ' ,'000 .5887 I .070 4575 [0159~ 7348* .0442 5463 °0068- 7238 (.031 7447S0 ,0136 7179 .2 ' ' ' .0284 7397 (.054 5637PC . .0137 7315 (.102 7440S~c ,.0273 I. 7~32 3 ..0.409 7424 .0884 __6291 .0205 .. -.7348 o1239'. 6384*~t~ .0409 7255 4 .0534 . .7444 . ,1326 .633_1 .0273 7368 .2500 6338 °0546 . 72..7~ 5 ' .0659 7454 . .1768 6331 .0341 7381 (.335 6328CC ~.0682' ... 7'25' 6 ,0784 7464 . .2210 6328 .0410 7391 .3762 5720 .0819 7295 7 .0909 7470 .. .0478 7401 .5023 5697 '.'0955 7301 8 ,1034' 7474 .0546 7407 (.601 5690CC' .1092 7308 9 . ,1159 . ' 7477 ,0615 7414 ,6285 5907 .1228 , . 73_11 ~o .... 1280 .. 7480 .... ,0683 , .. 7_4_2!_ :_ .7546 5907 ..~,.~_3..6_.5._ ' 7318 ._ · ~ ~ ..... 1252 7437 _. ,8808 5903 , 3640 7341 ~ .. .1821 7450 1,006.9 5900 .__,_59_!5-- _=__ .__73.6.4_ ' 23__ ........ ~.2_ 3__9.0 .... 7460 _1 ,_!D0_1_!_589.3 ...... .~_655_0~_]I' _707.l_. 14 , _~_29~._9 ~_4§.~L__ _~_5887 .CLOCK S'IOPPED I)[IR_I_N..G__.C_..I.] ~5 ~3790 '7467- - ONLY ,576 MINLr£E~ RECORD~ Reading Interval . 11 3 9 ** 111 Minutes REMARKS: *FirSt interval equal to '14'min~tes **First 10 intervals equal to6 'minutes; next 4' intervals equ~;!'ng~.. ~6 minutes each and last interval equal to 73 ~inutes. *~'~¢First interVal equal to 109 minUtes ****First 10-interx equal to 12 minutes each; next 4 intervals equal to 200 minutes and last interval equal to 113 minutes ! ....... %---:-~: ~'..., "'-~. .'. ~': ---~,-,. .~.;. .-.T_ ~ ~':_',~ ,- ' ' ' ' · l-,..~ ~ ,,i ,,.i D. al: PC~u~uluze caere c~adge' ' 6C=~ur~ace cio~'ure uu=unoke ciFan~e . '"'-"°'-".'.^. ~Di~C'~_I A I DI:Pl~-,~! II:Pl~ r~Z[TA ~"""' Gauge No. 352 . , ,Depth 15~112' Clock Nq. ,. ,6196 ...... 72 ho,u.r No. 308499 . . .. First First Second -Second Third Third . Flow Period Closed In Pressure Flow Period Closed In Pressure.. Flow Pe.rio, d Closed In Pressure , , ,, , Time Deft. PSIG Time Deft. t -1t- 0 pSiG' Time Deft. PSIG Time Deft. t ~ 0 PSIG Time Deft. PSIG Time Deft. t ~ 0 P? IG Temp. Log Temp. Temp. Log Temp. * Temp. Log ' Temp. ,000" Corr. ,000" ~ Cart, .000" Cart, ·000'~ {~ Cart, -000°~ ' Corr. ,000" iq ,, Cart, , , . 0 .000 4190 .000 4630 .000 4807 .000 ~357 ·000 6495 .000 5911 I ,069 4630 .0168 73-53* .045 5498 .0071 ~261 (.034 7461SC' .01~0 " ' 7186 2 .030t ' 7405 (,054' 5652PC .0i41 "7330 (.f05' '7454S0' .0280 7239 3 .0433 7435 .090 6315 .'0212 7359 .1270 6410~'~';~ o0419 7268 4 .0566 '" 7451 .135 '6357 ·0283 7376 .2563.. 6364 .0559 7284 7294 _ 5 .0698 7464 .180 6361 .0353 7389 (.345 6354CC' .0699 . y_j64 6 0830 7474 225 6357 .0424 7402 -. 3857 5751 0839 · · · , ......................... · ,_ _ ., . ~ -7 ' .09'63 ":7480 .0494 7412 .'5150 5731 .0979 73. 8 .1095 "7487 .0565 · 7418 . (.617 5715C~' .1119 7317 ,. 9 · 1228 7490 . 0636 ... 7425 . 6.444 5925 . 125--8 7324 ]0 " ....1360 ... 7493' ±0706 ..- ..... . .'743.1 .7737 5931 __....1._3_9..:8~_.; 7327 1] .... __,1____295~. 7.454 ._9__030 .___5928 ,372_.9 ' 73_59 ]2 .... ~-1~.8_4 746,4 . j,03__2___4_: ~921 ,6_0.59 '' _--7376 ]3 .2472: .. ___l_42.,4 _ 1._16LZ_5_9_1_8. ,8389 . 7386 -]4 ' . _~3_0_61_ _7_~77 _L~_910 591_1 _1_~_._0_720__ . ._7_3__95 _ 15 I ......... 392C)".. 748'fl . 1~. 2040 7402 Gauge No. 13~ Depth 15,116' ' Clock No. 9184 .72h6ur~. 0 .000 4194;I ,000 ! 4645 .000 4813 .000 ' 6366 o000 6511 ~ .071 4645 o0166t 7369* .0452 5516 .00'70 7275 (.034 7479SC 2 .0296 ' 7421 .(.054 5661PC' ·0141 7350 (·1'06 7476SC 3 .0427 7453 .0904 6330 .0211 7379 .1277 ' ..6430'*' 4 .0557 7472 .1356 .6366 o0281 7398 .2577 6375 _~ 5 .0688 7485 · 1808 6369 .0351 7414 . _(. 348 6369CC~__ ,. '6 .0818 7495 .2260 . 6366 .0422 7424 .3877 .5768 .... 7 ,0949 7502 o0492 7434 .. ,5176 ., :5742 - .1079 7505 .0562 7440 . ~,625 _5732¢_C. _ 12101 7508 .06_32 7447. ~6477 _5932 9 ]o .13..40 7511 .... ~.3~ 7450 ._7_7_7_7 _59.Z. L5 .! -- ]] '. 1288 7'4'72 .87'7~ -'5945 ]2 .1874. ,.7482 .,. ., .. ]3 ' . '~, ............ 2460 ..... 7489 .... CLOCK S';0PPE~ A].,TER .~ ~14 .... 3045_ _7495 749 MIN!~1,'.S OF ]IIRD __ ] 5...... '~ qOfl 75'02 _FLOW. ,, PE]~IQD. , , Reading Interval jJ 11 ' 39 ** 111 **** Minu?s REMARKS:*Fi~st interval eqUal to 14 minutes **First 10 intervals equal t~ 6 minutes; neXt 4 intervals equal .to..50 minute~ each and last interval equal to 73 minutes. **'*First interval equal to 109-minutes *~'~'.'*First 10 inter' equal to 12 minutes-each; next 4 intervals equal to 200' minutes and last interval equal t6 113 minutes ,,,,,~o,,,.,.~.C=P°ss{b-le chok& change Reversing Sub ................. Water Cushion Valve ............ Drill Pipe ....................... Drill Collars ...................... O. D. 5 ~ 00" 4.276" 2.764" .87" 5.00" ,. 3.50" Handling Sub & Choke Assembly ...... Dual CIP Valve ................... 3.85" ~..T.~..~. Z. ~O.m., .SU.B ~. 00" Hydro-Spring Tester ................ 3 ~ qO" Multiple ClP Sampler ............... .50" .62" .AP...CASg ............ 3.75" AP Running Case ................... 3.75" Hydraulic Jar ...................... 3,87" · 62" VR Safety Joint .................. Pressure Equalizing Crossover ......... 3,88" · Packer Assembly ................... 5 .. 75" 2:3§" LENGTH DEPTH 1.00' 8439' 3618' 14,8_72.42' 6,5' 8.30' 6.12' 15,079._34' .. 4.09' 5.08' 2.83' 3.63' 15,083' 15~.088' 4,34' - ., 15,096' Distributor ........................ 8o77' Packer Assembly ................... ~ X~DJ~Qgg~Q~g, PE.RF,. P. IPE ...... 2.88" Pressure Equalizing Tube ........... Blanked-Off B.T. Running Case ....... · Drill 'Collars ...................... Anchor Pipe Sairety Joint ............ Packer Assembly ................... ,vi' Anchor Pipe Safety Joint ............ !' Side Wall Anchor .................. i I~;~.~ Drill CoHar~ ...................... ~v~[]~orB. o.T...CASE ....... 3 o 85" Blanked-Off B.T. Running Case ....... 3 o 88" .HT- 500 TEMP. 2.259" 4.05' 15,112' 4.09' 15,116' 1.00' 15,117'-- I~llNTIrO IN U.$.A, EQUIPMENT 'DATA I I II II I IIII1! I I I IIIII LITTI. E'S 901lJ, SM 2/7Z III II iiiiiii ,,i,,,,, I "" . . . (,"; b<:,r:-I fJ £--:-4- (2.~ BtHl;. ).uP Test Data: ;) (" .. ' , "'" ' " . Test, Date ' I L.-/'l--I/ì L ' , Producing' Formation 'U~pë V' 'e:; II 2:: One, [,/ ,Casing Size (I.D. Inchés) , Z" 5it ,', Cum.,oProd. Np (bbl) , ',' ' , , ""'::-----1..- V'A-- -f,'a 0 '2.- ~V'>- Stabilized DailyProd.,(B!D) , 133-/) 1$/1> .~ Effective Prod ~ List t (hr) = 24Np/<¡ ,5"'qbþ, k~:' . ',,', c;: 0'" " . '" 0.:: (33.? 'PIt> I. ' Calculation of kh. (md-ft) an~ k (md): ~ ,'o°I.L;';" "G2.S9,JJ' ',. ::2-'2- Bo/4- 'L""'~' .'If" - ',m , " L.ft, ß/4,v. .. ','" 30" ,co, ',~' ,ýJ;~ fÐ ' ,'0' ' Company Lease . . Well No~ Field' Stàte, frl tit v¿C..fh. (F", E'e:a.,v<,-v C-r ~eJ( , 4- ' , ß.ea-v~Y('I-<:(,( Ul-1def -:~~ c7~'1 ~/úo'$i,¿ ¿..,' ' " 3~.'JØAPT ' , , 2.:'2.,1"':': - ~¿-"'D<'>@ /':;-,0"1..(" , / " F 1~ U. I D S A M P L E D . Date 12-21-72 ,',lumber 308500 Sampler Pressure P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. C~s of Job [-L0_~~, District AN~..~RAC~ cc. Oil DAVE GOLDEN cc. Water Tester HAROLD 1~ "~.Witness BOB ME~ cc. Mud Drilling Tot. Liquid~c. Contractor READING & BATES .- .~ S GraviS. ~ 'APl ~ z'. "" "F. E~UIPMENT & HOLE,, DATA ~s/Oil Ratio cu. ft./bbl. Formation Tested Upper"G Zone ~levation 1681 . Ft. RESISTIVI~ CHLORIDE Net Productive Inte~al 30 ~ Ft. , CONTENT All Depths M~sured From Kelly bushing R~e~ Water ~ . 'F. .ppm Total Depth 15 ~ 130 ' Ft. R~e~ Mud ' ~ eF. Main Hole/Casing Size ',9 5/8 -. 7" , R~ove~ Mud Filtrate ~ , *F. .ppm Drill Collar Length.. - I.D Mud Pit ~mple ~ ,, 'F. Drill Pipe Length 11387 - 3618' I.O 4. 276 - 2. 764" M~ Pit Sample Filtrate ~ ~' *F. .ppm packer Depth(s). ~53005,~ ,' ., ,Ft. Mud Weight ~1.5 vis 55 cp Depth T~ter Valve 14~ 988 ~ Ft. , , , ~PE ~OUNT Depth Bock Surface Bottom Cu~ion Water 2300 Ft. Pres.'Valve Choke 1/4~ Choke Gas Afoo ~8~ ...... _ R~over~ 1700 ~S~ Feetof gas cushion , R~over~ , 2300 Feet of water cushion , Recovered 22 bbls. ~of gas and oil ~ ~ ~ ~ovo ' ' ' I ~ ~ ~J ~ ' A~CHORAGE Recover~ Feet of ,,, ,,,Remar~ ~a~ ~o t5005~ ~tb 2300~ ~a~e= 'cdsb~o~ aud,. t700 ~s[ 8as hero= oPe~ [oo~s. Opened ~oo~ ~o= 6t ~u~e ~=sC ~tou. Otosed toot ~o= tt9 ~u~e ~=st ctose8 p=essu=e.' ~oo~ r, eope~ed ~o= second ~to~ ~b t~Sbt bto~ ~ bubbte bucket & bubbZe hose o~ ~o= 8u=a~o~ o~ ~[o~. Ctosed toot ~o= 973 m&~ute seco~8 ctoSe8 ~u p=e. ssu=~ ~e~e=Sed out app=ox~a~ety ~3 bbts. ~=esb ~a~e=, ~ bbts. o~ o~t a~d 8as & ~ate= ' Gouge No~~; Gauge No. 1237 Gauge No. 352 T~ERATURE~~- '. TIME .,Depth: , Ft. Depth: ~4997 Ft. Depth: ~502[ Ft.~ 2~ HourCIock 72HourC~ock 72Hour~l~k Tool ~2-2L A.M. Es~. 'F. Blanked ~f aD B~gnked Off,. QO', ' Blanked Off yes Opened 02~[ P.M. z ,02e' ? " Actual, 220 "F. , , Pressures , , pressures Pressures Closed. O~35 P.M. Field Office Field Office Field Office Reported ~mputed Jnitiat Hydrostatic 90~8 9t56 9036 9089 9012 .. 9069 Minutes, Minutes.. ;~ Flow Initial 3209 33[0 3202 32~5 3203 3222 · · · ~: " F~o~ ~366 t~fi3 [375 ~402 ~373 ~392 60 _. Dosed i~ 7536 7627 7483 7543 7559 756fi ~20 ~ Flow Initial ~239 [322 ~209 ~256 [242 . ~ Final ~685 [76fi [708 ~708 ~6~ [722 549 . Dosed ~, - 7555* 7:582 76~9 762~ 7630 975 -~-7-3 Initial ~ Flow -Closed in ~ .... ~" F~nol Hydrostatic 7~73 CT~ 9069 9089 . ' . 9Ot2 9069. · ~ea& a~ E~e end o~ '~37 m~n~e~ when ch~ ~me e::p~ed, ~(',T~=Cha~ .~me ~ ~ ~ ~ , , , ,,, ~ , , , , , .. ~ FORMATION TEST DATA "'"""°'"'°"'/" , , , F k U I D S A M P I. E D Date 12-21-72 Number 308500 Somber Pressure P.S.I.G. at Surface Kind Halliburton R~: Cu. Ft. Gas of Job HOC~ WA.LL District ~C~0~AGE cc. Water' Tester ['LA'OLD ~ Witness BOB ~E.--~) · cc. Mud Drilling Tot. Liquid cc. ,,C, ontroctor RE~'[NG & BATES , ,~[ , S - Gn:~ 'APl @ °F. EQUIPMENT &, HOLE DATA ~Oil Ratio cu. ft./bbl. Formation Tested .... Elevation , Ft. RESISTIVITY CHLORIDE Net Productive Interval Ft. CONTENT Ail Depths Measured From Recover/Water . ~ 'F. ppm Total Depth , Ft. F._~:o~ery Mud " @. °F. Main Hole/Casing Size R_~,ery Mud Filtrate (~_ cF. , ppm Drill 'Collar Length I.D f.~x;1 Pit Sample __ @ °F. Drill Pipe Length I.D .%~ Pit Sample Filtrate , , · @ ;F. ,ppm Packer Depth(s) . , Ft. Mud We~ht , vis , cp Dep,th Tester Valve , ,,,Ft. TYPE AMOUNT Depth Back Surface Bottom C~_~o~ , '. Ft. Pres. Valve , Choke , Choke .,, Recovered ·, Feet of Reco.,ered Feet of . Recovered ' Feet of ' ' °<:- , , , Reco~red Feet of .... , , -Ra.~rks Fourth gauge ,,, · , , , Gouge'No. 138" Gauge No. Gauge No. TF.~CP-G'~kTU R E TIME , , ,Depth: 15025 Ft. Depth:' · 72 HourClock HourClock HourClock Tool A3~A. ~t. °F. Blanked Off yes Blanl~ed Off Blanked Off Opened P.M. Too A,~,*t~i °F. Pressures Pressures Pressures Closed P.M. Field Office Field Office Field Office Reported · '~omputed Init~c] Hydrostatic 9061 9084 Minutes Minutes - Initial 3215 3222 , j~'~ .Final 1/-+20 ,1397 . ~' ~ Closed in 7573 7570 ., j-=.~ Initial 1260 1272 ' ,i ,, g =Fiow ' . ' ' ~'[ Final 1708 1724 , j '"~' C:osed in 7605 7628 ......... Initial ~., Final . . ......... C('osed in Fir, c~ H'ydrostotlc 9061 9081 ' , ..... "" b I I FORMATION. TEST DATA II I __. IIII I J I I I! rst Jl Fir s t $ ocond S~;cond Third Th l rd F Fie. w, PeriodI ,. Closed 1. Pressure Flow Perle_d ......... __ ._Clospd_!r~.Pre._s_s?.O:: ; . .. Flow P~riod Closed In Pressurt, Time D~fl, ] PSIG Time Dell. Log t -~- 0 PStG Time Deft. PSIG Time Dell. Log t -~- 0 P$1G Time Deft, P$1G Time Dell, t -~- 0 P'ClG 'l'emp. ~- Temp. Temp. ~ ' Temp. .Temp, Log Tcmo. .000"I Corr. .000" ~ Corr. .000" Corr. .000" ~ Corr. .000" ' Corr. .000" t'/ Corr, 1 .0371~ 3323 .0372' ' 6161 .1709~'* 1398 .1005 7166 2 .0709 2829 .0777 7116 .5059 1548 .2010.. .7445 " 3 .1047 2340 .1182 7433 8409 1640. ,3015 7480 ~ . 1385 1818 .. 1587 7486 1. 1759 1678 ,4020 7536 s . 1722 1548 .1992 7527 j. 5109 1723 (. 4580~ ** 755.5) 6 . 2060 1443 .2397 7561 1.8459 1764 ,5025 ~i~ 7 .2802 7577 .6030. - 8 .3207 7592 ,7035 . ' 9 . 3612 7611 , 8040 - ~0 ,4020- 7627 .904§. . .' ] ] 1.0051 - '] 2 1. 4406 ' · ]5 ~ ..... 2 7472 - . I .... 16 " 3%~259 7 - ' ' Gouge No. 1237 Depth 1,,4,997 ~ Clock No. 619,6 72 · hour ", .0'128'.1 3222 .0120. 6202' ~0577.'* 1332' .0336 7146 2 .02441, 2744 I .0251 7073 .1707 1488 .0673 7381 3 .03611 2239I 0.382 7354 ' 2838. 1588 ,1009 7434 4 .0477I 1754' ...0513 7401 .3969 1625 ,1345 7477 , , $ .0594 1488 ..0644 7450 .5099 1671 .1682 7500 ' ~_ 6 .0710 1.402 ,.0775 ..... 7490. .62~0 1708 ,2018 7517' , .... 7 ..0906 7510 ' .2355 7526 8 .1037 7523 .2691 - 7540 . 9 .1168 7536 . ~027 7546 .i0. . .1300 7343 ,. .33,64_ 7556 ' ] 2 I ,677q · .7593 , .]3 _ 7_7_36- 7603 Re°ding lnlcrvol l0 l{ 12 100 ,,** . Minutes RE~ARKS: '" ~First inter, val..is equal to 11 minutes. ¢~'<First interval is..equ'al".to 5'l..minutes. ~*'* Read at the end of approximately 137 minutes when chart time .expired. ALL READINGS ON BT # 1238 QUESTIONABLE DUE TO BASE LINE IN ERROR · ***First 10 intervals are_ equal to 30 minute's each, next 4' intervals are equal to 130 minutes each and last interval SPECIAL PRESSURE DAT Gouge No.. ..... 352 Depth .15 .021 ' .... CloCk.,No.. 9866., ,,. 72~, hour ! No, 308500 II First Second Second Third Third Flow PeriodII Closed In Pressure Flow Per!od Closed In Pressure Flow Period Closed In, ,Pressure Time Deft. P~IG ~ Time Deft. - t -t- 0 PSIG Time Deft. PSIG Time Doff. Log t -~- 0' 'PSIG Time Deft, PSIG Time Dell. Log Temp. Temp. .000" .000" .ogT Temp. Temp. . Temp. Temp. .000" Corr. .000" Corr. .000' Corr. .000' I~ Corr.. ~ Corr. Corr. 0 .0000 3222 .0000 1392 .0000 1268 .0000 1722 1 .0121' 3239 .0119~'~ 6180 .0565~w~ 1340 .0'330 7134 2 .0231 2788 .0249 7085 .1672 1497 .0660 7393 _ 3 .0341 2350 .0379 73.77 .2779 1598 .0990 7449 4 ·0450 1830 .0509 7430 .3886 1634 .1320 7492 5 .0560 1 536 .0639 7472 .4993 1683 .1650 7515 6 .0670 1392 " .0769 7508 .6100 1722 .1980 7531 7 .0899 7531 .2310 7541 8 .1029 7541 .2640 7554 · 9 .1159 7551 ' ' .2971 7561 .10 .1290 7564 ' .3301 7570 1'1 .4731 7593 12 .6161 7607 13 .7591 7616 14 . ,'90.21 , ~ 7625 _ ,.1,5 , .i ...... 1.0750 7630. . , , Gauge Ng', . , 138 . Depth 15,02,5' , ,CloCk No. . 9.184 72 .hour .... . c- .0000 3222 .0000 ~ 1397 .0000 1272 .15000 1724 .1 ..0124- 3238 0125-xJ 6068. .0579~'~* 1356 .03.41 7126 ,,. .. , . 2 .0238 2776 .0261 7019 .1716 1510 .0682 7392 3 .0351 2'292 .0397 7369 .2852 16'06 .1023 7450 4 .0464 1801 .0533 7424 .3988 1644 .1364 7492 .. 5 .0577 1535 .0669 7466 .5124 1689 .1705 '7515 .' - 6 .0690 1397 .0805 7511 .6260 1724 . .,.2046 7531' 7 .0941 7534 .2387 7544 8 .1077 7547 .2728 - 7553 , 9 .1213 7560 ..3069 7563 ,, .1o .1350 7570 ~ ~-3A.1.0 ~, 7570 ' 1] ', , ,4887 ...... ' 7595 ,. , _ 12 .6365 7605 13 7843 7615 ., :: ~ 4 ',.. ~ 320__ __2 62L .... 1 $'' , ....... .. l_ 1060 ..... 7 628 : . . , . Reoding Ir;tervol 10 12 ' _ .... 100 .... *** .. ., . . ,~ , ~M^RKS: *First interval is eo~ual to ll mtnutes. ~irst ~nterval is equal to 51 minutes v~*First 10 intervals ,, are equal, to 30 m~nutes each', next 4 are equal to 130 minu~es each and last interval is equal ~o 153 minutes. SPECIAL PRESSURE DATA PRINTED IN tl.i.A, .. aeversing Sub ................... Water Cushion Valve ............ Drill Pipe ....................... Drill Collars Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Dual CIP Sampler .... .... : ........... Hydro-Spring Tester ................ Multiple CIP Sampler ............... Extension Joint .................... O, D. J. Do 5II 5" 3. SOI1 3. 88II S.O0II 2.25" 4. 276" 2. 764" .87" · 50" .62" 3,90" . ' 308500 LENGTI-I DEPTI-i 1' 14782.42' 11387i 3618' 6.5" 8L 30 ' 6.12' !4,988' AP Running Case II Hydraulic Jar ..................... 3.75" 3.75" 3.87" .62¥ · . 4.09' 5.08' 2.83' VR Safety Joint ................... Pressure Equalizing Crossover ......... · Packer Assembly ................... · Distributor Packer Assembly ................... Flu~:~'~~r Perf. s ........... Pressure Equalizing Tube ........... Blanked-Off B.T. Running Case ....... Drill Collars ...................... Anchor Pipe Safety Joint ............ Packer Assembly ................... Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... Flus'ftx~;~h~r ~.T..Qa.~ e. ......... Blanked-Off B.T. Running Case ....... HT - 500 Te,.mp 3.88" .75" 3.63' 5.75" 2.36" 4.34' 2.88" 2.259" 8.77' , 3,88". 3.88" 4.05' ff.09' 1.00' EQUIPMENT DATA I III I IIII I 1499Z'. 14997' 15005' 15021' _ 15025 ' 15026' LITTL[ lt. ~O,11il, S~4 a/~f~ C~ng perfs. 15082 151~tro'~m{' ~e' 1/.2" Surf. temp __'F Ticket No , 308500 Gas gravity. Oil grav;ty, . , GaR S:)ec. g?.vity Chlorldeq ..... ppm Res., , Date 12-21-72 Choke Surface Gas Liquid Pre.~ure Rate Rate Re~rks Time a.m. Size psi AACF BPD - 12:00 On b~ttom · 1:30 AM Gas c~shion · 2:00 1700 PSI 2:11 Opened tool . 2:26 1" Bled gas off 3:11 1" Closed t:ool , , 5:11 1/4" Opened to flow-18 turns, by locked ' clutch. · 6:11 Bubble hose - 3" Light blow on bubble hose. ' ' 11:00 Bubble hose - 11" ., .Light blow with continuous increase. 14:20 Bubble hose- Li" - Closed tool 12_22_72 ...... 0440 started reverse circulating ,, 0524 Recovered approximately 22 bbls. '0528 Oil and gas. 0635 Pulled loose .. , , , , · · · , , , , , , ,, , .... Pffl~tT&~ IN PRODUCTION TEST DATA IIIII II II II I II I II III _ ii _ i1' _ APPENDIX A Reservo i r Perforated I nterva I s SUMMARY DST'S 4 & 5 DST #4. G-Zone .15155'175 '15190-200 DST #5 G-Zone 15060-72 15082-100 Total Fluid Prod.., Bb I. Est. BID Rate Gauge Depth Ft; IFP 'ISIP FFP FSIP k · DR Z~Ps · . rd · . (30') 1244 (Mostly 0il) 1392 BO ' 15112 46}6 (i hr) 7493 (2) 5908 . (21 .,3) 7385 (15) 80 72 2.42 885 1300' ,5-~3o (30') 50 Bb I/ 9 hr. Oil &O & GCM · I 33 BO 15021 1392' (I h'r) 7565 (2) 1724 (9,3) 7629 (16) 7670 3.2 5.3 4825 200' FLU I D SAM P L E DATA Ticket Date ~2-L6-72 .Number ]08~ Sampler Pressure P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. ~s of Job ~00~ ~A~ District cc. Oil cc. Water Tester ~. ~ Witness. cc. Mud Drilling. Tot. Liquid cc. " Contractor ~ADZ~G & ~A~S ZC S Gravity "APl ~ ~F. EQ U I PM E N T & H O L E D A Z A Gas/Oil Ratio cu. ft./bbl. Formation Tested ~G~ ~o~e Elevation ~ ~ ~ Ft. RESISTIVITY CHLORIDE Net Productive Interval 30 ~ Ft. CONTENT All Depths M~su~ed From ~e~[~ ~8h~. Recove~Water ~~ ~"F. '.ppm Total Depth I ~5~ Ft. Recove~ Mud ' ~ ~ ~ ~F. Main Hale/Casing Size ~ 5/~" - Recove~ Mud Filtrate ~ ~ ~ ~F. .ppm Drill Collar Length. - I.D - Mud Pit Sample ~ ~ ~ ~F. Drill Pipe Length ~6~8~-8~]9~ i.D. 2. 764"-4. 27 6" Mud Pit Sample Filtrate ~ ~ ~ oF. .ppm PackerDepth(s) 15:09~~ Ft. Mud Weight ~.~ vis cp Depth,T~ter Valve ].5~079~ ..... Ft. TYPE AMOUNT De~th Back Surface Bottom Cushion ~S~ ~A~ 2~00m ([7 F~~. Valve Choke ~/~" Choke ~8 CgS~ZO~ ~700 Recovered 2~00 Feetof ~Ce~ c~sb[o~ , PSI Recovered 1~0 ~o~ Recovered 380 ~of ,G~ ~ ~") '~' '" ,' Recovered Feet of $,,..~j.{~Jr~( Remarks SEE PRODUCTION ~ST DA~ S~ET FOR ~RKS ............. , , Gauge N0. '1238 'Gauge No~.~ 1237 ....... ~Gauge No. 3~52 ................. Oepth: 15~083' ~t. Oepth: 15~088' ~t. Oept~: 15,112' ~t, 24 HourCIock 72 HourCIock 7'2'"HourCl~k Tool i2'~16A.M. , Est. . ?.... manked .O.f.~ ..,NO 81an~ed Off NO Bbpked Off ~S ... Opened ... 14:55 P.M. 15,117' _ ~ Tool 12-18A.M. Actual .22~ ~F. , Pressures ..... Pressures , . Pressures Closed Field Office Field Office Field Office Reported [' 'Compuled , - .............. Initial Hydrostatic 9068 9125 9036 9109 9095 9115 ~inutes minutes ................ Initial 4285 4161 4262 4143 4413 4190 ~ Flow ........ .~'~ Final 4633 4627 4561 4575 4675 4630 62 61 ~ ...... C~osed~n 7504 7517 [ 7450 74~0 . . 7493 7493 120 11~ v~ Initial 4759 4788 4661 . 4724 4806 4807 =o Flow .... 8'= Final - 6372 5860 6328 5888 6357 1685 195 Closed in - 7495 7318 74~_7 7395 7480 1060 333 . Initial - 6D_Q5 - 6_fk6_7 - 6495 ~ o Flow · ~'~ ~ina~ . 6404 __ 6379 - 5887 - 5911 - 11,0~. Closed i. ~RT TIME EXPI~D - 7371 -7z~G - 1033" , , --i1 ,,, , , ,, , ' , , , ,,,, ,, ,, ,, ,, , ...~'PRINTE:D IN U.I~.A. FORMATION TEST DATA Ticket F L U I D S A M P L E D A T'A Dote 12-16-72 Number 308499 Sampler Pressure. P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of Job HOOK WAT,L District ANCHOR~G-~.... cc. Oil cc. Water Tester cc. Mud Drilling Tot. Liquid cc. '" Contractor~AD~[NG & BA'[~$ ]~(~ S Gravity. ° APl @ °F. EQ U I PM E N T & H O L E DA TA Gas/Oil Ratio cu. ft./bbl. Formation Tested Elevation _Ft. · RESISTIVITY CHLORIDE Net Productive Interval .Ft. CONTENT All Depths Measured From. Recovery Water __ @ __ °F. 'ppm Total Depth Ft. Recovery Mud ' __ @_ °F. Main Hole/Casing Size Recovery Mud Filtrate __ @ __ °F. .ppm Drill Collar Length. I.D. Mud Pit Sample __ @ __ °F, Drill Pipe Length I.D. Mud Pit Sample Filtrate __ @ __ °F, .pPm Packer Depth(s). Ft. Mud Weight vis ' cp Depth Tester Valve Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke I Recovered Feet of Recovered Feet of . Recovered Feet of · " Recovered Feet of .,./ o< Recovered Feet of , Remarks .......... , , , , FOURTH GAUGE Gauge No. 138' ' " ..... Gau'ge'No. " Gouge'No. ' '' TEMPERATURE TIME ,,DffPth: 15; 72 Hour Clock Hour Clock Hour Clock Tool A.M. Est. OF. Blcmked Off ~S .. Blonl~ed Off .... Blanked Off Opened P.M. Tool A.M. Actual °F. Pressures Press. ur.es , . Pressures . Closed . .. P.M. Field Office Field Office Field Office Reported CompUted Initial Hydrostatic 90~3 9i-2--~ Minutes Minutes Initial 4~-2 41~f .... .... =.~ Flow , 4-664 462+-~ .,- ,. Final Closed in... 7508 7511 'a= Initial 4826 4813 -- c o Flow _ 8'c Final ~366 ~ Closed in - 7502 Initial - 6~11 ~ F'ow . ~_~. Fin°l 5922 5945CS Closed in CS Finol Hydrostotic CS ,,, CS=CLOCK STOPPED FORMATION TEST DATA "'"'"'-""'°'"'""'/" Casing perfs. 15,190-15,200'Bad'tom choke .... Surf. temp i~ 4 °F Ticket No,- 308?99 Gas gravity ..... Oil gravity. GaR Spec. gravity ..... Chlorides .... ppm Res. .. @ °F .... Date Choke Surface Gas Liquid Time a.m. Size Pressure Rate Rate Remarks psi MCF BPD p.m. i2~16 ..... 14:00 ..... '" On bottom- rigged up gas cushion 14:30 OPEN 1" 0 Gas cushion , . · 14:45 1250 Gas cushion ! 14:55 ~,"'~ Opened tool 15:00 Gas rise ,,. 15:09 1900 . Bled p. ressure to ..trap ~'"~'~-57~> 20 Closed for closed in-pressure , , 17~'i-~-5-~,~,' 2 ,, , Reopened tool for'secOnd flow 18:15 11 ,, On bubble hose-opened to flow line 18:31 ' 1/4" choke 18:41 .,, 500 " ,/ Fluid to surface 18:53 1/4" ,, 900 ...... 1/4" c,hoke - still, fluid 19:15 1/4" 1000 Oil & gas to surface 19:44 1/4" 1100 ,, ,Gas..,.,& ,oil .... 21:13 1/4" ........... 1100 C,l,osed..mal~ifold at surface · 2200 12-17-72 02:57 2350 Opened to flow to separator, .... "';~'~)"~-0-~'.~ . 1200 ..... Closed tool for closed in pres,sure .... 0~:-~ .ii) 2350 Opened to flow .. 03:49 1300 Closed at surface 04:30 2350 ,!80 1200 _Opened to flow ., 04:35 1100 290 900 3,.4.5° APl_Gravity 08: 02 550 1/2"- flow 08: 20 375 .... Flow ....... 08:58 355 380 i&AO Flowed gas & oil - oil cut ........ 09:00 _ 1/2" 355 380_ 1440 Small fluid over Shalker; prohabl~_ " i,],'i . ....... ~ ........... e,xpa,nded volume,,& !Tea,t. in d. ril.,i pipe -""'"'"""'"""'""'""- PRODUCTION TEST DATA "'"'"""' /..2.. Casing perfs. , Bottom choke . ,. Surf. temp °F Ticket No.= 308499 PAGE ~2 Gas gravity. Oil gravity .... GOR . Spec. gravity Chlorides ppm Res Date Choke Surface j Gas Liquid Time a.m. Size Pressure J Rate Rate Remarks psi MCF BPD I 12:00 1/2" 355 " t 1/2" choke-ready to change to 3/8" cho' . 12:02 3/8" 355 On 3/8" choke · 12:40 3/8" 600 ....Had a_,gradual increase 22:04 3/8" 600 Gas line froze up-pressure increased- ~,~'--~' closed surface manifold 2'~ [0~z 3/8" 2000 Closed tool ".~~8- 72 13:10 3/8" 0 Started reversing ......... ............. .~ ,.,'"i5:45 / Pulled loose ~.._.[~_ ..~" 1,6:00 ..... Circulated & condition ~d long way 20:45 _ Stopped .girculating-broke down_head & equipment 21:30 ' Ta~ged bottom depth, at 15,315' , ,, . 2%:45 _ ,,,, Came Out of, hq!e ...... ......... · , , , .... ...... .. ........... ................ , ................... ............. ...................... ......... ........ ................ , . ........... , .... ... . .... , .., ............ ........ ...- ... . ...... , ,. ,,,,, ~ ,,,, , ,,,, ,, , ,,, ,,,, .,.,, "'"'""'"'"""""'"'"' PRODUCTION TEST DATA .,.,-,.,,-, ..-.2.. Gauge No. , First Flow Period Time Deft. .000" .000 ·209 Gauge No. PSIG Temp. Corr. 4161 4627 .000 .070 · 4143 4575 Reading Interval L238 J Depth · First Closed In Pressure Time Deft. .000" .000 .04 94 · °ss3I .1271 .1660 , ,2048 2436i --12825 L og~ PSIG Temp. Corr. 4627 7382* 7436 7464 7480 7492 7498__ 7505 .3213 7511 .3602 7514 °3990 7517 1237 Depth 000 0159 0284 .0409 4575 7348* 7397 7424 · 0534 7444 .0659 7454 .0784 ·0909 °1034 ,1159 ,1280 7464 7470 7474 7477 . 7480 15,083' Second Flow Period Time Deft. .000" .000 .1336 ( .161 .2672 ,4008 ,5344 ,6680 15,088'' PSIG Temp. Corr. 4788 5535 5680PC' 6331 '6379 6375 6372 . .000 .O442 (.054 .0884 ,1326 .1768 .2210i 11 2 4724 5463 5637PC' 6291 6331 6331 6328 Clock No. 8422 Second Closed In Pressure Time Defl. .000" .000 ,0207 .0414 ,0621 ~o0828 ,1035 ,1242.._ .1449~ ,1656 ,I863 _,2070 j3796 _~55_2_1 _~7_246 .8971,. '1:149b ' Clock No. 9866 .000 .0068 .0137 .0205 .0273 .0341 .0410 .0478 .0546 .0615 .0683 .1252 .1821 ,2390 °'2959 ,3790 PSIG Temp. Corr. 6372 7298 7361 7389__ 7408 7420 _2_429.. .7439 7445 7448 7455 7473 i '7489 l 7492 , 7495 6328 7238 7315 7348 7368 7381 7391 7401 7407 7414 7421 7437 7450 7460 7464 !7467 JTicket 24 hour No. Third Flow Period Time Deft. .000" o000 (.101 (o311 °376 .668 PSIG · Temp. Corr. 6505 7483SC 7476SC 6426'*~ 6379 308499 Third Closed In Pressure Time Defl. .000" CHART 'IbM EXPi ~D AFTER 94 MINI~ ES OF THI].D FLOW PERIOD ', 72h0ur .000 6467 (.031 7447SC (.102 7440SC o1239 6384-~ .2500 6338 (.335 6328CC .3762 5720 .5023 5697 (.601 _ 5690CC .6285 5907 · 7546 5907 .8808 5903 1.0069 5900 1,1331. 5893 .12590_ 5887 i Log t + 0 P?IG Temp. Corr. .000 5887 o0136 .0273 .0409 °0546 .0682 .0819 .0955 .1092 7179 7232 7255 727f ..... 7285. 7295 7301 7308 .1228 7311 73].8 ], ,3640 J 7341 · / ..... ..... _ ·/ CLOCK S,~OPPED D_~.ING CIt ONLY 57~ l~t~UZ~-~ ~"~0-~ ...... Minutes REMARKS: *First interval equal to 14 minutes **First 10 intervals equal to 6 minutes; next 4 intervals equal to 50 minutes each and last interval equal to 73 minutes· ***First interval equal to 109 minutes ****First 10 inter~ equal to 12 minutes each; next 4 intervals equal to 200 minutes and last interval equal to 11.3 minutes FC~Po~ible choke ci-?ange ~=sur~ace ci-crs~ure Cc~chOke ch~n~e 'als Gauge No. 352 j Depth 15~112' First Flow Period First Closed In Pressure Second Flow Period Clock No. 6196 Second Closed In Pressure ITicket 72 hour No. Third Flow Period 308499 Third Closed In Pressure Time Nfl. PSIG Time Defl. , t + 0 PSIG Time Defl. PSIG Time Defl. Lo- t ~ ~ PSIG Time Defl. PSIG Time Deft. .