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Home My WebLink About169-011STATE OF ALASKA ~ ~.~~/~-s• c ~ ALASKA L AND GAS CONSERVATION COMMISSI~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: Oil ~ Gas ~ Plugged ~ Abandoned ~ Suspended ~ 20AAC 25.105 • 20AAC 25.110 GINJ^ WINJ^ WDSPL^ WAG^ Other^ No.ofCompletions: 1 b. Well Class: pevelopment ~• Exploratory [] 5ervice ^ StratigraphicTest~ 2. Operator Name: Marathon Alaska Production, LLC 5. Date mp., Susp., or Aband.:' 8/4/2009 • 12. Permit to Drill Number: 169-011 ~~Q ... ~ ~~ 3. Address P.O. Box 196168, Anchorage, AK 99519-3043 6. Date Spudded: 1/30/1969 13. API Number: 50-733-20175-00-00 ~ 4a. Location of Well (Governmental Section): Surface: 2613' F~qL, 2495' FEL, Sec. 26, T10N, R13W, SM • 7. Date TD Reached: 3/5/1969 14. Well Name and Number: North Trading 8ay Unit S-03 . Top of Productive HorizorY AG~ ~ 9~g~i ~, C7' "" `~ ~ 8. KB (ft above MSL): 115 Ground (ft MSL): 15. Field/Pool(s): Total Depth: 2031' FSL, 4627' FEL, Sec. 26, T10N, R13W, SM 9. Plug Back Depth(MD+TVD): 172 WLM, 57 BML G-NE/Hemlock-NE Oil . 4b. Location of Well (State Base Plane Coordinates, NAD 27): d1JIJ Surface~~ ax-*~F~~~47117~ C~~59~~t~#b~9,9,yq~! Zone-~~/ TPI: (~`~~1 x- ~~ 7~~ ~ ~i- 5'~y ~~ Zone- 7 Total Depth:~ x- -~~f~9~68~84 - . ~ Zone- 10. Total Depth (MD + TVD): . 10541 MD, 10127 TVD • 11. SSSV Depth (MD + TVD): 16. Properry Designation: ADL0035431 - 17. Land Use Permit: 18. Directional Survey: Yes ~ No ~ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: 60 (ft MSL) 20. Thickness of Permafrost (TVD): 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD H S AMOUNT FT TOP BOTTOM TOP BOTTOM OLE IZE CEMENTING RECORD pULLED 13-3/8 61 K-55 0 2006 0 2006 12-1/4, 18 1275 sk G/10% Gel/Neat 9-5/8 47 P-110 0 10484 0 10003 12-1/4 1000 sk G w/ 1% CFR-2 23. Open to production or injection? Yes ~ No ~ If Yes, list each 24. TUBING RECORD interval open (MD+TVD of Top & Bottom; Pertoration Size and Number): SiZE DEPTH SET (MD) PACKER SET (MD) 9-5/8" Baker "DB" C~3 9750 E",~'~ ~~ ~~~1~ : 3 ~ 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. . . . ~,, ~ , ,- _ " DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 172 WLM - 575 MD 41 bbls (124 sk 1.132 yd) 15.9 ppg G Neat 575-600 CIBP completed 1986 9645 TOC, 9695 retainer cement retainer w/ 50' cmt plug completed 1986 9697-10218, 10265-10541 cement plugs 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): 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: Calculated 24-Hour Rate ~ Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity - API (corr): 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No ^ Sidewall Cores Acquired? Yes ^ No ^ If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core ch~ ~, photo raphs and laboratory analytical results per 20 AAC 25.071. ~,~6,e? l,l~a~t.`~~~~ F~ECEI ~~` VED . .. .. ~. ~~ . ~ n . ~~~~ 9~~.. : ~ ~ ; , SEP ~ ~009 ~ ~~Q~ ~ i7ER~flEq ± ~~-,,: Ala~ka ~il & Gas Cons. Commissian Anchorage Form 10-407 Revised 2/2007 CONTINUED ON REVERSE q .~ ~ ~G ~ f <d.e~ ~ L ~ • 28. GEOLOGIC MA~KERS (List all formations and markers encountered): 29. FORMATION TESTS ~-I NAME MD TVD Well tested? ^ Yes ^ No If yes list intervals and formations tested , , Permafrost - Top 0 0 briefiy summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071 Permafrost - Base 0 0 . G-zone formation, perf tops G-1 9,994 9,613 G-2 10,022 9,640 G-3 10,083 9,696 G-4 10,112 9,724 G-5 10,152 9,761 Hemfock formation, perf tops H-1 10,208 9,814 H-2 10,247 9,861 Formation at total depth: Hemlock 10,541 10,127 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tiffany Stebbins Printed Name: Tiffany Stebbins Title: Regulatory Compliance Representative Signature: Phone: 907-565-3043 Date: 9/2/2009 ~i y,zs~,~ d U INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on ali types of lands and leases 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. Item 1a: Ciassification of Service we11s: Gas fnjection, Water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply tor /njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pooi is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level 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 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location ot the cementing tool. item 23: If this weli 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 intervai reported in item 26. (Submit a separate form for each additionai interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water injection, Gas injection, Shut-in, or Other (expiain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ftem 29: Provide a Iisting of intervals tested and the corresrionding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. ~on~ 10-407 Revised 7_~`20G7 ~~~ ~..~~tl~~ ~ STATE OF ALASKA ~ ~~~~~ ~ ~ ~~~y ALASKA L AND GAS CONSERVATION COMMISSI WELL COMPLETION OR RECOMPLETtON REPORl~~~~~~t~a. ~'~~~r~~~s~R;£~~~ 1a. Well Status: Oil ~ Gas ~ Plugged ~ Abandoned 0 Suspended ~ 20AAC25.105 20AAC25.110 GINJ^ WINJ^ WDSPL[] WAG ^ Other^ No.ofCompletions: 1b. Well Class: "~ ;~?~ Development [~{i~~!~~ µExploratory^ Service ^ ~~ StratigraphicTest^ 2. Operator Name: Marathon Alaska Production, LLC 5. Date Comp., Susp., or Aband.: 8/4/2009 ' 12. Permit to Driil Number: 169-011 ' 3. Address: P.O. Box 196168, Anchorage, AK 99519-3043 6. Date Spudded: 1/30/1969 • 13. API Number: 50-733-20175-00-00 • 4a. Location of Well (Gover mental Section): Surface: 2613' G~2495' FEL, Sec. 26, T10N, R13W, SM ` 7. Date TD Reached: 3/5/1969 - 14. Well Name and Number: North Trading Bay Unit S-03 . Top of Productive Horizb~ j,~` p~ ~' . ~- 8. KB (ft above MSL): 115 Ground (ft MSL): 15. Field/Pool(s): Total Depth: 2031' FSL, 4627' FEL, Sec.;26, T10N, R13W, SMj 9. Piug Back Depth(MD+TVD): 172 WLM, 57 BML G-NE/Hemlock-NE Oil ~ 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- y- Zone- 10. Total Depth (MD + TVD): • iQ541 MD, 10127 TVD • 16. Property Designation: AbL0035431 • TPI: x- y- Zone- Total Depth: x- y- Zone- 11. SSSV Depth (MD + TVD): 17. Land Use Permit: 18. Directional Survey: Yes ~ No ~ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: 60 (ft MSL) 20. Thickness of Permafrost (TVD): 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE C AMOUNT FT TOP BOTTOM TOP BOTTOM EMENTING RECORD PULLED 13-3/8 61 K-55 0 2006 0 2006 12-1/4, 18 1275 sk G/10% Gel/Neat 9-5/8 47 P-110 0 10484 0 10003 12-1/4 1000 sk G w/ 1°/a CFR-2 23. Open to production or injection? Yes ~ No Q If Yes, list each 24. TUBING RECORD interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) 9-5/8" Baker"DB" @ 9750 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 172 WLM - 575 MD 41 bbls (124 sk 1.132 yd) 15.9 ppg G Neat 575-600 CIBP completed 1986 9645 TOC, 9695 retainer cement retainer w/ 50' cmt plug completed 1986 9697-10218, 10265-10541 cement plugs 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): 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: Calculated 24-Hour Rate .~ Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity - API (corr): 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No ^ Sidewall Cores Acquired? Yes ^ No ^ If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. Form 10-407 Revised 2/2007 CONTINUED ON REVERSE 28. GEOLOGIC MARKERS (List all forma ions and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ^ Yes ^ No If yes list intervals and formations tested , , briefiy summarizing test results. Attach separate sheets to this form, if Permafrost - Top needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Sase Formation at total depth: 30. List of Attachments: Final P&A well schematic diagram 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tiffany Stebbins Printed Name: Tiffany Stebbins Title: Regulatory Compliance Representative Signature: ' Phone: 907-565-3043 Date: 8/19/2009 V INSTRUCTIONS Generai: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases 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. Item 1a: Classification of Service wells~ Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for /njection, Observation, or Other. 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 compietion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea levei. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this weil should show the details of any muitiple stage cementing and the location of the cementing tool. Item 23: It this well is completed for separate production from more than one interval (multipie 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 torm for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersibfe, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analyticai laboratory information required by 20 AAC 25.071. Form 10-407 (~evised 2/20C7 /• • • J~ ~TM~ ~ RKB-MSL 115' Water Depth 60' TMD @ 10541' ND @ 10127' MASTP 10 psi MIT 5/08/09 PBTD @ 9645' Current API # 50-733-20175 Surface Casing @ 2006' 13 3/8' 61 PPF K55 Buttress 12.515" ID .1521 BBL/FT CMT 875 sks Lead 400 sks Tail CMT Returns to Surface 02/03/69 CTOC 95/s° @ 7310' 03/10/69 "Backside of 9 5/a" Casing" ALL PERF'S DIL SQUEEZED 12/10/86 G-1 9994' - 10006' G-2 10022' 10170' G-3 10083' G-4 10112' G-5 10152' H-1 & 10208' 10102' 10140' 10190' H-2 10344' Production Casing @ 10484' 9 5/s" 47 ppf P110 Buttress 8.661" ID .0732 bbl/ft CMT 1000 sks "G" CTOC @ 7169' 03/10/69 Per Drilling Report Marathon North Trading Bay Unit Spark Platform Weli S-3 "FINAL P&A CONFIGURATION" MARATHON SPARK S-3 FINAL P&A CONFIGURATION All Depths measured RKB to top of equipment A1I depths are RKB unless otherwise noted DRY HOLE TREE 8/4/2009 • AOGCC Witnessed Tag TOC @~232' RKB TOC @ ~57' BML PAGE 1 8/1/2009 -343' Surtace cement plug Setinthe9 5/a"and95/s"X133/e° Mixed and Pumped 41 bbis 15.9 ppg "G" Displaced TOC to 232" RKB 7/21/2009 Pertorated 9 5/a" @ ~575' RKB 7/20/2009 Set CIBP @~575' RKB in 9 5/a" Casing 1000 PSI Test 9 5/8" and 400 psi 133/s" INLET WATER 9645' TOC 12-10-86 9695' BAKER 9 5/$" MOD "K-1" CMT RETAINER 9750' BAKER 9 5/s" MOD "DB" 5/08/2009 Pollard Wire Line to 9354' with 2.850" Gauge Ring 10061' TOF 12-01-86 XO SUB OIL JARS BUMPER JARS XO SUB 3ea 61/4" DC BIT SUB 2ea JUNK SUB 81/z" BIT OAL FISH 10218' FILL Cement Plug @ 10265' 1.10' 7.80' 9.05' 1.12' 93.47' 2.22' 6.87' .50' 122.13' 8/10/2009 TMD 10541' Marathon Well Status Matrix WELL # Gauge Ring Depth RKB -njection Rate BPM/PSI : Bottom Hole Date pmp : TOC / Tagged @ Test Date : PSI: 9-5/8" Casing Test Test Date : PSI: 13-3/8" Casing Test Test Date : PSI: Intermediate Perforation Depth Date Intermediate Plug Date pmp TOC / BBLS Test Date : PSI: Tubing Remove Cut Date Cut Depth Feet Retrieved NORM Y/N Top Job CIBP Depth Feet of Cmt BOC - TOC Date Set OMMENTS 10069'RKB 7/15/2009 7 21/2009 8/2/2009 8/4/2009 575'RKB 8/14/09 CIBP - Bailed cmt 7796' RKB 7128' RKB/ 25 bbl 600' RKB Pert at 575 RKB 1 S 300' fINiSHED - Ta Q 9460' RKB 575' to 275' RKB 2.25 BPM 7/20/2009 7/20/2009 7/21/2009 8/3/2009 597' Tag TOC - 55' BML 2500 si 1000 si 1000 si 400 si 1000 si N 8/18/2009 GRto 9227'RKB 7/14/2009 7/16/2009 7/22/2009 7/24/2009 575'RKB 7/28/09 7267' RKB 6481' RKB/ 25 bbl 600' RKB Perf at 575 RKB S 2 300' FINISHED Tag Q 7440' RKB 575' to 275' RKB 2.5 BPM 7/16/2009 7/10/2009 7/14/2009 7/24/2009 609' Tag TOC - 47' BML 2800 si 1000 si 1000 si 250 si 1000 si Id 8 1 2009 GR to 1017' RKB Pre- 575' RKB 7/20/09 Existing Pert at 575 RKB ' 3 Pre-existing Pre-existing N/A 300' FINISHED 575' to 275' RKB 7/20/2009 7/20/2009 7/20/2009 Ta TOC-57'BML 1000 si 1000 si 400 si 8 2009 Ta CiBP @ 9351' 9/2/2009 9/4/2009 9/4/2009 7/24/2009 575'RKB 9/9/09 Dmp Baii - 25'-CIBP 2282' RKB 1932' RKB/ 25 bbl 600' RKB Perf at 575 RKB 4 S 9/3/2009 300' FINISHED - Sqeeze - 33 bbls 575' to 275' RKB 2.5 BPM 9/4/2009 9/4/2009 9/31/2009 9/5/2009 545' Tag TOC - 57' BML 2500 si 1000 si a-4205' 1000 si 350 si 1000 si N 9 12 2009 GR to 10776' RKB 9/13/2009 5 S - Tag ~ 10440' RKB 200 bbls/22Q0 psi 9/14/2009 9/14/2009 at 2 b m 1000 si 1000 si GR to 10885' RKB 7/22/2009 8/30/2009 8/30/2009 9/4/2009 1005' RKB 9/8/09 Additional top plug 1000' - 7000'- 9/11/09 Tag @ 9912' RKB 7900' RKB 7600' RKB/24 bbls 1010' RKB Perf at 1005' RKB Tested to 1000 psi - 9/12/09 S 7 7/24/2009 Tag - 7533' RKB TOC Q 744'RKB Tbg -1000 psi 9/2/2009 9/3/2009 CIBP-Perf ~ 575' Circulate Clean 7/24/2009 7/24/2009 2571' RKB 2271' RKB / 24 bbis 1009' 300'cmt - 9/12/09 Pmp 300' Top plug @ 575-275' 9/12/09 45 bbl 0 si cs - Failed cs - Failed 500 si tb -1000 cs -faifed N Ta TOC at GR to 10,020' RKB 8 6 2009 8/9/2009 8/16/2009 8/22/2009 575' RKB 8/26/09 CIBP Q 9885' RKB 2185' RKB 1835' RKB/24 bbl 600' RKB Pert at 574' RKB S$ 350' Bal Piug Tag TOC Q 1797' 300' FINISHED Tag @ 9661' RKB 2nd 2nd - 8/20/2009 574' to 274' RKB Can not inject 8/9/2009 8/9/2009 8/20/2009 1444' RKB / 24 bbl 595' Tag TOC- 51' BMl at 3000 si 1500 si 1500 si 500 si 1794' 8 2 09 - 1000 si N 9 2 2009 GR to 11,899' RKB 8/6/2009 8/20/2009 8/23/2009 8/24/2009 575' RKB 8/26/09 10318' RKB 9918' RKB/24 bbl 600' RKB Perf at 574' RKB S 9 Tag @ 9555'RKB 300' FINISHED Ta ~ 10418' RKB 574' to 274' RKB 1.5 bpm 8/9/2009 8/9/2009 8/24/2009 597' Tag TOC- 51' BML 1800 si 1500 si 1500 si 500 i 1000 PSI N 9 2 2009 9/15/2009 ~ • • Report Date: 8/4/2009 Well # S- 3 PROSERV OFFSHORE DAILY ACTIVITY REPORT & COSTS Proj Team Leader: Jeff Thompson Field Sup.: PIC Site: Todd Paxton PLATFQRM: Spark PROJECT NUMBER: 29052-21 WELL NUMBER: S- 3 PROJECT: Marathon Oil Co. - P&A Day 44 C ~ ~ Proseru ost & Activity Date: 8/4/2009 TtME 11:00 R/U slickline and RIH with 1.5 G.R. to 172' WLM (57' BML) and tag TOC. POOH. 11:30 Move over to well # S-1RD Work Scope for 8-5-09 S-1R Pull out of hole, set CIBP and perforate for top balance plug. CREW NAME HQt1RS GREW; NAME : iiQURS Jeff Thompson 0.5 Randy Lafleur 0.5 Gene Hess 0.5 Mathew Boudreaux 0.5 Cyprian Ukudi 0.5 Page 1 of 2 ~ ~ Report Date: 8/1/2009 Weil # S- 3 PROSERV OFFSHORE DAILY ACTIVITY REPORT & COSTS Proj Team Leader: Jeff Thompson Field Sup.: PIC Site: Todd Paxton PLATFORM: Spark PROJECT NUMBER: 29052-21 WELL NUMBER: S- 3 PROJECT: Marathon Oil Co. - P&A Day 41 B ~., ~ ~ Proseru ost & Activity Date: 8/1/2009 TIME 12:00 Circulate dye around in well and establish full capacity of displacement. 13:00 M/P 41 bbls, 124 sks of 15.9 ppg, 1.132 yield, class "G" Neat cement for a 300' cmt balance plug in both the 9-5/8" and the 13-3/8"x 9-5/8" casings, from t 575' RKB to ± 275' RKB. 15:45 Clean aN equipment and work deck. 16:45 Dispose of waste fluid. 17:30 Secure wells and equipment. 