~ PFIG Temp. Log Temp. Temp. Temp. · l'emp, Log Temo. .000" Corr. .000" ~ Corr. .000" Corr. .000" YT Corr. .000" Corr. .000" ,. Corr. .000 4190 .000 4630 .000 4807 .000 6357 o000 6495 .000 5911 .069 4630 .0168 7353* .045 5498 .0071 7261 (.034 7461SC .0140 7186 .0301 7405 (.054 5652PC .0141 7330 (.105 7454SC .0280 7239 .0433 , 7435 .090 6315 .0212 7359 .1270 6410~'~" .0419 .0566 7451 ,135 '6357 .°0283 7376 .2563 6364 .0559 .0698 7464 .180 6361 .0353 7389 6354CC .0699 7418 (.345. .3857 o1095 7268 7284 7294 .0830 7474 .225 6357 .0424 7402 5751 .0839 7304 .0963 ' 7480 °0494 7412 :5150 5731 .0979 7310 · 5715CC~ 7487 .0565 .1119 (.617 .6444 7317 o1228 7490 .0636 7425 5925 .1258 7324 I .1360 7493 .0706 7431 .7737 5931 .1398 7327 7454 5928 7359 7464 · ,1295 ,1884 .2472 _L~0~I" 5921 _5918.__ 5911 ,3920"1 7474 .7477 · 372_.9__' ·6059 ,8389 1,072__0_0 1.20401 ,9030 1.03_24 --l._161.l 1.291~ Gouge No. 138 Depth 15,116' Clock No. 9184 72h0ur 7376 7386 7395 I 7..402 C 7 8 11 12 13 14 15~ .000 Reading Interval 4194 .000 4813 4645 .000 ·000 .071 4645 o0166 7369* .0452 5516 .00'70 .0296 · 0427 7421 7453 , (. 054 .0904 5661PC' 7485 .0141 .0688 6366 - 7275 7350 7379 o000 6511 (.034 7479SC (.106 7476SC 6330 .0211 .1277 6430**' .0557 7472 .1356 ..6366 .0281 7398 .2577 6375 7414 .0818 o1808 .2260 7495 .0949 7502 .1079 7505 6369 6366 ,1210 .0351 .0422 . o 0492 .0562 _~_0_0632 .0703 .1288 .1874 _°2_460 ,1340 7508 .~511 7424 7434 7440 7447 745O 74'72 7482 (.348 i 7502 i 11 .3877 5176 .~°625 ~ 6477 .77_17 ~_8770 6369CC 5768 5742 _5732C_C 59_32 5945 7489 CLOCK S,FOPPED A]'TER 7495 749 MINIITES OF/il'HIRD FLOW PEi~IOD, 111 39 Minutes REMARKS: *First interval equal to 14 minutes **First 10 intervals equal to 6 minutes; next 4 intervals equal to 50 minutes each and last interval equal to 73 minutes. ***First interval equal to 109 minutes *~'~'.'*First Y0 inter~ ~ .... ~,o,,o.,.~.C=Posslble choke change equal to 12 minutes each; next 4 intervals equal to 200 minutes and last interval equal to 113 minutes S C=SUg~Cl~ ~q]u~? I::) I:~ ~:~k- j~ i ~_~g~-~ A -r- A ~,..-.'. 'als 308499 Reversing Sub ................ Water Cushion Valve ........... Drill Pipe ...................... Drill Collars ...................... O.D. 5 ~ 00" 2.25" 4.276" 2. 764" .87" 5.00" 3.50" Handling Sub & Choke Assembly ...... Dual CIP Valve ................... ~. T.! .G~H. T .HOLE..sUB Hydro-Spring Tester ................ Multiple CiP Sampler ............... ~ .AP...~. SE ............ 3,88" 5.00" 3.90" 3,75" _ .50" .62" AP Running Case .................. Hydraulic Jar ..................... VR Safety Joint ................ Pressure Equalizing Crossover ......... 3.75" 3987" 3,88" .62" ,75" Packer Assembly ................... 5 ~ 75" 2,36" LENGTH DEPTH 1.00' 8439' 3618' 14~872.42' 6,5' _ 8.30' 6.12' 15,079.34' 4.09' 5.08' 2.83' 3.63' 15,083' 15,088' 4..34'. 15,096' Distributor ........................ Packer Assembly ................... Pressure Equalizing Tube ........... Blanked-Off B.T. Running Case Drill Collars ...................... Anchor Pipe Safety Joint 2.88" , 2.259" 8.77' Packer Assembly ....... ............ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... ~rB.o.T...CASE ....... 3°85" Blanked-Off B.T. Running Case ....... 3 o 88" .HT-500 TEMP. 4.05' 4.09' 1.00' 15,112' 15,116' " -i5,117r- PRINTED IN IJ.$.A, EQUIPMENT DATA Dote 1.2-21-72 Number 308500 ' ~'o Sampler Pressure .... P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of Job lt.0~l', District Abl.~-],_C).[~uG_E ~' cc. Oil DAVE GOI'.DEN ,.~ cc. Water Tester HAROLD MANN Witness BOB cc. Mud Drilling Tot. Liquid cc. Contractor READING & BATES., SM S Gravity, ° APl @ °F. EQ U I PM E N T & H O L E DA T A Gas/Oil Ratio cu. ft./bbl. Formation Tested Upper "g" Zone ~levation 1681 Ft. RESISTIVITY CHLORIDE Net Productive Interval. 301 l=t. CONTENT All Depths Measured From Kelly bushing Recovery Water ~ @ ~ °F. ppm Total Depth 15,130' Ft. Recovery Mud ' @ ~ °F. Main Hole/Casing Size. 9 5/8 - 7" Recovery Mud Filtrate ~ @ ~ °F. ppm Drill Collar Length - I.D. Mud Pit Sample @~ °F. Drill Pipe Length. 11387 - 3618' I.D. 4. 276 - 2. 764" Mud Pit Sample Filtrate ~ @ ~ °F. ppm Packer Depth(s) 15,005 ' Ft. Mud Weight 11 5 vis 55 .cp Depth Tester Valve 14~ 988I ' Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Water 2300 Ft. Pres. Valve Choke 1/4" Choke 1/2" Gas 1700 >_ ,, Recovered 1700 PSI Feet of gas cushion ~ Recovered 2300 Feet of water cushion · ,.. r'"' ,~(,c-7..-.~ Recovered 22 bbls ~,mof gas and oil F~.i] I ,..~ ,~/c, < Recovered Feetof ~:?,."]~]C}~x,'i .,I~: 'C"',~t?,L A~,,,.I,~ ~ ,~e. o ANCH!ORAGR Recovered Feet of ,, Remarks Ran to 15005' with 2300' water cushion and 1700 PSI gas befor opening tools. Opened tool for 61 minute first flow. Closed tool for 119 minute first closed in pressure. Tool reopened for second flow with light blow in bubble bucket & bubble ,~- hose only for duration of flow. Closed tool for 973 minute second closed in. pre.ssur Reversed out approximately 13 bblso fresh water, 44 bbls. of oil and gas & water cut _mud and 22 bbls of oil and ~as. SEE PRODUCTION. TEST .DATA SHEET Gauge No. 1238 Gauge No. 1237 Gauge No. 352 ill TEMPERATURE TIME __ Depth: 14992 Ft. Depth: 14997 Ft. Depth: 15021 Ft. , O 24 HourCIock 72HourCIock 72HourCIock Tool 12-21 A.M. _~Esf. °F. Blanked Off no Blanl~edOff no , Blanked'Off yes Op~ned 0211 P.M. c:: 15,026i " .Tool 12-22 A.M. __Actual 220 °F. Pressures Pressures Pressures Closed. 0635 P.M. Field Office Field Office Field Office Reporte~l ComP~ted I__nitial Hydrostatic 9068 9156 9036 9089 9012 9069 Minutes Minutes i, "~o Initial 3209 3310 3202 3215 3203 3222 " C.c Flow' 2~ -. Final 1366 1443 1375 1402 1373 1392 60 61 _ Closed in 7536 7627 7483 7543 7559 7564 120 119 =~ Initial 1239 1322 1209 1256 1242 1268 c o Flow ..... ~-,TM Final 1685 1764 1708 1708 1699 1722 549 551 Closed in - 7555* 7582 7619 7624 7630 975 973 ~ initial ~ Flow --.. ~.__, Final ALL REf. J]INGS ON llT # 1238 QUESTIONA;~LE DUE ~:O BASE LIiqE IN ERROR Closed in F~inol Hydrostatic 7473 CTE 9069 9089 9012 9069 *Read at t?e end of 1~7 minute~ when chirr time e:rpired. (:TE=Chart ime ~RINTED IN FORMATION TEST DATA Ticket F L U I D S ^ M P h 1= D ^ T ^ Date 12-21-72 Number 308500 Sampler Pressure .P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of Job HOOK WALL District ANCHORAGE cc. Oil DAVE GOLDEN cc. Water Tester HAROLD MANN Witness BOB MEAD cc, Mud Drilling Tot. Liquid cc. Contractor READING & BATES 5-~ S Gravity. ° APl @ °F. EQU I PM E N Z & H O L E D ,A T A Gas/Oil Ratio cu. ft,/bbl. Formation Tested J~levotion Ft, RESISTIVITY CHLORIDE Net Productive Interval. Ft. CONTENT All Depths Measured From Recovery Water ~ @ ~ °F, .ppm Total Depth Ft. · Recovery Mud ~ @ ~ °F, Main Hole/Casing Size. Recovery Mud Filtrate ~ @ ~ °F, .ppm Drill Collar Length , . , I.D Mud Pit Sample ~ @ ~ °F, Drill Pipe Length I.D Mud Pit Sample Filtrate ~ @ ~ ~F. .ppm Packer Depth(s) ..Ft. Mud Weight vis cp Depth Tester Valve. Ft. , , TYPE AMOUNT Depth Back Surface Bottom Cushion Ft, Pres, Valve Choke Choke Recovered Feet of .. Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of Remarks Fourth gauge Gauge No. 138 Gauge No. Gauge 'No. TEMPERATURE TIME Depth: 15025 F.t. Depth: Ft. Depth: , Ft. 72 Hour Clock , Hour Clock Hour Clock Tool A.M. Est. °F; Blanked Off yes Blanked Off Blanked Off Opened P.M. ,,, Tool A.M. Actual °F. , Pressures Pressures Pressures Closed P.M. Field Office Field Office Field Office Reported Computed Initial Hydrostatic 9061 9084 Minutes Minutes '~o Flow Initial 3215 3222 >-': Final 1420 1397 Closed in 7573 7570 'ob Initial 1260 1272 ~'o 8.r. Flow ~ ~ Final 1708 ,1724 Closed in 7605 7628 Initial >_.9 Flow' " ~. ..... Final .... Closed in , Final Hydrostatic 9061 ... 9081 PRINTED IN FORMATION TEST DATA Gauge No. 1238 Depth 14,992' Clock No. 8422 24 hour No. Flow PeriodI Closed In Pressure Flow Period Closed In PressureI Flow Period Closed In Pressure Time Dell.'Temp.P$IG Time Deli. Log '-I-0 Temp.PSlG Time Dell.' Temp.PSIG Time Dell. Log t-l-0 Temp.P$1G ' Time Dell. Temp.PSIG Time Dell. Log-t -t-0 TemD.P?IG .000"I Corr. .000" ~ Corr. .000"I Corr. .000" 0 Corr.I .000" ° Corr. .000" ¢'/ Corr. o .0000 I 3310 .0000 1443 .0000/ 1322 .0000 1764 . 1 .0371' 3323 .0372' 6161 1709~,~,¢ 1398 .1005 7166 2 .0709 2829 .0777 7116 .5059 1548 .2010 7445 3 .1047 2340 .1182 7433 8409 1640 .3015 7480 4 . 1385 1818 .1587 7486 1. 1759 1678 .4020 7536 5 .1722 1548 .1992 7527 ~.5109 1723 (.4580'** 7555) 6 . 2060 1443 .2397 7561 1.8459 1764 .5025 - 7 .2802 7577 .6030 - 8 I · 3207 7592 ,7035 . - 9 .3612 7611 ,8040 - 10 .4020 7627 .9046 - ]] 1.0051 - 12 1.4&06 - · 13 I .8761 - 16 3,'2597 - Gauge No. 1237 Depth 14,997' Clock No. 6196 72 hour .... 0 .00001 3215 .0000 I 1402 .0000 I 1256 .0000 1708 ] .0128'~ 3222 .0120' I 6202 0577,'* 1332 .0336 7146 2 .02441 2744 .0251 I 7073 .1707 1488 ,0673 7381 3 .03611 2239 .0382 7354 ' 2838 1588 ,1009 7434 4 .04771 1754 ' .0513- 7401 .3969 1625 .1345 7477 .... 5 .05941 1488 .0644 7450 .5099 1671 .1682 7500 _ 6 .0710 1402 .0775 7490 .6230 1708 ,2018 7517 7 .0906 7510 .2355 7526 8 .1037 7523 .2691 7540 9 .1168 7536 .3027 7546 ~o ,1300 7543 .3364 7556 11 .&82] 7579 12 677q 7593 13 77q6 7603 ]4 .9194 7609 Reodino Intervol 10 [ 12 100 ~¢,~¢~','f.'I ) Minutes REMARKS: *First interval is equal to 11 minutes. **First interval is equal to 51 minutes. *** Read at the end of approximately 137 minutes when chart time expired. ALL READINGS ON BT {J 1238 QUESTIONABLE DUE TO BASE LINE IN ERROR · *~First 10 intervals are equal to 30 minute's each, next 4' intervals are equal to 130 minutes each and last interval is " ...... '"""'"" .SPECIAl_ PRESSURE DATAequal to in,tes. ,.,¥.,.,_.,., Gouge No. 352 Depth 15,021' Clock No, 9866 72 hour No. 308500 FirstII First Second Second Third Third Flow PeriodII, Closed in Pressure Flow Period Closed In Pressure Flow Period Closed In Pressure I I ITemp' Log Temp.I Temp. Log Temp. Temp. Log~ Temp. .000" Corr. .000" T Corr. .000" Corr. .000'~ ~ Corr. ,000" 0 Corr, .000" Corr. . ,0000 I 3222 .0000 1392 .0000 1268 .0000 1722 0 ] .0121- 3239 .0119'* 6180 .0565,w~ 1340 .0330 7134 2 ,0231 2788 .0249 7085 .1672 1497 .0660 7393 3 .0341 2350 .0379 7377 .2779 1598 .0990 7449 4 .0450 1830 .0509 7430 .3886 1634 .1320 7492 5 .0560 1536 .0639 7472 .4993 1683 .1650 7515 6 .0670 1392 .0769 7508 .6100 1722 .1980 7531 _~-, 7 .0899 7531 .2310 7541 _ 8 j .1029 7541 .2640 , 7554 9 .1159 I 7551 .2971 7561 ]0 .1290 7564 .3301 7570 ]] ~4731 '7593 ]2 .6161 7607 ]3 .7591 7616 14 .9021 7623 _ ]5 ~ I.1.0750 { 7630 Gouge No. 138 Depth 15,025' Clock No. 9184 72 hour O .0000 t 3222 .0000i 1397 .0000 1272 .0000 1724 ] .0124'1 3238 0125~ 6068 .0579~'~* 1356 .0341 7126 2 0238I 2776 .0261 I 7019 .1716 '1510 .0682 7392 3 '0351 I 2292 .0397I 7369 .2852 1606 .1023 7450 4 ,0464 I 1801 0533[ 7424 .3988 1644 .1364 7492 5 .0577 1535 .0669I 7466 .5124 1689 .1705 7515 ..... ~_ 6- .0690 1397 .0805I 7511 .6260 1724 .2046 7531 7 .0941 7534 .2387 7544 8 .1077 7547 .2728 7553 9 .1213 7560 .3069 7563 ]0 .1350 7570 .3410 7570 ]] ¥4887 7'59 .~ ' ]2 ,6365 7605 ]3 7843 7615 14 .9320 7621 15' =l_-j '1060 76?8 Reodin~ ~,te~ol 10 I' 12 II 100 *** . Minutes_ REMARKS: *First interval is eaual to 11 minutes. ~,~,First interval is equal to 51 minutes. ***First 10 intervals are equal to 30 minutes each, next 4 are equal to 130 minutes each and last interva.1 is equal to '153 minutes. ....... '"'"-'-"' SPECIAL PRESSURE DATA Casing perfs. 15082 151~gtt°m choke 1/2" Surf. temp ........ °F Ticket No.., 308500 Gas gravity Oil gravity GOR Spec. gravity _Chlorides ppm Res. ,. · Dote 12-21-72 Choke Surface Gas Liquid Time a.m. Size Pressure Rote Rate Remarks psi MCF BPD p.m. 12:00 On bottom 1:30 AM I Gas cushion , I · 2:00 1700 PSI 2:11 Opened tool 2:26 1" Bled gas off 3:11 1" Closed tool 5:11 1/4" Opened to flow-18 turns by locked clutch. " 6:11 Bubble hose - 3" Light blow on bubble hose. 11:00 Bubble hose - 11" ,Light blow with continuous increase. 14:20 Bubble hose- [1" · Closed tool 12-22-72 0440 . Started reverse circulating 0524 Recovered approximately 22 bbls. 0528 oil and gas. 0635 Pulled loose ~_. PRINTED iN U.II,A. PRODUCTION TEST DATA 308500 'l Reversing Sub ' Water Cushion Valve ........... Drill Pipe ...................... Drill Collars ...................... Handling Sub 8, Choke Assembly ...... Dual CIP Valve ................... Dual CIP Sampler .... ............... Hydra-Spring Tester ................ Multiple ClP Sampler ............... Extension Joint .................... AP Running Case .................. ,, Hydraulic Jar ..................... VR Safety Joint ................... Pressure Equalizing Crossover ......... Packer Assembly ................... O, D, 5I' 5" 3.50" 3.88" 5.00" 2.25" 4.276" 2. 764" .87" .50" .62" LENGTH DEPTH 1I 11387' 3618' 6.5' 8'. 30' 6.12' 14782.42' 14,988 ' 3,90" · 3.75" 3.75" 3.87" 3.88" 5.75" 2.88" .62'~ .75" 2.36" 2.259" _. 4.09' 5.08' 2.83' 3.63' 4.34' 8.77' 14992' 14997' 15005' · Distributor ........................ Packer Assembly ................... FI us~"~xXmxh~r ~erf. s ........... Pressure Equalizing Tube ........... Blanked-Off B.T. Running Case ....... Drill Collars ...................... Anchor Pipe Safety Joint ............ Packer Assembly Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor' .................. PRINTED IN U,~.A, Drill Collars ...................... 4.05' 15021' Blanked-Off B.T. Running Case .... .... HT -,,500 Temp ...... 3.88" EQUIPMENT DATA ., .4.09' ,,, 1,00' ,15025' , 15026' LITTLE · gO~I6 6M :~/7~ F L U I D · S A M P L E D A T A 12-28-72 Ticket Date Number 308451 ..... Sampler Pressure P.S.I.G. at Surface Kind HOOK WALL Halliburton Recovery: Cul Ft. Gas of Job District ANCHORAGE cc. Oil cc. Water Tester [v,~. MANN Witness MR. cc. Mud Drilling Tot. Liquid cc. Contractor READING AND BATES DR S Gravity. ° APl @ °F. E Q U ~ PM E N T & H O'L E D A T A Gas/Oil Ratio cu. ft./bbl. Formation Tested. Upper (3 1 Zone .... Elevation. 164 ' .Ft. RESISTIVITY CHLORIDE Net Productive Interval 301 Ft. CONTENT All Depths Measured From Kelly Bushing Recovery Water __ @ __ °F.2200 ppm Total Depth 14625' Ft. Recovery Mud ~ @ ~ °F. Main Hole/Casing Size, 9 5/8~-7t' Recovery Mud Filtrate __ @_ °F. ppm Drill Collar Length - I.D - Mud Pit Sample__ @ __ °F. Drill Pipe Length 3618'-10817' ,I.D 2. 764"-4. 276" Mud Pit Sample Filtrate __ @ __ °F. ,ppm Packer Depth(s). 14478' Ft. Mud Weight 11'° 5 vis 55 cp Depth Tester Valve 1.4461 ' Ft. BubDie TYPE AMOUNT Depth Back Surfoce Bottom 2" Cushion 2300' Fresh water Ft. Pres. Valve Choke Hose Choke 1/ Recovered 1700 X;~'fx p.,si,gas cushion Recovered 2300 Feetof water cushion 17 bbls. i .... Recovered 63 ~ formation salt water 2200 PPM!, , .- Recovered Feet of ,, ' , ,~< Recovered Feet of [ Di1~';C~!~, Oki:;h,":"a;~ Remarks SEE PRODUCTION TEST DATA SHEET ........... · ;',, t' '"" ~ ,:~'.~D GAS "' ~,,..,' ~k ' Gouge No. 1238 Gouge No. 1237 Gouge'No. '352 TEMPERATURE TIME Depth: 14465 ~,t. ,Depth: 14470 Ft. Depth: 14494 ....... Ft. 24 Hour Clock 72Hour Clock 72 Hour Clock Tool A.M. Est. . ..... °F. Blonl~e,d,0ff'No ,, Blanked Off No Blanked Off ye,.s Opened ,, P.M. i4z+~ ' Tool A.M. Actual 2,14 OF. Pressures Pressures Pressures Closed" P,M. ................... Field Office Field Office Field Office P, eported Computed Initial Hydrostatic 8-~-~-0- 88-~-f:) 8838__ 885'I 8866 .............. 8869 Minutes ..... Minutes .. Initial 3304 33-16 3235 3258 3268 3284 ~ Flow ........... · '- ,- Final 1908 180-3 1708 2316 1928 1902 31 30 Closed in 9006 9016 8970 8983 8964 8977 90 88 -o-o Initial ' 14-----94 15-~-~ 1442 --t-4V'2--- 1503 --1510 c o Flow .............. --- .... 8'c Final 2987 29"94 2937 2937 2941 2967 482 484 Closed in 8568 8600 9102 9122 9095 9108 1100 1101 ,, .initial CHART ,T.IJ~E EXPIRED ._~.o_ Flow ~-~ ,, Final AFTER AP].!~OX ~.~T~i~ ..... Closed in : 92_6 MTNII'?E._q. , , ,, Final Hydrostatic - - __.8_8_~ 8 8851 .... 8866 8869 ,., ;I )RINT£D IH U.B.A. FORMATION TEST DATA F L U I D S A M P L E D A T A Date 12-28-72 Ticket 308451 Number Sampler Pressure P.S.I.G. at Surface Kind Halliburton ANCHORAGE Recovery: Cu. Ft. Gas of Job tlOOK WALL District cc. Oil cc. Water Tester ~. MANN Witness · MR. KUKLA cc. Mud Drilling Tot. Liquid cc. Contractor READING AND BATES DR S Gravity ° APl @ *F. EQ U I PM E N T & H O L E D A T A Gas/Oil Ratio cu. ft./bbl. Formation Tested Elevation Ft. RESISTIVITY CHLORIDE Net Productive Interval Ft. CONTENT All Depths Measured From,, Recovery Water __. @ __ °F. ppm Total Depth Ft. Recovery Mud · @ ~ °F. Main Hole/Casing Size, Recovery Mud Filtrate ~ @ ~ °F. ppm Drill Collar Length I.D, Mud Pit Sample ~ @ __ °F. Drill Pipe Length, I.D, Mud Pit Sample Filtrate @ ~ °F. ppm Packer Depth(s) .Ft. Mud Weight vis cp Depth Tester Valve Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of Remarks FOURTH GAUGE Gauge No. i5~5 Gauge No. Gauge 'No. TEMPERATURE 14498 TIME Depth: F,t. Depth: Ft. Depth: .... Ft. 72 Hour Clock Hour Clock Hour Clock Tool A.M. Est. °F. Blanked Off ¥e$ Blanl~ed Off Blanked Off Opened P.M. Tool A.M. Actual °F. Pressures Pressures Pressures Closed P.M. , , Field Office Field Office Field Office Reported" Computed Initial Hydrostatic 88-~'7 8"8'83 Minutes Minutes _.~,, initial '~-~-0 ~ Flow ----0-1 ....... · ""~ Final 19 1917 Closed in 8996 8999 '~o Flow Initial 1484 _1516 8'r- Final 2958 2971 Closed in 9126 9 126 ~ Flow ....Initial ,, = ~ Final Closed in .... Final Hydrostatic 8867 8877 ...... I PRINTED iN FORMATION TEST DATA L. ITTLE'$ ~0~'17 tOM 1453 4565, i' 1/2', i' 303451 Casing perfs. Bo,.om choke · Surf. temp ' °F Ticket No Gas gravity Oil gravity .. GaR . Spec. gravity Chlorides___ .ppm Res. ~ °F Date f'2- 2'8- 7 2 .... Choke Surface Gas Liquid Time a.m. Size Pressure Rate Rate Remarks psi MCF BPD p.m..,,. Ope'ned'nool for 30 minute first 12:06 Gas cushion · 12:40 1700 Closed in at Surface 12:57 1700 ' Reopened tool 13:05 1700 Bled gas cushion · Closed tool, Clutch would"'not"diS ~ng'a 13:28 500 at 11 turns, pick up out of slip to Bubbl~. "' stoP rotation. 14 turns° 14:58 Hose Opened tool 15:09 1/4" 2 Open to 1/4" bean 1/4 ...... 15:30 3/8 2 Open 3/8" & 1/4" bean '" Bubbl ~ ..... 16:00 hose 1/2 closed chokes both to bubble hose · 16:19 1/2 . to bottom bubble b6cket 1 6:30 1/4 1 ... Open 1 6:55 Closed 1/4" choke .... Light blow on...bubble hose , , 22:30 .... 1 ....... 92 in.ches-1 lb. on.gauge ..... 23:00 Closed tool 12-29-72 15:10 1/2 Rotate to reverse !7: 20'. , ,, : Pull.~loose , , PRODUCTION TEST DATA I..rr'ri..,', Gouge No. 1238 Depth 14465' Clock No.8422 ,24 hour No. 308451 II First Il First Second Second Third Third Flow PeriodI] Closed In Pressure Flow Period Closed In Pressure Flow Period Closed In Pressure TimeDefl. PSIG TimeDefl. I Logt.Jr-t~ PSIG TimeDefl. I PSIG TimeDefl. ILo_t-l_~ PSIG TimeDefl. PS1G TimeDefl. t-k ¢ P?IG Temp. I Temp. Temp. Temp. Temp. Log Temp. .000" Corr. .000" ~ Corr. .000"[ Corr. .000"I w ~ Corr. .000" , Corr. .000" f~ Corr. 0 ,000 3316 .000I 1803 .000 1522 '~ .000 z~94 1 ,0178 3345- .0271I 7984 .1448 1745- -.2671 8097w'~ 2 .0356 3193 .0542I 8406 .3098 1908 .5139 8413 3 .0534 '2638 .0813.I 8563 .4748 2070 .7607 --4 .0712 2270 !! 1084I 8669 .6398 2219 (.763 8600~.~E 5 .0890 I 2019!j..13551 8772 .s04s 2352 1.0075 6 .1070 I 1803 ]l .1626 I 8782 .9698 2489 j 1:_2543 . .. -7 I o1597j' 8875 1]'1348 2616 I! 1~5oli ' s " l',,2168 i '_s~i6 1.2998 J 2746 1.7479 ..... 9 I · 2439 I 8953 1.4648.1 2870 i. 9942_ · ._ Io J ,2710I 8984 1,630 2994 2.2415 11 .29801 '9016 2.48Jt3_ 12 _2~7351_ · 13 _2,9819 ~4 I I I 3, Gouge No. 1237 Depth 14470 ' 3. 7220 Clock No. 9866 72 hour 0! .000 I 32~8 j .000 j 2336 I] 000 1472 II .000 2937 1i .006i 3272 j ' .0087 j 7924 0476 1684'11.0872 8059** ~ .024 2904 .0548 i 8-6~0 ~2105 2156 !.3290 8686 5 .030 I 2631 .0435 j 8746 264-8 2296 '4096 8778 " 9 .0783 j 8927 ,4820 2810 7320 8990 lo .0870 I 8957 5360 2937 8126 9016 11 .0960 J 8983 '".8932 ~.46 __ 12 ! .9738 9066 ~3 ..t 1,0544 9089 14 I 1. 135'0 9103 ,~ i il ~.2~0 '1 912~_ I . Reeding i~tervol 5 li 8 I 49 ii 73 REMARKS: * First interval equal to 43 minutes **-79 minutes CTE-Chart time expired after apProximately 226 min. , , .... "'"'"'"'""' SPECIAL PRESSURE DATA '"'"""" j Depth Time Deft. .000" ,, o .000 1 i · 0057 21 .0114 3 ·0171 ~ .0228 5] .0285 Gouge No. 352 14494' Clock No. 6196 Flow Period I', Closed in Pressure Flow Period Closed In Pressure Temp.PSIG Time Deft. Log~ Temp.PSIG Time Deft. Temp.PSIG Time Deft. Lo- t -3I- {~ Temp.PSIG Corr. .000" ~ Corr. ,000" Corr. ,000" 9T Corr. i3284 .000 1902 .000 1510 .000 2967 3301 .0087 7833 .o34o .0490 1708' .0888 3268 .0174 8346 .1049 1873 .1709 8379 2673 .0261 8526 .1608 2029 .2530 8565 2294 .0348 8624 .2167 2176 .3351 8679 .0435 2042 1902 8739 8788 .0522 .2726 .3285 2314 2451 .4172 .4993 8076** 8761 '8837 I Ticket I 72 hour No. 308451 Third Third Flow Period Closed In Pressure Time Deft. PSIG Time Deft. t -I- {~ P? ~G Temp. Log~ Temp. .000" ' Corr. .000" Corr. ]2 J j · 0609 .0696 .0783 ,0870 ,0960 8833 8879 -8918 8948 8977 · 3 844 .4403 .4962 ,5520 2585 2709 2837 2967 · 5814 .6635 .7456 ,8277 ,9098 ,9919 1,0740 1.1561 1,?~gO 8892 8941 8980 9007 )036 9056 9075 )092 19108 Gauge No. 138 Depth 14,498' Clock No. ' oi .000 J 3299 .000 1917 .000 1516 .000 0056 ! 3305 .0092 7735 .0492 1 724* ·0903 918z 2971 8087** 72 hour 2J .0112 J 3280 .0184 8317 .1053 1894 .1738 8398 0168 12788 .0276 8531 .1614 2051 .2573 9589 0224 j 2388 .0368 8641 .2175 2189 .3408 8699 0280 12112 .0460 8751 .2736 2330 .4243 8789 0340 1917 .0552 ~ 8816 .3297 2462 I .0644 8868 .3858 2590 Reading interval 5 2715 2846 2971 49 8906 ,5078 ,5913 .6748 .7583_ .8418 _9253 1;O08f 1.0922 1.175f 1. ? 59C 73 8945 8974 8999 ,-0736 .0828 .0920 .1010 8861 8916 8964 8999 9029 9055 9074 9094 9110 9126 ..4419 .4980 .5540 Minutes REMARKS: * First interval equal to 43 minutes **-79 minutes. PRINTED SPECIAL PRESSURE DATA · 3O8451 Reversing Sub ' ' Water Cushion Valve ........... Drill Pipe ....................... Drill Collars ' Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Dual CIP Sampler .................. Hydro-Spring Tester ................ Multiple CIP Sampler ............... .AP-Case ........... AP Running Case .................. Hydraulic Jar ..................... VR 'Safety Joint .................. Pressure Equalizing Crossover ......... Packer Assembly ................... Distributor .................. : ..... Packer Assembly ..................... Flush Joint Anchor ................. Pressure Equalizing Tube .......... Blanked-Off B.T. Running Case ....... Drill Collars ...................... Anchor Pipe Safety Joint ............ Packer Assembly ................... Packer Assembly ................... Anchor Pipe Safety Joint .......... ... Side Wall Anchor .................. Drill Collars ...................... ~b Jc~t. Aachor B'o'~o' ' .C.a.s.e. ...... Blanked-Off B.T. Running Case I-IT 500 Temp. O.O. I.[~., LENGTH 5.00" 2.2~. 1. O0 ' · ~'" 2. ?'64" ..... 361'8 ' 5" 4.276" 10817' 3.50" 2. 764" 4. O0 ' 3.88" . 87" 6.5' 5.00" .50" 8.30 ' 3.90" .62" 6.12' 3.75" 4.09' 3.75" 5.08' .3.87" .62" 2.83' 3.88" .75" 3.63' ,, 5,75" _ 2.36" ..... 4,34' 2.88" 3' 88" 3.88" 2. 259" PRINTED IN EQUIPMENT DATA DEPTH 14249.48' 14461.4' 14465.49' 14470.57' 14478.06' 8.77' 4.05' 4.09' 1,00' 14494.19' 14498.28' 14499.28' LITTL£'~ ~'O21~ '~M 2/72 Ticket F L U I D S A M P L E D A T A Date 1-1-73 Nu,nber 308452 , -ir'" Sampler Pressure . P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of Job HOOK WALL District ANCIIORAGE cc. Oil cc. Water Tester MRo ~4J~ Witness MR. HEAD cc. Mud Drilling Tot. Liquid cc. Contractor ~ADING & BA'L'~S DRILLING COMPANY Gravity. ° APl @ °F. E Q U I PM E N T & H O L E D A T A IC S Gas/Oil Ratio cu. ft./bbl. Formation Tested Upper · Elevation 1647 Ft. RESISTIVITY CHLORIDE Net Productive Interval 156.82 ~ .Ft. CONTENT All Depths Measured From.__~elly Bush. lng Recovery Water o ~ @ _.~ °F. ppm Total Depth 1.6r:~ 600~ Ft. Recovery Mud @ °F. Main Hole/Casing Size_~_9 5/8~f 7,, ~ I Recovery Mud Filtrate ~ @ ~ °F. ppm Drill Collar Length - I.D, , Mud Pit Sample ~ @ ~ °F. Drill Pipe Length11;_2..88~ -3!~_!,7 I.D~-L. 276"-2_._7_6_4" Mud Pit Sample Filtrate @ ~ °F. ppm Packer Depth(s) ~-~L,~L/-+3~ Ft. Mud Weight 11.7 vis 55 cp Depth Tester Valve 14:4!_6m Ft. , , ,,,, ,, TYPE AMOUNT Depth Back Surface Bottom Cushion 50007 ~R,1~$~ WA'EER Ft. Pres. Valve -- Choke - Choke 5/8f~ Recovered 5000 Feetof Water cush±o~ Gal-ions '" ~ ~- Recovered 16 X~tof Mud - rat hole - no water - maybe some gas Recovered Feet of Recovered Feet of ~ _ Recovered Feetof ~ ,~-L" ti,~"~ ~[? ~ ~/~ ~' F:i~ Remarks SEE PRODUCTION ~ST DATA S}~ET... D'P,,q?~C ",,~ .... ~' O~L ,,:,HD GAS , Go~ge No. 1238 ' ' Gauge No. 123f Gauge'N0. 352 I .. .oopth:. 14,420' .~.t. Ooath: 14~425' ~t. O~p~h: 14:459' ~t. ' ~8 ~o~rCmock 24 ~ou~C~0ck 24~o~C~k ~°o~ A.~. o ...... Est. 'F., Blanked Off ..NO BlankedOff NO BlankedOff YES opeqed ,, 02 : 08 P.M. o 14,464'~ Zoo~ A.M. _Actual 197 ~F. Pressures Pressures Pressures Closed 06: 25 P.M. , ........... FicRJ Office Field Office Field Office Reported Computed s~ Fbw .. ~nitiom 2194 2165 2140 ~~ . 2157 2163 2~ _ F~o~ 2225 2181 2173 2_$~ 2_!~0 2190 P~ 60 _ C~osed in 8975 .... 8P_~.~ ..... 8937 89~.Z .............. 8.9~t 89~8 ....... ~.~!,,, Z22 _ ~ ~ I nit iai U~BLE ~ABLE ~BLE ~.~ ao~ ................................................. o~ Final TO ~AD TO P~AD TO READ UNAB~:,E TO ~ ~, ~ ' , ................... _ C~ose!i~ - 8834 - 8828 - 8827 76 7~ Initial ~] F~ow ..................... ~ - Final ........ Closed in ~ Hy~,o~,~ ~__8P!.~_ ........... 88~_k ...... 887.~ ..... 8888 .... J8~.8 '~.88.95__.-- ...... -- , ,L , ,, 0 :O PMINTI~D IN U,I,A. FORMATION TEST DATA FLU I D SA M P L E D^TA Ticket ~ Date 1-1-73 N,m~ber 308452 Sampler Pressure P.S.I.G. at Surface Ki,',d Halliburton Recovery: Cu. Ft. Gas ¢;f Jab HOOK WALL District ANCIIORAGE cc. Oil CC. Water 'rester MR. MANN Witness I'll. MEAD cc. Mud Drilling Tot. Liquid cc. Contractor READING & BATES DRILLING COMPANY Gravity ° APl Gas/Oil Ratio. cu. ft./bbl. Formation Tested Elevation Ft. · RESISTIVITY CHLORIDE Net Productive Interval, Ft. CONTENT Ail Depths Measured From Recovery Water ~ @ ~ °F. ppm Total Depth Ft. Recovery Mud ' ~ @ ~ °F. Main Hole/Casing Size. Recovery Mud Filtrate ~ @ ~ °F. ppm Drill Collar Length.. I.D Mud Pit Sample ~ @ ~ °F. Drill Pipe Length. I.D Mud Pit Sample Filtrate ~ @ ~ °F. ppm Packer Depth(s) Ft. Mud Weight vis .cp Depth Tester Valve Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke Recovered Feet of , Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of ~ . Remarks .... FOURTH GAUGE _ G~luge No. 13'8 Gauge No. Gouge'No. ' ' TEMPERATURE TIME _ Depth: 14=463' Ft. ,,,,Depth: Ft. Depth:, Ft. · 24 Flour Clock Hour Clock Hour Clock Tool AiM. ,, , _EEsi-. °F. Blon.k. ed,Off, .,,,YES Blanked Off Blanked Off Opened P.M. Tool A.M. · --Actual °F. Pressures Pressures Pressures Closed, P.M. .... Field Office Field Office Field Office Reported Computed ..I.n_itiol Hydrostatic 8867 8909 Minutes Minutes ~., '-~o Initial 21'57 2189 ~-'c Flow .................. ~ Final 2189 2212 o~ Closed in 8932 8958 :~ Flow -- Init__i_al .U..N...A.._B.L_E._ __ -- ..... 'C - Final TO PJ]AD Closed in - 8845 , - '.::~ Flow --I-nit--~i'a-L ...... ~- Final __ Closed in ,,, .F~i .n_9/j-I yd ros ta t i c,, 8880 8909 _ FORMATION TEST DATA ,.,,,,.,,,o,,, .... z,, SQUgI.;ZEI)' OFF ,t { ..... Casing perfs. DRY TE~ST Bottom choke .... Surf. temp i~J 'F Ticket No. 308452 Gas gravity__ Oil gravity. GaR Spec. gravity Chlorides .... ppm Res ....... .~._ __of: Dote Choke Surface Gas Liquid Time a.m. Size Pressure Rate Rate R.emarks psi MCF BPD 1-3-73 02:08 Opened tool _ 02:25 Very light bubble hose blow-l" in bucke increasing to 3" in bubble bucket 03:05 _Could be due to temperature change 03:08 Closed tool 05:09 Started reversing No evidence of formation water by taste test 06:25 pulled loose i' , , PRODUCTION TEST DATA "'"'" Gauge No. 1238 I Depth , 14,420' Flow Period Closed In Pressure Time Deft. i PSIG i Time Deft. , Temp. Log .000" i Corr. .000" I PSIG Temp. Corr. . Second Flow Period Time Deft. ] PSIG I Temp. .000" Corr. Time Deft. .000" Ticket I Clock No. 8102 48 hour No. 308452 Second I Third !l Third Closed In Pressure Flow Period . Closed In Pressure 0' .000 J 2165 .000 J 2181 UNABL~ TO .000 .0173J 2165 .0170 I 5589* READ .0089 I , ~ o0346~ 2168 ,0307 J .7025 o0178 .05191 2168 ,0443J 7752 .0267 .06921 2175 ,0f80 I 81'19 °0356 .0865! 2178 .0716I 8319 .0445 o1040 2181 .085~ I 8463 .0534 L t+0 og~ ' 1121 J !31 i 14~ .0989 ! ,1125 · 12_6_2 .1_398 i .1534 .1671 ! .1807 · 1944 8644 PSIG Temp. Corr. 1669 0712 5076 6492 Time Deft. .000" PSIG Temo. · Corr. Time Deft. .000" Log t + 0 To,nD. Corr. 7458 7987 8241 8394 8563 ,0623 8494 8566 8847 8709 ,0801 8622 8759 .0890 8672 8809 .0979 8709 1068 8744 . 8878 8784 8809 8834. -I ' 1157 8909 1246 1340 ,2080 ! 8934 Gouge No. 1237 Depth 14,425' Clock No. 8739 C: .000 2150]J o000 2169 UNABLE TO .000 l i-,0342 2150![ ,0335 5917' R~AD .0171 7262 ,0342 2l .0684 3i .1026 .17101 !!i ,o o 2153 [ ·0603 1641 4683 6487 7533 24hour 215611 .0872 7887 .0513 2159 .1140 8195 ,0684 8050 2166 .1408 8373 .0855 8267 2169 .1676 8495 .1026 8399 .1944 8591 .1197 8495 .2213 8667 .1368 8564 .2481 8723 .1539 8624 8667 tI Recding Interval 10 .2749 8772 .3017I 8815 ,3285 ! ,3554, il .3822 ' II ,, 8851 8884 8914 Rqq7 .1710 ,1881 .2052 .2223 _~2394 92560 8706 8739 8776 8802 8828 Minutes REMARKS: .,.__I ~ PRINTED IN U.S.A. *First interval equal to 10 minutes SPECIAL PRESSURE DATA Gauge No. 352 I Depth 14,459' First l! First t! Second Flow Period , Closed In Pressure Flow Period Clock No. 8422 .000 Second Closed In Pressure I Ticket 24hour No. 308452 .000 Third !1 Third Flow Period. Closed In Pressure 2190 Temp. Log Temp. Temp. Temp. Temp. Log TcmD. .000" Corr. j .OOO" Corr. .000" Corr. .000" '~ Corr. .000" .Corr. .000" . ti Corr. 2163 TO ~D °0338 2163 .000 .0168 1670 4587 .0329 6082* .0676 2167 .0592 7333 .0336 6374 .1014 .0855 2173 2176 .1118 2183 il .1380 2190 Ii .1643 7905 8190 · 0504 °0672 · 0840 .1352 7412 7987 8225 8373 11906 2169 2432 2695 .1690 6j .2030 8497 o1008 8379 7,J i 8595 .1176 8480 8j 8673 .1344 8562 8627 .1512 8729 8 80 Ii .2 8i 88].v .]_848 Il .3221 Ii. 3484 .3747 · .40!0 I 8856 8948. 8752 ,8781 .8804 I 8fi27 ,2016 ,2184 .2352-- 13J J 8892 i 8922 Gauge No. 138 Depth Clock No. 8420 24 hour ol .ooo 0333 2189 2192 o000 .0333 2212 5648* 14~463' RE kD .000 .0167 1702 4742 2J °0667 2196 .0599~ 7120 .0334 6424 3j .1000 2199 .0865i 7828 .0501 7453 zl .1333 2205 .1131 i 8165 .0668 7964 5J .1667 2208 .1398 8353 .0835 8230 ~" , .2000 2212 .1664 8489 o1002 8385 .1930i 8592 .2196 8676 i .24631 8741 .2729 . . 29_95 .3261 o 352B .3794 ,406~ 8790 . 8835 8871 8903 8932 8958 __1169 .!336 .1503_ .1670_ .1832__ .2171 ;_ _2500 ,~ 8489 8566 8638 8686 9725 876! --8793 8845 Reoding Interval 10 REMARKS: 5 I *First interval equal to 10 minutes Minutes ............... c, Pi:"It. IAI PRF.C,.c::::;I IRE"_ DATA 308452 Reversing Sub ................ Water Cushion Valve ......... Drill Pipe ..................... Drill Collars ...................... Handling Sub & Choke Assembly ...... Dual CIP Valve ................... D~fC~ TIGHT. SHOE..SUB S Hydro-Spring Tester ................ Multiple CIP Sampler ............... ~.. AP. RUNNING..CASE AP Running Case .................. Hydraulic Jar .................... VR Safety Joint ................. Pressure Equalizing Crossover ......... Packer Assembly ................... Distributor ........................ Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube ........... Blanked-Off B.T. Running Case ....... Drill Collars ...................... Anchor Pipe Safety Joint ' O.D. 5.00" 5t' 3.50" 3o50" 3.88" 5.00" 3.90" · 3_J5" .... 3.75" 3.87" 3.88" 5.75" 2.88" 2.25" 4.276" 2. 764" 2. 764" .87" .50" .62" °62" .75" 2°36" 2.259" LENGTH DEPTH 1 o00' 11,288' 3121' 4.00' 6.5' 8.30' 6o12' 4°09' 5.08' 2.83' 3.63' 4.34' 13,974.24' 14,416' 14,420' 14,425' 14,443' 8.73' Packer Assembly ......... , .......... Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... ~~'~orB.,.T.,..R..Ult..N.I.N.G...C.ASE 3o88" Blanked-Off B.T. Running Case ....... 3 °88" Il'p- 500 ",' 1. F, MP,, CASE 4o05' 4.09' 1.00' 14,459' 14,463' 14~46~~ PRINTED IN EQUIPMENT DATA Ticket F L U I D S A M P L E D A T A Date 12-1-72 Number 308496 - A Sampler Pressure P.S.I.G. at Surface Kind Halliburton Rccove,y: Cu. Ft. Gas of Job HOOK WALL District ANCIIO[LA, GE cc. Oil cc. Water Tester ~ Witness cc. Mud Drilling Tot. Liquid cc. ~C.ontractor R & B DRILLING COMPANY ~ S I Gravity ~ APl ~ ~F. EQ U I PM E N T & H O.L E DA T A Gas/Oil Ratio ._ cu. ft./bbl. Formation Tested Hemlock ,Elevation 164 ' RESISTIVITY CHLORIDE Net Productive Interval 60' CONTENT All Depths Measured From . Kelly Busl~ing Recove~ Water ~ ~ ~ *F. ppm Total Depth ~5~ 875 ~ .... Ft. Recovew Mud ' ~ ~ ~*F. Main Hole/Casing Size 9 5/8~ - 7~ Recovery Mud Filtrate __ ~ __*F. ppm Drill Collar Length ' I.D ' Mud Pit Sample __ ~ __ *F. Drill Pipe Length 15~ 695' I.D 4. 276" Mud Pit Sample Filtrate __ ~ __ *F. ppm Packer Depth(s) 15~ 732' ... Ft. Mud Weight ~3.2 vis 72 .cp Depth Tester Valve ~5~ 7~5 ~ Ft. TYPE AMOUNT4500 ~ Depth Back Surface Bottom Cushion WATER Ft. Pres. Valve NONE Choke NONE Choke 5/8" Recovered 12 b~rrels Feetof 420,. ' drilling mud + Recovered 20 barrels Feetof oil and gas cut mud -(2.7 barrels fl Recovered Feet of Recovered Feet of ~x ~,,i~',,.~ ,~..~ ~ ..... Remarks Ran in hole at ~2,217' + 7" casing had weight loss on indicator and worked tool do~ to total depth. Hydrosprig. g opened and we caught it~. 12 barrels approximate entry. Put 1760 PSI gas cushion. Opened tool to flow. - bled gas cush- ion down Co 0 PSI in 15 minutes. Had a light bubble hose blow until tool was close~[g in for the 117 minute first closed in pressure. Tool reopened with a light to a light bubble hose blow. Closed tool. for a 1664 minute second closed in pressure befo:e reversing out formation egtry. Reverse rec?erxt SEE PRODUCTION TEST DATA SHEET FOR Gauge No. 3287 Gauge No. 3285 Gauge 'No. R~IMD~R O~ T~ TEMPERATURE ' Depth: . !.5~719' Ft. _p~pt.h:. 15~7.24.' Ft.i Dept.b:80l ' 15~.748~Ft.. 24 HourC~ock 72 HourC~ock 72 HourC~k ~0o112,1-72 A.M. Est. *F. Blanked Off ~0 "Blanked Off NO Blanked Off ~S Opened 0715 P.M. , ,, ,,, 15,253" ~ ' ' Z~l 12-3-72 A.M. Actual 221°*F. Pressures Pressures Pressures Closed 0545 P.M. ........... Field Office Field Office Field Office Rep°Fled Computed 'l~itial Hydrostatic ~1~008 10,988' 11,027 '~-~]"~'~-~ lZ,019 11,020 Minutes Minutes ........ Initial 6248 6183 6287 6279 6297 6272 ~ Flow ............................................ · ~'c Final 4266 4198 4306 4306 4271 4279 61 5'7 C~osed in 8113 8060 8188 8165 8121 8121 120 117 .... i ........ - Initial 4226 4190 4306 4302 4271 4283 -- ~Z F~ow- ,. ~ Final - 4202 "4347 4339 4271 4300 824 875 Closed in - CI.~RT .8188 8141 8162 CLOCK 1708 1664 ...... Initial TIME STOPPED ~ F~o~ ............................. F, o, . ..... , .. L' Closed in - _' ....... ..... 0',820 0,804..' ....... .... _. -- , ,,,, ,,,,, , ,, ...... , ,, , ...... ,, , ., , ,, , ....... ,,,,, P~INTIiD IN U.IJ,A. FORMATION TEST DATA Ticket F L U I O S A M P L F D A T A Dote 12-1-72 , Nu,nber 308496 - A Sampler Pressure P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of Job HOOK WALL District ANCHORAGE__ cc. Oil cc. Water Tester M~'~N Witness ' MEA.D cc. Mud Drilling Tot. Liquid cc. Conlroctor R & B DRILLINC- COI~[PANY Gravity. ° APl @ °F. E Q U I PM E N T & H O L E DA T A Gas/Oil Ratio cu. ft./bbl. Formation Tested, · Flevation Ft. RESISTIVITY CHLORIDE Net Productive Interval Ft. CONTENT All Depths Measured From Recovery Water ~ @ ~ °F. ppm Total Depth Ft. Recovery Mud ' ~ @ ~ °F. Main Hole/Casing Size Recovery Mud Filtrate ~ @ ~ °F.. ppm Drill Collar Length I.D. Mud Pit Sample ~ @ ~ °F. Drill Pipe Length I.D. Mud Pit Sample Filtrate ~ @ ~ °F. ppm Packer Depth(s) .Ft. Mud Weight vis cp Depth Tester Valve .Ft. ,, TYPE AMOUNT Depth Bock Surface Bottom Cushion Ft. Pres. Valve Choke Choke Recovered Feet of ,. Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of Remarks ,, , FOURTH GAUGE ' Gauge No. 791 Gauge No. Gauge TEMPERATURE TIME Depth: 15~ 752 ' __ F.t. Depth: Ft. Depth: Ft. 7'2 Hour Clock Hour Clock Hour Clock l Tool A.M. E'st. °F. Blanked Off ¥~S Blanked Off Blanked Off Opened P.M. Tool A.M. Actual °F. Pressures Pressures Pressures Closed P.M. -- ., Field Office Field Office Field Office Reported Computed ~ , , Initial Hydrostatic 1 ! ~ 028 11 ~ 056 Minutes Minutes .... Initial 6355 6306 .~ Flow ...... .~- 'r- Final 4248 4322 Closed ia 8131 8164 -- '~ Flow Initial 4289 4322 ~ ',~ Final 4322 ~355 -- Closed in 8172 81.64 .... Initial ~ Flow ......... ~. Final ... Closed in Final Hydrostatic 10¥8-6~5'-- 10~-8 54 ~_ - /~RINTE~ IN FORMATION TEST DATA £osi.gperfs.l. 5,795'-15,855'. ½" - to 308496 - A .... uottom choke .... Surf. temp ' 0°F Ticket No. Gas gravity. .Oil gravity. GOR Spec. grovily .......... Chlorides ,ppm Res.. @ ,, Date Choke Surface Gas Liquid Time a.m. Size Pressure Rate Rate Remarks psi MCF BPD. Load clocks at 17:45 PM 11,-30-72 12-1-72 Pres ured head t( 4500 PSI + 1617' of 13.2 Mud in 3½" Casing. · 0630 0 Gas cushion started 0650 1760 1760 PSI 0715 1760 Opened tool 0730 1770 Bled Gas ,_ 0800 120 Changed to tank 0816 3 Closed in 1016 0 Calc. 43 PSI Opened to second flow with a light blow -- · 1" deep on bubble hos~ in bucket - , , 1216 0 Calc. .22 PSI flow line closed 1516 0 SAME Li.,ght bubble hose blow - 4" deep 12-2-72 0117 0 Closed t°ol - Very light blow - closed 'l 2-3-72 0235 Reversed... Returned small gas and oil about 10 barrels approximately. $6 barrel~ excess oil cut mud + water cushion + 12 barrels of mud ,. __0545 Pulled loose... REMAINDER OF THE REMARKS FROM DATA SHEET CONTINUED ..... 20 barrels water cushion +- 12 barrels the hydrospring + 20 barrels oil and .... gas cut drilling mud - Unset tool and came out of the hole. Sample - TIGHT HOLE SUBS SIIOW VERY DARK OILL__G~_S. , -- .... '"'"""'""' PRODUCTION TEST DATA '-'""'-"' J Ticket 24 hour No. iTime Dell. .000" 0l .ooo -°z54 .061f7 , ,3 ! -0980 4! .1343 51 .1706 308496 - AI Gauge No. 3287 Depth 15,719 ' Clock No. 7031 Second Third Third Flow Period I',, Closed In Pressure Flow Period Closed In Pressure Flow Period Closed In Pressure Time Dell. .000" .1572 PSIG Time Dell. Temp. Corr. .000" .. 6183 .000 6183' .0315 5640 .0734 _. 4843 .1153 4391 . Log-~ PSIG Temp. Corr. 4198 -' 6614'*- 7243 7506 7684 7789 Time Defl. .000" .000 ' ". 1239- .3363 .5487 .7611 (.8160 PSIG Temp. Corr. 4 i'90 4185'* 4194 4202 4202 4202) Time Defl. .000" C~ Lo- t + t~ {ART TIM] PSIG Temp. Corr. 4242 · · · · · PSIG Temo. Corr. .1991 Time Deft. Log_~ ~ .000" Temo. Corr. J12 2070 4198 .2410 .2829 .3248 .3667 .4090 7883 7947 7992 8028 8060 .9735 1.1859 1.3983 1.6107 1.8231 2.0355 2.2479 2.4603 2.6727 2.8851 CHART TIME EXPIRE 3.0980 Gouge No. 3285 Depth 15 ei .000 6279 .000 4306 .000 lJ .0080 5101' .0104 6628~r~ .0398 5093 .0242 7312 .1081 5000 .0380 7591 .1764 2l .0194 I 3l .0308 141 .0422 si .0536 724' 4302 ~-4-30 6'*~'~' .. 4319 4327 4331 Clock No. 9866 hour 72 SEE :XTRA REz~DING SH :ET... 4500 .0518 7769 .2447 ~_ 4351 .0656 7887 .3130 4339 4306 0794 7976 .3813 4339 jJ .0932 8040 .4496 4339 Ii .1070 8084 .5179 4339 jr, .1350 8165 .6545 4355 4347 11 14J Reodino Interval 10 ~i~ 12 .7228 .79i1_ .8594 .9277 · , 9960 I 60 4347 4339 4335 4339 REMARKS: * INTERVAL = 7 MINUTES. ** INTERVAL = 9 MINUTES. *~',~'~ INTERVAL = 35 MINUTES. 230.5 MINUTES WAS RECORDED ON B.T~ # 3287 WHEN CHART TIME EXPIRED .... Minutes 5 Gauge No. 801 Depth 15,748' Clock No. 6196 72 hour No. 308496 - A First I! First Flow Period ,' Closed In Pressure Time Deft. .000' .000 0088 .o214 .0340 .0466 .0592 .0720 ,°t PSIG I! TimeDef,. j- Temp. Corr. ' .000' LOg------~ 6272 6256* 6191 5198 4559 4352 4279 .ooo .OLO5 i · 0244 · 0383 .0522 .0661 I · 0800 · 0939 I .1078 PSIG Temp. Corr. 4279 663'8~? 7316 7567 7737 7850 7943 8OO4 8049 Second Flow Period Time Deft. .000" .000 ·0418 .1135 (.1640 .1852 .2569 .3286 ·4003 .4720 I · 1217 i 8089 .5437 " .1360 i 8121 .6154 " ·6871 ·7588 .8305 · 90_22 .9739 PSIG Temp. Corr. 4283 4283 4296 4300) CLOCK STOPPEi Second Closed In Pressure Time Defl. .000" CLOC] L t-I-~ og--~-- ( STOPPE] PSIG Temp. ' Corr. )eee~ee· Third Flow Period Time Deft. PSIG Temp. .000" ' Corr. Third Closed In Pressure Time Deft. .000" Log t -6, 8 pCIG Tcm;~. Cart, Gauge No. 1·0460 " 791 Depth 15,752 ' Clock No. 9184 hour 72 -0 j . 000 0084 4 J .0203 4322 6616** .000 6306 ,J .000 6306* J .0106 5764 J .0248 i .0390 j .0532 I .0674 4322 I' ,0816 .1100 .lg42 .1380 . 4384 · 0413 4322 7893 4322** 4331 7339 .1121 .0322 4983 7591 .1829 4339 4533 7781 .2537 4343 4351 7979 8041 8086 8127 8164 1.0441 ],0560 J..,0680 ,3245 .3953 .4661 .5369 .6077 .6785 ,7493 ,8909 9617 81 ,.9j 10! 11 i41 ] 5 i ' 1 .'0330 Reading Interval 10 ij 12 4351 4351 4355 4368 4368 4360 4364 4355 4355 4355 SEE EXTRA EADING ~ I 60 ! Minutes REMARKS: * INTERVAL = 7 MINUTES. ~'~',' INTERVAL = 9 MINUTES. ~',~','* INTERVAL = 35 MINUTES. 137'2 MINUTES WAS RECORDED ON B.T. # 801 BEFORE CLOCK STOPPED... SPECIAL PREF SIIRE DATA MARATHON OIL COMI~ANY L~ase Owner/C6np;my Name B.T. 3285 Depth 15,724 ' B.T. 791 Depth 15,752 ' 308496 - A YiC'k~t- NUmber B,To Depth P-O P-1 P-2 P-3 P-4 P-5 P-6 P-7 P-8 P-9 P-10 P-Il P-12 P-13 P-14 P-15 P-16 P-17 P-18 P-19 P-20 Time Defh .000" SECOND- .o00 .0966 .1932 .2898 · 3864 .4830 .5796 .6762 .7728 .8694 .9660 1.0626 1.1592 Log-~ CLOSED 7664 7417 Il ~.1004 _ 2008 7781 7854 7911 7947 7980 8004 8028 8044 8064 8076 .3012 .4016 .5020 .6024 . '~028 ,8032 .9036 1.0040 1,1044 1,2048 Lo~ t +_0.. -u 0 PSIG Temp. Corr. 4355 7438 7674 7793 7868 , 7921 7959 7996 8020 8O45 8061 8082 8094 1.2558 8092 1.3052 8111 8100 1.4056 1,5060 1. 6064 1. 7068 1.8072 1-~, 9o7--7'6-- 8108 1.9650 85 MI~ 1.3524 1.4490 1.5456; 1.6422 8120 1.7388 1.8354 1,8910 85 MINI 8129 8137 8137 8123 8131 8139 8148 8141'** INTER [UTE INTI:RVALS. RVAL 49 MINS *~'~','* rTERVAL 49 MIl __ .000" PSIG Temp. Corr, SPECIAi, I'>I~d".sSuI:[I'; DATA Ticket F L U I D S A M P L E D A T A Date 12-8-72 Number 308497 '~r- I ,_ Sampler Pressure P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of Job HOOK WALL District ANCHORAGE cc. Oil cc. Water Tester HAROLD MANN Witness DAVE SMITH cc. Mud Drilling Tot. Liquid cc. Contractor READING & BATES SM S Gravity. ° APl @ °F. E Q U I p M E N Z & H O L E D A T A Gas/Oil Ratio cu. ft./bbl. Formation Tested Hemlock · Elevation 164' ,Ft. RESISTIVITY CHLORIDE Net Productive Interval 60 t .Ft. CONTENT All Depths Measured From, Kelly bushing Recovery Water __ @ __ °F. ppm Total Depth 15. 740 ' Ft. Recovery Mud ' __@ __°F. Main Hole/Casing Size 9 5/8 - 7" 32~ Liner Recovery Mud Filtrate __ @ __ °F. ppm Drill Collar Length - I.D. Mud Pit Sample __ @ __°F. Drill Pipe Length ] 5:4713J. 4.276" Mud Pit Sample Filtrate ~ @ __*F. ppm Packer Depth(s) ]5~51~' Ft. Mud Weight 11.1 vis .5.5 cp Depth Tester Valve !5 z 493' ' Il Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Fresh water 3500" Ft. Pres. Valve Choke - Cho_ke .... J_/.2-U. Recovered 1700 PSI Feetof gas cushion Recovered 3500 Feet o~ water cushion ~' ~! ~ ~,~ ~'~ ~ ~;,-"' ,,~. ' ,,_ Recovered 2 bbls. F~r~of gas & oil cut mud Recovered Feet of (Small oil sample caught in sampler) Tight Hole subs Remarks Tool opened using 1700 PSI gas cushion on first flow and bleading to '"'0" in one hour. Closed tool for 118 minute first closed in pressure. Tool reopened for 903 minute second flow with Llight blow in bucket on b~bble hose, about 18" water in bucket. Closed tool for 1736 minute second cTlp: Reverse circul, a,ted 4 hours before comin~ out of hole. Gauge No. 1238 Gauge No. 1237 Gauge No. 352 TEMPERATURE TIME Depth: 15497 Fit. Depth: J. 5502, Ft. ,pep,th: 15526 Ft. 24 HourClock 72HourClOck 72 HourClock Tool 12-8-72A.M. Est. , °F. Blanked Off 1;10 Blanl~ed Off no Blanked Off 15,53~' Tool 112" 10- A.M.'I ~ Actual 220 *F. Pressures Pressures Pressures Closed 1655 P_.M. Field Office Field Office Field Office Reported Computed 'lillrli 't ia I Hydrostatic g2-24 9-2-6-2 9'2-00 9-i~-2-1 9193 9-'1-90 Minutes Minutes · ~o Flow Init--ia--I 3937 3 §-5-6 38-97 ..:'c Finol 1-9--08 1927 1874 188'--4 17~-9-.~-- 1915 59 59 Closed in 7661 7655 7616 7642 7624 7641 121 118 Initial 1908 1952 1874 1904 1895 1938 c o Flow ~°~ Final - 2537. 3036 3073 3105 3101 900 903 w,~ Closed in - . 7682 7695 7657 7690 1736 1736 ~ Initial ~__o Flow .... ~2 Final .... Closed in ........ Final Hydrostatic I ' 9200 9128 9193 9128 · ,, · Read at the end of' approximately 371 minutes when chart time expirc~. ' I FORMATION TEST DATA I FLU I D SAM P L E DATA Ticket Date 12-8-72 Nu,nber 308497 Sampler Pressure P.S.I.G. at Surface Kind Halliburton Cu. Ft. Gas of Job }{00I( WALL District AN~.IORAGE Recovery: cc. Oil cc. Water Tester HAROLD MANN Witness DAVE SMITH cc. Mud Drilling Tot. Liquid cc. C0ntroct°~EAD-'[N~, ,& BATE~ SM S Gravity. ° APl @ °F. E Q U I P M E N T & H O L, E D A Z A Gas/Oil Ratio ' cu. ft./bbl. Formation Tested, · Elevation .. Ft. RESISTIVITY CHLORIDE Net Productive Interval Ft. CONTENT All Depths Measured From Recovery Water ~ @ ~ °F. ppm Total Depth Ft. Recovery Mud ~ @ ~ °F. Main Hole/Casing Size Recovery Mud Filtrate ~ @ ~ °F.. ppm Drill Collar Length I.D. Mud Pit Sample __ @ __ °F. Drill Pipe Length I.D Mud Pit Sample Filtrate ~ @ ~ °F. .ppm Packer Depth(s) Ft. Mud Weight vis _,cp Depth Tester Valve Ft. .......... TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke Recovered Feet of O Recovered Feet of · 3 Recovered Feet of Recovered Feet of Recovered Feet of '' Remarks FOURTH GAUGE , _ Ga'uge No. 138 Gauge No. Gauge'No. ' .... TEMPERATURE TIME ,, Depth: 15530 Ft. Depth: Ft. Depth: Ft. 72 Hour Clock Hour Clock Hour Clock Tool A.M. Est. °F. Blanked Offyes Blanked Off Blanked Off Opened P.M. ,, ...... Tool A.M. Actual °F. Pressures Pressures Pressures Closed P.M. , , Field Office Field Office Field Office Reported Computed initial Hydrostatic 9201 ,. Minutes Minutes Initial ~ Flow ........ iZ~ Final Clock stcpped ., __ Closed in --before tcol ~-o Initial opened · Co 8,r. Flow o ~ Final , , Closed in ~ Flow Initial !'-" Final I~'~' Closed in __Find H_ydrostatic .... PRINTED IN FORMATION TEST DATA LITTLE ~. 90317 IO14 ,3/72 fs 15560-15695 1/2" 22 308497 Cosing per .___ Bottom choke Surf. temp °F Ticket No Gas gravity. Oil gravity GOR Spec. gravity ...... Chlorides.. ppm Res... @ °F Date Choke Surfoce Gas Liquid Time a.m. Size Pressure Rate Rate Remarks psi MCF BPD 12-8-72 0 1700 Filled pipe With gas cushion · 1740 1700 PSI gas ok. 1759 1700 Opened tool. · 1806 1700 Open-gas to trap 1858 3 PSI Closed tool. --. 2059 0 Opened to second flow 2125 0 Light blow on bubble hose -bottom of 12-9-72 18" bucket. 2400 ' Medium blow on bubble hose, bottom of 18" bucket. 1159 Closed for second CIP-light blow .... 12-10-72 on bubble hose-same as other 15 hrs. 1259 Reverse circulated. ..... Conditioned mud 1655 Pulled loose. , ,, - .... "'"'""'""' PRODUCTION TEST DATA Gauge No. 1238 Depth First n First Flow Period Closed In Pressure .0000 .0302- .0638 .0973 .130¢ .1644 .1980 15,497' Second Flow Period Clock No. 7031 Second Closed In Pressure J Ticket 24 hour No. Third Flow Period 308497 Third Closed In Pressure Time Deft. PSIG Time Defl, ~ PSIG Time Defl, PSIG Time Deft, Lo- t Jr ~ PSIG Time Defl, PSIG Time Defl. Lo- t -J- ~ P.-' JG Temp. Log Temp. Temp, Temp, oTemp, TcmD. ,000" Corr. .000" ~ Corr. ,000" Corr. ,000" ~J ~ Corr. ,000' Corr, ,000" g -----~-~ Corr. 3956 .0000 1927 0000 1952 3533 .0342'~ 6274 .3518'~ 2124 2295 2444 +*'2537) Nolte recor, led .0752 j 7426. 7502 7552 7586 7618 2660 7028 2225 .1162 I 7301 1949 .1982 I 1927 .2392 ! Char~ time e: :pired · 2802 I .3212 J .6933 1.0348 1.2680-~ 1;3764 1,7179 2,0594 2.4010 10 11 12 .13I 14! .3622 I .4030 I 7639 7655 2.7625 3.0840 Gouge No. 1237 Depth 15,502' Clock No. 9866 72 hour Cl.0000 J 3901 .0000 1884 .0000 1904 .0000 3073 1'0102'I 3325 .0110"~ 6411 .1138'~* 2073 .0663 7136 21 .0216 I 2542 .0242 7070 .2244 2243 .1326 7315 31 0329 I 2156 .0374 7301 .3349 2392 .1990 .7401 I 1980 .0506 7421 .4454 2525 .2653 7454 0556 I 1904 .0638 7487 .5559 2645 .3316 7490 0670 1884 .0770 7536 .6664 2748 .3979 7520 1'4 .0443 :5 14 .0902 7573 .7770 2851 .4643 .1034 7603 .8875 2960 .5306 .1166 .1300 7623 ' 7642 .9980 3073 .5969 .6632-- .8843i 1.1054 1. 3265 J i 1.5476 151 I 1.9180 I Reading Interval 00 7540 7560 7576 7589 7593 76A9 7666 _7672 7695 REMARKS: Minutes *First interval is equal to 9 minU~es, i~'~First interval is equal to 10 rnint~eR. ~',~','103 mln,~m.~_ ****Read at the end of approximately 371 minutes when chart time expired, *****First 10 intervals are equal each, next 4 intervals are equal to 200 minutes each and last interval is equal to 336 minutes· Gouge No. 14 15 First Flow Period Time Deft. .000" 0000 0101- 0213 0324 0436 0548 0660 352 PSIG Temp. Corr. 3922 3294 2542 2167 2003 1938 1915 J Depth First Closed In Pressure TimeDefl. J - t mt. ~ .o00"J LOgT · oooo t · 0112','cfi .0246 0380 0515 0649 J.0783 PSIG Temp. Corr. 1915 6384 7059 7294 7418 7493 7542 15,$26' SeCond Flow Period Time Deft. .000" .0000 .2297 .3429 .4561 .5692 .6824 PSIG Temp. Corr. 3938 "2108 2281 2428 2556 2676 2784 Clock No. 6196 Second Closed In Pressure Time Deft. .000" .0000 .0679 .1358 .2037 .2717 .3396 .4075 LogZ PSIG Temp. Corr. 3101 7124 7310 7399 7451 7490 7516 JTicket 72 hour No. Third Flow Period Time Defl. .000" PSIG Corr. ! .0917 7578 .7956 2873 .4754 7539 .1051 7605 .9088 2987 .5433 · 7559 .1186 7624 1.0220 3101 .6112 7572 .1320 7641 .6791 7585 .9055 7618 · 1,1319 1.3583 1.5847 7644 766O 7667 96.50 I I 76q0 308497 Third Closed In Pressure Time Deft. .000" Log t nu 8 Gauge No. 0t 21 12 13 14 J Reading Interval REMARKS: 'RINTEDIN U.S.A. 138 Depth 15,530' Clock No. 918Z I Clock sto re tool ,ped bef( opened 72 hour Temp. Corr. 10 12 100 *First interval is equal to 9 minutes. **First = 10 minutes. ***First = 103 minutes. ****First 10 intervals are equal to 60 minutes each, next 4 are equal to '~200 minutes each and i'ast interval zs Minutes equal to 336 minutes. c;~f"'IAi PPg"CC:il II::PI~ FhATA '""~'"' Reversing Sub . Water Cushion Valve Drill Pipe .................... Drill Collars ..................... Handling Sub & Choke Assembly ..... Dual CIP Valve ................... Dual CIP Sampler .................. Hydro-Spring Tester ................ Multiple CIP Sampler ............... Extension Joint .................... Running Case .................. Hydraulic Jar ..................... VR Safety Joint ................ Pressure Equalizing Crossover ......... Packer Assembly ......... R??.~. ..... Distributor ........................ 5!t _._.__~ II 2.25" 4.276" 3¥88" ' 3VffO" . ~[~ii 2.43'j 3.75" 3.87" 3.88" 5.75" 2.88" , .62" .75" 2.36" 2.259" 308497 LENGTH DEPTH 15~471' -- 6.5' ~.30= 15,493' 4.09' 5.OB' 2.83' 3.63' 4.34' 8.77' 15,497' lb,bO~s 15,510' Packer Assembly ................... Flush Joint Anchor ....... Pgr. f.s .... Pressure Equalizing Tube .......... Blanked-Off B.T. Running Case ....... Drill Collars ....................... Anchor Pipe Safety Joint ............ Pocker Assembly Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... ~[I,~n¥~?ff B.T. Running Case ....... 3.88" 3. '88" 4.05' 4.09' 1' 15,526' ls_..53p' ,15,,53~ ' .... "°'" EQUIPMENT DATA FLUID Sampler Pressure Recovery: Cu. Ft. Gas cc. Oil cc. Water cc. Mud Tot. Liquid cc. Gravity Gas/Oil Ratio SAMPLE ° APl @ DATA P.S.I.G. at Surface °F. cu. ft./bbl. Dote 12-12-72 Ticket Nu,.nb~L- Kind Halliburton of Job HO0~ ~A~ District ANCHORAG~ Tester HAROLD ~ Witness DAV~ Drilling Contractor~AD~NG & ~A~S S~ S EQUIPMENT & HOLE DATA Formation Tested Hemlock RESISTIVITY Recovery Water __ @ __ "F. · Recovery Mud ~. @ ~ °F. Recovery Mud Filtrate __ @ __ °F. Mud Pit Sample __ @ __ 'F. Mud Pit Sample Filtrate ~ @ ~ °F. Mud Weight 11.4 vis CHLORIDE CONTENT .ppi .ppi .ppi Elevation 164' ,-. 100 ' Ft. Net Productive Interval Ail Depths Measured From Total Depth Kelly bushing 15520' Ft. Main Hole/Casing Size 9 5/8" 47~J 7" 32~J Drill Collar Length ' I.D Drill Pipe Length. 