1$:00 Shut down for the day. Work Scope for 8-2-09 S-1RD Set intermediate cement balance plug. S- 8 Perform diagnostics and slickline. S- 9 Perfprm diagnostics and slickline. CREW NAME HOURS CREW NAME HC-UFtS' Jeff Thompson 6 Randy Lafleur 6 Gene Hess 6 Mathew Boudreaux 6 Cyprian Ukudi 6 Pagelof2 ~~ ~ Report Date: 7/21/2009 Well # S- 3 Day 30 A PROSERV OFFSHORE DAILY ACTIVITY REPORT & COSTS Proseru Proj Team Leader: 1eff Thompson Field Sup.: PIC Site: Todd Paxton PLATFORM: Spark Cost & Activity Date: 7/21/2009 PROJECT NUMBER: 29052-21 WELL NUMBER: S- 3 PROJECT: Marathon Oil Co. - P&A T(ME DESCRIPfIQN~FACT'iViT'tES : 6:00 Travel to Spark platform. 6:30 Held safety meeting and JSA on pressure testing and running e- line, & offloading boat. 7:00 Offload cement and weatherford pipe and tools from workboat. 8:00 R/U e- line and RIH with 2' of perf guns (~? 4 spf & tag top of CIBP at 575' RKB and fire guns. POOH 9:00 Move to well # S-1RD CREW IWA~AE FtOi1RS CREW `NAMf Ht?UftS; Jeff Thompson 3 Randy Lafleur 3 Gene Hess 3 Mathew Boudreaux 3 Cyprian Ukudi 3 Page 1 of 2 ~ ~ Report Date: 7/20/2009 Well # S- 3 Day 29 B PROSERV OFFSHORE DAILY ACTIVITY REPORT & COSTS Proseru Proj Team Leader: Jeff Thompson Field Sup.: PIC Site: Todd Paxton PtATFORM: Spark Cost & Activity Date: 7/20/2009 PROJECT NUMBER: 29052-21 WELL NUMBER: S- 3 PROJECT: Marathon Oil Co. - P&4 T11~4E ` DfS~CRIP'T'tON OF ACTt1li1'IES 9:00 R/U pmp hoses to 9-5/8" csg. 9:30 Pressured up to 1000 psi and charted for 15 minutes. Good test. Csg was already full. 10:00 RU on 13-3/8" csg & pressured up to 400 psi and charted for 15 minutes. Good test. Csg was already full. 10:30 N/D #ree and remove. 12:30 R/u e- line and RIM with gauge ring & junk basket to 1017' RKB and POON. 13:~0 M/U CIBP for 9-5/8" csg and RIH to 575' RKB and set. 14:30 Out of hole. R/D e- line. 15:00 Move over to well # 2RD ` GREW MAaAE HQt1R5 ' CREW NAME 'tiE~1RS` Jeff Thompson 6 Randy Lafleur 6 Gene Hess 6 Mathew Boudreaux 6 Cyprian Ukudi 6 Page 1 of 2 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg I~ ~~ ~7~~'~ DATE: August 6, 2009 P. I. Supervisor FROM: Lou Grimaldi SUBJECT: Wellbore plug integrity Verification Petroleum Inspector Marathon Oil Company North Trading Bay Unit S-03 ' Spark Platform PTD #169-011; Sundry #309-140 ' Tuesdav, Auqust 4, 2009; I witnessed the tag of top of cement (T.O.C.) by wireline (W.L.) and pressure test of the Surface cement plug in Marathon's Spark platform well # S-03 in the North Trading Bay Unit. A 1.5-inch gauge ring was run into the well on W.L. to a depth of 172' WireLine Measurement (W.L.M.) where it fetched up hard. The plug was jarred upon 3-4 times with out any signs of going deeper or sticking. Upon withdrawal of the gauge ring from the wellbore I inspected it and observed no signs of damage from tubing obstructions and saw white-like staining on the bottom. There appears to be a competent Surface cement plug at 232' R.K.B. (elevation 60') or 172 W.L.M. (T.H.F.). Attachments: None Non-Confidential ,~! ~,~~~y~,s~~~. ~;; ~a ~J ~~ ~ ~T~~ ~ Wellbore Plug TBU Spark S-3 08-04-09 LG.doc 1 of 1 . Marathon MARATHON ® Alaska Production LLC Alaska Asset Team P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/565-3076 August 3, 2009�� Cathy Foerster "`' T [,'-1 L State of Alaska Alaska Oil and Gas Conservation Commission S ED OCT G 7 2( 14 333 W. 7"' Avenue, Suite 100 Anchorage, AK 99501-3539 Re: 20 AAC 25.300 (Request for Information) — Status of Oil and Gas Wells Dear Ms. Foerster: In response to your June 22, 2009 letter requesting a plan of action and timing for such activities associated with the referenced list of inactive wells, please find attached a table with the requested information. As indicated in the table, Marathon anticipates a measured program of P&A activities, averaging three -to -five well abandonments per year. Marathon has already begun such a program with its offshore wells, beginning with the Spark Platform wells in 2009. All of the onshore wells on the list are within active oil and gas leases that are regularly visited and inspected. Marathon anticipates updating plans for its inactive wells in the appropriate annual Plan of Development for each property. Any and all forward activities are subject to funding approval. Please also note that your June 22 letter erroneously referenced "KU 41-08". We believe that your June 22 letter reference to well "KU 41-08" was a typo and is intended to refer to Well KU 41-18. This well matches the referenced drilling permit (171-010). Should you have any questions or wish to review the attached plans with us, please feel free to call Lyndon lbele at (907) 565-3042. Sincerely, �a Carri Lockhart Alaska Asset Team Manager Attachment: Marathon plan for list of inactive wells cc: B. Schoffmann L. Ibele K. Skiba T. Stebbins Well Files Marathon Oil Company, Alaska Asset Team Anticipated schedule of well abandonment activities Confidential 8/3/2009 Timing lWell I Permit No. I Pad or location 2009-2011 S-1 RD 174-005 Spark S-2RD 174-024 Spark S-3 169-011 Spark S-4 169-034 Spark S-5 169-039 Spark S-7RD 169-096 Spark S-8 171-033 Spark S-9 174-027 Spark TS -1 168-048 Spurr TS -2 168-050 Spurr TS -3RD 168-065 Spurr TS -4 168-066 Spurr TS -6 168-090 Spurr TS-7RD 169-026 Spurr TS -8 169-027 Spurr TS -9 169-092 Spurr 2012-2015 BC 7 176-006 BCU Pad 7 CLU 3 181-058 CLU Pad 3 CLU 4 187-034 CLU Pad 3 KU 33-30 159-015 KGF pad 33-30 KU 42-30 181-091 KGF pad 33-30 KU 44-30 168-071 KGF pad 33-30 SU 23-15 161-014 Sterling Unit KU 41-18 171-010 KGF pad 41-18 KU 43-12 169-087 KGF pad 14-6 KU 11-6 165-017 KGF pad 34-31 KU 21-5 169-035 KGF pad 43-32 WF1-21 rd 193-183 West Fork WF2-21 192-010 West Fork ~ U 'I~ffany Stebbins Regulatory Compliance Rep. Marathon Oil Company ~ ~ '~~~ , r~ ~ ~ 20u.~ P.O. Box 190168 ~~~,,~~~ ~ ~ ~- Anchorage, Alaska 99519-6168 ,~41 ~ ~`~ Re: G-NE/Hemlock-NE Oil North 'IYacling Bay Unit S-03 Sundry Number: 309-140 Dear Ms. Stebbins: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Corrunission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, withul 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 Comrnission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next wor~ng day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. / Chair J,~, d- DATED this ~ day of July, 2009 Encl. ~,~ ~~~~~~~~ Y ~`• ~'~~,,'~ STATE OF ALASKA ' ~ O~ ~ALA S OIL AND GAS C ON SERVATION COMMI ION ~ P~ ~~ 7 Q p~ ~ ~ ~ti APPLICATION FOR SUNDRY APPROVAL ,~,~$$;Q~ ~ ~11Sa$k~ fl~i & Gas Cons. Ca~ 20 AAC 25.280 1. Type of Request: Abandon ~• Suspend ^ Operational shutdown ^ Perforate ^ Waiver Other ^ Alter casing ~ Repair well ~ Plug Perforations ^ Stimulate ^ Time Extension ~ Change approved program ^ Pull Tubing ~ Perforate New Pool ~ Re-enter Suspended Well ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Marathon Oil Company Development ~ Exploratory ~ 169-011-0 ' 3. Address: Stratigraphic ~ Service ~ 6. API Number: P.O. Box 190168, Anchorage, AK 99519-6168 50-733-20175-00-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: NOCth Tt'adlllg Bay UCllt 5-03 Spacing Exception Required? Yes ^ No ^ Spark platform 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL035431 ' RKB-MSL 115' ' G-NE/HEMLOCK-NE OIL 12• PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,541' - 10~7' lp /~"'~~~ ~~ 9,645' ~,~+~ 9,2~7" `jr'~'t`} ~? 