15273' I.D 2.764 & 4.276" Packer Depth(s) 15313 ' Ft. Depth Tester Valve 15293~ Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Fresh water 3500 Ft. Pres. Valve Choke 1" Choke 1/2" Recovered 1500 PSI F~[of gas cushion Recovered 275 BBLS ~X'of water cushion in 3~" pipe Recovered 19 BBLS.~re~of oil & gas Recovered Feet of Recovered Feet of Remarks Ran 3500' of water cushion in 3~" drill pipe and used 1500 PSI gas cushion...opened to flow for 10 minutes and started bleading down gas cushi Remained open for 1 hour. Closed for 120 minutes. Reopened for 607 minutes with light bubble hose blow. Closed tool for 1037 minute second closed 'in pressure. TEMPERATURE Est. °F. - 1~334" ' Actual 217 °F. I~_)itiol Hydrostatic Initia_____~l Flow Final Closed in t ~-o Initial co oFlow ~'~, Final 'a Initial ~.o Flow ~ ~ Closed in Final Hydrostatic /'MINTED IN U.I.A, Gauge No. Depth: 15300 Ft. Reversed out 27.5 bhls. water, 5.2 bbls rat hole mu~, 19 bbls 1238 Gauge No. 1237 Gauge No. 352 or- oil & gas. TIME , Depth: 15305 Ft. 7:~our Clock Blanked Off no ,Depth: 15329 Ft. 7 2 Hour Clock Blanked Off ye ~ Pressures 24 Hour Clock Tool Opened Tool Closed Blanked Off no Pressu res Pressures Field Office Field Office Field Office Reported 9'1.30 9202 9102 9095 9190 Minutes 3467 1741 3494 1748 7348 3528 1764 7382 9174 ----:~477 1748 3497 1768 1732 3507 1768 1748 i ~, e~d ,of a 7351 1741 7368 7362 7386 1734 1732 1761 2060 2092 2105 7417 7395 7428 '9093 · tool apF 9174 nutes whet 9190 arent ly mz TEST DATA 1882' 2040 - 7384 - 9134 pproximat¢ lY 166 mi FORMATIO A.M, P.M. A.M. P.M. Computed Minute,s 60 60 1 functi~neJ] LITTLE 8 g0217 IOM 2/7" , /) Ticket F L U I D S A M P L E D A T A Date 12- 12-72 Number 308498 Sampler Pressure P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft.. Gas of Job HOOK WALL D:s:..!ct ANQJORAGE cc. Oil cc. Water Tester HAROLD MANN Witness DAVE SMITH cc. Mud Drilling Tot. Liquid cc. ContractorREADING & BATES ~ $ Gravity. ° APl @ °F. E Q U I P M E N T & H O L E D A T A Gas/Oil Ratio cu. ft./bbl. Formation Tested Elevation Ft. RESISTIVITY CHLORIDE Net Productive Interval Ft. CONTENT All Depths Measured From Recovery Water ~ @ ~ °F. ppm Total Depth Ft. Recovery Mud ' ~ @ ~ °F. Main Hole/Casing Size Recovery Mud Filtrate ~ @ ~ °F. ppm Drill Collar Length ,,. I.D, Mud Pit Sample ~ @ __ °F. Drill Pipe Length,. I.D, Mud Pit Sample Filtrate ~ @ ~ °F. __ppm Packer Depth(s) Ft. Mud Weight vis .CD Depth Tester Valve Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke ., Recovered Feet of Recovered Feet of . Recovered Feet of Recovered Feet of Recovered Feet of Remarks Fourth Gauge " Gauge Nol 138 Gauge I~lo. Gauge 'No. TEMPERATURE TIME __ , .... Depth: 15 ~ 333 ' F.t. Depth: Ft. Depth: Ft. ,, 72 Hour Clock HourClock Hour Clock Tool A.M. __Est. °F. Blanked OlaF,es Blan~ed Off Blanked Off Opened P.M. Tool A.M. Actual °F. Pressures Pressures Pressures Closed P.M. -- ~ Field Office Field Office Field Office Rep°rled Computed In__ iitial Hydrostatic 9126 9204 Minutes Minutes ._~o Initial 3505 3518 ~'r. Flow .... u:~. Final 1740 1776 ,,, __ Closed in 7411 7401 , ,, ,~ Initial 1740 1776 8 r- Flow ~ ~ Final 2093 2109 ~ Closed in 7411 7434 Initial ~ Flow" ~..,. Final Closed in Fin__.____~l Hydrostatic 9223 __9204 ,, , , , FORMATION TEST DATA LITTLE ~ 1*0,117 IOM Cosingperfs. 15 361-15 461' 6° °F TicketNo. 308498 ~ ' Bottom choke ,Surf. temp Gas gravity Oil gravity GOR Spec. gravity Chlorides. ppm Res, @ °F Dotel2- 12- 72 Choke Surface Gas Liquid Time a.m. Size Pressure Rate Rate Remarks psi MCF BPD p.m. 15:00 On bottom with tools. 15:30 Started gas cushion · 15:35 Stopped gas cushion, break in line from sas well. 19;48 Started gas cushion 20;07 1475 1500 PSI gas 20:15 2" 1475 Opened tool 115~000 down Full 20:25 2" 1500 Bleading off gas cushion 21:15 30 Closed tool. 23.15 ' Opened for second ~low Bubbl~ 12-13-72 hose 0 Light blow on bubble hose, 00:44 4" in bucket, 09:22 0 closed tool. 12-14-72 , , 00:22 Reverse circulated , Circulated and conditioned mud 19 bbls oil in recovery. 02:40. Pulled loose. .., , PFII~TED IN U.I~.A. PRODUCTION TEST DATA "'"""'" Gauge No. 1238 Depth First I! First Flow Period Closed In Pressure 15,300' Second Flow Period Clock No. 7031 Second Closed In Pressure 24 jTicket hour No. Third Flow Period 308498 Third Closed In Pressure Time Deft. PSIG Time Defl. · t -{- 0 PSIG Time Defl. PSIG Time Defl. _~ PSIG Time Defl. PSIG Time Defl. Lo- t nt- ~ p? IG Temp. Log Temp. Temp. Log Temp. · Temp. Temo. .000" Corr. .000" ~ Corr. .000" Corr. .000" ~ Corr. .000" Corr. .000" g---~-- Corr. .0000 3528 .0000 1764 .0000 1768 .0337 3494 .0401 5601 .5520 1882 .0674 2724 .0802 6429 Closed in · 1011 222-2 .1203 6809 t the ssure no .1604 .2005 .2406 7022 7132 7219 7288 7329 Read a · 1348 .1685 end of approx 166 mi when t appar~ malfun imately nutes ool mt ly ctioned 1946 1815 pre rec cha exp orded... rt time ired. 1764 .2807 .3208 .2020 .3609 7357 · 4010 7382 Gouge No. Depth 15,305 ' Clock No. 9866 72 hour cl.0000 .0000 il0224 , 0336 ,0448 .0560 61.0670 2532 1734 .0000 3477 .0000 1748 1!'0112 3258 0129 5847 .~1188- 1807 .0630",~ .2299 1870 .1404 .0258 0387 ,0516 j0645 .0774 6546 , 6848 7017 7129 7205 2121 6586 6930 1900 1784 1748 7073 .3409 1920 .2178 .4519 1967 .2952 7156 .5630 2018 .3726 7212 .6740 2060 .4500 7255 .5274 7285 .6048 7315 7331 10 11 13 14 15, ~~ Reoding Interval · REMARKS: _ .0903 ·1032 .1161 _1?gO lO Jj 12 7272 7315 7~48 7368 100 .6822 · . .7596 , .8370_ .9144_ .991g 1.0692 .1. 147o ~0 7351 7368 7381 7394 7407 7417_ Minutes *First interval is equal to 107 minutes, **First interval is equal to 57 minutes. Reversing Sub .... Water Cushion Valve O.D. I.D. Drill Pipe ....................... Drill Collars ...................... 5" 2.25" 3~z & 4½ 2.764 & 3.826" Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Dual CIP Sampler ................... Hydro-Spring Tester ............... Multiple CIP Sampler ............... Extensk)n Joint .................... AP Running Case .................. II Hydraulic Jar .................... VR Safety Joint .................. Pressure Equalizing Crossover ......... Packer Assembly ...RT..T.S. ........... Distributor ........................ Packer Assembly ................... Flush Joint Anchor .~er.fs .......... Pressure Equalizing Tube ........... Blanked-Off B.T. Running Case ....... Drill Collars ................. '. .... Anchor Pipe Safety Joint' 5.88" 3.90" · 3.75" 3.75" 3.87" 3.88" 5.75" 2.88" , .87" 2.43" · 62" .62" .75" 2,36", 2.259" Packer Assembly ......... .......... Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... Flush Joint Anchor ................. Blanked-Off B.T. Running Case ....... HT 500 3.88" 3.88" 308498 LENGTH DEPTH 1' 15,087.0 ' 15,273' 6.5' 9.64' 6.12' 15~93' 4.09' 15,300' 5.08' 15,305' 2.83' 3.63' 4.34' 15,313' 8.77' 4.05' 15,329' 4.09' 15,333' 1' 15,334' Gauge No. 9 11¸ 13 352 First Flow Period PSIG Temp. Corr. j Depth Time Deft. .000" 0000 First Closed In Pressure Time Deft. .000" PSIG Temp. Corr. 15:329' Second Flow Period Time Deft. .000" PSIG Temp. Corr. Clock No. 61 g Second Closed In Pressure Time Defl. .000" Log~ PSIG Temp. Corr. 3507 .0000 1768 .0000 1761 .0000 2105 3242 .0135 5931 .1216' 1843 .0643'~ 6610 .0224 2578 .0270 6554 .2353 1909 .1433 6951 .0336 2154 .0405 6872 .3490 1958 .2223 7092 .0448 1922 .0540 7036 .4626 2007 .3013 7170 .0560 1817 .0675 7154 .5763 2062 .3803 7225 ,0670 1768 .0810 7225 .6900 2105 .4593 7268 .0945 7288 .5383 7297 ITicket 72 hour No. 308498 Third Flow Period Time Defl. .000" PSIG 'memo. Corr. .1080 7327 .6173 ' 7324 .1215 7363 .6963 7343 .1350 7386 .7753 7363 .8543 7376 . .9333 7389 7405 7415 14 1.0123 1.0913 1.1700 Gauge No. 138 Third Closed In Pressure Time Deft. .000" p.ClG Temo. Corr. Depth 15,333 ' Clock No. 9184 72 hour iJ 13 14 15. .0000 .0112 .0224 .0336 · 0448 .0560 .0670 3518 3309 2606 2157 1929 1824 1776 Reoding Interval 10 .0000 .0136 .0272 ,0408 .0544. .0680 .Ogl 6 .0959 , lOSg .122~ :1360 12 1776 5748 6560 6874 .0000 · 1216- .2353 .3490 1776 1856 1917 1965 2013 7045 .4626 7149 .5763 2067 7233 .6900 2109 .0000 · 0 647'~ .1442 .2237 .3032 .3827 .4622 7294 , 7337 · 7375 · 7401 . 100 5417 6212 7007 7802 ,8597 .9392 1.0t87 1.0982 1:1777 2109 6631 6964 -7100 7178 7236 7278 7311 7333 7356 7372 7388 7401 7A]A 742A 7434 REMARKS: * First interval is equal to 107 minutes· **57 minutes. /"~!-"~1'"~! 7~. ! ~__~i._.~l._~/..~/..~I Minutes L SY~'IGOL OF SERVICE COMPANY WELL NAME LOCATION TYPE OF SURVEY DATE I~'~t~J~ O-,:~:~a, R ~. LITHO BY EASTCO tN U. S. A, RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY i B M ELECTRONIC COMPUTER TRUE YEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH SUB DRIFT .SEA DIREC DEG, TOTAL COORDINATES CLOSURES DISTANCE ANGLE D M S -,.~.65 0 30 .4264,9~ 4100.94 S 30 W 4445 0 30 4444,93 42B0,93 S 50 W 4625 0 15 4624,95 4460,93 S 29 W 4805 0 30 4804.92 46~0.92 $ 85 W ~985 0 15 ~984.92 4820e92 N 61 w 5156 0 15 5155,92 4991.92 N 57 W 5~5 0 15 53~4,92 5180,82 S 65 W 5525 0 0 5524,92 5~60~92 S 0 ~ 5705 0 15 570~,92 5550,92 N ~5 ~ 5885 0 15 5884,92 5720.92 N 20 W 6065 0 15 606~,81 5900,9!' N 20 ~ 6245 0 15 62~$,91 6080e91 N 26 E 6~25 0 45 642~,90 6260,90 N 51W 6785 1 15 6784,81 6620,81 N 55 W 6965 ! 0 6964e78 6800,78 N 56 W v'~5 1 15 7144,74 6980,74 N 71W ~25 I BO 7324,68 7160,68 N 69 W 7505 1 BO 7504,62 7~40.62 N 54 W 7685 I 30 7684°56 7520e56 N 50 W 7865 1 30 7864~49 7700.49 N 55 W ~045 1 15 8044,49 7880.45 N 50 W 8225 I 30 8224.39 8060,39 a 50 W 8405 ! 30 8404.33 8240°33 N 45 W 8585 1 30 8584.27 8420.27 N 39 W 0,88 S 6,05 W 1.89 S '/.2~ t~ 2.58 S 7.64 W 2,72 S 9.20 W 2.34 S 9,89 w 1,93 S 10,51 W 2,28 S 11,26 W 2,28 S ' 11e26 W 1,64 S 11.71 W 0~0 ~ 11,9~ W 0,16 S 12.25 W 2,56 N 1~.12 W 5,18 N 16.04 W 7,44 N 19.25 W 9.19 N 21,86 W 10,47 N 25,57 W 12,16 N 29,97 W 14,93 N 33,78 W 17.96 N 37,39 W 20,65 N 41.25 W 23,18 N 44,26 W 26,21 N 47,87 W 29,54 N 51,20 W 33,21 N 54,16 W 6,12 S 81 38 48 w 7,50 $ 75 20 27 W 8e05 S 71 18 5 w 9,59 S 73 31 20 w 10,16 S 76 40 48 W 10~69 S 79 34 20 W. 11.49 S 78 32 16 W 11,49 $ 78 32 16 W 11,82 S 82 1 ~9 W 12~0! S 8~ 41 ~1W 12,2~ S 89 13 47 w 11,92 N 87 2B 52 W 13,~6 N 78 57 26 W 16,8~ N 72 4 ~3 W 20,64 N 68 52 27 W 2~,?i ~ 67 10 58 W 27,6~ N 67 43 29 W ~2.84 N 67 54-~8 W ~6,9~ N 66 9 12 W 41,48 N 6~ 20 ~ W 46.14 N 6~ 2~ 33 W 49,96 N 62 20 ~8 W 54,58 N 61 17 30 W 59,11N 60 0 38 W 63.5~ N 58 29 13 W FOLLOWING SURVEY DATA FRO~ SINGLE SHOT MAGNETIC SURVEY INSTRUMENT '~8765 2 0 8764,16 8600,16 N 36 W 38,29 N 57.86 W 69,38 N 56 30 9 W DOG LEG SEVERITY DEG/IOOFT 0,241 0,096 0-156 0,231 0.180 0,010 0,128 0,139 0,036 0,000 0,109 0,360 0.320 0.085 0-i~9 0o218 0.1~1 0,218 0,058 0,07~ 0.154 0.139 0,073 0.087 0,282 SECTION DISTANC~ -6,11 -7.40 ' -7,84 -9,42 -10.06 -10,65 -11,81 -12,21 -11.80 -12,82 -15,48 -28~69 -35~53 -39~12 -45,19 -48~i9 -54,00 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER TRUE MEAS, DRIFT' VERTICAL DEPTH ANGL~7 DEPTH D ,M SUB DRIFT SEA DIRE¢ DEG, 8796 3 30 8795.10 8631.10 N 5 W 8828 3 30 8827.04 8663.04 N 16 E 8858 4 45 8851.94 8692,9~ N 20 E 8904 5 15 8902,74 8738.74 N 27 E 8982 6 0 8980,32 8816,32 N 27 £ 9185 7 45 9181,46 9017,45 N 55 E 9360 9 15 9354.!9 9190,19 N ~0 E 9522 9 15 9514,08 9350.08 N 44 E 9778 10 45 9765,9~ 960!.9~ N 50 E 10110 11 30 10091,2B 9927.28 N 56 £ 10~21 1~ 0 10296,01 10I$2.01 N 5B E 10~6 1~ 45 10416.89 I02~2,89 N 60 [ 10543 14 30 10510,80 I03~6,80 N 62 E ~0664 ~4 ~0 ~0627.95 ~0463.95 N 62 E ~0752 ~5 30 ~07A1,65 ~0577.65 N 66 E ~0828 I5 30 ~0785,95 ~0621~9B N 66 E 10932 15 15 10886,32 10722,32 N 68 E 11039 15 15 10989.55 10825,~5 N 70 ~ 11198 15 ]5 11142,95 10978.95 N 7~ E 11289 15 ~5 11230.5~ 11066.5~ N 74 E 11562 15 15 11493,58 11329.58 N 78 E 11666 15 15 1159B~91 1t~29~91 N 80 E 11761 15 !5 11685.57 11521,57 N 80 E 11835 15 0 11757,05 11591o05 N 82 E' 119Z9 1~ 45 11847,95 1168~95 N 85 E 12015 14 45 1!931.12 11767.12 N 86 E TOTAL COORDINATES AO,17 N 58,02 42,05 N 57,48.W 44~39 N 56,6~ 48,14 N ~4,72 55,40 N 51.02 77,83 N $5,52 99,~7 N 17.24 118,11N 0,84 1~1,52 N 14.7~ 148,54 N ~5.02 16B~76 N 54.50 186.9~ N 88,88 214,00 N 132.17 229.91N 159,73 241,~2 N 181,17 255,~4 N 207,92 268.~6 N 236.7~ 293.2~ N 299,77 306,16 N ~B9.55 B22,69 N 402.27 B~4.28 N 461.37 338-61 N 485°98 ~41°28 N ~04~95 ~4B.$7 N 528,79 ~44.89 N ~50o6~ ¢ k 0 $ U R E S DISTANCE ANGLE D M S 70,57 N 55 18 0 71.22 N 53 48 41 71.96 N 51 54 41 72,88 N 48 39 46 75.32 N 42 B8 ~4 85,47 N 24 26 40 ~00-86 N 9 50 34 118,11N 0 24 ~B 132,34 N 6 2~ ~1 152,61N 1~ 16' 0 172,59 N lB 24 30 207,00 N 25 25 39 251.5~ N 31 42 0 279.96 N B4 47 21 ~0~,76 N ~6 5~ 54 B29.44 N ~9 8 3 B57,86 N 4~ 24.59 $69.07 N 42 12 .37 393,88 N 43 56 30 419.$5 N 45 ~7 52 457,20 N ~7 ~7 34 479o51N 49 15 19 515.71N 5i ~5 5! 5~5,27 N 52 ~9 ? 569.74 N 54 4 ~2 592,32 N 55 7 56 609,46 N 55 56 46 630,49 N 57 0 8 649.73 N 57 56 18 DOG LEG SEVERITY DEG/IOOFT 6,649 ~,984 4,273 1.71~ 0.962 0.981 0,955 0.~97 0.525 0,864 0,680 0,383 0.719 0,581 0,000 1.219 0.000 0,564 0.492 0.331 0,804 0°307 0.585 0.506 0o000 0°7~2 O,8&l 0,296 SECTION DISIAi~CE -53.98 -53.27 -52o20 -49.95 -4D,58 -27,84 -7.81 11~95 27,04 ~9,67 106.08 1~I,72 180~66 260~ 272~59 29S,80 326,04 366.85 4~0.85 490.78 5].b,69 534.82 ~58,79 RECORD OF SURVEY - ALL CALCULATIO,,~$ PERFORHED BY I B H ELECTRONIC CONPUTER TRUE MEAS, DRIFT' VERTXCAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, 12142 14 15 12054,21 11890,21 N 89 E 12251 14 0 12159.97 11995.97 S 89 E 123~1 13 30 12247.~8 12083,48 S 89 E 12542 12 0 12443.80 12279.80 $ 86 E 12738 15 0 126~3.12 12469.12 S 84 E 12942 16 ~0 12828~72 12664,72 $ 84 E 1~5~0 17 45 15588,75 1322~73 $ 82 E 15780 18 15 13626,16 1~62~16 S 80 E 1~10~ 17 15 1393~.63 t3770.6~ 5 79 E !~658 15 ~5 14276~30 14112,~0 $ 79 E' 15010 14 15 14811,32 14647.~2 S 82 E 1.5065 lq 15 14864.62 i4700.62 $ 75 E 15~64 1~ 15 14960,99 14796.99 S 61 E 15:45 1~ 30 1523~,04 15069.04 $ 67 E 15603 1~ 0 15386,34 15222.~4 ~ 65 E 15720 13 50 15500,il 15335,11 S 66 E 15820 12 45 15597.65 154~3,65 S &5 E 159~0 12 45 15714,69 15550,69. S 66 E TOTAL COORDINATES 345.44 N 581.89 E B44.98 N 608.25.E 344,6i N 629~26 E 343.82 N 65i.98 E 342.40 N 672,30 E $~7e09 N 722.75 E 331.0~ N 780.37 E 306~09 N ' 957.89 292.69 N 1034,99 274,22 N 1129.01 255.8~ N 1223,61--E 236,92 N 1358.I6 2~,42 N 1~1.24 222,42 N 1~91o08 19~,93 N 1455,85 178.77 N 1~90.~9 167,66 N 1515.~ 158o~ N ~535,~4 147.56 N ~559.64 CLOSURES DISTANCE ANGLE O 676.70 N 59 18 15 E 699.27 N 60 26 22 E 717.44 N O1 17 33 E 7~7.08 N 62 11 42 E 754.47 N 6~ 0 37 E 797.50 N 64 59 43 E. ~47.69 N 67 0 46 E ~005.6~ N 72 16 43 E 1075.5~ N 74 13 9 E 116i.84 ~ 76 20 52 E 1250.07 N 78 11 25 E 1~78.67 N BO 6 lb E 1390.96 N 80 20 21E 1405.75 N 60 54 57 E 1468.84 N 82 22 25 E i501.17 N 83 9 37 E 152~.69 N 83 ~1 11E 1543.59 N 84 6 44 E 1566~60 N 84 35 ~1 ~ DOG LEG SEVERITY OEG/IOOFI 0,710 0,503 0,550 0,761 0,881 1,549 0,735 0,235 0.318 0.324 0.423 0o~06 3.131 3,500 0.67~ 0,444 0,473 0.784 0.184 SECTION DISTANCE bll,~l 65U,90 0U1,44 701o~fl 751.27 8OS,07 982-45 1097.9~ 1149,81 1242,25 1374~43 1387o1~ 1405,84 1467.73 lboO~ 1524~ J 154B~53 1566,60 BOTTOM HOLE CLOSURE '1566.60 FEET AT N 84 35 41 'o,m 9-~3,,~' NITED STATES sunmT IN Ti~" 'T~ICATE* Budget~°r~ ~rO~ ~ ~ ~~ ~ j D ' ~ I /I ~ :~ ~g~ DEPART ,._NT OF THE INTERIOR ,e,~.l~) GEOLOGICAL sUrVEY A-208083 SUNDRY NOTICES AND REPORTS ON WELLS ~ ~ ~,,~.o ~/ ..... (Do not use this form for proposals to drill or to deepen or plug back to a different ~ese~vol¢. U~ 'APPBICATIO~ FOR PgR~IT--" for such ~mpoads.) ~ ..... om ~ ~,'s ~ o~a~ Beaver Creel:~-t0 ..... 8. r~a~ Ga nmAsm Beaver Creel -O[OL ' HaraChon .Oil Company 9. w~ ~o. ~--~ 3' ~R~SS OF P. 0. ~ox 2380, Anchorage~ Alaska 99510 4 4. LOCAT;O~ OF W~LL (Report location clearly and In accordance with any State requirements.' 10.~ FIELD AHP POOL~ 8~ also space 17 below.) Wildcat _ At surface ~700~S~ 660~ from NE corner protracted Sec zz. ~e..,~.,a.,~.,o~a~:x~: 33, T7N, R10W, SM Prop., Bottom hole location: 1700'S & su~v~ 725'E from ~ corner Sec. 34 , T7N, R10W, SM (1,385' due E Sec. 34, T7},, %ICW, from surface location) SM . 1~. cou~ Ga Kenai Pemin. I 72-13 Gg 144.8' ~B ].64' ~orougn I Alaska ... 16. Check Appropriate Box To Indicate Nature of Notice, Report, or C)~her Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASINO ] [ FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEquENT REPORT OF: WATER SHUT-OFF REPAIRING WELL FRACTURE TREATMENT ALTERING CASINO SHOOTING OR ACIDIZINO ABANDONMENT* (Other) Weekly Report NOTE: Report results of multipl~ completion on Well ompletion or Reeompletlon Report and Log form.) 17. OESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state ali pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths for all markers and zones perti- nent to this work.) * January 8,.. 1..973 through January 15~ 197,3 .,~ , , Depth - 15,940 T.D., 15,315 P.B.T.D.. Rigged up Halliburton to displace, mud' from. well with diesel. Pressure tested lines to 5000 psig. Circulated down tubing at 4 BPM rate at 4000 psig maximum. Displaced mud with 950 BBLS of 'diesel. 'Rigged up Otis lubricator and pressure tested to 2500 psig. Attempted to. close circulating sleeve in two runs. Unsuccessful. Tubing pressure 2200'psig - casing pressure ' , , 2200 psig. ' . ~ , Ran in hole with sleeve to blank off Otis circulating sleeve, could not set.. Pulled blanking sleeve. Attempted to jar circulating sleeve closed - unsuccessful. R1H with x-nipple blanking plug but could not set. P.O.0.H. found plug filled with weight material. Rigged down Otis. ' . · · Opened well to separator and produced well from 10:30 a.m., 1-10-73 to midnight 1-10-73 in an attempt to clean up circulating sleeve. Shut well in and rigged up Otis. Ran wire brushes on wire lines and brushed circulating' sleeve. P.0.0.H. with brushes, rigged down Otis and resumed producing well to clean up tubing string at 04:00 hours, 1-11-73. Shut well in at 8 a.m.,· 1-11-73, rigged up Otis and closed circulating sleeve. Bled casing pressure at i1 a.m., 1-11-73 and de- termined tubing was not communicating with casing. Opened well to prodUctiou 18. I hereby c~t~ t~at tho foregoing is true and correct SIGNED-"'~' ~ ~ W. E. ROurke TITLE Area Drilling Superintende~ATE 1=24=73 (This space for Federal or State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE *See Instructions on Reverse Side "¢',,'. '.. JAN". 2 6".. ' :,,g / o-'* D"~':'"'"" i,, t l'" C-IL /',NO GAS A[~CHORaG~ January 8~ 1973 throush January 1.5, 1973 (Cont'd.) at 1:30 p.m., 1-11-73. Started unloading well with gas lift at'5:30 p.m. Total production for 24 hours - 1284 BBLS diesel and oil. Continued unloading well to separator with gas lift. Produced 1662 barrels of oil and diesel in. 24 hours. Unloaded well with gas lift to 11 a.m., 1-13-73. Blow down casing and stabilized well. Commenced flow test on well at 2 p.m., 1-13-73. Well produced 1198.5 B.F. in 24 ~.hours, 0.2 percent BS&W - GOR-180 on 3/8" choke T.P.-143 psig, C.P. 320 psig For= ~-~ "NITED STATES S~B~IT I~ T~" "',ICATE. (May 1963) (Other tnstruct~~ on r~ DEPARTIt ....NT OF THE INTERI~ verse side) ,. GEOLOGIC ~ ~ SU DRY NOTICES LS (Do not use this form for proposals to r~t~-~n o~'~-~g baE-]~-~ ~d~t resettle Gsa"APPLICATION FOR ~'~"gr~CL~o~s~ O O ~. ~ ~,,; 3. ADDRESS OF OPERATOR P. O. Box 2380, Anchorage, Alaska 99510 4. LOCATION OF V,'ELL (Report location clearly and in accordance with any State requirements.* Form approved. Budget Bureau No. 42-R1424, ,~. LEASE DESIGNATION AND SERIAL NO. A-208083 6. IF INDIAN, ALLOTTEE. OR TRIBE NAME 7. UNIT AGREEMENT Beaver Creek Unit Beaver Creek:- 94 WELL NO. 10. FIELD AN~) POOL~ OR ~VILDCAT See also space 17 below.) At surface 1700'S, 660'W from NE corner protracted Sec. 33 T7N, RIOW, SM Prop., Bottom hole location' 1700'S & 725'E from NW corner Sec. 34, T7N, RIOW, SM (1,385' due E from ~4. PER~I~u~face 1 ocati on ) ~5. E,.-V,T,O~S (Show whether D~, RT, ~R, e~.) 72--13 GR 144.8' KB 164' Wildcat 11. SEC., T., a,, M,, OR BLK. AND SURVEY OR AREA ' ,. Sec.. 34, T7N; RIOW, 12. COUNTY OR PARISH] :,1:3. STATE Kenai Pen'in :' i'~:'~ 'BoY'ouch ' '/ ~lA'~a_~ka 16. , , Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSE(~UE~T REPORT oF~ WATER SHUT-OFF [-~ ', "' RE~AIRtNO' WlmLL J-~ (Other) Weekly Reoort ,, ' ~,; :::, J J {~o~: gepo~t ~e~lts of"~ltfple eogofl~¥~'iwell ' ~ompletton or R~eOmpleflon Report and ~og"fo~m,,) 17. DESCRIBE I'ROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated, d:a/e .of starting any proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths for all marker~ o~d zones perti- J. anuary 1, 1973. through January 8, 1973 ENTI :., ,.:,; . Depth - 15,940 T.D., 15,315 P.B.T.D. Ran in hole with bi:t conditioned :mUd ::!whiile W.O.C. Drilled cement retainer at 14,51.5' and good cement to...14'"~:,578:-:.', :~:Pul:]''' ed: out of hole and pressure tested ~qaeezed perforations 14,535'. tO-:.l 4,565' "-"? '.:.. an.d casing to 2500 psig, O.K. Ran Halliburton DST tools to dry test squeeze~..per- forations. Ran 5,000' of water cushion, set packer at 141];443"?, Opehed !~t06}l at 2'10 A.M., January 3, 1973, had very weak blow. Closed tool'.after one :!'hour.~ flow period. Shut-in test for two hours. Reversed out 56 barrels Of water and'.one barrel rat hole mud. I.H.M.P. 8833 F.H.M.P. 8898 Pull Ran in hole with 5-7/8" bi to bridge plug at 15,315'. laying down drill pipe. ed out of hole. Pressures from te's~:t:'":ane as fo. l i'°Ws· F.C.I.P. 8931 (2 hours) ~.F~'P. :2157 (.l'.'hO~ur) F.F.P. '2190 - ~ _. t and drilled bridge plug at 14,600'.- Cleaned-.:.°,ut Circulated to condition mud and pulled oat Of ~hOle Rigged up Dresser-Atlas lubricator and pressure tested to 2500 psig.;;. Dre§ser- Atlas ran gauge ring and junk basket to 15,315'. Ran Otis Pe~mad'ri'll packelr on wire line and set at 14,615'. Ran and set second Otis permad.ril.]-packer ' at 14,469'. Rigged up to run tubing. Changed pipe rams in B".O'~P.s.: ·'" .. 18. I hereby ce~,~,t~t t_h~~d. , . correct ' ' SIGNED ' WJ.'J;. RourKe TITLE Area Drilling Supt (This space for Federal or State office use)'. APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE *See Instructions on Reverse Side DtViSJOI"~ CF OiL. AND ANCHORAGE January l, 1973 through January 8, 1973 (Cont'd.) Ran production tubing string as follows: Guideshoe 3-1/4" x 20' Otis seal assembly, 4 joints, 2-7/8" EUE, 8R tubing (125.01'), 4" x 20' Otis seal assembly with locator sub.,, x-nipple, 1 joint 3-1/2", 9.2# buttress tubing, circulating sleeve set at 1~4,432', 367 joints, 3-1/2", 9.2# buttress tubing, 129 joints, 3-1/2", 9.2# P-lO5 seal lock tubing, 3-1/2" x 6' P-lO5 tubing pup, with gas lift valves at: 10,385', 9,981', 9,577', 9,205', 8,800', 8,395', 7,990', 7,617', 7,212', 6,804', 6,213', 5,408', 4,118', and 3,215'; ball valve at 197' Landed seal assembly locator l-l/2" above top packer. PresSure tested tubing Jouplings while running to 8,000 psig externally, and gas lift mandrel, s to 5,000 psig internally, O.K. Installed O.C.T. back pressure valve in tubing head. Rigged down B.O.P.s and installed O..C.T. 5,000 psig W.P. x-tree and pressure tested to 5,000 psig. Mud Weight. - ll.7 ppg. B.O.P.s - Checked for operation. Form REV. 9-30-6 9 CON iDENTIAL J. $~bmtt "Intentions" in Trt ica { STATE OF A~KA · · O[[ AND GAS CONSERVATION COMM[~S~ .................................. 5UND~Y NOTiC'E$ ~ND ~EPO~T5 O~ WE~ (~O ~ot use thi~ ~otm ~ot proposals ~ drJH ot to Use "A~CA'FZO~ FO~ PE~Fr~" '~or ~uch 'p~o~o~al~.) A-028083 1. 7,IF INDIA-N,ALLOTTEE OR TRIBE NA.~%LE OIL ~ GAS ~'~ WELL WELL OTHER 2. NAME Of' OPERATOR Marathon Oil Comuanv 3. ADDRESS OF OPERATOR P. 0. Box 2380, Anchorage, Alaska 99510 4. LOCA'£1ON OF WELL ^~s,,,'~ce 1700'S, 660'Wfrom NE corner protracted Sec. 33, T7N, RIOW, SM. Proposed Bottom Hole Location 1700'S, 725'E from NW corner, Sec. 34, T7N, R1OW, SM (1,385' due E from surface location) 8. UNIT, FARN[ OR LEASE NA~IE Beaver Creek Uni~; 9. WI/iLL NO, 10. FLELD AND POOL, OR WILDCAT Wi I dcat 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 13. ELEVATIONS (Show whether DF, RT, GR, etc. 12. PERiVIIT NO. GR - 144.8 KB 164' 72-13 14. Check Appropriate Box To ind:i,cate Nature o~ N~tice, Re ~ort, or Other Data NOTICE OF INTENTION TO | TEST WATER 8HUT-OFF ] [ PULL OR ALTER CASINO FRACTURE TREAT ~ MULTIPLE COMPI,ETE SIIOOT OR ACIDIZE ABANDON* · REPAIR WELL CHANOE PLAN8 ,Other) Long Term Production Test 8UBSEQUENT REPORT OF: REPAIRING WELL FRACTURE TREATMENT ~ ALTERING CASING SHOOTING OR ACIDIZINO ~ ~ ABANDONME,~T~ (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form,) I5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. It is necessary to place Beaver Creek #4 on an extended production test. The recently conducted drill stem test revealed the possibility that the producing interval may be' of limited size and that recoverable oil may not be of sufficient quantities to justify investment to drill additional wells. A long term test with observation of production and pressure performance is required 'to obtain data to determine the volume of recoverable reserves that might be ex- pected from thi's field. In order to produce the well at rates adequate to obtain sufficient reservoir performance data, it will be necessary to utilize gas lift gas to lift the oil. We request permission to produce and test this well until about May 1, 1973. We estimate that the maximum oil rate will be from 2,500 to 3,000 barrels of oil per day. This production will be sold. The estimated volume of gas lift gas required to lift this well will be approximately 1.3 million cubic feet per day. The estimated volume of solution gas to be produced with the oil from this zone will be approximately 800 thousand cubic feet per day. Lift gas and solution gas will be flared. The only source of gas for gas lift purposes is from the gas wells now. completed in the Beaver Creek Field. We plan to produce Beaver Creek #1-A to obtain the necessary gas for fuel and lift. The duration of the Beaver Creek #4 production test is estimated at 100 days, and therefore the total volume of lift gas required ~_m_u~J C.~.P~_~,I.b tc ~ftmat~H fm h~ 1Ra mill|an at,b|a feat. 16. I h~re~ ~er fly tha~6regbihg'i~ t~ ~ ~d/~6e~ ............... ~wen W~ (This space for State office use)z, CONDITIONS OF APPROVAL, IF TITLE Division Drilling Supt. ~a~. 1~-73 ....... .2___-- ~:,-'~-RS !1 T~I! f~ ll~_ ..... ' TITLE ~ JAN O ' See instructions On Reverse ~ISION OF C)|t AI~ GA~ App,0ved.. Rwtt~ ~[~y' Form 9-331 ' UNITED STATES SUB~T ~?' ?RIPLXCAT~,. ~orm approved. Budget Bureau No. ~2-R14~ (Other lnj ~tions on r~ 5. LEASE DESIGNATION A~ SERIAL NO (~ ~,~3) DEP , ,'MENT Of THE INTERIOR verse~ide)' GEOLOGICAL SURVEY A-298~83m~/~i/? - SUNDRY NOTICES AND REPORTS ON WELLS ~'.. "'"~~~~~ ~. Use "APPLICATION FOR PERMIT--" for suc~ pm~o~s.) ~ UNIT ~ --~ Marathon 0il Company R6~'v~"rs P. O. Box 2380 - Anchorage, Alaska 99510 ~ .... ~. ~oe,tiom o~ w~ (~epott ioeatlo: eleet]~ ~8 1~ ~eeot~aee wtt~ ~ State ~e~elme~e:t~.· 10. ~[~ D -~ -2oo~ See ~1~o ~p~ee 17 below.) - ~; ~u,~e 1700'S, 660'W from NE corner protracted Sec.33 [7N, RIOW, SM prop., bottom hole location' 1700'S, 725'E from NW :orner, Sec 34, T7N, RIOW, SM (1,385' due E from surface location 14. PERMIT N0. 15. E~VATIONS (Show whether DF, RT, ~R, e~.} .12. C~;.~X~M~ 13~STATE 72-13 GR-144 8 KB 164' 16. Check Appropriate Box To Indicate Nature oE Notice, Report, or Other Data NOTICE 01~ INTENTION TO: FRACTURE TREAT ,~IULTIPLE COMPI,ETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) . SUBSEQUENT REPORT OF: SHOOTING OR ACIDIZING J J' ABANDON,~IENT* (Other)Supplement~o Weekly Report NOTE: Report results of multiple completion on Well ompletion or Recompletion Report and Log form.) 17. DESCRInE I'ROPOSED OR COMPLETED OPERATIONS (Clearly state all pertine,~t details, and give pertinent dates, including estimated date of starting an proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths.for all markers and zones pert nen~ to this work.) * , Supplement to Weekly Reports' December 11, 1972 through December 1'8, 1972 , December 18, 1972 through December 25,' 1972 .., The GOR for DST #4 oil was approximately 300 SCF per bbl. Exact determination cannot be made due to the lack of a PV'I' analysis on the crude. This test was from the interval 15,190~!~-200' and 15,155'-175' on December 17, 1972. , ... ,~, A similar GOR was observed in crude oil from the interval 15,060'-0'72..~.uand.: ''''; 15,082'-100' during a flow test after acid treatment on ~ecember 24, 1972 ANCHORAG~ .. 18. I hereby certify that the foregoing is true and correct DATE Owen W. AKins Div. Drilling Supt. (This space for Federal or State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: ,, TITLE DATE 1/3/73 *See Instructions on Reverse Side (Other instruction', on r~ ~. LEASE Budget Bur r AN~'~~DESIONATIO ~a~ ~,O. t~ ~' ~ '~ DEPARTM~,~T OF THE INTERIOR ~ ~ GEOLOGICAL SURVEY A- g 08 08 ~ ~ C. ~N~ NDRY NOTICES AND REPORTS ON WELLS (Do ,at use t~ts ~o~m fo~ p~opos~ls to 8~iH o? to deepea o~ plu~ bAc~ to A diVe,cae ~ese~olm J ~ E~ o,, ~ ~,~ ~ o~ Beaver Cr ~~ ~ N~M~ o~ o~*~o~ ~. ~,~ o~ ~,~ ,. ~j 10EOL J~" ~~O~ 0il Comp~ ... 3e~ve~ C~~'~OL J~ ~. 0. 3ox g380, A~cAo~ge, Al~sk~ 99510 4 ~J REV 4. nOCATIO~ O~ WBL~ (Report location clearly and in accordance with any State requirements.' 10. Fi'EL. AND POOL, See also space 17 below.) ~ " SE~ xt~u~,~ 1700~S, 660~ ~rom NE corner protracted ~ildcat ~. Sec. 55, TTN, A10W, S~ Prop., Bottom hole location' n.~,~..T..~..~..o,~~:~,~o~ 1700'S ~ 725~E from N~ corner Sec. 54, TTN, A10W, S~ Sec. 54, ~ (1,585' due E ~rom surface location) .. SM 14. P~n~ ~o. I 15. BLBVAT~ON3 (Show whether DP, ~T, Gg:'e~.) 12. eOUN~X og PA~SH[ 1~. 72 15] GA 144.8~ KB 164~ Kena~ Pen~A. - ~orougn/ Alaska 16. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPI,ETE SIt00T OR ACIDIZE ABANDON* REPAIR WELl, CHANGE PLANS (Other) ' SUBSEQUENT REPORT OB': WATER SHUT-OFF J 'J~--~ REPAIRING WELL FRACTURE TREATMENT [ [ ALTERING CASING SHOOTING OR ACIDIZINO [ [ ABANDONMENTs (Other) Weekly~eport NOT~: Report 'results of multiple completion on Well ompletion or Recompletion Report and Log'form.) 17. DESCaln~; I'ROPOSED OR COMPLETED OPERATIONS (Clearly state all pertine'nt details, and give pertinent dates, including estimated date of starting any p'ropo,ed work. If well is direetionally drilled, give subsurface locations and measured and true vertical depths for all markers and ~ones perti- fient to this work.) * December 25, 1972 through January 1, 1975 Depth - 15,940' T.D., 15,315' P.B.T.D. Started up after Christmas holiday at noon December 26, 1972. Circulated on top of bridge plug, pulled out of hole with bridge plug~.ianHalliburton "N" quick 7" bridge plug and set at 14,629', tested to 2000#, O.K. Rigged up and Perforated with 4" casing guns 14,535' to 14,565 Halliburton 7" DST tools and set at 14,478' with 1700 psi gas cushion for DST #6. Opened tool at pressure tested lubricator. four shots per foot. Ran 2300' water cushion and 12'57 p.m., December 28, 1922, for 1/2 hour initial flow, closed tool for 1-1/2 hours for initial buildup. Opened tool for 8 hour final flow and closed for 16 hours final buildup. Had slight blow throughout flow period. Reversed out at 3 p.m. December 29, 1972, recovered 17 bbl of water cushion, trace of mud and 63 bbl of formation Water. Pressures from DST #6 charts are as follows: I.H.M.P. 8866# F.F..P. 2941# (8 hours) I.F.P. 3268# (1/2 hour) F.C.I.P. 9095# (16 hours) I.C.I.P. 8964# (1-1/2 hour) F.H.M.P. 8866# Pulled DST tools and ran back in hole, retrieved bridge plug and condi- tioned, mud. Spotted 20 bbl diesel across perforations from 14,535' to (See attached sheet) 18. I hereby certify that the foregoing is true and correct (This space for Federal or State office use) APPROVED BY CONDITIONS OF APPROYAL, IF ANY: TITLE *See Instructions on Reverse Side DIVISION C,/; OIL AND GM ANCHORAGE December 25, 1972 through January 1, 1973 Depth - Continued 14,565'. Set Baker model "K" bridge p].ug at 14,600' and Baker model "K" cement retainer at 14,515'. Broke down perforations with 15 bbl diesel at 4,500 psi. Mixed 150 sacks class "G" cement with 1% CFR-2 and .7% HR-?, pumped 10 bbl diesel ahead and 10 bbl diesel behind cement. Displaced cement at 3600 psi. Shut down for 3 minute stages and pressure increased to 4500 psi, 5000 psi and final pumping pressure. of 5500 psi. Pulled out of retainer and could not reverse out. Pulled out and found 1023' of cement in 3-1/2" drill pipe. Total cement dis- placed into formation was 115 sacks. Waiting on cement. Mud Weight - 11.6# per gal. B.O.P.s - Checked for operation. oF Form 9-431 (May 1963) }~ud~e.', .....:. ,c., ~ {~/',~ (Other lnstrue?,m~ on re--~T ........................... ~ .......... ~ DEPAR "ENT OF THE INTERIOR ,-~.,,~) { ~:~,:,,E~,,N,,:,O~],,~[~ ~ L~OLOGICAL SURVEY A-208083 .... .'-~"" ~ iN,G-- ~ SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this fnrra for prnpo,~nls to (]rill or to deepen or plug back to a different reservoir. Use "APPI,ICATION FOR PERMIT--" for such proposes.) WELL WELL OTHER 2. NAME OF OPERATOR Marathon Oil Company ADDRESS OF 0PI~RATOR P. O. Box 2380, Anchorage, Alaska 99510 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) At surface 1700'S, 660'W from NE corner protracted Sec. 33, T7N, R10W, SM Prop., Bottom Hole Location: !700'S & 725'E from NW corner Sec. 34, T7N, R10W, SM (1,385' due E from surface location) 6. IF INDIAN. ALL ., ,?. UNiT AGREt~,ME2 · Beaver Cr, 8. FAP,,%£ OR LEAS3 / --i _3- IL! "BeaVer Cr{ · 4. "' SURVEY OR Sec. 34, T7N',~ 'RiOW,' S~ ·, 14. PERMIT NO. j 15. ELEVATIONS (Show whether DF, RT. OR, etC.) /~' C°U~TY~'°g PAnlSU t 13' STATml~ena z 72-13 GR-144.8 ' KB 1(>4 ' Borough Alaska Check Appropriate Box To Indicate Nature o[ Notice, Report, or Other Data . NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ PULL 01~ ALTER CASINO ,MULTIPLE COMPI,ETE ABANDON* CHANGE PLANS FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) - SUBSEQUENT REPORT OF: WATER SHUT-OFF ' i: REI'AIRINO' ~VI~I,L FRACTURE TREAT~ENT ALTERING CA~tNG (Other) (NOWE: Report resnlts o~ multtple eompletlon.on Well Completion or Recomplet[on i~eport and 'Lo~ form.) 17, DESCRIBE ,I'I'.OPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, IBcl'udi'ng estimated date of starting any ])roposed work, If well is dircctionally drilled, give subsurface loeatiuns and measured and true vertical depths'for ;}11 markers and zones perti- nent to this work.) * . ,. December 1.8, 1972 through December 25, 1972 ~U[~IT-JuENTJ .Dept~h- 15,940' T.D., 15,315' P.B.T.D. Continued final buildup On. DST #4 to. ]."p.m., 12-18-72. Opened tool and reversed out 155 bbl oil. Released packer at 3:45 p.m. Circ'~'lated to condition gas cut mud, ran in hole with test tool and tagged bridge plug at 15,3].5'. Pulled out of hole, layed down DST tools.. Tested BOP§, O.K. Ran Haliburton 7" retrievable bridge plug, set at 15,130' and pressure tested, O.K. Displaced drill pipe with diesel and set Haliburton RTTS tool at 14,994'. Rigged up lubricator and attempted to perforate. Perforating guns would not pass· through RTTS tool. Reversed out diesel., released packer and pulled out of.:hole. Rigged up and tested lubricator, perforated with casing gun as follows: 15,060' to 15,072' (12') and 15,082' to 15,100' (18') with 4 shots per .foot. Picked up Haliburton 7" DST tools, ran in hole and set packer..at ].5,005'~ Ran 2300' water cushion and 1700 psi gas cushion. Opened tool at 2:].2 a.m., .12-21-72, bled off gas cushion, shut tool in at 3:12 a.m., after 1 hour initial flow.. Opened tool at 5:12 a.m., 12-21-72 after 2 hour initial buildup. Very weak blow slowly increasing through test. Closed tool for final shut in at 2:20 p.m.~, 12-21-72. Reversed out at 4:40 a.m., ].2-22-72, recovered 13 bbl water cushion, 44 bbl of gas and water cut mud and 22 bbl of clean oil. Circulated for 1/2 hour and pulled out of hole. Pressures from DST #5 charts are listed below: (See attachment) 18. I hereby c.er$ffy that the~4qregoing is true and correct '...: t ?-.¢.' "'"" TITLE Div. Drilling Supt. DATE'·_i'2127-72 (This space for Federal or State office use) APPRO~tED, BY CONDITIONS OF APPROVAL, IF ~NY :' *See Jnsiructio~m.oaJ~.ev~me Side uw;~{C;.N C'~ OIL AND GAS ANCHO~AG~ December 18, 1972 throush December 25~ 1972 (Cont'd.) · I.H.M.P. 9063~~ F.F.P. I.F.P. 1392# (1 hour) F.C.I.P. I.C.I.P. 7565# (2 hours) F.H.M.P. 1724# (9 hours) 7627# (14 hours) 9108# Ran in hole with bridge plug retrieving tool and conditioned mud. Phlled out of hole. Picked up Haliburton RT%S packer with 90' of 2-7/8" tubing for tail pipe, ran in hole. Pumped 20 bbl of diesel, 2,000 gallons of mud 'cleanout acid, displaced with diesel, spotted 10 bbl of acid across perforations, shut down for 10 minutes. Pumped 20 bbl in 4 bbl stages 5 minutes apart. Set RTTS packer at 15,012' with tail pipe at 15,111'. PresSured up to 4500 psi. Bled off and repressured to 3800 psi, formation did not break down. Opened ~ell. to flow on 1/4" choke at 2 aom., 12--24-72. Flowing pressure 550 psi. From 2 a.m. to 6 a.m. flowed 206 bbl diesel, pressure increased to 675 psi. At 6 a.m. started flowing acid with pressure increasing to 1000 psi. At 7:10 a.m. put well on test through separator to test tank with 1000 psi flowing pressure. Well flowed 387 bbl oil from 7:10 a.m. to 11:30 a.m., 12-24-72. (Reversed out 227 bbl oil and circulated for 1 hour to condition mud.) Ran in hole and retrieved bridge plug at 15,128' pulled up and set bridge at 14,625'. Pressure tested, O.K. Closed well in and shut down for Christmas. Mud Weight - 11.4# per gal. B.O.P.s - Tested ttydrill to 1500# and pipe rams to 4000#, test O.K. DIViSiON G F Oil, 'AND ANCHORAGE Form 9-331 (May 1963) i UNITED STATES su~IT Ia' ~PLICAT~.' (Other instl( .ons on re- DEPA i MENT OF THE INTERIOR verse side) I GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) Form apl :o,ze A-208083 Beaver Cr4 . . Beaver ~o. FIELD AN~ PC ~ Wi I dcat. Sec. 34, ~/M, SM a~ Pen~n. Borough I Alaska 1. OiL WELL WELL OTHER 2. NAME OF OPERATOR Marathon Oil Company 3. ADD~ESS OF OPERATOR P. O. Box 2380, Anchorage, Alaska 99510 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* SeeAt surfacealS° space 17 below.) 1700' S, 660 'W from NE corner protracted Sec. 33 T7N, RIOW, SM Prop., Bottom hole location: 1700'S & 725'E from NW corner Sec. 34, T7N, RIOW SM (1,385' due E from surface loc.) 14. PERMIT NO. 72-13 15. ELEVATIONS (Show whether DF, aT, GR, etc.) GR 144.8' KB 164' 16. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF I I PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: '' FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZiNG ABANDoNMI~i'Uk* (Other) Weekly I NoTE: Report results of multi'pie completion on. Well ompletion or Recompletion Report and Log form.) 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths for all markers and zones perti- nent to this work.) * December 11, 1972, through December 18, 1972----''''----''--'--UUNklUEN/IAL.', . Depth - 15,940' T.D., 15,315' P.B.T.D. Set Baker Model "N" bridge plug at 15,530', tested to 2,000#, OK. Ran dump bailer with 1-1/2 sacks of class "G" cement with 1% D-31. Perforated with Dresser Atlas Jumbo Jets, 4 shots per foot f.rom 15,446'i to 15,461' - 15,416' to 15,431' - 15,382' to 15,397' - 15,361' to 15,376' (60'.tOtal). Ran Halliburton 7" D.S.T. tools with 3,500' of water cushion and 1,475# of gas' cushion. Set packer at 15,313'. Top perforation at 15,361'. Opened tool 'at 8'15 p..m.~ 12-12-72 initial flow one hour, had 25# pressure increase. Bled off gas cushion. Closed tool for two hours for initial buildup. Opened tool for final flow peri. od at 11'15 p.m. 12-12-72 tool open for 10 hours, closed tool at 9:22 a.m. 12-13-72, had weak blow increasing from 4-1/2" to 5" then decreasing slowly throughout final flow period. Closed tool for final buildup for 15 hours. Completed D.S.T. No. 3 at 12:2.2 'a.m., 12-13-72. Reversed out 55 bbls. of total fluid including 26 bbls. of water.'cU'shion with show of oil and gas-cut, mud, 29 bbls. total formation fluid, 15. bbls. of:oil, and 14 bbls. of oil and gas-cut mud. Pulled out of hole. Pressures from D'S;IT. charts are listed below: '" .::~!., I.H.M.P. 9186# F.F.P. 2105# (10 hours). I.F.P. 1771# (1 hour) F.C.I.P. 7398# (15 hours) I.C.I.P. 7382# (2 hours) F.H.M.P. 9190# 18. I hereby certify that the foregoing is'true and correct t~'l~ ? ..,'.i ...~t~ .~'~ ...... :,. "" ~ ~ ~' '~-- ~r'~' ' 'L'' I ~'--~:' f''' '~ '~''' ~ '''~ Division Drilling Supt. ' 12-19-72 0wen w. ^k i n's (This space for Federal or State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE *See Instructions on Reverse Side December 11, 1972, through December 18, 1972 (Continued) Set 7" Model "N" bridge plug at 15,315', tested to 2,O00#, OK. Setting of bridge plug was verbally approved by Messrs. W. C. Wunnicke and and Rodney Smith of U.S.G.S. Perforated with Dresser Atlas Jumbo dets, 4 shots per foot from 15,190' to 15,200' and 15,155' to 15,175'. Ran Halliburton 7" D.S.T. tools with 2,300' of water cushion and 1,7OO# of gas cushion. Set packer at 15,O96'. Opened tool at 2:55 p.m. 12-16-72 initial flow one hour, had pressure increase of approximately 50#. Began bleeding off gas cushion at 3:09 p.m., pressure bled to 20 psi at 3:55 p.m., when tool was closed for initial buildup. Bled gas off to 2 psi during 2-hour initial buildup. Opened tool at 5:55 p.m. for final flow period. Pressure increased to 50 psi with fluid to surface at 6:41 p.m. with pressure increase to 500 psi. Recovered water cushion and oil and gas-cut mud. Surface flowing pressure increased to 1,100 psi on 1/4" choke. Closed weli in at surface at 9:13 p.m. to rig up separator. Opened tool at 2:57 a.m., 12-17-72 and. gas vent froze uP. Closed well in at 3:04 a.m. Opened at 3:26 a.m. and oil dump line froze up. Closed well in at 3:45 a.m. Opened well at 4:30 a.m. flowing through separator at 1,100 psi on 1/4" choke holding 95# on gas separator. At 7:00' a.m. had flowing rate of approximately 40 bbls./hour, APl gravity 34.5 at 64° with 1/2" bottom hole choke in D.S.T. tool. Flowed well on 1/4" choke until 8:00 a.m. at estimated rate of 40 bbls./hour with drill pipe pressure of 1,088#. Changed choke to 1/2" at 8:00 a.m. and flowed well at rate of 65 bbls./hour with a flowing pressure of 364 psi. Changed choke to 3/8" at 12:C0 noon and flowed well at an approximate rate of 62+ bbls./hour and flowing pressure of 395 psi until 10:00 p.m. Closed well in at 10:00 p.m. for final build-up. Mud Weight - 11.2# to ll.4# per gallon. B.O.P.s - Checked for operation. ror~9~3, ~ .... NITED STATES . , ~ ,. (Other tnstrc~ ' on r~~ ~ ~) DEPAR ~., .qT OF IH~ INTERIOR ,,o~a~) .~ (Do not . Use "'XPPL1EA~ioN ' I(~{~nf -' ~:~ ~ ~ a ~ ~.~ ~ ~ ~:~;~)..I I WELL _ 2. NAME OF OPERATOR Marathon 0il Company ADDRE88 OF OPERATOR P. O. Box 2380, Anchorage, A_laska 99510 4. LOCATION OF W£LL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) Atsurfaee 1700'S, 660'W front NE Corner protracted Sec. 33, TTN, R10W, SbI Prop., Bottom hole location' 1700'S & 725'E from NW corner Sec. 34, T7N, R10W, SM (1,385' due E from surface loc.) 14. PERMIT NO. 15. ELEVATIONS (Show whether DF, RT. Ca, et~) 72-13 GR 144.8' 1,73 164' Form apDroved. Budget l;urr':tu No. -12 .-R14 24 . A-208083 ~ , Beaver Creek Unit Beaver Creek 9. WE[,I,, No. 4 10. FIELD AND POOI,~ OR WILDCAT ¥ildcat !1. SEC., T., R., ?A., 0.~I BIoE~. AND SURVEY 0!% Sec. 34,- .T7N, RI0W, S~.I - 12. COUNTY OR ?Ant$tt~ 13. STATE Ke},.a z Boro_ugh_, :: A1 ~ 16. FRACTURE TREAT StlOOT OR ACIDIZE REPAIR WELL (Other) Check Appropriate Box To Indicate Nature of Notice, Rcporb or Other Data NOTICE O~ INTENTION TO: TEST WATER SHUT'OFF ~ PULL OR ALTER CASING · %[ULTIPLE COMPI,ETE ABANDON* CIIANGE PLANS SUBSEQUENT }%Et'ORT OF: WATER SHUT-OFF ~ .. RETdAIRINg WELL FRACTURE TREATMENT . -. ALTEiqlN(] CASt. NG SHOOTING OR ACIDIZING ABANDONMENT~ (Other> We e k 1 NOTE ' Revort results of multt~>'le compietlou on Well ompi~ti~n-or Recom~letion tlek;or~ and Lug form.) 17. DESCRIBE I,BOPOSEr) OR CO.',IPI,ETED OPERATION8 (Clearly state all perti~mnt details, and give pertinent date.% fnctudh'~,- estimated date of starting any proposed work. If well is direetionMly drillc~, give, subs~ace lomx~ions and measured and true vertical depths for ail markers and zones perti- nen,. tiffs work.)' CO:NFI DENTIAL - December 4, 1972, through.December 11, 1972 ' , . Dg~ - 15,940~ T.D. 15,S75' P B~'~'.D. - ... ~~lated through bit at 15,~4~ running mud through cen'tri~uge: lowering mud weight from 15.1fi per gal. to 1]...1~ per ga. 1. ., Set Baker model "N" bridge plug a.t 15,750/ tested to 2000#, 0..K. Ran dump bailer with 1-1/2 sacks of cl. ass "G" cement with 1%.' Perforated with Dresser Atlas Jumbo Jets, 4 shots per foot from 15,560' to 15,580' - 15,600' to 15,610' - 15,640.' to 15~660' - - 15,685' to 15,695 Ran Haliburton 7" D.S.T. tools with 3500' water cushion and 1700# of gas cushion Set packer at 15,510'..'- Opened tool at 5'55 p.m. 12/8/72 initial flow one hour, had :weak' constant blow after bleeding off 1700# of gas cushion, closed tool for two hours for initial buildup. Opened tool for final flow . period at 8'55 p.m. 12/8/72 tool open for 15 hours, Closed tool at 11'55 am. 12/9/72 had slow constant blow throughout final flow period. Closed tool for final buildup for 25 hours. Completed D.S.T. No. 2 at 12'25 a.m. 12/10/72. Reversed out 26 bbls of water cushion and 56 bbls of formation water with some oil and gas cut' mud. Pulled out of hole Pressures from D.S.T. charts are listed . . : below. (Se4 'attached' Sheet) Drilling Supt. ~AT~..12:12-72 (Thil, space for Federal or State office use) TITLE Div. 18. APPROVED BY CONDITIONS OF APPROVAL; IF ANY: correct Instructions on Reverse $ia¢ O~C :} 5 ' ''''~ ' DiVtSIC:N CF OIL AND ANCHORAG~ December 4, 1972 Continued through December 11, 1972 I.H.M.P. 9226# I.F.P. 1905# I.C.I.P. 7637# F.F.P. 3092# F.C.I.P. 7663# F.H.M.P. 9160# Formation- Sa~d, Mud Weight - 11.1# B.O.P.s - Checked sil. tstone, and conglomerates to 11.2# per gal. 'for operation. Aj,,IcitC)RAO~ ~'o~., 9-3~ N]TED STATES (~'~Y ~) DEPA ,, MENTGEoLOGiCALOF THEsuRvEyiNTER]OR SUND~Y NOTICES AND REPORTS ON WELL~"-h'~'' Marathon Oil Company 3. ADDR~S~ OF OPERATOR P. 0. Box 2380, Anchorage, Alaska 995~0 '-~~. ~. ~;~ON O~ w~ (Report location elearl~ and~ accordance wlt~ 8n7 8tare require See also space 17 below.) ~ILE~ Sec. 33, T7N, 1700'S & 725'E SM [!,385' due 14. PERMIT NO. 72-13 0 S, 660 W from NE corne~ R10W, SM Prop., Bottom hole location' from NW corner Sec. 34, T7N, R10W, E f rxlrLau ~f~c. e 1 o c. ] 15. ELEVATIONS (Show whether o~, RT. OR, et~.) GR 144.R' KB 164' 16. Form approved. Budget Bureau No. 42-R1424. /5. LEASE DESIONATION AND SERIAL NO. A-208083 6. IF INDIAN, ALLOTTEE OR TRIBE NAME 7. UNIT AOREEMENT NA-','IE Beaver Creek Unit 8. FARM OR LEASE NACRE Beaver Creek 9. WELL NO. 4 I0. FIELD AND POOL~ OR WILDCAT Wildcat 11. SEC., T., R., ~., OR BLK. AND SURVEY OR AREA Sec. 34, T7N, RI0W, SM , 12. COUNTY 0E PARISH[ 13. STATE Ke~ai Penir~. ~orougn./ Alaska C~eck Appropriafe Box To Indicafe Noture of Notice, Reporb or Other NOTICE OF INTENTION TO: TEST WATER SHUT-OFF I I PULL OR ALTER CASING FRACTURE TREAT ~ MULTIPLE COMPLETE ' SHOOT 0i% ACIDIZE ABANDON* " REPAIR WELL CHANGE PLANS (Other) Plug back deptli 1S, 740' SUBSEQUENT REPORT OF: WATER SHUT-0F~' REPAIRING WELL FRACTURE TREATMENT ' ALTERING CASING SHOOTING OR ACIDIZING . ABANDONMENT* (Other) ~ (NOT~: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 17. ~)~':SCR[BE ZmOPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionaily drilled, give subsurface locations and measured and true vertical depths for all markers and ~;ones perti- nent to this work.) * December 8~. 1972 " , , , Set 7" 3aker model "N" bridge plug at 15,750' tested bridge plug with 2000#, test O.K. Ran dump bailer with 1-1/2 .sacks of class "G" cement with 1 percent D-31 (filled 10' in 7" lines)"., Mr. Rodney Smith gave verbal approval for above plug back. . ,, ? .,~ DEC 'i 1 197P DIVI$1GN G F OIL AND GAS ANCHORAGE 18. i hereby cer,tify that the ~oregoing is true and correct e~ ........... ~-._e..a_ _~=.=_~-n.-a_ (Thio apace for Feder~ or Smte o~ce use) APPROVED DY CONDITIONS OF APPROVAL, l]~ ANY: · ITLE Div. Drilling Supt DAW~ 12 - 8 - 72 TITLE DATE *See I.structior~s on Rever~e Side GAS FROM BEAVER CREEl< WELL*~I-A BEAVER CREEK WE L L"~ 4. SEPARATOR tHEATER LIQUID PIT TANK BEAVER. CREEK WELL ,-~ IA CHOKE TANK _KNOCK GAS CHOKE GLYCOl FLARE HEATER GAS TO BE AVER CREEK WELL Form 9-331 (May 1963) ~l xIITED STATES sv~MIT Ix ~ (Other instrl~Ii DEPAR'~ .r_ZNT OF THE iNTERIOR verse side) ~[ GEOLOGICAL SURVEY LICATE* aS on re- SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) l, OIL []WeLLG*S [--I1 OTHER Wildcat WELL 2. NAME OF OPERATOR Marathon Oil Company ADDRESS OF OPERATOR P. O. Box 2380, Anchorage, Alaska 99510 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) At surface 1700'S, 660'k~ from NE corner protracted Sec. 33, T7N, RIOW, Sbt Prop., bottom hole location: 1700'S & 725'E from NW Corner Sec. 34, T7N, RIOW, SM(1,385' due E from surf. loc.) 14. PERMIT NO. 72-13 15, ELEVATIONS (Show whether DF, RT, dR, et~.) GR 144.8' KB 164' For,m appro~ Budget Bur~au~..~ .47- 5. LEASE A-20808 I AGREEMEN'~ Server ~ree 8. FARM OR [~1. LEASE Beaver Cre ~ ldcat 11. ~., ~., ~., ~., ' Sec. ~,°~ SM aena} ren ln. I Borouqh I Alaska 16. Check Appropriate Box To Indicate Natore of Notice, Report, or Other '.¢OTICE OF INTENTION TO: TEST WATER SHUT-OFF II PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CIIANGE PLANS I (Other) SUBSEQUENT.. REPORT OF: WATER SHUT-OFF ' REPAIRIN0 ~VELL FRACTURE TREATMENT ALTERING. CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) Weekly. Report ' (NOTE: Report results of multiple completion on Well Completion or Rec0mpletion Report and Log form.) 17. OESCRIBE Vn0VOSeO OR COMPLETED OPERATIONS (Clearly state all pertinent details, and' give pertinent'dates, including estimated da{e of starting any proposed work. If well is dimction~ly drill~, give subsurface laotians and measured and true ve=tical.dePths'for all markers and ~ones patti- November 27, 1972, through December 4, 1972 .. , ' I ' , ~- 15,940' P.B.T.D. 15,875'. Ran 5-7/8" bit and 7" casing,..~scraper, and cleaned out 7'l liner to 15,875'. Closed BOP and tested 7"~line'P' wi. th 2260 PSI for 30 minutes. Tested O.K. Ran Dresser Atlas Gamma Ray clement Bond 'Log, with collar locator from 15,875' to 4,500'. Ran Halliburton 9-5/8" Drillstem Test Tool and tested 7" liner lap. Set packer at 12,167' Took 35-m.inute open period, and 1 hour shut-in period. Liner lap test:-was dry. Perforated 7" liner with.Dresser Atlas 4" carrier gun from 15,795'. to'15,855' with 4 jetshots per foot. Ran DST #1 of perforated interval 15,795'-15,855'. 5/8" bottom choke. Ran 4,500' water cushion plus 1700 PSI gas cushion. Set packer at 15,732'. Took 1 hour initial open periOd, 2'hour initial shut-in period, 15 hour final flow period, and 25 hour and 20 minute.final shut-in period. Had very weak blow at surface throughOut final floTM period. Bled 1700 PSI gas cushion off during initial flow period. .Recovered a total of 74 bbls. fluid, consisting of 41 bbls. of water cushion, t2' bbls. of drilling mud, and 21 bbls. of oil and gas cut drilling mud. Pressures: IHP 11,035 PSI, IFP 7,716 PSI, ISIP 4,327 PSI, FFP 4371 'ps!, 'and FSiP 8,205 PSI. Ran in hole with 5-7/8" bit and now conditioning mud. (See attached sheet) 18. I hereby certify that the foregoing is t~ue SIGN'ED · and correct TITLE Div. Dril 1 inq Supt. DATE 12-,~-72 (This space for Federal or State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE .. DATE *See lnstroctions on Reverse DEC6 DIVISION ~,,,~L -2- November 27, 1972, through December 4, 1972 Formation - Sand, siltstone, and conglomerates. Mud Weight - 12.9# to 13.1# per gal. B.0.P.s - Tested with 1500 PSI on Hydrill ~nd 4200 PSI on pipe rams. Tested O.K. DEC6 DIVI$1C~N L F C;:'IL AND GAS ANCHORAGE Form 9-331 (May 1963) DEPAI~' 'INITED STATES SUBMIT (Other inst~ .