9645-10218, 10265-10541' 10060fish, 1 021 8-1 0265 , ~ ~ Casing Length Size MD ND Burst Collapse Structural Conductor Surface 2,006' 13 3/8" 2,006' 2,006' Intermediate Production 10,484' 95/8" 10,484` iQ003' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9,994 - 10,344' 9,613 - 9,942' None Packers and SSSV Type: Baker Model "DB" Packers and SSSV MD (ft): 9,750' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ~ Exploratory ^ Development ^~ • Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas ^ Plugged ^ Abandoned ^~ • 17. Verbal Approval: Date: WAG ^ GINJ ~ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tiffany Stebbins Printed Name Tiffany Stebbins Title Regulatory Compliance Rep. Signature , Phone Da e 907-565-3043 c~Q ~ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~Q~ /~ • Plug Integrity d BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~ A 1~rr~~. ~w.a~ p I~~ ~J ~4c~,,,te~" ~ s a/O~O~o~oc.~ ~s ~-~ A~C Z S,. ~l Z c., Subsequent Form Required: f Q~- y O7 C~ APPROVED BY ~ ~ Approved by: COMMISSIONER THE COMMISSION Date: ~ j Form 1~O~~f~ ~ ~!~ a ~ />!> ~ . ~r. ~ ~~ Op~ ~~~d~j', ~~,, ~j~j~ ~~ ZQQ~ ~~ Submit i li~,a~e ~l ~' 7'/?~/03 ., . `, ' ~ • ~ MARATHON OIL COMPANY NORTH TRADING BAY UNIT SPARK PLATFORM WELL S-3 TEMPORARYABANDONMENT PROCEDURE 03/31/09 WELL DATA API# 50-133-20175 Elevation: 115' RKB - MSL Retainer: Baker 9 5/a", "K-1" C~9695' Water Depth: 60' Total Depth: 10,541 MD Packer: Baker DB packer C~ 9750' Surtace Casing: 13 3/a" 61 ppf C~ 2006' 12.515" ID, .15215 bbl/ft Intermediate: 9 5/s" 47 ppf N80 @ 10,484' 8.681" ID, .0732 bbl/ft Perforations: 10,220 - 11,320' "Plugged" Fi I I to "~~Z ~' ' N p-'To `fle~5 c: PBTD. "^,~n-,-,~;'-~, °1~ ~''~ ~ CURRENT STATUS The well has no further utility and is to be temporarily abandoned following the procedure below. ABANDONMENT PROCEDURE 1. Mobilize tree technician to location to ensure the operation of the tree valves, flanges. Repair as needed. 2. Mobilize abandonment crew and equipment to location. PerForm JSA and rig up equipment. 3. Check casings for pressure. Bleed off through gas buster. Fill and test casings with weighted fluid and record results. 4. Rig down "DRY HOLE" tree. 5. PerForm JSA for safe electric line operation and explosive handling. RIH with 9 5/s" gauge ring to 9645' RKB and record results. POOH. 6. RIH with 9 5/s" CIBP to 600' RKB, pick up to 575' RKB and set CIBP. 7. RIH with pertorating gun armed with 2 ft of 4 SPF casing punch, tag CIBP @ 575' RKB and fire guns. POOH. RD electric line. 8. PerForm JSA on cement mixing and pressure pumping. Rig up pump and pump lines. Test pump lines to 1500 psi. NOTE: IF POSSIBLE A)Circulate clean, down the 13 3/s" casing and up the 9 5/a" casing with weighted fluid. Mix and pump 41 bbl cement slurry for a 300' cement plug in the 9 5/s" casing and the 9 5/a" x 13 3/s" casing annulus from 575' RKB - 275' RKB. B)If unable to circulate the 9 5/s" X 13 3/s" casing annulus, RIH with work-string to CIBP, pick up work-string 10' and displace a 22 bbl slurry for a 300' cement surface plug from 575' RKB - 275' RKB in the 9 5/a" casing only. 9. Pick up work-string 20' above TOC and circulate work string clean. POOH. 10. WOC. PerForm JSA on wireline procedures. RIH with blind box and tag TOC for surFace cement plug @ 275' RKB and record results. POOH. 11. RD. Well is temporarily abandoned. Spark Well 3 ~ Page 1 ~ ~ 4/17/2009 . .t , y . ~ RKB-MSL 115' Water Depth 60' API # 50-133-20175 Surtace Casin~ 13 3/s", 61.0 PPF, @ 2006' 12.515" ID, .1521 BBL/FT CEMENTED WITH 1275 SKS "G" ' HOLE TREE INLET WATER ALL PERF'S DIL SQUEEZED 12/10/86 G-1 9994' - G-2 10022' ETOC 95/a° (~? 7700' 10006' 10170' G-3 10083' 10102' G-4 10112' G-5 10152' H-1 & 10208' Production CasinF 9 5/s", 47 ppf, @ 10484 8.661" ID, .0732 bbl/ft 10140' 10190' H-2 10344' • Marathon North Trading Bay Unit Spark Platform Well S-3 "CURRENT" All Depths measured RKB to top of equipment All depths are RKB unless otherwise noted ~5' TOC 12-01-86 i5' BAKER 9 5/s" MOD "K-1" CMT RETAINER ~0' BAKER 9 5/a" MOD "DB" )61' TOF 12-01-86 XO SUB 1.10' OIL JARS 7.80' BUMPER JARS 9.05' XO SUB 1.12' 3ea 6 ~/a" DC 93.47' BIT SUB 2.22' 2ea JUNK SUB 6.87' 81h" BIT .50' OAL FISH 122.13' >18' FILL nent Plug @ 10265' ND / 10541' RKB-MSL 115' Water Depth 60' API # 50-133-20175 ~0' Surface cement plug :rForate 9 5/s" Casing @ 575' RKB 5/a"and95/s"X133/s°=4lbblslurry 5/s" only = 22 bbl slurry 75' RBK - 275' RKB IBP C~ 575' RKB Surtace Casin~ 13 3/8", 61.0 PPF, @ 2006' 12.515" ID, .1521 BBL/Ff CEMENTED WITH 1275 SKS "G" ETOC 95/s" @ 7700' "Backside of Casing" INLET WATER 9645' TOC 12-01-86 9695' BAKER 9 5/a" MOD "K-1" CMT RETAINER ALL PERF'S DIL SQUEEZED 12/10/86 G-1 9994' - 10006' G-2 10022' - 10170' G-3 10083' - 10102' G-4 10112' - 10140' G-5 10152' - 10190' H-1 & H-2 10208' - 10344' Production Casin~ 9 5/s", 47 ppf, @ 10484' 8.661" ID, .0732 bbl/ft All Depths measured RKB to top of equipment MUDLINE All depths are RKB unless otherwise noted 750' BAKER 9 5/s" MOD "DB" ~061' TOF 12-01-86 XO SUB 1.10' OIL JARS 7:80' BUMPER JARS 9.05' XO SUB 1.12' 3ea 6'/a" DC 93.47' BIT SUB 2.22' 2ea JUNK SUB 6.87' 81h" BIT .50' OAL FISH 122.13' ~218' FILL ~ment Plug @ 10265' ND / 10541' ~ ~ Spark Platform Abandonment Review North Trading Bay Unit Marathon Oil Company Well NTBU S-O1RD (PTD174-005) - Sundry Application 309-138 Well NTBU S-02RD (PTDl74-024) - Sundry Application 309-139 ~~~ell NTBU 5-03 (PTD169-O11) - Sundry Application 309-140 Well NTBU 5-04 (PTD169-034) - Sundry Application 309-141 Well NTBU S-OS (PTD169-039) - Sundry Application 309-142 Well NTBU S-07RD (PTD169-096) - Sundry Application 309-143 Well NTBU 5-08 (PTD171-033) - Sundry Application 309-144 Well NTBU 5-09 (PTD174-027) - Sundry Application 309-145 Requested Action: Marathon Oil Company (Marathon) proposes to permanently abandon the above referenced wells on the Spark Platform in the Cook Inlet. Recommendation: I recommend approval of the above referenced Sundry Applications to a11ow Marathon to permanently abandon the wells. Discussion: Marathon proposes to permanently abandon the above wells on the Spark Platform by setting the required multiple cement plugs in the wellbore. (At a later date to be determined the Spark Platform structure will be removed; at this time the casing strings will be cut and pulled just below mudline to complete the total abandonment of the wells. ) The Spark Platform is one of two, the other being the Spurr Platform in the North trading Bay Unit (NTBU). Production began from the Spark Platform in January 1969 and peaked at nearly 12,000 bopd in November 1969 before beginning a rapid decline. By January 1992 production from the platform had fallen to less than 300 bopd and production was shut in. In November 1996 gas production, but not oil production, from the platform was reestablished but and peaked at over 5.2 mmcfpd in May 1998. The platform produced no water during the first year an a half of gas production but then quickly rose to over 200 bwpd. The initial attempt at gas production ceased in May 2000, a second attempt was made beginning in July 2003 but as soon as there was any significant gas production there was a.lso