~ENT OF THE INTERIOR ,erse side) GEOLOGICAL SURVEY 'PLICATE' )ns on re- SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) 0XLwEL~. [~ OAS WELL [] OTHER Wildcat NAME OF OPERATOR Marathon Oil Company Form approved. Budget Bureau No. 42-R1424 5. LEASE DESIGNATION AND SERIAL NO. A-208083 6. IF INDIAN, ALLOTTEE OR TRIBE NA.ME 7. UNIT AOREEMENT NAblE Beaver Creek Unit 8. FARM OR LEASE NAME Beaver Creek 3. ADDRESS OF OPERATOR 9. WELL NO. P. O. Box 2380, Anchorage, Alaska 99510 " No. 4 4. LOCATION' OF WELL (Report location clearly and in accordance with any State requirements.' See also space 17 below.) At surface 1700'S, 660'W from NE corner protracted sec. 33, T7N, R10W, SM Prop., Bottom hole location: 1700'S & 725'E from NW corner Sec. 34, T7N, R10W, SM (1,385' due E from surface loc.) 10. FIELD AND POOL, OR WILDCAT Wildcat 14. PERblIT NO. 15. ELEVATIONS (Show whether DF, ET, GR, 72-13 GR 144· 8' KB 164' Alaska z6. Check Appropriate Box To Indicate Nature pi Notice, Report, or Other Data 11. SEC., T., R., M., OR BLIr. AND SURVEY OR AREA Sec. 34, T7N, R10W, 1~. COUNTY OR PAaI~HI 13. STAT~ Kenai Penin. Borough IqOTIC, E OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE · SHOOT OR ACIDIZE ABANDON' REPAIR WELL C~IANGE PLANS (Other) SUBSEQUENT REPORT OF: ,. FRACTURE TREATMENT ALTERIN0 CASING SHOOTING OR ACIDIZING . .ABANDONMENTs. (Other) Week__ly Report ,, (NOTE: Report results of multiplecompletion on Well Completion or Recompletion Report and Log form.) 17. OESCRInE I'RO~OSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths for all markers and ~;ones pertJ nent to this work.) * November 20~ 1972 throush November 27~ 1972 Depth - scrapper to top of liner at 12,217'. . Survey!- 15,940, 12-3/4°, S 66 E 15,940', P B .T.D. 15,875' drilled 8-3/8" hole from 15,820' to 15,940' Ran DIL with Gamma Ray Log from 15,938' to 14,700', 'Gamma Ray-Density!' and Dipmeter logs from 15,936' to 12,504'. Ran Sidewal't core gun .... attempted 30 cores. Recovered 1 core and 7 partial"cores. Ran.7". ,' 29# - 32#, P 110, X-line liner with top of liner at'12,217' and bot'tom of liner at 15,921'. Cemented 7" liner with 1400 sacks.:Cement.' Reversed out approximately 120 sacks cement. Ran 8-3]8" bit and.'9"5/8" casing`.'· · , · Mud Weight - 12.9# to 13# per gal. B.O.P.s - Tested with 1500# on Hydrill and 4200# on pipe rams. CONFIDENTIAL , , : Tested .O.K. ., 18. I hereby certify that the foregoing is true and correct O. W. Akin~ TITLE Div. Drilling Supt. DATE 11-27-72 (This space for Federal or State office use) APPROVED BY CONDITIONS OF APPROVAL, IP ANY: ,_., .-.,. =,,-., ,,, m.=.o o o,,~ ~!,~!~1 I TITLE *See Instructions on Reverse Side '. , ' DATE NOV ANCHORAGE Form 9-331 (May 1963) DEPA~ NITED STATES SUB~IT I~ ~I ,~ENT OF THE INTERIOR ersestde) . GEOLOGICAL SURVEY 'LICATE* Jn8 au r~- SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a dll~erent reservoir. Use "APPLICATION FOR PERMIT--" for such prop~3als.) Form approved. Budget Bureau No. 42-R1424. LEASE DESICNATION AND SERIAL NO. A-028083 6. IF 'INDIAN, ALLOTTEE ORTRIBE NAME ,.. . 1. 7. UNIT .AOREEMENT NA3IE OILwELL ~] GAS E] OTHE, Wildcat ~ Bea'ver Creek'.Unit WELL . 2. NAME OF OPERATOR 8. Marathon Oil Company 3. ADDRESS OF OPERATOR P. O. Box 2380, Anchorage, Alaska 99510 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) At surface 1700'S, 660'W from NE corner protracted Sec. 33, T7N, RIOW, .FARM OR LEASE NAIk[E . Beaver'. Creek" 9. WELL NO. .. No. 4 10. FIELD AND POOL~ OR WILDCAT Wildcat 11. SEC., T., a., M.; oR BLK. AND SURVEY OR AREA, SM Prop., Bottom hole location- 1700'S & 725'E from NW 'Sec. 34, T7N, RIOW, corner Sec. 34, T7N, RIOW,,SM (1,385' due E from surface locatt°nSM ." 14. PERMIT NO. 15. ELEVATIONS (Show whether DF, ~T, OR, etc.) 72-13 GR 144.8' KB 164' ~ Rn~n,igh -Alaska ~6. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data : ". HOTIC]~ OF INTENTION TO: SUBSEQUENT: REPORT OPI ~ : FRACTURE TREAT MULTIPLE COMPI,ETE FRACTURE TREATMENT , ALTERING'CASINO SHOOT OR ACIDIZE ABANDON* SHOOTING OR ACIDIZING ABANDONMENT$ REPAIR WELL CHANOE PLANS (Other) Weeklv Report .. (Other) (NOTE: Report results'of multiple completion on Well Completion or Recompletion Report and Log form.) 17. D~;SCRZnE I'ROPOSEO OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths'for all markers and aches perti- nen~ to this work.) * ' :: .... ., ,, .' . .';.: , L ,,: '7'" :-',~ N.ovember 13; 197.2.. t.hrou9h November. 20, 1972_ .ii~~'"~ Depth- 15,820'. Drilled 8-3/8" hole from 15,471' to 15,820"](. i'~"~Nt/AL~ Formation- Sand, siltstone, and conglomerates, i! ,?i;ii~,I ?' ':'~" ': ]'?'":'~i[~ D,~//~' Surveys - 15,720', 13-1/2°, S66E; 15,820', 12-3/4°, S65E ['; :'i ]:.. ::'~" .': Mud Weight - 12.8# to 13# per gal. '~;.,::; '!!i :-i,:i':i' ", B.0.P.s - Tested w~th ]500# on Hydr~]l and 4200# on p~pe rams, ,,1;e~'.tadi O.K. ;(/:; ;; ,;,";.i :: '," 'ir- ,::: .:,.',., . ;: :,. ? ,', ,'," ~' :':; ':'. , ", I , ' :" .... 1 : I':~'~:"":'":':' -'l 18. I hereby certify that the foregoing is true and correct Owen W: Akins (This space for Federal or State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE Div. Drillinq ' :: DATE .1.1-.20~.72 ~or., ~l UNITED STATES svB~IT I~I 'IPLICATE' Budget B'~ (Other ins~I )ns on r~ ~. LEASE DESIGNAT ~,~ ~6~) DEPAg iENT OF ~HE INTERIOR ,~,~, side)~i GEOLOGICAL SURVEY A- 0 2 8 0 8 6. IP INDIAN, lLLO~ SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a ~erent reservoir. Use "APPLICATION FOR PERMIT--" for such pmpo~s.) o,, ~ o~,, Wildcat Beaver NAME OF OPERATOR 8. FARM OR LEASE Marathon 0il Company Beavez Cr ADDRESS OF OPERATOR 9. WE~ P. 0. Box 2380, Anchorage, Alaska 99510 No. 4 LOCATION OF WEnn (Report location clearly and in accordance with any State requirements.' 10. F~EL9 ~N~ Poo~, ~t,~f~e~ 1700'S, 660'W from NE corner protracted Wildcat 11. see., :., m, m., Sec. 33, TTN, R10W, SM Prop., Bottom hole location' I?00'S & 725'E from NW corner Sec. 34, T7N, R10W, Sec. 34, SM (1,385' due E from Surface location) SM ~ERM~ ~o. 15. E~VAW~ONS (Show whether ~F, aw, ca, e~) 12. ~o~ oR Kenai Penil~. 72-13 GR 144.8' .KB 164' Borough 16. 'Check Appropriate Box To Indicate Nature of Notice, Report, or Other Da~a IgOTIC,~ OF INTENTION TO: TEST WATER SHUT-OFF I ] PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDONS REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENTS (Other) Weekly Report NOTE: Report results of multiple completion on Well ompletion or Recompletion Report and Log form.) 1~'. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths for all markers and agnes pert. neat to this work.) * November 6, 1972 through November 13,. 1972 UU ' Depth - 15,471'. Oriented turbodrill S 30° W and drilled from. '." 15,016' to 15,085'. Pulled out of hole and laid down turbodrill. Ran in with drilling assembly'to shoe of 9-5/8" casing and slipped drilling line· .Drilled and surveyed from 15,085' to 15,445'. Pulled out.:of hole, . changed bit and roller reamer and picked up junk.sub and.. one stabilizer. Ran into shoe of 9-5/8" casing.and slipped drilling line. Reamed 30' to bottom and drilled '..from 15,445' to 15,471' Now drilling ahead ' I ',' I: ' · · . . ; ~.:' " · ~ormation - Sa~d, Siltstone, ~ Conglomerates "' :,~' · .,' .', , Surveys- 15,010' 14-1/4° · - 0 : , 40, S82E 15,065' 14 1/4u S7SB;' 15,164' 13 1/ S61E; 15 445' 14 1/2 S67E ' ~ , , , .'' ... Mud Weigl!t - 12.8# to 13#/gal. B.O.P.s tested 0 ,. K.., 18. I hereby certii, that the foregoing., is tru~ iU.d_c..o~r.ect ~I~I~T~D ......... nw~.n W~ Akin} (This space for Feder~ or S~te o~ce use) - Tested with 1,500# on Hydrill and 4,200# on pipe rams, APPROVED BY CONDITIONS OF APPROVAL, IFANY:. Drilling Supt· DATE !i'13-72 TITLE DATE *See Ins,ructions on Reverse Side NOV ! '4 1977 DIVI,SIGN OF OIL AND GA5 ANCHORAGE Form 9-331 Form approved. (Other inst,( ns on re- Budget Bureau No. 42-R1424. (.~,~ ~,63) OEPAI~i UNITED STATES soB~,IT i~.,,~mmc.~. ENT OF THE INTERIOR ,e~a~) ~, ~. ~,~ ~ :~,~,o, ,~ ,, '~o. . ~ DIR ~ GEOLOGICAL SURVEY A- 0 2 8 ~~-5-~ SUNDRY NOTIEES AND REPORTS ON WELLS . ; 3 EN~ ~. ~,~s o~ o~s~,~o~ 8. ~ o~ .=*~ ~.~ I Ms~t~o~ O~l Compan7 Beaver a. P. O. Box 2380~ Anchorage~ Alaska 99510 No. ~~.~,.-~ {. ~oc~o~ o? xx'g~b (Report location clesrl7 and in accordance with 8n7 8tale requirements.* 10. ~g~n ~; S~ also space 17 below.) At surface W i 1 d c a -~-~;-.. 1700'S, 660'~ from NE corner protracted Sec. 33, T7N, ~o~~r R10~, SM Prop , Bottom Hole LocatSon' 1700'S ~ 725~E c~ 4-, ...... ,~_ · o~. ~FF~:./ ~ ~ ~ i ~om NW co~e~ Sec. 34, TTN, R10~, SH~1,385~ dueEfrom 'R10~ ~~~ ~4S~Y~e location) I[5. E~VATIONS (Show whether OF, RT, CR, e~.) 12. COUNTY O~'~XRISHI 13. Kenai Pehin,I 72-13~ GR 144.8' KB 164' ~Borou~H .'.l'Alask~ 'Check Appropriate Box To Indicate Nature of Notice, Report, or Offer Data NOTIC,EO~ INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON$ REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SI:IUT-OF~ ~ ': I' REPAIRING WELL ~ FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENTs (Other) Weekly Report NOTE: Report r~sults of multiple completion on Well ompletion or Reeompletlon Report and Log form.) 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date.of starting any proposed work. If well is directionally drilled, give subsurface locations and mens.red and true vertical depths, for all markers and sones perti- October 30, 1972 .through November 6, 1972 . Depth' 15,016' - Pulled out of hole and left 5 joints.'0f' 5" dril1 pipe in hole. Top.of fish at 15,120'. Changed Hydril'l':rubber, tested Hydrill to 1S00# and pipe rams to 4200#, test O.:K'.' Ran in with bit and conditioned mud and hole. Pulled out .and ran drill pipe open ended to 15,112'. Pumped 10 barrels diesel and. 10 barrels of water with surfactant. Cemented with 100 sacks,',, :' type "G", 10% sand, 18% of water with surfactan hole and ran in with bi waited for cement. Ran Washed to top of plug a 15,010'. Pulled out of salt, 1% CFR2. Displaced with' two barrels t and 1,445 cu. ft. mud. Pulled out of. t to clean out cement. Stopped...at shOe and into 14,150' and circulated bottoms ~up... t 14,907'. Drilled firm cement~.14.,907' hole and ran in with turbo-dri.ll · Oriented ,. turbo -dri 15,016'. Ran in wi and while 1 ine brok a ~p_r_q x ima d r i 1%~-~g 11 and kicked off plug at 15,010'. Drilled iS,'010': - Pulled out of hole and found· turbo-drill No ~ 1 had:'failed. th turbo-drill No. 2. Started running directional'survey circulating and moving drill string, the 2'""steel mud e out of the circulating head. Drill string dropped tel_~.y_~'. Pulled out of hole to 12,300~200' line. Repaired and cleaned up rig. Checked drill' string 18. I hereby cbrt ~if~ that the foregoing is tru~ .~ud correct ,i. .... "'. (~his space for Feder~ or S~te o~ee use) APPROVED BY TITLE Div. Drilling Supt ' .. DATE 11-6-72 IF ANY: *See Instructions on Reverse Side October 30, 19 ?2_ thr?ugh November 6, 1972 Depth Continued for damage, changed drill string for turbo-drill and checked B.O.P.s. Ran back in hole with same bottom hole assembly. Found 25' of fill on bottom. Hole in good condition. Now surveying to orient turbo-drill. Formation: Sandstone Surveys: None Mud Weight: 12.8# to 13#/gal. B.O.P.s: Tested pipe rams to 4200# and Hydrill to 1500# .test O.K. Form 9-33I (,May 1963) DEP^I JNiTED STATES su~:~ (Other .MENT OF THE INTERIOR verse sid~)~ GEOLOGICAL SURVEY .IPLICATE* £ions on re- SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) Form approved. Budget Bureau No. 42-R142. LEASE DESIGNATION AND SERIAL NO. A-028083 6. IF INDIAN, ALLOTTEE OR TRIBE NAM] OIL [~.. oas [~] OT.ER Wildcat WELL WELL 2. NAME OF OPERATOR 8. FARM OR LEASE NAME Marathon Oil Company Beaver Creek 3. ADDRESS OF OPERATOR 9. WELL NO. P. O. Box Z380, Anchorage, Alaska 99510 No. 4 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) At surface 1700' S & 660' W from NE Corner protracted Sec. 33, TTN, R10W, SM Prop., Bottom Hole Location: 1700' S & 725' E from NW corner Sec. 34, TTN, R10W, SM (1,385' due E from Surf. Loc.) 14. PERMIT NO. 72-13 I15. ELEVATIONS (Show whether DF. RT, OR, etc.) GK 144.8' KB 164' 7., UNIT AOREE.MENT NAME Beaver Creek Unit 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., T., R., lt., OR BLK. AND SURVEY OR AREA Sec. 34, TTN, R10W, SM 12. COUNTY OR PARISH[ 13. STATE Ke~ai Pepin. iAlaska . borough . 16. Check Appropriate Box To Indicate Nature o~ Notice, Repod, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON$ REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT'OFF REPAIRING WELL , FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) Weekly. RepOrt NoT~,: Report results of multiple completion on Well ompletion or Recompletion Report and Log form.) 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting proposed work. If well is directionaily drilled, give subsurface locations and measured and true vertical depths for all markers and ~ones per Bent to this work.) * ' :." , ' October 23~ 1972 t'hrough October 30, 1972 ;~ : ....... Depth - 15,630' drilled 8-3/8" hole from 15,505' to 15 600' Cut core No 3.:.' from 15,600' to 15,630'. Started to pull out of hole and core barrel' :2': was stuck at approximately 15,609'. Jarred and worked drill pipe with no results· Ran free point with Dia-log and foundlfree point at' 15,594', top of core barrel. Everything free to that..'p0...int~ ': ' , , Backed off at 15,508'. Left in hole: 1 core barrel, l'crossover'Sub, 1 drill collar, 1 stabilizer, and 1 drill collar. Top of' fish at 15,508'. Pulled out of hole. Ran in with 12 drill collars and Bowen overshot with bumper sub and oil jars. Latched onto fish and jarred 1 hour. Overshot pulled off fish. Pulled out of hole and found graPple in overshot broken. Ran in hole with screw-in sub, bumper sub, oil 'jars', and accelerator jars. Screwed into fish at 15,508' and jarred for 9.hours, with no results. Tried backing off safety joint on top of Core barrel. Pulled out of hole and had backed off at screw-in sub. Tested BOPs, test OK. Left in hole: 1 core'head, 1 core barrel, 1 drill collar, stabilizer, and 1 drill collar. Top of fish at 15,508',. 18. I hereby certify that the foregoing'is ,tr~e and~correct ~ ' r ,"", .L....~ t ~.~---. sxg~mgO[2~! g".-~.?')~ ~ ~< ~V:~.,.'M~..,[~ TXTL~ Div. Drilling Supt. ;'~..'"'~- Ow en~}.. Akin s_ J (This s~ce for Feder~ or State office use) DATE 10-30-72 TITLE *See Instructions on Reverse Sid'e · · , : .. October 23, 1972 through October 30, 1972 (Cont'd) l{an open-ended drill pipe to 15,490', cenaented 100 sacks type G cement with 10~0 sand, 18~0 salt, and 1~0 CF1{2. Slurry weight 17~/gal. 1{eversed out of hole with water and diesel that was ahead of cement, plus approximately Z barrels cement. After reversing out, drill pipe was stuck at 15,271'. Worked pipe and circulated, with no results. iKan Dia-log and free point. Drill pipe free at 15, 132'; stuck completely below this point. Backed off drill pipe and now pulling out of hole. Left '4 joints 5" drill pipein hole. 'Top of fish. at 15, 132', wireline mea sur ement. Mud Weight. - 1Z.8# to 13.0# Per gallon'- Vis. 54 - 60. Surveys - 15,556', 12-3/4°, S80E. Formation - Sand, conglomerates, and shale. B. O. P. s - Tested pipe rams to 4, 500# and Hy-drill to 1,500# test O. K. Form 9-331 (May 1963) '~NITED STATES SuB~IT ~i (Other instj ,tENT OF THE ~NTERIOR ,e,sesidc) ~ GEOLOGICAL SURVEY PLICATE* ,)ns on re- SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such propo-~ls.) 1. O,L [] CAS [--I OTHER Wildcat WELL ~. WELL 2. NAME OF OPERATOR Marathon Oil Company Form approved. Budget Bureau No. 42-R1424. LEASE DESIGNATION AND SERIAL NO. A-028083 6. IF INDIAN, ALLOTTEE OR TRIBE NAME 3. ADDRESS OF OPERATOR P. O. Box 2380, Anchorage, Alaska 99510 '7. UNIT AGREEMENT NA:%IE Beaver Creek Unit 8. FARM OR LEASE NA1KE Beaver Creek 9. WELL NO. N°. 4 4. LOCATION OF WELL (Report location clearly and in accordance with. any State requirements.* See also space 17 below.) At surface ' 1700'S 660'W from NE Corner Protracted, Sec. 33, TTN, R10W, .SM ; ...Subsurface 17.00'~S 660'E .from NW corner, Sec. 34~..TTN~ R10W, SM 14. PERMIT NO. { 15. ELEVATIONS (Show whether OF, RT, OR, etc.) 72-13 (State) I GR 144.8' KB 164' 16. 10.. FIELD AND POOL, OR WILDCAT 'Wildcat 11...SEC., T., R., M., OR BLK. AND · ' SURVEY OR AREA S:ec. :.34 ,.. T7N, RI OW, SM }2. coUN. TY~.~R PA]~IS~r} 13. SmAmE enal yenlnJ Alaska ~orougn ~ Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data , NOTIC,E OF 'INTENTION TO: TEST WATER SHUT-OFF ~ PULL OR ~LTER CASING FRACTURE TREAT I~I '5IULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other).Plug Back SUBSEQUENT REPORT OF: WATER SHUT-OFF ,. REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) '" NOTE: Report results of multiple 'completion on Well ompletion or Recompletion Report and Log form.) 17. DESCRInE I'ROPOSEO OR COMPLETED OPERATIONS (Clearly state all l)ertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionaily drilled, give subsurface locations and measdred and true vertical depths for all markers and ~ones perti- It is proposed to set cement plug from 15,508' to 15,~ . .- at 15,609' - 15,508' consisting of S?' core barrel, cross, ov'eri'sub and 2 - 6-1/~" drill collars. Present T.D. 15,630' with top. of': Hemlock, 15,325'. Propose to kick off at approximately"lS,200', with ,' , new hole. . .. '... Set plug with 100 sacks, type 6, with 10% sand, 18% salt, and 1% CFR2. Slurry weight 17#/gal. Preceded cement with 10 barrels unweighted Invermul followed by 10 barrels diesel wit]: 5 gals. Hyflo:, followed by 10 barrels water with surfactant. Displaced cement with 2 bar,reis water with surfactant and 269 barrels mud. ,', :'.: .... Submitted in accordance with telephone 1972. communication, of October.,.,'.29, · .., ~ , , ".',' i' ,'. '; .. ';' . . , 18. I hereby certify, that the foregoing is,t~uc and correct ~, ~ ~, . <.~l.~ ,:-::.-.?~ Owen W. Akins TITLE (~ls space for Feder~ or S~te o~ce use) Drilling Supt. DATE 10-30-72 ,. APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE *See Instructions on Reverse Side s~3, j' '~IlTED STATES sm',.~{"~ l~) DEPAR( ,ENT OF THE INTERIOR ,,,,?,l'd~c GEOLOGICAL SURVEY "i 1' ENG"-~ SU'~DRY NOTICES AND REPORTS ONI WELLS ~" ~.._ (Do not use this form for proposals ,o drill or t~, deepen, or ~ ~e~, di~ere~, ~9oi~ : :.- " U~ "APPLICATION FOR PER. fIT--" or P P ' ') t. ~ o,, ~ ~*' '~ o,.,, ~ildcat ~ , C.~OL ~ 'BeaVer Cree.k Unit Mara:hon ail'Company ~ ~ a~oz'-~ Beaver Creek P..0. Box 2~80, Anchorage, Alaska 99510 [-'b'i,FT ~oc*~o~ o~ w~zz (~eport loeatiou elearl~ and In accordance with s~ State requir,:m~;~;~~- ~ - 10.. ~l[~D tN~.POO;, aa I'ILDCt~ Atsu~aee 1700'S 660'W from NE Corner Sec. 33, TTN, R10W, SM Prop., Bottom Hole?'~-~~o~ ~ SUR?~Y OR ~A 1700'S & 725'E from NW corner Sec. 34, TT~, ~IOW, S~c.. 34, TTN', R10W, SM (1,385' due E from Surf. Loc.) S'Mf' P~a~n: ~o. ls. E~VA~ONS (Show whether B~, ar, ~ ~) 72-13 GR 144.8' KB 164' ~.:. Borough J'Alaska 16. FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data TEST WATER SHUT-OFF ~'~ PULL OR ALTER CASINO ~I ULTIPLECOMPLETE ABANDONs CHANGE PLANS SUBSEQUENT R~IPORT OF: .'-'='~-' ~''!' · ,~ WATER SHUT-OFP .'. ut REP~'IRiN~' .W~LL ,SHOOTING OR ACIOIZING ~" '~ L :, ABkNDONMEN~,* (Other) ~e e k 1 y~p o r~, '-, ~j. ~ (NOTE: Report results of multiple compl~tion~bn'W~ Completion or Recomp!etion Report and Log.form.) DESCP. IBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent 'dates, including estimated date of s~rttng any proposed work. If well ia di~tion~y drill~, give s~s~ace l~tions and measured and true vertical dep~s, for all markers a~d zones pertt- October 16 through October 23, 1972 ~ ....:.: _ ~ ~ .... ~ ~'. .....?~, ;~ ,~, ,'~ , ' ~, "~' Depth - 15,505', drilled 8-5/8" hole from 15,222' :~to dual induction with.Gamma Ray log from 15,'358" ~6 off 9-5/8" cog at 12,521'. Drilled 8-5/8" :hole.)fiom~.:lSi}.338' to 15,550'. Cut core No. 1 from 15,550' tb :15;580' p~:l~led 8-5/8" hole from 15,580' to 1~,450' cut core Not';:"?2 15,430' to 15,460', 100% recovery on both coresL? Driile. d:.' 8-3/8" hole from 15,460' to 15,505'. Mud Weight - 12.8 per gallon.vis. $3-~.L. 2 6 ~/4o -s'~ a := '-': =. ~..:~ ~ .. SurveZ. s - , - , , Formation - Shale, Sand and Clay. B.O.P s - Tested pipe rams to 4,200~ and Hy-drill to}l':.;500~[: ies::i:~O K :~2, :: 1; ;'~ ~.. ~ ~, : ' ' , 18. I hereby ce~if~ that ~ foret~nK-i~9'?le and~ correct ~ Ow '. ' kin.q (This.space for Federal or 'State offiee use) TITLE Div. DrillSn~ g~lnt:J(' '~"~'~ ':':':' 10424-72 " .'~ DATE, · .~ A .h -: "' ' ' ' '-' :' ,., ...... . .....:~ ~ -.. ,. '~ .-'- " APPROVED BY OCT 2 5 1972 TITLE *See Instructions on Reverse Side DIVISION OF OiL AN9 ~:;~-:~ Form 9--331 (May 1963) DEP~" INITED STATES SUB~IT ~ :PLICAT~' (Other ir' ~-,lon8 on re- I MENT OF THE INTERIOR verse sid~ (~EOLO~ICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) OILwE~L [] .~ASWELL [~ OTHER Wildcat 2. NAME OF OPERATOR Marathon Oil Company 3. ADDRESS OF OPERATOR P. 0. Box 2380, Anchorage, Alaska 99510 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below,) At surface 1700'S 660'W from NE Corner protracted Sec. 33, T7N, R10W, SM Prop,Bottom hole location: 1700'S & 725'E from NW corner Sec. 34, T7N, R10W, SM (1,385' due E from Surf. Loc.) 14. PERMIT NO. 72-13 16. 15. ELEVATIONS (Show whether DF, a~, aR, eta.) GR 144.8' KB 164' Form approved. Budget Bureau No. 42-R1424. 5. LEASE DESIGNATION AND SERIAL NO. A-028083 6. IF INDIAN, ALLOTTEE OR TRIBE NAME 7. UNIT AOREEMENT NAME Beaver Creek Unit 8. FARM OR LEASE NAME Beaver Creek 9. WELL NO. 10. FIELD AND POOL, OR WILDCAT Wildcat ]11. SEC., T., R., M., OR RLK. AND SURVEY OR AREA Sec.. 34, T7N, R10W, · SM 12. cou~,z,x OR P~RISH[ 13. STATE Kenai Penin. } Check Appropriate Box To Indicate Nature of Notice, Report, or O~her Do~a WOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASINO MULTIPLE COMPI,ETE ABANDON* CHANGE PLANS WATER SHUT-OFF " REPAIRING WELL FRACTURE TREATMENT ' ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT.$ (Other) Weekly Report NOTE: Report results of multiple comple~ton on Well ompletion or Reeompletton Report and Log form.) 17. D~;SCRIB~, rnOPOSEO OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths for all markers and ~ones perti- nent to this ,work.) * October 9~ 1972 through October 16~ 1972 Depth- 15,222', Drilled 8-3/8" . hole from 14,762' to 15,'222" !'"" Formation - Shale, Sand, Clay and Coal Stringer. ' B.0.Y.s - Tested pipe rams to 4,500t~ and Hy-Drill to 1,500~J test O.K. ~_../.~.~[;~:,[~ ' r ~ ,', .... 18. I hereby certify that the foregoing is true and correct SIt,rED Owen, W, iB~ TITLE Div. Drilling Supt. "DATE 10-16-72 (This space for Federal Or State office use) ,. APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE *See Instructions on Reverse Side' Form 9-331 (May 1963) ...... 'NITED STATES S"BMIT ,-'~ (Other .... ,ENT OF THE INTERIOR ve,sesi~ GEOLOGICAL SURVEY PLICATE* /ns on SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) Form approved. Budget Bureau No. 42-R1424. 5. LEASE DESIGNATION AND SERIAL NO. A-028083 6. IF INDIAN, ALLOTTEE OR TRIBE NAME 1. 7. UNIT AOREEMENT NAME OILWELL [] . OASwELL [[] OT~Ea Wildcat Beaver Creek Unit 2. NAME OF OPERATOR Marathon Oil Company 3. ADDRESS OF OPERATOR P. O. Box 2380, Anchorages Alaska 99510 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) Atsurfaee 1700'S 660'W from NE corner protracted Sec. 33, T7N, R10W, SM Prop. Bottom Hole Location: 1700'S & 725'E from NW corner Sec. 34, TTN, R10W, SM (1,385' due E from Surf. Loc.) 14. PERMIT NO. 15. E~VATION3 (Show wh~her DP, RT, aR, e~) 72-13 GR 144.8' KB 164' 8. FARM OR LEASE NA~E Beaver Creek 9. WELL NO. · No. 4 10. FIELD AND POOL, OR %VILDCAT Wildcat 11. SEC., T., R., M., OR BLK. AND SURVEY OR AREA Sec. 34, T7N, R10W, SM 12. COUNTY OR PARI~ 13. STATE Kenai Pen~' gmrnugh _ A!~ska 16. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data I~OTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF ~ WATER SHUT-OFF ~ i REPAIRING WELL ~-~ FRACTURE TREATMENT I--I' ALTERING CASINO I--I (Other) Week_] y Ra~nrt ~ i ~o~: ~port-~s~ts o}~itpie completion on We~ ' Completion or Recompletion Report and Log form.) 17. DESCRIRE PROPOSED OR COMPLETED OPERATIONS (Clearly state ali pertinent details, and give pertinent dates, including estimated date of starting an~ proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths for all markers and ~ones perti. nent ~ ~is work.) * October 2, 1972 t.hro.ugh October Depth - 14,762', Drilled 8-3/8 Formation - Shale, Sand, Clay, S~.r. veys - 14,305', 16°, S79E; B.O.P.s - Tested pipe ram to 4,500# test O.K. inch hole from 14,079" tO]'14 , , and Coal Stringer. · : 14,458' 15-3/4O S79E , ',. and Hy-Drill to 18. I hereby certify that the foregoing is true and correct ()wen w. ~k_~ns TITLE Div. Drilling Supt DATE 762, '. [ DRAFT I SEC I" CONFER: FILE: 10~10-72 (This space for Federal Or State office use) · APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE *See Instructions on Reverse Side' ,. Form 9-431 (May 1963) DEPA~ INITED STATES SUBMIT ~(" ,PLICATE' (Other tnst~ 'OhS on re- lENTOF THE INTERIOR verse side)~[ GEOEOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) 1. OIL [] OT.ER Wi ldc at WELL ~ GAS WELL 2, NAME OF OPERATOR blarathon Oil Company 3. ADDRESS OF OPERATOR P. O. Box 2380, Anchorage, Alaska 99510 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) Atsurface 1700'S 660'W from NE corner protracted Sec. 33, TTN, R10W, SM Prop. Bottom Hole Location' 1700'S & 725'E from NW corner Sec. 34, TTN, R10W, SM (1,385' due E from Surf. loc.) 14. PERMIT NO, { 15. ELEVATIONS (Show whether DF, RT. (~R, ~t~) 72-13 [ GR 144.8' KB 164' 16. Budget Burs 5. LEASE DESIGNATION ~AND~SERIAL A-028083 Beaver Cree Beaver Cr ~ ~_ ..- 9. WELL ~0. ' No. ~ 10. ~IELD AND POOL, OR _.~ Wildcat 11. SEC., ~., a., M., OR SURVEY OR ~A Sec' 34~ T7N Kenai Peninl. Check Appropriate Box To Indicate Nature of Notice, Report, or O~her Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDONs REPAIR WELL CHANGE PLANS (Other) SUBSEQUEN,T REpoRT OF: . WATER SHUT-OFF REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENTs Weekly, ort ' (Other) NOTE: Report results of mnlttple completion on Well ompletion or Recompletion Report and Log form.) 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all perttneDt details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths for all markers and ~ones perti- ' nent to this work.) s '~, !i, ,, i'[ , , ~.: ,~? ,"!, i( September. 25~, 1972 through October 2, 1972 ~ - 14,079', Drilled 8-3/8 inch hole from 12,942' Formation - Shale, Sand, Clay and Coal Stringer. ,, Surveys - 12,942' 16-1/2~ S84E; 13 530' 13,780' 18 1/4u S80E; 14 103' .., , : , , B.O.P.s - Tested ram to 4,500' and Hy-Drill 18. I hereby certify that the foregoing is tr~e and SIGNED ~o o: w_ Akins (This space for Federal or State office use) correct APPROVED BY CONDITIONS OF APPROVAL, IF AlT/: TITLE Div. Drillin~ Supt. 10-3-72 '. DATE TITLE *See Instructions on Reverse Side Form 9-331 NITED STATES SUB~T ,~ (Other ins ,~ OhS on re- (,~ay ~*0a) DEPAF{ IENT OF THE INTExRI0~ v~eside) GEOLOGICAL SUNDRY NOTICES AND ~~ELLS~[ J.J t J (go not .se ...... Marathon Oil Company 3. ADD'E88 OP P. 0. Box 2380, Anchorage, Alaska 99510 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) Atsurface 1200'S 660'W from NE corner protracted Sec. 33, T?N, R10W, SM Prop. Bottom Hole Location: 1700'S & 725'E from NW corner Sec. 34, T?N, R10W, SM (1,385' due F. from Surf. loc.t~ 14. PERMIT NO. J 15. ELEVATIONS (Show whe er DF, RT, OR, et~.) 72-13 J Gl{ 144,8' KB 164' Form approved. Budget Bureau No. 42-R1424. 5. LEASE DESIGNATION AND SERIAL NO. A-028083 i- IF INDIAN, ALLOTTEE OR TRIBE NAME . I?.fNIT AGREEMENT N&ME J .~eaver Creek Unit ARM OR LEASE· NAME .-neaver. Creek 9. WELL NO. No. 4 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., T., R., M., OR ELK. AND SURVEY OR AREA Sec. 34, T7N, RIOW SM COU~IT¥ ,qR ~'a~,IsHJ 13. STATE n~g ~en;~n ~ rougn ~ Alaska 16. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data '-~IOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF . REPAIRING WELL FRACTURE TREATMENT II ALTERING CASING SHOOTING OR ACIDIZING ~v~' ABANDONMENT.$ (Other) Weekly ~eport (NOTE: Report results of multiple completion on' WeI1 Completion or Reeompletion Report and Log form.) 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths for all markers and ~ones perti- nent to this work.) * . September 18~ 1972 through September 25~. !_97~2_ '" I~'' Depth- 12,942' to 12,510'. Drilled out drilled sho set at 12,4 200 sacks o built from Pressure he mud. Drill with 2000#; out to 12,5 Formation - Shal Survey._s - 12,738 Drilled out float collar at 12,438' and soft cement Tested 9-5/8" casing to 1600 # and would not.ho'Id' soft cement to shoe of 9-5/8" casing at 12,52'1', e, cleaned out to 12,542' T.D. Ran cement retainer 50'. Cement squeezed bottom of 9-5/8" casing with f class "G" cement with 1 percent D-19. Pressure 2200# to 3600# with 50 sacks cement into.for'marion. id at 3600#. Displaced water b,~se mud with oil base ed Cement retainer at 12,450', 'tested.' 9,.5/8 tested O.K. Drilled hard cement to 12,'$26 42'. Drilled 8-3/8" hole from 12,542' to 1 e, sand, cla7 and coal stringer. . . ' 15b S84B "casing ',. ',Cl.eaned 2',9'42". · . , B.O.P.s - Tested after running 9-5/8" casing. Checked on trips for ,open and closing. 18. I hereby cert. ff_y that the foregoing is_true and correct SIGNED ()wen W. Akh n s - T~TL¢ Div. Drilling Supt. DATE 9-25-72 (This space for Federal or State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: *See Instructions on Reverse Side SE? 2'7 1972 ..... DIVISION OF OiL A~4D GA'S Form 9-331 (May 1963) · ~'~r~ STATES SUBmT ~ 4 ".~ATr,. ~'~ (Other lustruc't,...,~ ~ re- DEPARTM~'~. OF THE INTERIOR ,~a~) } GEOLOGICAL SURVEY SUNDRY klt'hTIf[:¢ ANIh DIrDi~DT< ON WELLS ' (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. U~ "APPLICATION FOR PERMIT--" for such prop,s.) O,L Q OT~Ea Wildcat WELL ~] GAS WELL 2. NAME OF OPERATOR Marathon Oil Company 3. ADDRESS OF OPERATOR P. O. Box 2380~ Anchorage, Alaska 99510 4. LOCATION ON WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) ~tsu~ace 1700'S 660'W from NE corner protracted Sec. 33, T7N, R10W, SM Prop. Bottom Hole location' 1700'S & 725'E from NW corner Sec. 34, T7N, R10W, SM (1~385' due E from Surf· loc.) 14. PERMIT NO. I 15. ELEVATIONS (Show whether DF, ET, GR, et~) 72-13 I GR 144.8' KB 164' 16. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data Form approved. Budget B~~P~I~t~41 .... C ".'. : ~ Beaver 'C'~ ..... ,. ..~ 'No. 4 r:~' S GEOL 10. POO~} . 'Sec. 34, [enai Penin', Borough A1 ~,, ~ t;; ~.' '.~OTICE OF INTENTION TO: · TEST WATER SHUT'OFF I I PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT 0R ACIDIZE ABANDONs REPAIR WELL CHANGE PLANS (Other) 8UBSEQUENT' REPORT 0F':. ~'.. ?; -.., ' FRACTUHE TREATMENT I I .... :..L~ '3 SHOOTING OR ACIDIZ~N~ ~: ~ ' '. ABANDONMEN~ Weekl~euort [~o~: Report results of multiple completion ompletton or Recompletlon Report and Log form.) 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date 'of starting any proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths for all markers and ~ones pertl- nen~ to this work.) * ONFIDENTIAL ' September 11, 1972 through September 18, 1972 .... Depth 12,542' T.D., 12,521 P.B.T.D. Drilled outilD.¥'.';t, bol')at ~:~61.3' . a:n~l' 8', 52' tested to 3,000#, held 0 K , . . ,.~ -'. L: ~ '" .... .~ ' :~ .~;, 1'5 "? :? Formation stringers ;', Surveys - - Shale, 12,542' sand, clay, and coal 12° S-86E Mud Weight - 11.4 to 11.5# per gal. B.O.P.s After nippling up on 9-5/8" casing, 2,500~, pipe rams to 4,500# and Hy-Drill to 1,500#; t'es.t:.~O.K. Ran logs as follows' D.I.L. log from 12,536' to 5,700,..:::"sonic:"log from 12,536' "t'o 5,588' FDC/CNL log from 12,540' to%.4.,90.0':"' ' · , Dipmeter log from 12,540' to 5,700'. Ran and Cemented 9-5/8" Casing as follows' TITLE Div. 18. I hereby cert~y that the foregoing is tLue and correct SIG1FED ' Owen W. Akins (This space for Federal or State office use) · APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE *See Instructions on Reverse Side ANCHO~,AG~ Ran and Cemented 9-5/8" Casing as follows' Ran 65 joints 9-5/8" P-110 Buttress 53.5# per foot, 61 joints 9-5/8" R.S. 95 Buttress 47# per foot and 197 joints N-80 Buttress 4?#/foot with Baker float shoe and collar and Baker D.V. tools at 8,545' and 4,603'. Used centralizers on bottom 3 joints and on every other joint from 5,000' to 5,300'. Landed 9-5/8" casing at 12,521'. Cemented first stage with~696 sacks, class "G", 0.5% per cu. ft. of Perlite 4% gel, 1% D-31 and 0~8% R5 followed with 300 sacks, class "G" with 0.5% R5 and 1% D-.19 circulated out trace of cement from first stage. Cemented second stage from 8,552' ~ to 4,613' with 760 sacks of class "G", 0.5% of Perlite, 0.5%.R5 and 1% D-19 followed with 200 sacks of class "G" with 0.5% R5 and 1% of D-19 closed D.V. tool with 3,000#; held ©~. Opened D.V. tool at 4,613' and circulated out estimated 240 sacks of excess cement. Cemented third stage with 912 sacks, class "G", 0.5% cu. ft. of Perlite 4% gel and 1% D-31 had good cement returns to surface. Job completed~at 9:10 a.m., September 16, 1972. 9-5/8" casing design and cementing procedure was approved verbally before' run- ning by Mr. Bill Wunnicke. .OONFIOENTIAL MARATHON OIL COMPANY PROOUCTION-UNITEO STATES AND CANADA ANCHORAGE DIVISION 1:3.0. BOX ANCHORAGE,ALASKA 99510 RECEIVED OF MARATHO~I OIL CO~IPANY One Set of Washed Ditch Samples from the Beaver Creek Unit No. 4 Well from 7390 ft to 11,650 ft. DEA- 1 pb Form 9-331 (May 1963) ,~ ~ ~'~ a LO SUi~I~tT iN T-"PLICATE* ~' ~ ~ff 07 ~ ~ %~'~'1~ ~ ~0~ verse(0thersidein,~;~" ,s on r~ ~OLO~tCAL SU~VSY (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) 1. 0IL [] GAS W~LL ~'ELL []] O~ER Wi I dcat 2. NAME OF OPERATOR Marathon Oil Company ~. ADDEESS O~ OPEnATOE P. O. Box 2380, Anchorage, Alaska 99510 Form approved. Budgcl Bureau No. 42-R142 5. LEASE DESIGNATION AND SERIAL NO. A-028083 6J IF INDIAN, ALLOTTEE OR TRIBE LOCATION O~' WEt,L (Report location clearly and in accordance with any State requirements.* See also space 17 below.) At surface i 700'S 660'W from NE corner protracted Sec. 33, T7N, RIOW, SM Prop. Bottom Hole location: 1700'S & 725'E from NW corner Sec. 34, T7N, RIOW, SM (1,385' due E from Surf. loc.) 14. PERMIT NO. 72-1 5 15. ELEVAY~ONS (Show whether DF, RT, GR, etiL) GR t44.8' KB 164~'' 7. UNIT AGREEMENT Beaver Creek Unit 8. ~AR~f OR LEASE Beaver Creek 9. WELL NO. No. 4 10. FIELD AND POOL, OR %VILDCAT W i i dcat 11. SEC., T., a., ~., OR RLre. AND SURVEY OR Sec. 34, T7N, R IOW, SM 12. COUNTY O'~ PAnISH| 13. STATE Kenai Pen ins~dla Borouqh /Alaska 16. Check Apprqpria;'e Dox 7o bdicc,~e Nature o~ Nodce, Rcpo~, or O~her Dc,~a NOTICE OI0 INTENTION k'X): FRACTURE TREAT ,~IULTIPLE COMt'LETE StI00T OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (O~her) SUBSEQUENT REPORT OZ': WATEII SHUT-OFF REPAIRING WELL __ FRACTURE TREATMENT , ALTERING CASING SHOOTING OR ACIDIZING ABANDON,N[ENT* (Oth~r) Week l y Report o~:.Ro~ort results of multiple eom~leflo~ on We~ ompletion or Eeeompletion Re~ort and Log form.) 17. D~:SCR~B~: I'~OI'OSEO OR CO,~IPLET~:D OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting proposed work. If well is dimction~ly drilled, give suba~ace lo~tions and measured and true vertical depths for all markera aaa ~one~ per nent ~ this work.) * ,: .. September 4, 1972, through September I I, 1972 .',. . ,, ,. . 14-5/4 . 12,444' 12-3/4° S88E; ' ".:": gud ~eigh? - 11.4 go 11.5~ per gal. ~ . , , B.O.P.s: Tested Hy-Drill with i,500tt and pipe rams to 4,500//...Tes~.~. ' ".? .... ~ '~ L ~ ~ .... '" ,, Dri lied 12-1/4" hole from 11,835' to 12,542'. Formation- shale, sand, clay, and coal stringers. Surveys - 11,929', 14-3/4~ N85E-, 12,015' , 12,251r, 14° S89E; 12,34I', 13-1/2° S89E; 18. I hereby certify that the foregoing is true and correct Owen W. Akins TITLE Oi v. Dri I I i ng Supt. DATE 9- I 1-72 (This space for Federal or State office use) APPROVED BY CONDITIONS OF APPROVAL, i~' ANY: TITLE *See [nstwctions on Reverse Side DATE ; · .. 'PLICATE' Form approved. ns on re- Budget Bureau No. 42--R142 Form 9-331 (~[ay 1963) ' N]TED STATES ' (Other in, i~' ,,. ENT OF YHE ]NTER[OR GEOLOGICAL SURVEY 5. LEASE DESIGNATION AND SERIAL NO. A-028083 6. IF INDIAN, ALLOT'i'EE OR TRIBE SUNDRY NOTICES AND REPORTS ON WELLS 7. UNIT AGREEMENT Beaver Creek Unit 8. FARM OR LEASE NAME Beaver Creek 9. WELL NO. '; No. 4 LOCATION OF WELL (Report location clearly and in accordance with any State requirements.' See also space 17 below.) 1700'S 660'W from NE corner protracted. 33, T7N, RIOW, SM Prop. Bottom Hole location: 700'S & 725'E from NW corner Sec. 34, T7N, RIOW, SM due E from Surf. loc.) , ~Mr:,--~ (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. · ~'~ _~ ' Use "APPLICATION FOR PERMIT--" for such proposals.) '-3 ENG- Ir. c · 4 ~NG ~ 2 o~o[]~. O. Box 2380, Anchorage, Alaska 99~10 .... ] ..... Bc~, '--~ Se~lso sp~ ~ ~uv ~ At surface 1[. ~a~n~ so. 15. ELEVATIONS (Show whether DF, R%', GR, etc.) GR 144.8' KB 164~ 72-13 10. FIELD AND POOL, OR %VILDCAT W i I dca t 11. SEC., T., R., M., OR ELK. AND SURVEY OR AREA Sec. 34, T7N, RIOW, SM 1~, COUN.T¥~X P~,RISttl F, enal ~eninsu~'STATE Borough I Alaska 16. Check Appropriate Box To Indicate Nature o[ Notice, Report,, or O~her Data '-gOTICE OF INTENTION TO: TEST WATER SHUT-OFF I I PULL OR ALTER CASINO I--1 FRACTURE TREAT .%£ULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDONS REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER ,HUT-OFP I--[~-~ REPAIRING WELL FRACTURE TREATldENT J I ALTERING CASING SHOOTING OR ACIDIZING ~ ABANDONMENTs NOTE:'Report results of multiple completion 'on Well ompletion or Recompletion Report and Log form.) 17. D~;SCa~nE I'aOPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting a~ proposed work. If well is directionally drilled, give subsm'face locations and measured and true vertical depths for all markers and aones per' · ' August 28, 1972, through September 4, 1972 Drilled 12-1/4" hole from 11,198' to 11,835'. Formation - Shale, sand, clay, and coa.l~ stringers. Surveys - 11,198', 15-1/4~ N 72E; il,289', 15-3/4~ N 74E; 11,562', 15-1/4~ N 78E; 11,666', 15-1/4~ N 80E; il,761', 15~ N 82~E. Mud weight - 1~.4 to !i.5// per gal~ 11,437' '15-3/4° N 76E; , , , 15-1/4°~N~ 80E; 1"ii,835', , , . c. B.O.P.s: Tested Hy-Dri ii with 1,500//and pipe rams to 4,500// - t&st O:K 18.SIGN-EDI hereby ce~,u:~j']that thews~':t~Jf°reg°lng is true and correct TITLE Division Drilling Supt. DATE 9-5-72 (This space for Federal or State office use) (/; '~"'" i3 ' ', f'fTO TITLE *See Instructions on Reverse Side DATE · . MARATHON OIL COMPANY PRODUCTION-UNITED STATES AND CANADA ANCHORAGE DIVISION B.G, HOWARD OPERATIONS MANAGER September 6, 1972 P.O. SOX 23S0 ANCHORAGE.ALASKA SS Mr. Homer L. Burrell, Director State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Sir: Sundry Notices and Reports - Beaver Creek Well #4 We are attaching one additional copy of all Sundry Notices and Reports previously submitted on the Beaver Creek Well #4. Again we apologize for the inconvenience to you with regard to sub- mittal of these reports. Yours very truly, Enclosures Division Operations Manager MARATHON OIL ICOMPANY PRODUCTION-UNITED STATES AND CANADA ANCHORAGE E)IVISION EB.G. H OWAR E) OF~ERATION S MANAGER August 25, 1972 ~.O.BOX 2380 ANCHOAAGE.ALASK State of Alaska Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Mr. O. K. Gilbreth Gentlemen: Attached are copies of Sundry Notices and Reports on Wells filed with the United States Geological Survey on the Beaver Creek No. 4 well. Future reports and notices on. this well will be filed with your office on a current basis. As noted on the forms, this information is being held confi- dential until released by the owners. Please accept our apologies for this oversight. Yours very truly, Enclosures Division Operations Manager Form 0-321 UNITED STATES A (Other lnaf ~ons on re- DEP .... lENT OF THE INTERIOR ,e,,e.l,le)('- '3. GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form fey propo.~nls to drill or to deepen or plug back to a dlt~erent reservoir, Use "APPLICATION FOR PERMIT--" for such Proposals.) Form approved. Budget Bureau No. 42-R1424 A-028083 INDIAN. ALLOT'rRB Oft TniRR NAMI · e,L [] OAS Wildcat WELL wELL [--] OTHER Beaver Creek Unit ~. NAMI OF OPERATOR 8. FARM OR LRASE NAME Marathon Oil Company Beaver .Creek S. ADDRESS OF 0F=RA'I~OR SI, WILL NO. P. O. Box 2380, Anchorage, Alaska 995'10 No. 4 4. LOCATION OP' WELL (Report location clearly and in accordance with any State requirements.· See also space IT below.) At,urn,ce 1700'S 660'W from NE Cor. protracted Sec. 33, T7N, R10W, SM Prop. Bottom Hole location: 1700'S & 725'E from NW Cor..Sec. 34, T7N, R10W, SM (1,385' due E from Surf. loc.) 72-13 J15. ELEVATIONS (Show whether DF, GR 144.8 ' KB. 164 ' 10. FIELD AND POOL, OR WILDCAT Wildcat g~tT, p~~ :~a. sT,,R . Borouqh JAlaska 10. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data .~O't'ICE OJ~ INTElq~rlON TO: FRACTURg TRZAT MULTIPLE COMPJ,ETI SHOOT O8 ACIDlY*I ABANDONe · REPAIR WELL CIIANGR PLANS (Other) 1L · August 21, 1972 through August 28, 1972 !~ .~;/..~:,. ~, c'"'"" · " ~ ,~. ~: - , :.~ ~ -.~::~:., . : .... :.. ...... Formation: ShaZe~ Sand~ C~y, and CoaZ SEt,risers.. /2 Surveys: 10,543' 14-1/2° N62E; 10,664' 14-1 o N62E;~."~.. 10,782' 15-1/2° N66E;. 10t828' 15-1/2° N66E;:: ...... ~': >,. ~,/' t ' ' 10,932' 15-1/4° N68E; 11,039' 15-1/4° N7~0E.':.:~ Mud ~e~ght~ ~1.4 to l~.SE Pe= gal. .~. ,: > ,: ~ :*..'. ,~ i · e=ted Hy=Dr~I1 with l~00~ and p{pe =~m~;'~0;'4"500~ [ "' . ~. ~,;.. i ...... , '.r.. E', :. o ........ . ~ ] I': j~ '...,, ~:. .'- ' CONFIDENTIAL , · ' ~,~ ~. . :'- - (".,O~ r%'~ ..... ,~ ,,, . .. , ,, , · z~ D~v, D~~ng Sup~. ~ 8-28-72 DKSCRIBr. l'nOPOSr, o OR COMPL[;TZD OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date'of starting an proposed work. If well in dlrectionally drilled, give subsurface locations and menmired and true vertient depths for nil markers and sone~ pert B.O.P.s: 18. I hereby certify that thq foregoing is trqe a~id eorse~t -6wen %~.- · Akins (This 'Ipaee for Fe~Lsr4d or State. omc, ~m~o~z o~ ~ov~ · ., . eSee Instructions on Reverse Side ~, , , · Form (May 1963) 'INITED STATES -. (Other ln,-tr Bs on re- DEP{' ' ..... ,FNT OF THE INTERIOR ~EOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATIOH FOR PERMIT--" for such propm~Js.) OIL [~ GAS wE,.L .'E,.L J--J OTnE. W i J dcat NAM~'- 0g OPERATOR Marathon 0ii Company Form approved. Budget Bureau No. 42-R14 LEASE Di;SICNATIoIq AND Si;RIAL N~ A-028083 INDIAN, ALLOTTEE oR TRIBE ,. UNIT AGREEMENT I~'AMg Beaver Creek Unit 8. FAR~[ OR LEASE NAME Beaver Creek ~, ADDRESS OF OPERATOR 9. WaLL NO. 4. LOCATtOX 0r W~LL (Report location clearly and in accordan~ with any State requirements.* 10. ~I~LD AND POOL, O8 WILDCAT S~ also space 1~ · ~,,a.~/~s 660'W (rom ~E CoP. protracted Wi Idcat ( I ,385' Sec. 33, T7N, RIOW, SM Prop. Bottom Hole location: 1700'S &'725'E from NW Cor. Sec. 34, T7N, RIOW, SM due E from Surf. loc.) 16. 72-13 15. Et~VATIONS (Show whether DF, RT, Git, et~.) GR 144.8' 'KB 164' Il. SEC., T., rt., M., OR ELK. AND SURVEY OR AB.gA .Sec. 34, T7N, RIOW, SM 12.,.COUNT! O~ PARTSHI 13. STATE ~enal ~enln~ t Ro~t,gh .'mj 'Alaska Check Appropriate Box To Indicate Nature si Notice, Report, or O~her Data .'~OTICB OF INTENTION TO: TEST WATER SHUT-orr I [ PVLL on ALTER CASINO PRACT~aE TREAT MULTIPLE COMPLETI'1 SHOOT OR ACIDIZB ABANDONe REPAIR WELL CilANGE PLANS (Other) SUBSEQUENT REPORT OF: ~ WATER SHUT-OFF . . REPAIRING WELL FRACTURE TREATMENT I J ', ALTERING CASING SHOOTINO OR ACIDIZING ] ] ~ ABANDONMENT~ (Other) Weekly R~rt omol~tlo~ o~ ~o~1~o~ ~ort ~d Lo~ ~o~.) DESCRIBE I'aoPOSED OR COMPLETED OPERATIONS (Clearly state ali pertinent detailS, and give pertinent dates. Including estimated date of starting proposed work. If well is dlrectionally drilled, give subsurface locations and measured and true vertical .depths for all markers and sones pet neat to this work.) · · Au.gust 14, 1972 thr'_o_ugh August 21, 19_72 Dri I'led 12-1/4" hole from 9650' to 10,500'. Formation: Shale, Sand, Clay and Coal Stringers. ~ 9778' 10-3/4° N5OE; 9902 11-1/2° N52E; I0,110' '.' .. : 10,321' 14° N58E; 10,446' 14-3/4° N60E Mud We i.ght..: B.0.P.s: 11.4 to 11.5// per gal. .. -' ":).?. Closed and opened on trip to check operations, . ;: ... , "~ "' ; i . ' i ',.': ->' ' CONFIDEi ITIAL ~8. I hereby certify that the foregoing is true an4 /. ,~ ., ,., uwen w. AKIns- -,..,' "CC'::-. ... ...... .. EN TI f,' Div. Dri I I l',ng Supt. 8/21/72 correct TITLE (This sptce for Fejl~r~ COIqDITION$ OF'~I~I'ROVd~'"IF TITLE eSee In~uctions on Reverie Side Form 9-331 (May 1963) HNITED STATES s..~,T ,., -L,CA~* (Other Instrt..:, ~s on re- DEPAR'I] "NT Of THE INTERIOR .e.es,Ue, GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use thl~ form for propo.qnl~ to drill or to deepen or plug back to a different reservoir, U~ "APPLICATION FOR PERMIT--" for such proposals,) OiL WELt~ L~ nAS W~LL [] OT,n Wildcat HAMS3 Or Oi~ERATOR Marathon O i I Company ~J~ ADDSES8 Or OPERATOR P. O. BoM ~§0; Anchora§e~ Alaska 99~10 LOCAT~O,~ or w~r.L (Report location clearly and in accordance with any State requirement8,* I~ee also space 17 below..) At su~rac~ 1700'S 660'W from NE Car. protracted Sec. 33, TTN, RIOW, SM Prop. Bottom Hole location: 1700'$ & 725'E from NW Car. Sec. 34, TTN, RIOW, SM (I,385' due E from Surf. loc.) 14. PRIt,~IIT ]~O. ] 15. teL~VATIOlqa (Show whether DP, RT. OR, etc.) 72-13 J GR 144.8' KB 164' 16. Form 8ppro?td, Budffet l~ureaa No. 42-R1424. LEASE DESIGNATION AND SERIAL !~O. A-028083 INDIAN, At, LOTTgE OR TRIal NAME 7. UNIT AGREEMENT NAME Beaver Creek Unit 8. fARM OR LEASE NAME Beaver Creek 9. WELL NO. No. 4 10. fIELD AND POOL, 0jt WILDCAT W i I dcat Il. rIEl.'., T., n., M,, OR BL~, Alql) RURYRT OR Anna Sec. 34, TTN, RIOW, SM .eOO~T~-,OR PARISHI 18. 8TATS enal ~enln, I · B.o. ro,ugh J AI asks Check Appropriate Box To Indicate Nature o[ Notice, Report, or Other Data .NOTICB 0~' INTENTION TO: FRACTI;RE TREAT MULTIPLS COMPLETE SHOOT OR ACIDIZB ABANDONS REPAIR WELL CIlANOR PLANS (Other) . SUBfIEqUEIqIT , REPORT OIP: J'RACTURE TREATMENT ALTgRIN~ CASINO 8H~TINO O~ACIDIZINO ABA~NMENTm (Other) Week ] y · NOTE: Report iesult8 of multiple eompletion on Well ompletlon or Reeompletlon Report and Log term.) IT. DESCRIDE I'IIOPOSED (Ill CO.%iPLET~D OPERATIONS (Clearly state fill pertinent details, and give pertinent dates, including estimated date of.startinw a.n~r proposed work· If well is dJrectionaily drilled, give subsurface locations and measured and true vertical depths for all markers tuna Sones p~ru- nent to this work.) · ....... . . · A_ugust 7, 1972 throu_g.h ,August 14, 1972 ' '- " '"' ' '; .... Ran turbo-drill and drilled from 8808 feet to 8858 feet, Chahged drilling:.asse~b.!,¥ end drllled 12-1/4" hole from 8858 feet to 9650 feet, Now drilling.ahead. ". /, .,,..:., . · ~'~,.:"": · ~ i. '. . ..'-., Formation: Shale, Sand, Clay and Coal Stringers. -.~ .~., Surveys: 8858'.-'3-1/2°, NI6E; 8904'-5-1/4°, N27E; 8982"6°, N27E;. 9'185'-7r-~/4°~'. N35E; 9360"-9-1/4°; N4OE; 9522"9-1/4°; N44E; 9636 '-9:3/4.0 ~ N46E." '" . i '. ,.;, ,3, . ' - ..~ , Mud__ .Weight: 11.4 to 11.5# per gal. ,'. ': B.O.P.s:' Tested Hy-dri'll with 1500~, ok and pipe rams with 45 k. '.'!' ::"-=~ - -- II Il ' "' 18. I hereby eertl~'~.b~ J~e tore¢olng 18 true and ~orreet CONFIDENTIAL' TX?La AcT'lng DIv. Drll, llng Supt,]. DATa 8-14-72 ~ [..~ 'FUbllq:Jl ..... (Thio sp~' f~r Fedsx~! or 8mte o~ nMI / ' ' ' "'' ' ' ' "' " · 'z o c, s 'AU'B 1 5 1972 APPROVED B TIT~ ,,, ' °~e In~ons on Revere Side ' ' ;'" ':' ~ '" IPorm J-3:J! (~a7 19G3! DEPA.{ 'IN ITED STATES s~nm? ~ ~ ' ~ ~C~ ~' (Other- Inr/ "~s on i.t,,. :NT OF THE INTERIOR verse ,,d,; ~ GI:'OLOGICAL SURVEY o,~w,~ [~ ~'*'wE~.. ~] o,,,., Wildcat ,......o.....o. P. O. Box 2380, Anchorage, Ak. 99510 SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for propo,qals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" ,~or-~uch propo~lL)'. ' · Porto approved. Bud;I_e_t_Bureau lqo. 42-1114~4 ~. I,RASII; DESIGNATION AND SI~IIAL NO. A-028083 ,' ~. IF INDIAN, ALLOTTIE St ?RIBI NAMI" LOCATION OF WELt, (Report location clearly and in accordance with any State requirements.* See also space 17 below.) iS · At surface 1700 660 'W from NE Cor protracted ' Sec. "33, T7N, R10W, SM Prop. Bottom Hole location: 1700'S & 725'E from NW Cor. Sec. 34, TTN, R10W, SM (1,385' due E from Surf. loc.) Beaver Creek Unit 8. FARM OR LKABE NAME Beaver'Creek ~: ~l~t~f~ #8: ,.. : .. NO. 4 ~ 14'. rrR..r so. 72-13 16. JlA. SLEYATTOHS (Show wheLber Dr, a?, nB. eta.) GR 144,8' KB 164' Checl~ Appropriate Box To indicate Nature of Notice, Report, or Other Data 10. FIELD AND POOL, oB WILDCAT !','.~ldc at , 11. SgC., t., a., M., 0" BLlt. 8URvB! OR ~i Sec. 34, T7i';, R10W, St, i 1~. COUNTY %R riA~aJ 13. Kenal ~enl~l. Borough' '*l'Alaska .'(OTICIi OF INTmN~TION TO: ' PAACT~;Ri~ TREAT ~IULTIPLB COMPLr. TR SHOOT OR Acmxzm AnANDON* REPAIR WiEL~ CIIANOS: PLAN8 (Other) JrRACTUILB TRmATMBNT , ',: ALTgRINO CASINO fjrlrOOTlNO OR ACIDIZINO ABANDONMENT® . (Other) _~eekly Re~Ot'~ HOTZ: Report results of multiple completion on Well ompletion or Recompletion Report and Log form.) it. DESCRIOg l'norosED OR CO~IPI. ETED OPERATIONS (Clearly state fill pertlne.t details, and give pertinent dates, Including estimated date of starting t~ pro~s~ work. If well is di~tlon~y drlli~, five au~ur~ace locations and mens. red and true vertic~ depths for all markers and sones ~rtL nent~iswor~)* ' ',' · ? ~ .i ' , ' ,.~ July 31, 197'2 through August 7, 1972 ,'" :' :' ~' ' ' ', Tagged top of cement at 8,772 feet and dressed off plug..."to 8,777 feet. Ran Turbo-Drill and drilled from 8,777 feet to 8,833 feet. Opened hole to 12-1/4 inches from 8,777 feet to 8,833 feet. Ran survey at 8,833 feet - 4", N16W. Ran drilling assembly and drilled, from"8,833'feet, to 8,878 feet. Ran survey at 8,878 feet - 1-1/4O, N60W '. . Rehran survey at 8,878 feet - 1-1/4O. Ran open ended drill pipe to 8,87.4 feet and cemente, with 255 sacks of Class "G". . Tagged top of hard cement at 8 654 feet and dressed plug to 8,~61' 'feet. Ran Turbo-Drill and drilled from 8,661,feet to 8,735 feet. Ran survey at 8,735 feet - 2-1/4", N36W. Opened hole to 12-1/4 inches from 8,661 'feet to 8,735 feet. Ran Turbo-Drill and drilled from...8,.~35 feet to 8,808 feet. Pulled out of hole to change bit. NOw rqnni~g TurbopDrill. " :" :' ~'i" :~:' !: Mud Weight'- 11.4 to 11.5# per gal. B;O.P.s - Tested IIy-Drill with 1,500#, O.K. ilS,' ,I h~reby certify ' ~e ~egolug la .true. and correct BIG)TED and pipe r~m~'wifh 4,500#, CONFIDENTIAL 0.] _/,_T~ ~ Fosher (Thll spd~e'~r Federal or State o~ce use) APPROVED ~' ~') ~OD~'~ CONDITIONS OF APPROVAL, IF *See Instructions on Reverse Side · /.'erin S-231 ' (MGy l'JG3) UNI'FED STATES s,,.~I? (Other I.~true' DEPARTr .... '~T OF ~HE INTERIOR SUNDRY NOTICES AND REPORTS ON WELLS (~o not u~e this form fei ~t,~,:ll~ t, drllT or to deep,n or plu~ b~ck to a dl~erent relervolr. Use "APP~ICATION FOR PERM~T~" for ~ueh p~po~s.) o,,..r.L~ I~l CA.w.;L~ l-] OT.E~ Wildcat 2.NAMR OF OP£aATOR Marathon Oil Company ADDRESS OF OPERATOR 14: rra.~,l~ ~o. P. O. Box 2380, Anehora~e~ A~a~ka S~ also space 17 below.} ~ · ~,,,e 1700 S 660 W from NE cDr. orotracted Sec. 33, T7N, R10W, SM ProD. Bottom Hole location: 1700'S & 725'E from NW cDr. Sec. 34, T7N, R10W, SM (1385' due E from Surf. loc.) ~AT~ONS (Show whether ~. 72-13 OR 144.8' KB 164' Form approved. lhJ,h;*t )~tlrcf~u ]~o. 42-R1424. .... ~. Li:ASE DE:~I~,NATION AND SERIAl, NO. A-028093 O. IF INDIAN, ALI,OTT£F, OR TRIBE NAME .. · '.: -'.. :?. .* · ..- .:: · ' - ~-' ,.;- ,~,-. ,' , : " -~ ~'- ~:/.-.~ .. i ~ .' ~. UNIT AGREEMENT NA~lm ."Beaver Creek Unit 8..rARe. Oa LEASE NAME.; 'Beaver Creek' :No, 4 5 .... '.' ~ Wildcat "-."'' 16. 11. sec., T., R., M., OR BT, E. SURVET O~ Sec. 34,. T7N', R10W, SM nal Pen~q .Borough. ! '.Alaska . Ch~k Appropriate Box To Indicate Nature of Notice, Report, or Ot~e, Data ' ? ~'~ '~;% ~ NO~ICI~ OY INTENTION TO: FRACTURE TRi:AT MULTIPLE COMPLETE B/lOOT OR ACIDIZB ARANDON. (Other) BUBSRQ~ENT REPORT 0~': ' ' -.. " I I FRACTURE TREATMENT SHOOTING OR ACIDIZINO] l[ J': :~ 'J ":.' ABANDONMENX~ Wee~ (Other) Iv~eoort (NOTE: Report results of nmltlple completion on Well Compiotlon or Recompletton Report and Log ~orm.) 1~'o I)ESCRIB[L: PROPOSED OR COMPLETED OPERATIoN.q (Clearlr state all nertine,t d,talls find give oertinent dates including estin]ated (late of a~rtlng any. proposed work. If well is di~tion~ly d' ' '" 'r " ' .... d th f I markers an n ....... , rdl~ g~ve s~s~face I~tmns and measured and true vertical ep .s or a.l .. . d zo es ~rtl- nentmtamwor~; ' A~tl~l~kl~lfll' ' . .;' ~ ;J ' ',- Julv 24 throuqh July 31, 1972. UUI VIUEI /I L = .... ' .