significant water production, up to almost 400 bwpd. By September 2005 significant gas production had ceased on the platform but intermittent, averaging about 1 mmcfpd but only producing, usually, one day per month, production continued until July 2007. There have been no further attempts to resume production from the platform. Cumulative production from the platform is about 17.5 mmbo and 6.8 bcfg, 4.6 bcfg of which was associated gas recovered during oil production. ~ • There have been a total of twelve wells drilled from the Spark Platform, of which four have already been P&A'd (NTBU S~O1, 5-02, S-02DPN, and 5-07). Of the eight "active" welis that are the subject of this review two are waste disposal wells (NTBU S- 04 & S-OS), one is classified as a gas well (NTBU S-02RD) but has not produced since July 2007, and the remainder are classified as shut in. Decline curve analysis of the oil production indicates that remaining reserves in the known oil accumulations accessible from the Spark Platform range from zero for an economic limit of 300 bopd for the platform to i,096 mbo for an economic limit of 50 bopd for the platform. The following table shows the remaining reserves at various economic limits. Economic Limit (bo d) Remainin Reserves (mbo 50 1,096 100 869 200 410 300 0 Below is a graph of the decline curve analysis showing production extrapolated to a 50 bopd economic limit. Without specific economic information it is impossible to say what truly the economic limit is for the Spark Platform. However, in a May 23, 1992, letter from Marathon to the Department of Natural Resources (copy attached) Marathon stated that the platform had been uneconomic since 1990 and that at that time the break even oil price was in excess of $20/bbl. Although oil prices are substantially higher than that now operation costs have also increased dramatically since that time and the platform likely remains uneconomic today at any oil production rate that could be obtained from the existing facilities and wellbores. ~ • ~ ~ ~ V j . ~ ~ . . . . . . V\brldn6 Forecast Para~rteters l ~ .. ~ . . . . . - _ _ . Fhe56 : C11 . Casa P6rta : Caset b O Ci : 0.0783624 A.e. . .. .. . . . . . .. qi : 288.357 bbl/d tl :0131/1982 ~ ~ ~ ~ te :02282014 Fnal Rate : 49.9198 bbVd dm Rotl. : 17508.8 M%~I p° ~ CLm ~te . 01l31/1992 I Reserves : 7086.35 MY~I I ~ t I~serves C~te ~ ~t28~20t4 . . . I I . ' . BS2 : t8BW2 M6bl . . . Forecast Ended 6y : F~ate ~. .I ~ ~B Farecast C~te : I.kx Seved ~ . F~serve Type : N~ne p'. 1 ' t ~ ; f , .~ . . .. . . . . . ~ 4 e ~ . . . a~ : ~;~.d .. .. . 6 ~1 ~~ j i ~ ' . . ~ . ~ . .. . ~~.,y~4~w~ ~~~i ~ . . . . . .. . '~. 96907'172T37475767778~98D8182838485868788899D9t929394959697968800010203040506070809107t12'1314 Ll4"fE Several attempts have been made at sustaining substantial gas production from the platform but none of them have lasted more than a year of regular production, and you have to use a pretty broad definition of regular to get that as they were only able to maintain production for an entire month a handful of times in the 11 plus years they attempted gas production. Conclusion: The Spark Platform appears to be well beyond its economic life and permanently abandoning the wells at this time, to prepare for a future platform and casing removal , appears to be the prudent course of action. ~~j D.S. Rob ~ ,~ ~ ~~!~: Sr. Reservoi~rigirieer Aprii 23, 2009 - Revised July 2, 2009 V/� Marathon MARATHON Oil Company March 1, 2009 l,(A.q_ C) l\ Alaska Asset Team North America Production Operations P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/565-3076 r Efv. MAR 0 2 2009 Grolt'ske" Oil & 9.71e'oi tBBS. � 4� S1l3 Z it°'i Commissioner: Cathy Foerster Alaska 0ii and Gas Conservation Commission 333 W. 7t" Avenue Suite 100 SCAMM Anchorage, AK 99501-3539 Re: Notice of Revised Suspended Wells Regulations and Request For Verification of Suspended and Shut-in Well Information Dear Cathy: Marathon received your letter dated January 28, 2009 (Cert # 7005 1820 00012499 5999) requesting Marathon to validate information contained within it. Marathon has reviewed the data and found it to be accurate. Marathon is in the processes of reviewing and addressing the new regulatory requirements in "20 AAC 25.110 Suspended wells". If you have any questions, please do not hesitate to contact Gary Laughlin at 907-565-3036 or email him at galaughlin@marathonoil.com. Sincerely, Ben Schoffmann Operations Manager MARATHON OIL COMPANY LIJ)ft� Qui I��I!3 ALASSA OIL AND GAS CONSERVATION COMUSSION January 28, 2009 CERTIFIED MAIL RETURN RECEIPT REQUESTED 7005 1820 0001 2499 5999 Ben Schoffman Marathon Oil Company PO Box 196168 Anchorage AK 99519-6168 \ (-t ck,- 00, SARAH PALIN, GOVERNOR 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7 54 2 Re: Notice of Revised Suspended Wells Regulations SCANNE�3 and Request for Verification of Suspended and Shut -In Well Information Dear Mr. Schoffman: Enclosed are the Alaska Oil and Gas Conservation Commission's revised regulations regarding suspended wells (i.e., 20 AAC 25.110). Also enclosed are a list of suspended wells and a list of long term shut-in wells operated by Marathon Oil Company. For each list, please verify the information for each well, and provide any corrections by April 1, 2009. Location inspections required under 20 AAC 25.110 should be coordinated with Jim Regg at 907-793-1236 or jim.regg@alaska.gov. If you have any questions regarding this notice, please contact Tom Maunder at 907-793- 1250 or tom.maunder@alaska.gov. Sincerely, Cathy P. Foerster Commissioner Enclosures ra C3 U.S. Postal Service��,, 13 IL In Rasbided DONVWY Fee tEndWwmeM ReQulredl MAIL,, RECEIPT CERTIFIED Provided) Mail Only: No Insurance Coverage (Domestic _._. visit our website at www.usps.com ra C3 Grt W Fee C3 C3 Ron RecW Fee tEr4W8@MWd Regtltred) 13 IL In Rasbided DONVWY Fee tEndWwmeM ReQulredl 49 � TOW P~ Ben Schoffman� � o Marathon Oil Company E3 WWAXW. PO Box 196168 arF09MN .- W;; Anchorage AK 99519-616 E, Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. IIE Print your name and address on the reverse so that we can return the card to you. E Attach this card to the back of the mailpiece, or on the front if space permits. 