~ a :.' U ~: -' ~ ~,.': ~6 ~ee~ an~ one .~o~n~ o~ 5-inch ~ti~ oi~e ~s six 8-~e~ DCs.an~ ~' .. ;. ~', ._. ~o~ o~ ~ish ~as eot~ ~etewe~ an~ eqg ~ha~e~, ran ~Z.~o' ~ess'-to~ ~h, tan ~o~en o~et ~hot, ~nab~e ~o qe~ o~er ~s~ ~.a~ o~en 'e~e~ d~ pi~e ~o 8,960 ~ee~, ee~en~e~ w~h ~80 sae~s o~a~s ~ ~ -' U ' ' ~agge~ ~o~ o~ ~ar~ ee~en~ a~ 8,785 ~ee~. ~-'~,:~:~ :-: ..... ~' 5 ~.. ~ ~ ~, .', .~ Ran multi-shot from 8,765 feet to bottom of 13-3/8 i~%h surface"' casing. Ran Eastman Gyro-survey from bottom of 13-3~8 'inch .surface every 200 feet to surface. ~.~:::;~ ~ ~ ~ ~.'.~ , ..r. - , ,. .. . -: ~ :' ..' Dre~se~ off cement ulug to 8,790 fee~. Ran Turbo-Dr~f and dri'~l~d from 8,790 feet to 8,931 fee~. Ran survey, showed we'would be'too close to too of fish. Ran o~en ended drill pipe to 8,926' feet." .Cemented with 180 ~ae~s, tvoe G, with 13 sacks of 10-20 Frac-san~. Cement ~n olace at 1 p.m., ~ulv 30, 1972. (See attached sheet)-;' 18. I hereby ce~y that the fo. regotng 15~%,a~4I COFFee.( 81G~; D ~%4~11 i', , t~i~- TITLE (This space for F~er~ or State APPROVED. B~, Sgd.) RODNEY ~ S~T~ , ~N~ITIONS OF Div. Drillin~ sUut$ '.'~a~j~ 7-'~I=7.2 ~,~ Oil k G~ Su~e~c~. ~ ..~ -~ ~ ~.1 --. ~.., t,~ ,. Insfludiofls off Reverie Side U.S. July 24, 1972 through Ju'ly 31, 1972 (Cont'd.) Mud weight_- 11.45' Der gal. B.O.P.s - Tested ]]v-drill with 1,5005, O,'K., and pipe rams to .... - 4,500#, O.K. Porto ~--,~ ~ 1 (May 19G3) 14. I~"'ITED STATES nFP,~R~'" ~T nF I'HE IN~rT~_. ~"~;'6q%~,~ ....... '~, '" '! ]1 ~ 'r r- SUNDkY NCslCcS AND Use "API'LICATION FOR fEI{MiT--" for such o.~ [] ~'*~ Wildcat '~£1,~ WLLL U OTHER NAME OP OI'ZRATOR Harathon Oil Company (~OlISlffV;,ItloII l)J'~ I.',it)tl U. ~ C P. O. Box 2380, Anchoracre, Alaska 99510 - I,OCXTION Or w£nt (Kt.p.~rt location clearly and In accordance with any State requirements.* See alsn space 17 belo',v.) At surface 1700 'S 660 'W from NE car. protracted Sec. 33, T7H, R10W, S~.I Prop. Bottom Hole location: 1700'S & 725'E from NW car. Sec. 34, T7N, R10W, SM (1385' due E from Surf. loc.) PgRMIT NO. 72-13 1,5. CLEVATION8 (Show whether vt, GR '1'44.8 ' 'KB 164 ' Form v pprov(-d. "5'TZ~-AS~',, s,,:~i?,i~ ,~o' ~/,ii7 ~o.- A-028083 .. 7. UNIT AGREEMENT NAMI; Beaver Creek Unit Beaver Creek. No'. 4 · · '-'1'0. I'IF. LD AND POOL, OR WILDCAT Wildcat .' . 11. S-~C., T., R., ~., OR BL£. AND SeC. 3zi , , R10W, SM [2. Cot;,~'r¥ ~:t PAI;l,qlJI 13. kenax t c:t'.xn ~ . '. F.,orou~!h .I Alaska Check Appropriate Box To ladicate Nature o1: Nolice: Report., or O~her Data :~o,xc~ o~ ,t~T.,~T,O.'., ~o: TEST WA~R B~UT-OFF PULL OR ALTER CASINO FRACTURE TREAT MULTIPI,~1tO.MPI,ETE BHOOT OR ACIDIZ~ ABANDON~ (Other) · I~UBSgQUI:.%'T RI~PORT Ol~.: -. FRACTURE TREATMENT ' { [ ' . .' '? AI,~RINO C~INC 8~OOTING OR ACIDIZINO { [ . ABANDONMENT~ Weekly~port' · .: .-., No~: Re~ort reaults of multiple conmleilon ~n Well ompletlon or i~ecompletir, n It..port arid I,og form.) 1~. DESf'I'.III}: PROPOSED On COMI'LETEO OPClIATTONg (CleLIr]y state nil pertluent dotails, and ~ivo pertinent dates. IneludhJ;: esthnatvd d.n te of st,irtlng prolmscd work. If well is dircctignally dritlcd, give subsurface locations and meashrcd and true vertical depths.for ail markers and zones pertl. ncnt to this work.) * '.: " ,.'.. · ~..! z : ~., ";j " · . .. % ,, July· 17 through July 2 4 a ,,' ._ .:..: ,, .':'.' ..'.':: ....x a_. ~, : .- ." .. '-. ~, i, : :'~: · - ' ~.:' .2 · .. ':,. · .... ; · ' ~ '~ Drilled 12--1/4 inch hole from 8,905' to :':-.:- '" ;~.~.~ ,. '" "..~ ':; 2 f!. '..~ ...... - ~ '-."2 Format£on - Shale, Sand, Clay, and Coal : .... · .. . 'Surveys @ 9,196' - 2-1/4~ 9 356' - 2° 9,65b' '.~ 2~-' I ~ I .. · c'.' .' ~' '7 :'!:~' :'. .: ~. :: .. .. . -. rams' w/4,'5005 - .. .... -- .': ~.. t? ;- .- .' ' Remarks - l,~hiie drilling.ak 9,754', 'one jet in the bit be'came .~'].6gged. Driller picked up off bottom 60' and drill line parted 142' from.rig floor dropping kelly and swivel. Restrung drilling line and picked up, drilling string at 6 a.m., July 24, 1972, the drilling strin9 weighed 230,000~ when drilling stopped after being dropped,-Lhe: weight was 162,000# indicating drill string in two. :~,~.:.:--:- .. ~.-[~:::.. · ', !?... 'c: '.: :':.- ~ .:.,. ~.=, ~. ,' "; =' ': t~ -. · . ,:~ ,. '.'.':'-:' ~. - .... :, ..: E., .... ~.~ ;," -' ~ :' -- bUl lrl UEPt/laL ;,'."' ;; ~'."": ': .5 '~ -f o c '- '; '; ~, :..- -: ..;~ =..-, ~:~'..,:- 9,754' :.. Stringers '~.~- 9,515' - .2°, · Mud Weight- 11.41[ per gallon~ ~.O.P.s tested tly-drill w/1,500~. - O.K. Tested pipe' .O.K. Test witnessed 'by Mr. Wannick w/U.S.G.S. · 18. I hercb$ certify that the foregoing is true and correct 8IGI~,'EI~ _,. ,_ .Ovzan__W,._ -Aki~-g Div. Dril. linq. Supt.~ ' r,x?s :?7--2:4':72 (This space for Federal or Slate olllce use)// ".APpROvED B~~~/~ ,. .CONDITIONS ~' APP'ItOVAI,. IF ANY: · · !972 ., TITLE '---- ~'~,Q/%[~'~,,.~.t~'~,' ,'%.t '{Jli~ = . '" , '.. ' ....... .':..:.: z, *See [.~.~lons on , ( MARATHON OIL COMPANY PRODUCTION-UNITED STATES AND CANADA ANCHORAGE OIVISION P,O. BOX 2380 ANCHORAGE,ALASKA 99510 RECEIVED OF HARATtlON OIL COf,IPA~IY One Set of Washed Ditch Samples from the Beaver Creek Unit I'lo. 4. Well from 280 ft. to 7390 ft. Form 1-331 (May 1963) DEF'A~ 'INITED STATES s,.,.m? ~." (Other Inet, tENT OF THE INTERIOR ,e,.e side) ( GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such propozals.) O,L k----] CA. ~] uT... Wildcat WELL WELL ~. NAMil OF OPERATOR Marathon Oil Company ADDRESS Or OPIiRATOa P. O. Box 2380r Anchorage, Alaska 99510 4. LOCATION Or wr, Ll, (Report location clearly and in accordance with any State requirements.® See also space 17 below.) *t..rface 1700'S 660'W from NE cur. protracted Sec. 33, T7N, R10W, SM Prop. Bottom Hole Location: 1700'S & 725'E from NW cur. Sec. 34, T7N, R10W, SM (1385' due E from Surf. loc.) 14. PERMIT NO. 15. ELEVATIONS (Show whether M', RT, OR. et~.) 72-13 GR 144.8' KB 164' Form approved. lhtdget llur~,au No. 42-R142' 5. LEAgF, DESIGNATION AND SERIAL A-028083 6. IF INDIAN, ALLOTTJ~E OR TRIBE NAM! 7. UNIT AORZEMENT NAMB Beaver Creek Unit 8. FAR'.1 OR LEASE NAMS Beaver Creek 9. WELL NO, No. 4 10. fIELD AND POOr', OII WibDCAT 'Wildcat 11. flee., T., u., M., oR BLK. AND SURVEY OR A~EA Sec'. 34, T7N, RiOW, SM 12. COUNTY o- PARISHt 13. STATE Kenai PeniS. Borouah | Alamka _- 16. Check' Appropriate Box To Indicate Nature of Notice, Report, or Other Data · *qOTICB Or iNXl~NTION N: FRACTGRS TREAT MULTIPLIO COMPLETI~ SHOOT OR ACIDIZS ABANDON® REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT R~POBT. O1': J'RACTURB TREATMENT [ [' ALTERING CASING flHOOTINO OR ACIDlY-lNG L___] ABANDONMENTS (Other) Weekly Report NoTs: Report results of multiple completion on Well ompletlon or Reeompletion Report and Log form.) IT. DY. SCalar I'noPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting proposed work. If well is dlrectionally drilled, save subsurface locations and meastlred and true vertical depths for all markers and sones imrt nent to this'work.) ® ' :':' ' h' . '.':' ~' '"" ' ' ~-" ., July 10, 1972 through July 17, 1972 Drilled 12-1/4" hole from 7,952' to 8,905'. Formation - Shale, Sand, Clay and Coal Stringers. Surveys @ 7,995 - 1-1/2°, 8,163' - 1-1/2°, 8,336' 8,674' - 1-3/4°, 8,801' - 2-3/4°. Mud Weight - 11.3#.to 11.5% per gal. B.O.P. - Checked.and crew Performed a B.O.P~ ,, 18. I hereby eert_[fy that the foregoing is true and correct ' 5 ' BIGN'~D -- . .~.. · TITLn , :' 7-17'7 2 (~,./e.,n W. AKzns . . Div. Drillino Supt. , ,.. :., ..., ;... UE...,.:1'..9 1972. ~mo.. 6Ff.~~ ~ ~; ' . ,, . -. Form J-331 ')NITED STATES (Other Ii,,~* on r~- DEP( lENT OF THE INTERIOR GEOLOGI~A~V~ r .... ~ SUNDRY NOTICES A~d-]~EPORTS:'~N (Do not use this form for propo~nl~ to drlll~ ~ doepPn or plu~ back to a dl~e~pt~ervolr. U~ "APPLICATION FOR ~E~IIT--" for ~uch p~po~) . , .UL ~ 2. 'NAME orr OPERATOR C,);,$,..rv~d:i(In l')ivi~:ion Marathon Oil Company .U.S. G[6OLOC]C..\I, SU~V~ '8, ADDRESS or OPERATOR ~lal~tfigc~ A'~ka P. O. BOx 2380, Anchorage, Alask~ 99510 4. LOCATION OP' WELL (Report location clearly and la accordance with any State requirements.· See also space 17 below.) Atsu,~acc 1700'S 660'W from NE cor. orotracted Sec. 33, T7N, R10W, SM Prop. Bottom Hole Location: 1700'S & 725'E from NW cor. Sec. 34, T7N, R10W, SM (1385' due E from Surf loc.) 14. FERMIT NO. I 15. ELEVATmNS (Show whether Dr, RT, GP~ etc.) 72-13 J GR 144.8' KB 164' Form approved. Budget llureau ~fo. 42-R14 5. LtASE DE~ql6NATiON AND SKBIAL N~ A-028083 INDIAN, ALLOTTEE OR TRIBE ?. UNIT AGREEMENT NAMR Beaver Creek Unit 8. FARM O~ LEASE NAME :Beaver Creek ~. WKLL NO. NO. 4 10. FIELD AND Poor,, OR WILDCAT .Wi id cat ll. REC., T., st., M., OR BT.K. AN1) Sec. 34, T7N, R]OW. SH Kenai Peninl. Borou=h I .Ala~k~ FRACTURE TREAT RHOOT OR ACIDIZB REPAIR WELL (Other) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data ~OTICB OF INTENTION TO: TEST WATER SHUT-GIT ~'~ FULL OR ALTER CASINO MULTIPLE CUM PI.ETIq ABANDON' CllANGE PLANE WATER SHUT*OFF I I~ ' ' ~ REPAIRING WELL FRACTURE TREATMENT ] I · ALTERING CARING SHOOTINg OR ACIDIZiNO L_~ ABANDONMENTS , , (Other) WeeklV Letter NOTE: Report results of multiple completion on Well ompletlon or Recompletion Report and Lo~ form.) DESCRIBE I'BOPOSED OB COMPLETED OPERATIONS (Clearly state all pertineut details, and give pertinent dates, including estimated date of starting proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depth8 for ali markers and tones p~ Bent to thin work.) * , ~ ,, 7/4/72 Drilling 12-1/4" hole @ 6825' mud wt. 11.4# per"gal. Formation sand and shale. ":: 7/5/72 Drilling 12-1/4" hole @ 6975' mud wt. 11.4'~ per gal~. Formation sand and shale. Survey @ 6873' ' 1-1/4°.,. ~ 7/6/72 Drilling 12-1/4" hole @ 7112' mud wt. 11.4# per gal. .-.'.~ . . Formation sand and shale. Survey @ 7112' - 1/2°. '" .' Tested Hy-Drill to 1500# - test O.K. Tested B.O.P. 't0..i'~'.. 4700# - tested O.K. ' .. : '., 7/7/72 Drilling 12-1/4" hole @ 7333' mud wt~ 11.4# ~er gal'.' ~.....: Formation sand, shale and coal. Survey @ 7333"- 1°. '.:. · · 7/8/72 Depth - 7548' mud wt. ll 5# per gal ~ormation sand,,._ .... shale and coal· ,." ..." 7/9/72 Depth - 7745' mud wt. ll.5#,per gal. Formation sand,, : shale and co~l SUrvey @ 7745' - 2°. 7/10/72 Depth - 7952' mud wt. 11.4# per gal. Formation' sand,. , shale and coal' '. E N 18. I hereby eertl/y that the foregoing Is true and correct SNOrED-Owen-%;. PAins ~,XL~ Div. Drillihg Supt. oaTS-7710/72 co~vmo~s ~~b~ ~ ~: ...... r, ~. :; .: :~ ,. : ; '.- ':, · :, .. · ~e In~dlons on Reve~ Side "' Form J-~33 I (May 1063) DEPAF{ 'INITED STATES (Other InstJ,,,. '-,-~s on re- £NT OF THE INTERIOR ...,,,de) ( . GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different res~rvolr. Use "APPLICATION FOR PERMIT--" for such proposals.) .O'..EL,. '[X-----q ~'*',,-,L~, Fl o~.z. Wildcat ~AM~ OF OPERATOR Marathon Oil Company 8'~ADDRESS OF OPi;BATOR · P. O. Box ~-380, Anchorage, Alaska 99510 dj.LOCATION 01' WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) At,urface 1700"S 660'W from NE CDr. protracted Sec. 33, T7N, R10W, SM ProD. Bottom Hole Location: 1700'S & 725'E from NW cDr. Sec. 34, T7N, R10W, SM (1385' due E from Surf. loc.) 14. PERMIT NO. 72-13 16. Form approved. Budget Bureau No. 42-R1424. 5. LEASE DE$1ONATION AND SERiaL NO, A-028083 IF INDIAN, ALLOI-rRg OR TRIBE NAME; UNIT AOREr.XlgNT NAM~ Beaver Creek Unit 8. FARM OR LgA~tR NAME Be aver Creek 9, WRLL No. 4 10. FIELD AND PODIa, OR WI?.DCAT Wi ldcat 11. sEC., T., a., al., Da BZ)K. AI~'D SUR¥IIY OR ~A Sec. 34, T7N, ,RiOW t SM 15. EL~VA?IONS (Show whether m', RT, o~, etc.) ..12. cov;ITr_.oa P~/usa I 13. STATE ~ena~ Fen~n.I GR 144.8' KB 164' Borough I ~Alaska_ Check Appropriate Box To Indicate Nature of Notice, Report, or Other D~ta i~OTICI O)~ INTRNTION TO: FRACTURE TREAT MULTIPL~ COMPLETE SHOOT OR ACIDIZB ABANDON* · (Other) RUBSZqggNT RB~ORT or: WATgn EitUT.OFr ~-_~--1 ." ' : REPASS,NO WlILL r'.~-- (Other), (No~E: Report results of ~l~l~comsletiou on We~ Completion or Recompletion Report and Log form.) DESCRIBE I'ROPOSED oR COMPLETED OPERATIONS (Clearly state nil pertinent details, and give pertinent dates.' including estimated date of starting proposed work. If well is dir~ctJonally drilled, give subsurface loc~tion8 and measured and true vertical depths for nil markers and stones p~rti. nent to this work) * ' July' 7, 1972 We had originallv planned .to set 2,200 fe~t of casing on the Beaver Creek Well No. 4. After we decided it would be better to 'set 13-3/8 inch surface' deeper; " Therefore, we set 13-3./8 inch surface at 2,988 feet and cemented" with a total of 2,300 sacks of cement. Cement di~ circulate to surface. The above procedure was discussed with Mr. :.Bill Warneke' · . · *. . .. : ;- .-: .~ '..~ :.", . .,, :..:-' .. · ...,- ... ., =..-. ' .~.'. .. .... 2~ :... ,'..', , , ] .',<-.-;?.: ~?,. ~:-,,:, ,.-.,:¥,> c.~,..'- :..'I /'$i":,'. l lf;::i . .... - '~ .- :, ! .;,. I,:..-}~"::~:.~-'- :,. :::. i:..'. ,': . ' ,.-, , ? '. ~" ~. U, a.,~; ;,:. ::.:"" ' :: :' ...., _,<"".-.~ · '/:'.=.': ~i:: .:.' .... '_;,." ':'" . ! .. 13-3/8 inch surface. ':' further consideration,' ¥8.' I hereby certify that the foregoing is true .and eolreet Owen ~;. Akin-.~ ~ZTL~ Div. Drilling Supt. _, DA~]~. 7-7-72 . .. -" J U L i 0 i97 - - - L' -'~ '~ ':' i ....L c- 3'.-. ,¢. *See In~u~ions on Revme Side , Form 9-331 (May 1963) IITED STA'rES st, n:.fzT z~ ~ (Other lnstrt~,," on re- DEPAR( ;T OF THE INTERIOR ,cr,c.,,e) ( ~ GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen,~r-T~ug .bsck~.~ R-~ll~enfft ~'e~erFblY~ U~"APPLICATION FOR PER~IT~" lo~.~U~l ~ ~ ~ ~s.)~r, ....:"" .' ~': '. ~ ~ WELL ~ .,.. o, o..,o, jUL 6 1972 Flarathon 0~1 Company P.0. ~ox 2380, Anchorage, Alaska 4. LOCATION OF WELL (Report location clearly and In accordance with any $~te~emen~.~.~ S~ also spa~ 17 below.) ..... At surface 1709'5 550'~I rrm ~4i car. protracted Sec. 33, TT~,~lO~,~1 · ~ 725' ~ fro~ ~ car. Prop. Bottom Hole LocaUon. 1700'S , _ Sec. 34, T7~I,R10W,SH (13~5'Due E fro~ Surf. loc.) Form approved. Budget Bureau No. 42-R1424. . 0.2~fiB 3 I~'~NDIAN, ALLOTTEE oa TalBE NAME ?. UNIT AGREE~IENT N~ME Beaver Creek Untt 8. rAR~i OR LEASE NAL~ Beaver Creek 9, WELL NO. . · No. 4 10. FIELD AND POOL~, OR WILDCAT ".Wildcat 14. Pzn~nT No. 15. ~.L~.VArIO~¢9 (Show whether DP, ET, O~, etc.) . 72-13 GR 144.8' KB 164' Checlc Appropriate Box To Indicate Nature of Notice, Repofl, or Other Data NOTIC~ O~ INTINTION ~: MULTIPLE COMPLETE ABANDON* CHANG~ FRACTURE TREAT SHOOT OR ACIDIZS REPAIR WELL (Other) HUBSBQUENT REPORT 0~:, " . '" RE. PAIRINO WELL · FRACTURE TREATMENT A{,TERIN0 CAMINO 8HOOTING on ACIDIZINO AR~NDONMI:NTe (Other) l~eeklv Repo~t . "'- o~z: ~eport results d mulUNe eomDleUoa oa W~ ompleUon or ~ecompletlon ~eport and ~o~ form.) 17. v~sc~:n,: i,aoPosrn on CO5IPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date* of starting any proposed work. If well is directionally drilled, give subs~ace I~tions and measured and true vertic~ depths for all markers and Sones ~rtl- nent ~ ~ts work.) * - ',':: 6/13/72 Drove 30" drive p~pe ~o 6/14/72 6/15/72 6/19/72 6/21/72 6/22/72 6/26/72 6/29/72 6/30/72 7/3/72 ' Dri 11 ed to 296' Ran 20" casing to 288' K.B. cmtd with 740 sks Drilling 17-1/2" hole at 2452' Drilled 17-1/2" hole to 2996' Ran 13-3/8" csg to' 2989' cmtd with 2,000 $k$ Drilling 12-1/4" hble at 3886' Drilled 12-1/4" hole to 5761' Logging Drilling 12-1/4' hole at 6788 c tff :~ . o t s tru nd correct 18. I hereby .-.----.----- TITLE Dtv, Drtlltng Suot. A~I'INC OIL & CAS S~-PEn,-oA; .,.o~,, : - ':' '- TITLE AT *orr, .... * : ~ DA~ · See Ins~u~lons on Revere Side Form (May 1963) ~..""ITED STATES (Other lnstru~ '~ on re- DEPARI{ _.qT OF THE INTERIOR ,cr,e,,de) i -- GEOLOGICAL SURVEY SUNDRY NOT!CEa AND REPORTS ON WELLS_ (Do not use this form for propo, als to drill or to deepea'"'o'r phtg'l)~cJ~-~o'~ dlff~nt r~servoir. U~ "APPLICATION FOR PERMIT--" ~for such p~po~s.)- .~,~ ~ ~%~ ~ o,,,, Wildcat [ ~A~B Or OPERATOR ~UL U 2~1~ Marathon 0tl C~pany P. O. Box 2380, Anchorage, Alaska 995.]~;.c'''' .... ~ ...... " ~oclt~oN o~ wsb~ (Report location clearl~ and tu accordance with any ~ ~a[~t~.';'A S~ also sDace 11 below.) At surlace 170O'S 660't'~ from NE car. protracted Sec. 33, T7N,RIOW,91 proposed Bottom Hole Location 1700'S & 725'E fr~n I.!U car. Sec. 34, T7N,~lO~l,S;.I(1385' Due E from surf. loc) 14. PERMIT NO. 72-13 16. 15. ELEVATIONS (Show whether DJ'. RT. oR, et~.) GR 144. D' KB 164' Form approved. BRidget Bureau No. 42--R1424. LEASI~ DESIGNATION AND Bt;RIAL A-028Qa3.~ · IF INDIAN, ALLOTTg~ OR T~IBg NAMg Denver Cra~kS'Unt t Beawv Cr°~k.. :'"rio.. 4' -- 10. rl~Ln kND POOL, Oa '~ Sec. ~, 1711,R10W,~,l · 12- COU~T~ o~ PARIsHi · Kenai Penin.I Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data lqOTlCm OF INT1ONTION ~: 13. B~AT~ Alaska _ FRACTURe, TRI~AT MULTIPLB COMFhET~, (Other) DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clenrly state nil pertinent details, and give pertinent dates, Including estimated date of 8~rting any pro~s~ work. If well ia dl~gov~y drlll~ ~lvm n~n~ ~ons and meamtred*and true vertie~ depths for nil markers and sones ~rti- nest ~ ~im ~r~) * " ",~ ... --, 18. I hereby el~3ry/tff~t~ff~/foregoing ts ~ue and correct , o. om **s su=msoa ....[ - 6 i972 *he InfuSions on Reverie Side , · . , ', . , MARATHON OIL COMPANY PRODUCTION-UNITED STATES AND CANADA ANCHORA(TM DIVISl0N April 18, 1972 State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Gentlemen' Re' Beaver Creek Unit #4 Permit No. 72-13 I~.O. BOX ANCHORAGE,ALASKA 99~10 In accordance with your letter of Harch 20, 1972, forwarded herewith in triplicate is registered surveyor's plat of the proposed Beaver Creek #4 well location. Also enclosed in triplicate is plat showing the proposed location in relation to previously completed wells within the Beaver Creek Unit. Very truly yours, ~L~. 0 Li.L~~owma~ Senior Landman APR 1 9 1972 DIVISION OF OIL AND GAS MLL' lj A-173 o A-O28149 A-144 J_ A-028120 A---72 A-028078 28 A-74 A-028084 MARATHON- U N ION ! I I I I A-84 A-028083 --- ". PROPOSED LOCATION "BEAVER CRK. UN." No. 4 T7N. R IOW T6N R IOW UNLEASED 27 I ! ! ! I I I I. I i ! i L -,-- --'" ""! $ I i ! ! i ! I A ]/I,"~ ___ - ~-o2~ i · 1- --- r - %--' I i ! I PARTIC I PATI N G UNLEASED BEAVER CREEl< UNIT Scole I"= 2000' Dw .~o. !0226 SEC TION 55 PROTRACTED 28 55 27 54 ~...~Y : 2,4 35, 215. 8O X = $15~851.55 SEC TION 34 PROTRACTED IZ17i o I o , ~,2:'-"" - -- _L B.C.U. N O. ,3 _ /, -- ---2~y:2.455,897.5 // .' ~ .~ . ,, APR ~ 9 197~ ~ ~/~1 , DIVISION OF O11. AND GAS LEGEND AND NOTES: Found existing Well. New Well location (set spike in log) All bearings refer to Grid North. X' and Y values (;re State p/one coordinates for Zone 4. Y : 2,45 0,065.9 X : 514,417.7 MARATHON Oil_ CO. OPERATOR BEAVER CREEK UNIT NO. ~ SITU/~TED WEST FROM SEC.33, T TN, RIOW, S.M.,AK. SURVEYED BY- S.S. Mc Lane 1700 FT. SO. AND 660 FT. NE COR. OF PROTRACTED DATE OF SURVEY I SCALE March 29, 1972 L I"=. 600' R.L.S. BK. ~ver Creek Uni~' No. 4 Har'~thon Oil Co~an¥ Per~l~ No. 72-13 ;:~arathon OI 1 Comp.any P. O. Box 23~3. Anchor~je, Alaska 99501 E~closed Is t~e approved apptlca, ion for pe~,~t, ,o drill the aSove .referenced ~et t, on or .abou, ^prl t 1, t972,, a, a locafion 1700 '~ $.., 650'~ W.. fr~ ~':~£ .corner p.ro, rac~ed Sec, ton 3.~ To~:nship 7 Norfh, Range !0 ~es,, S. ~.~. ~elt samples end core chips are required. A directional survey ls required. A res I stared surveyor ? s p t at f s requ 1 red ,. Haay rivers In Alaska. and ~hetr .draln~..e sy$~a.ms have been classified es lmporta~,~, for the sp~nln9 or migration of ~adr.~s fish. Op.e:r~tlons. ~ese areas are s.ub~ec,' to AS 16,05.87:0 and *he m~3uta, tons p.~).ul~a~ed under (Title 5~ Al~ka Admlnts'fra~lve Code). Prior fo ~ncln9 operaft~s ~u aay be ~n:tacfed by tt~e Habitat C~.~dinator~s off[~, [~par,~n, of Fish and tn the even? of suspension or ab'andon~,~n~, please £~.i've 'this offic~ adequate advance notification so thaf w,~ ~,~ay have a .~'!~ness present.,, Very tr. l y yours, ~-k~er L. ~urre, l: t, Chai~an ^LASK,A OIL ^ND GAS ,~,JHSERVAT Eric I osure MARATHON OIL COMPANY PRODUCTION-UNITED STATES AND CANADA AN (CH OI~AGF= nlVISlON March 6, 1972 State of Alaska Division of Oil and Gas 3001 Porcupine Road Anchorage, Alaska 99501 Gentlemen: Re: Beaver Creek Unit #4 Well Forwarded herewith in triplicate is Application for Permit to Drill Beaver Creek Unit #4 Well whose surface location will be in Section 33, T. 7 N., R. 10 W., S.M. Also enclosed herewith is Marathon's check #5065 in the amount of $100.00 as filing fee for Permit to Drill. Very truly yours, MARATHON OIL C Morris L. Lowman Senior Landman MLL: lj Enclosures SUBMIT IN TRIi' '?ATE Form P--1 STATE OF ALASKA P I~ ~g ~50- I 33-20239 ~ ~ · '~,, ,~,~ OIL AND GAS CONSE~VA,TION ,COMMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR [[~'~'~ ' ,'~,A~028083-...~ ~,, .~ ,-,,,..... DRILL ~ DEEPEN ~ PLUG B~~'~' .... b. TYPE OF WELL W~:LL W!~r, O'1'~ ER gONg ZONE 2. NAME OF OPERATOR Harathon 0il Company ADDRESS lYF OPERATOR P. O. Box 2380, Anchorage, Alaska 99501 8. UNIT, FARM OR LEASE NAME Beaver Creek Unit 9. WELL NO. No. 4 10. FIELD AND POOL, OR WILDCAT 4. LOCATION OF WELL I W Atsur,ace 1700'S, 660 from NE corner protracted Sec. 33, T7N, At proposed prod. SMHemlock Formation 1700'S, 660'E from NW cur. protracted Sec. 24, T7N,RIOW,SM 13. DISTANCE IN MILES AND DIRECT,'ON F~OM NEAREST TOWN OR POST OFFIC,~* ll miles northeast from Kenai, Alaska R~av~_r Creek Gas 11. SEC., T,, R., ]Mi., (BO"Iq~O1VI HOLE OBJECTIVE) Sec. 34 T7N,RIOW,SM 12. 14. BOND INFORMATION: U.S. Nationwide TYPE Surety a.d/or No. NO. 554979 15. DISTANCE FROM PROPOSED* LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. 3700 ft ' (Als,o to nearest drig, unit, if any) ' 18. DISTANCE FROM PROPOSED LO.CATION* TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 3100 ft. from ]-h The Ohio Casual ty Company '116. NO. OF ACRES IN LEASE t 2560 19. P'ROPOSEID DEPTH 15,700 DD, 21. ELEVATIONS (Show whether DF, RT, C-R, etc.) 23. P~O'P'OSE'D CASING AND CEMENTING PROGRAM ,~o,,,,, $150,000. O0 17, NO. ACRES ASSIGNED TO THiS WELL 160.00 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START* April 1, 1972 SIZE OF I-IOLE., m] SIZE OF CASING WEIGHT PER FOOT GRAI)E SETTING DEPTH QUANTITY. OF CEMENT ,, . '26" 20" 94# H-'40 280' 40'0 s'i~'s .... -.,. 17~" 13-3/8. 68 & .72# J:55,,N 80 2200' 1600 sks .. l.~" . 9-5/8 .40,43~.47,53:~ RS-9~ 12600' 35Q.O..Sks .. · a-2/a" , 7"liner 32~/ P-110 12400"15700 500 s'ks Blowout Preventer'Program- Install 20",2000# hydril atop 20" casinghead, with 4" flanged outlets on mud spool & 2 relief lines while drilling to 2000'. Test hydril to 1000 psig.. Install & test 13-5/8" 5000 psig Cameron type U double gate, plus 13-5/8" 5000 psig hydril & 5000 psig choke manifold & kill line with 3000 psig after 13-5/8" csg is set. Same BOP hookup, for 9-5/8", te~t same with 5000 psig. Use same BOP's for 7" liner. Proposed bottom hole location' 1700' south & 725 east from NW cur. Sec. 34, T7N, RIOW, SM (1385'due east from surface loc.) IN ABOVE SPACE DESCRIBE PRO,POSED PROGIq,A/V~: If pro,posal is to deepen o.r plug back, give data o,n present produ,cttve zone arid proposed r~ew productive zone. If pro,posal is ~o drill or deepen direc,l ~onally, give pertinent data on s~bsurface l~cations and rneasure~ and true vertical depths. Give blowout preventer program. 24. I hereby certify that the Foregoing ts True anO Correct ,, a ~ ! ' ,,, ,~/ (This space for State office use) CONDITIONS OF APPROVAL, IF ANY: [SAMPLES AND CORE CHIPS REQUIF,~ED ~(YES [] NO [ DIRE~fTIONAL SURVEY REQUIRED ES [] NO APPROVED BY-- . -/~"~ *See In.ructions On Revere Side O'I'I-~ P, EQUIREMENTS: SEE TRANSMITTAL LETTER A.P.I. NTIMIKRICAL CODE March 20. 1972 ~A~ March 20, 1972 Apf:ro,/ed Copy ~Rei'urned ~.. ~ -, 221 25"; OiL CO., O?~'"RA'FOR -<- 2 7 2 2O 29 :52 5 , 34 35 16 I0 15 24¸ ,,~ 25i.: 'i: :: '; ,! Ii 13 2~ ,.. ; ( } ,-omtiãhý ..- ~rt7 -Alr~1-1 - -- .-- . LedSe '! ..r . No. ße:¡.vev(lrr2f?t:: ilvr';f #¿¡. 1. , ~ ," , 2. PERMITS \ c.' EOt Yes No :i.eî;¡d ~S \ C. £N~, \ - - - ,- \ 1 H~G \ ØùK \ 2 tNG \. . ~ - '.. . \ "3r~.JG .l.' Do statewide rules apply. . . . . . . . . . . . . ... \.4tN~ t . .ffi.JK - - . , \ '-S-ENG \- // . /' . / ~ 3. Is a registered survey plat attached. . . . . . . . . . . \.1 t7F.~ 1 ~-, . . - /ltJK- ((e,4-C//rec:f - \ 2 G~OL " {/i 4. Is well located proper distance from property line. . . . '. 3.Gtt>~. . . #Uk( - -: , LREV',-- OK -fôY 01/ ¿:.;p// V!t:¡,/llell located proper distance fran other wells. . . . .toRA~l:::'" II(J~ - (./vp-/- Jk #r--V~.tdL)" 6;) Is sufficient undedicated acreage available in this pool '~ESREC. '. . Jft.ðf<. CONF : - - 7 I 11 t b d . ted - FILE: '" . s we 0 e eVl a ................. . . . . ,Io/eJK -- CHECK 1 IS r Is well to be located in a defined pool. . . . . . . . . .- ~ --'" ... ""',- 8. Is operator the only affected party. . . . . . . . . . . . . . . . . . . ~~ --- ,t. Can penn; t be approved before ten-day wai t . . . . . . . . . . . . . . . ~J( :£,;*~;"'sr;y "', , "" ' "~'- - ~'O. Does 'operator h'ave a bond in force. . . . . . . . . . . . .. . . . . . . #t1J/(. - <,,11. Is conductor string provided. . . . . . . . . . . . . . . . . . . . . . /;t! - . 'i~,1,2. Is enough cement used to circulate on conductor and surface. .'. . ~' . jj - .' . Ii . l¿) - -- .IJi'¡':S. Will surfãce cas i ng cover all fresh water zones. . . . . . . . . . . . /11;) "",:o' ,--",- f:~;, i:::: :~~:: i ::9 ~i ::t:::~::~:f:::a : n . :0 :: :~::. a:: :::: i ::r~ n~ : : : : f ' ';o'¡,;;'I'~ji'",,", .. ,', ,.,,' ',c": '" '" "" ' Îf- _Does !lOPE have SUffiCi;:~l ¡r,essure rating. . . . . . . . . . . . . . . Ji11- -,-- -<-~~, ,.f' ',,4 '" -' ~J ~ fA f- 0/> I ""' JI..l.t.", ~) *.:.L....A"... ~d1;,- ""y~"'1 . . - HWIt..~AÇ , ~ s c "M . ~~.-.::.,~,~~ ~~"1"=~~~~._~----~_.- --" .r."- . p.11cement 'tie in surface ~nd intermediate or production strings. " ". .1./ l'l..f(11 cement cover all possibleproductlve horizons. . . . . . . . . . " "" 4>- _c.