1. Article Addressed to: Ben Schoffman Marathon Oil Company PO Box 196168 Anchorage AK 99519-6168 A. X Agent ❑ Addre B. Received by (Pnh d Name) C. Da of Deli v IT D. Is delive6 address different from item 1 r ❑Yes If YES, enter delivery address below: ❑ No rvice Type Certified Mail Express Mail ❑ Registered �"�'y� Return Receipt for Merchandise ❑ Insured Mail ❑ C.O.D. 4. Restricted Delivery? (Extra Fee) ❑ Yes 2. Article Number (rranster from service label) 7005 1820 0001 2499 5999 PS Form 3811, February 2004 DomeMle Retum Reoelpt 02595-02-M-1540 Operator Suspended and Shut In Wells MARATHON OIL CO Field Current Date of Permit API Number Well Name Status Status Surface Location .................................................. Lease(s).................................. *EXPLORATORY 202-129-0 50-133-20517-00-00 ABALONE 1 SUSP 3/9/2003 250 FSL 3000 FEL Sec 29 T 2 N R 12 W SM FEE-OSMAR KASILOF 202-257-0 50-133-20520-60-00 KASILOF SOUTH 1 L1 SUSP 4/15/2004 520 FSL 1340 FWL Sec 28 T 3 N R 12 W SM ADL0384529 ADL0384534 KENAI C.L.U. 206-121-0 50-133-20563-00-00 CANNERY LOOP UNIT 12 SUSP 9/8/2006 2490 FSL 2365 FWL Sec 4 T 5 N R 11 W SM ADL0324602 ADLO359153 ADL0365454 FEE-TR119 NINILCHIK 208-023-0 50-133-20574-00-00 NINILCHIK UNIT G OSKOLKOFF 7 SUSP 6/12/2008 2969 FSL 3023 FEL Sec 23 T 1 N R 13 W SM ADL0389180 STERLING 161-014-0 50-133-10012-00-00 STERLING UNIT 23-15 SUSP 10/23/1966 2715 FNL 1520 FWL Sec 15 T 5 N R 10W SM FEDA028135 TRADING BAY 174-005-0 50-733-20158-01-00 N TRADING BAY UNIT S-01 RD SI 1/25/1992 2608 FSL 2495 FEL Sec 26 T 10 N R 13W SM ADL0035431 169-011-0 50-733-20175-00-00 N TRADING BAY UNIT S-03 SI 2/25/1992 2613 FSL 2495 FEL Sec 26 T 10 N R 13 W SM ADL0035431 169-096-0 50-733-20197-01-00 N TRADING BAY UNIT S-07RD SI 2/25/1992 2612 FSL 2488 FEL Sec 26 T 10 N R 13 W SM ADL0018776 171-033-0 50-733-20233-00-00 N TRADING BAY UNIT S-08 SI 1/25/1992 2577 FSL 2566 FEL Sec 26 T 10 N R 13 W SM ADL0017597 174-027-0 50-733-20265-00-00 N TRADING BAY UNIT S-09 SI 1/25/1992 2570 FSL 2563 FEL Sec 26 T 10 N R 13W SM ADL0017597 168-048-0 50-733-20120-00-00 N TRADING BAY UNIT SPR -01 SUSP 8/18/1992 615 FNL 2072 FEL Sec 34 T 10 N R 13 W SM ADL0017597 168-050-0 50-733-20122-00-00 N TRADING BAY UNIT SPR -02 SUSP 8/19/1992 664 FNL 2007 FEL Sec 34 T 10 N R 13 W SM ADL0017597 168-065-0 50-733-20133-00-00 N TRADING BAY UNIT SPR -03 SUSP 8/18/1992 618 FNL 2068 FEL Sec 34 T 10 N R 13W SM ADL0017597 168-066-0 50-733-20134-00-00 N TRADING BAY UNIT SPR -04 SUSP 8/13/1992 666 FNL 2003 FEL Sec 34 T 10 N R 13W SM ADL0017597 168-090-0 50-733-20153-00-00 N TRADING BAY UNIT SPR -06 SUSP 8/10/1992 642 FNL 2072 FEL Sec 34 T 10 N R 13W SM ADL0017597 169-026-0 50-733-20181-00-00 N TRADING BAY UNIT SPR -07 SI 8/26/1992 622 FNL 2068 FEL Sec 34 T 10 N R 13W SM ADL0017597 169-027-0 50-733-20182-00-00 N TRADING BAY UNIT SPR -08 SUSP 8/26/1992 664 FNL 2000 FEL Sec 34 T 10 N R 13 W SM ADL0017597 169-092-0 50-733-20200-00-00 N TRADING BAY UNIT SPR -09 SUSP 8/18/1992 618 FNL 2076 FEL Sec 34 T 10 N R 13W SM ADL0017597 Wednesday, January 14, 2009 ~ W. ~on Production Manaqer Alaska Region J Domestic Production ~ Marathon MppATMON Oil Company P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 March 23, 1992 Mr. Harold Heinze, Commissioner Department of Naturai Resources 400 Willoughby Avenue, 5th Floor Juneau AK 99801-1796 Dear Commissioner: Sl1SPENSION OF PRODUCTION OR OPERATIONS Enclosed for processing is an appiication for suspension of production or operations and a fiiing fee of 550. Pursuant to 11 AAC 82.670 Suspension of Production or Operations, Marathon Oil Company, P. 0. Box 190168, Anchorage, Alaska 99519, hereby requests approval of suspension of production or operations for a two-year period commencing June 1, 1992. The leases affected are ADL-17597, ADL-18776, and AD1-35431. The lands within the North Trading Bay Unit, as shown on Exhibits 1 and 2, are described as follows: T10N, R13W, Sec. 26: SW;, SZ NW;; Sec. 27: SE;, SZ NE.; Sec. 34: EZ; Sec. 35: WZ. ~ Two platforms have produced from the Unit to an onshore processing facility at Granite Point. The Spark Platform, purchased by Marathon in 1984, was recently shut in because it was uneconomic to operate. The Spurr Platform. purchased by Marathon and Unocai in 1988, is currently operating at a loss. Oil production from Spark Platform was approximately 330 BOPD prior to shut-in, while Spurr Platform is currently producing about 250 BOPD. Spark Platform Overall, Spark has been uneconomic since 1986 when oil prices dropped dramatically. Since that time Spark has lost ~2.0 MM on an operating income basis as shown in Exhibit 3. Not included in this amount is the 56.7 MM invested during that time. The break-even oil price for 1991 was over g20 per barrel not inciuding the cost of investment recoupment through DD&A. Since reserves are defined as economically producibie, no oil reserves can be assigned to Spark with an oil price below ~20. The Unit does have economic gas reserves which couid be developed from Spark. Gas reserves have been proved with a down structure fuei gas well on the Spurr Platform which has recovered 3.5 BCF. Current plans call for developing remaining gas reserves by recompieting Spark Platform Wells A subsidiary or USX Corporation ~.~ ~ Mr. Harold Heinz~ ~ March 23, I992 Page 2 S-2R0 and S-8 uphole near the gas reservoir structure top. In addition, gas separation and dehydration facilities and compression wiil need to be installed on the platform. Proven Unit gas reserv~s are committed to both Unocai and Marathon con- tracts. Because both companies currently have sufficient deiiverability to ~~ _meet contract demand, it is not economically justified to invest the " necessary $7.7 MM gross cost to develop Unit gas at this time. If gas ,. ~~~ production was commenced from Spark Platform, Unit gas sold would displace ~ gas sales from other fields which have already been deveioped. In the J mid-1990's, Marathon will begin to need additionai deliverability to meet contract demand. Plans are to develop Unit gas to meet this demand. Spurr Platform The Spurr platform has been uneconomic since 1990. It has lost ~1.0 MM since that time as shown in Exhibit 4. Investments totaling 56.9 MM incurred since 1988 are not included in this calculation. As with Spark, the break-even oil price for 1991 was over ~20 per barrel, not including DD&A costs. Therefore, no oil reserves can be attributed to Spurr. Spurr does have one gas well, TS-3R0, completed in gas sands. It is currently shut in because of down hole mechanical problems. .~ '"~~ Losses are expected to increase in 1992 to $0.8 MM as a result of lower ~~`~ prnduction and a projected ~12.00 per barrel oil price. This does not 'J include the substantial ~onies required to stay in compliance with oil spill and process hazard management regulations recently enacted. These losses are not acceptable and as a result Spurr Platform and the attendant onshore production facility at Granite Point must be shut in. Until recently, the non-unit area developed by Spurr was thought to contain significant undeveioped reserves. Evaluation of 3-D seismic and the performance of Monopod Platform Well A-28RD now indicates no further economic deveiopment potential exists. With once planned development potential eliminated, Spurr has no further utility for oil production under current economic conditions. Future gas production from Spurr is possible and will be evaluated as part of the overall development scheme. Marathon's Plans During Two-Year Susoension The main reason for the requested two-year suspension is to eliminate unnecessary economic losses until Marathon develops Unit gas. During this two-year suspension Marathon will continue to evaluate the gas market to determine the optimum timing of gas development. The gas market is dynamic and Marathon constantly evaluates supply and demand. Marathon wiil also monitor oii prices to determine if resumption of oil production is feasible and will review alternate production strategies which could reduce operat- ing costs. This is applicable to both platforms. -,' ' ' Mr. Haroid Heir~ ~ March 23, i992 Page 3 A major undertaking during this suspension period will be the eva7uation of abandonmeni options for Spark, Spurr and Granite Point Production Facility. This evaluation will attempt to optimize method and timing of abandonment. As no platform has been abandoned in the Cook Inlet to date, much research needs to be done prior to abandoning the first structure. It is stressed that this work does not preciude the planned resumption of operations at Spark or the possibie resumption at Spurr. A revised plan of development refiecting the changes proposed in this application is being sent under separate cover. If there are questions or if further information is needed, please contact R. J. Murphy at 564-6425. Thank you for considering this application. Sincerely, . .-.~ -v , ~;~'1`x.i `. W. Watson cc: Mr. James Eason Department of Natural Resources Division of Oil and Gas P. 0. Box 107034 Anchorage AK 99510-7034 A;LAND2/MH07/BGP n L~ NORTH TRAOING BAY UNIT BOUNOARY PRIOR TO AUGUST 2, 1976 --, '}" EXHIBIT 1 ATTACHED ANO MAOE A PART OF UNIT AGRE~~IENT FOR TNE flEVEi.OPMENT AND OPERATION OF THE NORTH TRADING 8AY UNIT AREA -~' ~ 1 2T~ Zs ~ T 10 iU R 13 !~/ T9RI R13W btARATHON ~~~\ ~ AOL~]5Q31 _ \ ~ ~ ~ r~ U NORTH TRADING 8AY UNIT BOUNO AND HEMLOCK b 'G' FaRMAT10', PApTIC1PATING AREA BOUNDAR I EFFEC7IVE AUGUST 2, 1976 ~ 34 \35 2 ~p~rHo UNION MARATHON \ AD~•17597\ \ ADL 18776 \ ~ ~ MAPSOURCE DIVISION OF IANDS PROTRAC710N SHEET. GRID NO. 5•13•5 STATE OIL ANO CAS LEASES A0~•17597, AOL•18776, ROL•35431 LEGENO O ~~ TRACT NO. PARTIC1PATfNG AqEA NORTH TAADING 3AY UNIT AAEA HEi1l1LOCK & `G' PARTiC1PATiNG aREA ~ COOK INLET, ALASKA PARTiC1PATiNG AREA LATEST CONTRACTION DATE: AUGUST 2, 1976 ' OWNERSHIP AS OF:SEPT. 7, 1988 R~ARA~'~H~~y ~!L C~4APA~Y ~ ~~ ~ ~ ~ , t ~ - - zaa :.aee ~.aee z.eee .aae :.~ae =.:,ae =.ae~ s.eae "' uARA?HON 0[L C;,41Pq.Yy ~ i V4RTH TRADING aAY l,tiTf I " :YHIBIT 2 ~ .aDL ss.z3f 5` POYALTY P,EDUC";Q~ ~ I m ~ 9 ~ m ~. ~ I r A ' _ I ~ I m _ ' ~ 1 ' m ,~ ~~ 71 -_~ ~ L K.~ ~, ~i:a~~~~ `\ . ~~ `~\ ~~ ~ o L ~' ~ a~ 9~ 9 L D; 91 9~ V ` a3~a ~ ~ =- ,~ - a;. ~ P.4RK ' ~~ 's-a ~ :~~1~ ~ ;,' ~ j~ ,t~~S ~ ;~;, l;. ~• ~-:an ;1./ •/`'-- ~a~~ I _.~" ,•', :/ ~.R „' ~ / _ 0~~ " CO ~~ ~t _1 .' '.ti.615/ , j5-1 ,~' ~ sd529 ~ '~~ r~ ~~ ~ ~~r ~~: ~~'~ :aees ' ~~ :2i5i /'r ~ ti i, ~ ~-` , ~ ,~; ,pr.a~~-c~@S ~ Ir ~'y ~ I = ~~ ~ , ', a _ _ ,~~,, .~~'~~J;~~3i . - ~ ~ ~ ' ~ .: ~ : - i+t ~. d «9e - , ~ I ~, I i i I ~ ~ ."'',~: --I- •."r,,,'-~'_~,,. 5 ~r ,,/ ' ! ~:~oi~~ _ - ~ ~ ~~ ,. -~ • , ;, . 'aa • , ;~ ~ •,, ~,,. e9~3~ ~ I , . y ," i r / ,' .,`A ~ n ~ ,\ ~ / / V, , / // % y ' c / • ' + ' ~ ~t64 ' / ' ~ ~ !y~ _, ' ~ . • ~ ~ ~ :Ys2~I , ~. '~•! ' ~~~1 , ^ ~ ~ , ;, -' ~ % \, ~ , ~ ;, , ~ ; / i, ~ ~W ' . / , ` ' ~ : 44li ' , • , " : ? d4 'S- , • ,y-7a^D ~ .~~~1 /• ~ I ~ • • a.~l" ~ ~ = .J a 1~T85-! . 5~ t ~Z~t I I ;:z~ I „ Z~ d s - :"aT1e v~ ":ON-R13W J;59~ ~.aea 3.aee :.aae a.eae I ~ .4DL 18776 1 ..aea .~.aee .:.eae ,.aae ~~ ~ ~m ,. m 0 1~ Im I ~ 9 ' 9 • m ~ _m ,m ,m ~. ~0 i~ I I~ ,m _m ~~ ~ N I~ m ~? Iry I ~m -; . I~ H -~ s.ea~ Laughlin, Gary A. From: Laughlin, Gary A. Sent: Monday, May 18, 2009 8:35 AM To: winton.aubert@alaska.gov Cc: Laughlin, Gary A. Subject: FW: Conversation Follow-up Importance: High Sensitivity: Confidential Attachments: Picture (Enhanced Metafile); Picture (Enhanced Metafile) ~~ ~.~ Y..~.. ,. _ t V ;~'~. ., ~ . 1.. . .... A r .- i.lr From: LaughUn, Gary A. Sent: Monday, May 18, 2009 8:21 AM To: (winton aubert@admin.state.ak.us) Cc; Laughlin, Gary A. Sabied: Conversation Follow-up Importance: High Sensitivity: Confidential Winton, This is a follow up to our conversations May 13th and May 14th, 2009. All Wells • It is my understanding you will be checking to see if you can strike the phrase "temporarily abandoned" in each well abandonment procedure and repface it • with "'permanently abandoned" for the Spark Platform sundries submitted in April 2009. We are currently running a gauge ring and temperature surveys for all wells on the Spark Platform. I expect to see the results Tuesday or Wednesday next week. After reviewing, I will send you an email on the order we plan to abandon the wells. We plan to have simultaneous well abandonment operations. The anly certainty at this time is we will abandon S-5 last. . Marathon will be added an additional 70' of cement to the top of the cement surface plug, thereby increasing it to 370' to adhere to the regulatory citation 25.112 section (d). (d) Plugging of the surface of a well must meet the following requirements: .~ ~ ~ ~ ~ C '~ 's: ~ ~ '~ ~ o •~, 3 ~ o " a~ ~" ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ N v~ s~ ~ O ~ ~ ~ ~ ~ N ~ N ~ U ~ V ~ ~ ~ ~ 4.a ~ O ~ O r~'i, ~ ~ ..~y i~l ~ ~r i~ .,ti y}.,~ ~ ~ ~! r ~ 1~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~--~ ~ N ~ cd ~ ~ ~L ~ ~ ~ 3 ~ ~ i+l ~ ~ ~ ~ ~ ~ 0 U (~y cd ~ '~ E~0' ~ O ~~~..yy t~l ~ iti ~ Q~ ~ ~ ~ ~ O ~ ~ N ~ ~ ~ O ~ ~ N ~ y .~ y ...~ r., i ... C.k ~ i~.7. ~ ~ ~ ~ = '~+ ~ a~~~~ -~~ Q .~' ~ ~ . ~ R 7S d ~ ~ ~ ~ ~ - Y - ~ ~ m ¢ ~ ~ i n -- 2 -.' 9" -. y ~ ~' .. ~. ~' ~ II ^,~ . _ '4 .. ~ _ c? ~ -6 L A: '- . :;; i .~O x ~ T ~ ? . t~ . ` * ~ ~ ~ ..r ~ i O. t[' ;~ x!; C' y~ r~ ~+ C ' 3_ ,- . , [; u~ .i.r ~ ry :p!~. ~ ' R ~ h ~ ~'~. ~ i : ~ ~ ~' a . ~ , itD X ~~ ~ ~ j ~ 'r• .. '. ! ~ r ~ .,-a i . i .• . ..t ~] Si. ... ~. . t~ ~ ~ ~ ~ ~ ~'^ . : J 4'1 ~-~ "~ ~ ~ ~ ~ ~ ~ in 1^. 'u '+~~ 0 ~ ~ ~ ~ -1 .,."i.~ : ~ n ['! P ~ - , a} .~ G! ^`J~ ~ O 'n -~ . , ~ ,.. 4 L~ u ;~_ ~~ tl 'r .'a*. * ~ : ~ ~7 ~ ~ ~ ~ .'t. et il:~ ~y' ~f • ~ a~ .c ~ ~ c a~ ~ 3 .n ~ a~ .` ~ _ ~ ~ m c 0 ~ N .~ Q N N y L H - ~a ~. •.A `. G3 ' ~ L- - 35 - ' . - L ' ~ ~ ; ~ .J 1' L~ _1 i '. ~ ~. j~ S ~ - ~ •` l:: dr • ~~ _` _ cr. i ~1; ~ "~ it: r. " y } " ."t _ c' ,:g :i `C 1 ~. - .. ._ c_ Y ' '?C J. ~ _".l „ _ _ ~ ~ _ J. ~ . ~ _. ~ ' .: ~+ a.. ' -} ~ [~} :^'} '- t ;.,~ .. ~; - .i i ' _ _ o *y. - _ z' - v~) i. . ~ ~ f .. _ ' _ i` - y j, L Ji ' ~ ~ 4-. ~ ~: = .. fO 4:-. .i L ~ - ..~ W - ~-~ _ ~ 1 t . _ ~~ N S-9 We will be attempting to remove a fish located approximately 4' below the tubing hanger stuck in the early 90's from S-9. Thanks Gary • ~Marathon Oil ~ W~1T.` ~S-3 ~ Field:~Sparl~ ~05-08-2009 ~ Pressure (psia) 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 0 Pressure-Temperature Profile 1. Going in hole to 9300' MD 1000 - 2. Well Shut-In -- 2000 - 3000 - - ---- ---- 4000 ~ d ~ ~-' 5000 -- t ~ Q ~ G sooo -- ~ooo --- --. 8000 - - 9000 10000 30 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 Temperature (Deg. F) ~ Pressure 13 3/8" 9 5/8" Temperature REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Pull tubing ~ Alter casing 2. Name of Operator Marathon 3. Address P.O. Box Oi 1 Company 102380 Anchorage, Leg 4. Location of well at surface Repair well ~ 5. lype of Well: Development __X Exploratory __ Stratigraphic m AK 9951 Service __ 3 Cond. #6 Spark Platform Stimulate __ Plugging __ Perforate __ Other ~ ~""'~' 2,613' FSL, 2,495' FEL, Sec. 26-10N-13W-SM At top of productive interval 2,074' FSL, 4,443' FEL, Sec. 26-10N-13W-SM At effective depth 2,055' FSL, 4,539' FEL, Sec. 26-10N-13W-SM At total depth 2,031' FSL, 4,627' FEL, Sec. 26-10N-13W-SM 6. Datum elevation (DF or KB) 115' KB above MSL 7. Unit or Property name North Tradin~l Ba,y Unit 8. Well number feet 9. Permit number/approval number 91-409//'~,,,,,,,'~.~' ~' 10. APl number 5~r33-20175 11. Field/Pool · Hemlock & G-Zone 12. Present well condition summary Total depth: measured 10,541 ' feet true vertical 10,12 7 ' feet Effective depth: measured 9,645 ' feet true vertical 9,287 ' feet Casing Length Structural Conductor Surface 2,006' Intermediate Production 10,484 Liner Perforation depth: measured See Attachment #1 true vertical Size Plugs (measured) Junk (measured) Cemented 9,645' - 9~,695' CMT 9,697' - 10,218' CMT 10,265' - 10,541' CMT 10,060' Top of fish. MeasureloO~' - 10 ,-1~Sv~rti[Jl~C~pth 13 3/8" 800 sx 2,006' 2,006' 9 5/8" 1000 sx 10,484' 10,003' RECEIVED 13. Tubing (size, grade, and measured depth) p NO tub.ixu3.. £urrent lv i n wel 1 acKers an(] 3~v (,wPe ano measureo oepth) Baker DB Packer ca 9,75,0' Stimulation or cement squeeze summary Intervals treated (measured) APR 1 ? 1992 Alaska 0il & Gas Cons. Gom~ss~t0t~ AnchOrage 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 0 0 Subsequent to operation 0 0 15. Attachments 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 /~.~ .(~~. TitlOeperations Engineering Supv. Form 10-404 Rev 06/15/88 ,/ Date ~//~/, ~' Z~ SUBMIT IN/DU'P~.ICATE G-1 G-2 G-3 G-4 G-5 H-1 H-2 H-2 ATTA~II*E~ ~! Spark Well S-3 Perforations 9,944' - 10,006' MD 10,022' - 10,070' MD 10,083' - 10,102' MD 10,112' - 10,140' MD 10,152' - 10,190' MD 10,208' - 10,258' MD 10,258' - 10,265' MD 10,265' - 10,344' MD 9,613' - 9,624' TVD 9,640' - 9,684' TVD 9,696' - 9,714' TVD 9,724' - 9,750' TVD 9,761' - 9,797' TVD 9,814' - 9,861' TVD 9,861' - 9,867' TVD 9,867' - 9,942' TVD Cemented off II MRO/em/3gB/Sundr2 RECEIVED APR 1 ? t992 j~las.ka Oil & Gas Cons. t;ommission Anchorage Attachment #2 Note: SPARK WELL S-3 Daily Wel 10perat ions Report All producing intervals (G and Hemlock) were plugged and abandoned in December, 1986. 2/25/92 Installed pressure gauges on tubing and 9-5/8" casing. Tbg = 0 psi. Csg. : 0 psi. Well shut in with all valves on tree closed. \Spark\S3.doc RECEIVED APR 1 ? 199~ Alaska Oil & Gas Cons. CommissiOn Anchorage Attachment #3s~ Pu~' 2006' 13-3/8" Inlet Water ALL P EPI=$ __ ($queeze~ 12-i0-86) 9994' - 10,006' G-2 10,022' - 10,070' G-3 10,083' - 10,102' G-4 10,112' --i--10,140' G-5 10,152 '-'C-10,190 ' > II-1 & 11-2 10,208' - 10,344 9645' Top of Cea. mt 12-10-86 9695' Baker 9-5/g" Cement ..' 9735' Baker 9-5/B" t.~O. "DB" Packer 10,061' TOF 12-01-86 XO Sub 1.10' Oil Jars 7. B0' Bummper Jars 9.05' XO Sub 1.12' 3 - 6-1/4' D.C. Bit Sub 2.22' 2.- Junk Sub '6.87' 8-1/2" SlL .50' Gas Lift Valve 10,218 ~ Fill. < _ 10,255' C~ Plug 10,484' 9-5/8" 47l 10,541' TD ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casmg__ Repair well ~ Change approved program __ 2. Name of Operator ! 5. Type of Well: Marathon Oi 1 Company l Development X~ Exploratory ~ 3. Address Stratigraphic ~ P.O. Box 102380 Anchora,ge, ~AK,. 971 Service__ 4. Location of well at surface LCt~ O VO,'~U. ~'G .Spark 2,613' FSL, 2,495' At top of productive interval 2,074' FSL, 4,443' At effective depth 2,055' FSL, 4,539' At tot~l,cl(~§~, ESL, 4,627' Operation shutdown __ Re-enter suspended well ~ Plugging __ Time extens,on __ Stimulate ~ Pull tubing ~ Variance __ Perforate ~ Other _.Z. FEL, Sec. 26-10N-13W-SM FEL, Sec. 26-10N-13W-SM FEL, Sec. 26-10N-13W-SM FEL, Sec. 26-10N-13W-SM 6. Datum elevation (DF or KB) 115' KB above MSL 7. Unit or P_rope, rt.y nam.e North Irao~ng ~ay Unit 8. Well number S-3 9. Permit number 69-11 10. APl number 5~I-33-20175 11. Field/Pool Hemlock & 6-Zone feet 12. Present well condition summary Total depth: measured true vertical 10,541' 9 645' - g 695' CMT feet Plugs (measured) ' ' 9,697' - 10,218' CMT 10,127' feet 10,265' - 10,541' CMT Effective depth: measured true vertical 9,645 ' feet Junk (measured) 9,28 7' feet Casing Length Structural Conductor Surface 2,006 ' Intermediate Production 10,484 Liner Pe~foraticjri deptl~: meas~[ed 3ee At~acnmen~: ~z Size Cemented true vertical Tubing (size, grade, and measured depth) No tubing currently in well Pa~kQrs anqt.$.SS~V (type and..m¢,as.v [.e,,d,depth) uaKer UI5 I.'acKer LC~ 9,/3U' 10,060' Top of fish 10,218' - 10,265' Fill Measured depth True vertical depth 13 3/8" 800 sx 2,006' 2,006' 9 5/8" 1000 sx 10,484' 10,003' RECEIVED OEO 1 ? 1991 Alaska Oil & Gas Cons. Comm'~s¢~on Anchorage 13. Attachments 1, 2, Description summary of proposal _~. &3 Detailed operations program BOP sketch __ 14. Estimated date for commencing operatiOn 115. Status of well clasSification as: January 2, 1992 16. If proposal was verbally approved Oil ~T Gas ~ Suspended __ Name of approver Date approved Service 17. I hereby certify that the fo/cegoi ng is true and correct to the best of my knowledge. Signed (,,~''~¢ (~' ~//¢ FoRTitle 0perat i °n s En 'qi neeri n q Su Pe rv' DatecoMMISSION 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 mGNED BY LONNIE 6, SMITH 1 Approval No. ~ n,, ¢,-'5. 009¥ Commissioner Date G-1 G-2 G-3 G-4 G-5 H-1 H-2 H-2 ATTACHMENT -- Spark Wel 1 S-3 Perforations 9,944' - 10,006' MD 10,022' - 10,070' MD 10,083' - 10,102' MD 10,112' - 10,140' MD 10,152' - 10,190' MD 10,208' - 10,258' MD 10,258' - 10,265' MD 10,265' - 10,344' MD 9,613' - 9,624' TVD 9,640' - 9,684' TVD 9,696' - 9,714' TVD 9,724' - 9,750' TVD 9,761' - 9,797' TVD 9,814' - 9,861' TVD 9,861' - 9,867' TVD 9,867' - 9,942' TVD Cemented off MRO/em/39B/Sundr2 RECEIVED DEC 1 ? t991 Alaska Oil & Gas Cons. Commission Anchorage Attachment #2 SPARK WELL S-3 WELL SECURING PROCEDURE Note: le All producing intervals (G and Hemlock) were plugged and abandoned in December, 1986. Ensure pressure gauges on dry hole tree and casings are calibrated. Leave well SI - no other work required. \spark\s3.doc RECEIVED DEC 1 7 l~Jgl Alaska 0il & Gas Cons. Commission Anchorage Attachment ~3 12-11-86 Dry llole Tree N 2006' 13-3/8" 61~ Inlet Water ,/ .~, , ~ ~ 9735' Baker 9-5/8" ~.~)D. "DB" (Squeezed 12-10-86) I' ~, ~-c ' ^l Packer I.^~ ~ I I~ ~. ¥ ~ ~ 9994' - 10,006' > J. ~ ~ ~ ~ ~ / 10,022' - 10,070' > ~1 * ~ ~ ~1 10,061' ~F 12-01-86 ]' ~ <~ ~. c .~ XO S~ 1.10' . ~3 % ~ B~r J~s 9.05' 10,083,~10,102, > ~ ~. ,.l ~ a~ XO S~ 1.12' ~ . ~ 3 - 6-1/4" D.C. 93.47' ~ ~ , , / ~ ~l IV ~/ Bit S~ 2.22' , ~1 ~ ~ I I~ ~4 v~v 8-1/2" Bit .50' 122.13' ~5 10'152'~10'190' > l~.~ ~' ~/ ~ ~ 5[~t Valve 10,208' 10,3~4' > ~.:., .~ f · . 10,218' Fill ;v "u II~'.~/.< ~:.-~..b~,:. I'?. J::.-.... / . _10,265' C~ent Plug DEC 1 7 1991 AJ~sk~ Oil & G~s Cons. Corn Anchorage 9645' Top of Cement 12-10-86 9695' Baker 9-5/8" [.1od "K-I" Cement Retainer 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 102380 Anchorage, AK 99510 4. Location of well at surface Leg ;5 Cond. #b Spartc t'lattorm 2,613' FSL, 2,495' FEL, Sec. 26-10N-13W-SM At tOp of productive interval 2,074' FSL, 4,443' FEL, Sec. 26-10N-13W-SM At effective depth 2,055' FSL, 4,539' FEL, Sec. 26-10N-13W-SM At total depth 2,031' FSI,, 4,627' FEL, Sec. 26-10N-13W-SM 5. Datum elevation (DF or KB) 115' KB above MSL Feet 6. Unit or Property name North Trading Bay Unit 7. Well number S-3 8. Approval number 563 (also see 639) 9. APl number 50-- 133-20175 10. Pool Hemlock & G-Zone 11. Present well condition summary Total depth: measured true vertical 10,541 ' feet 10,127' feet Effective depth: measured 10,060 ' true vertical 9,632' Casing Length Size Structural Conductor Surface 2,006' 13 3/8" Intermediate Production 10,484 9 5/8" Liner Perforation depth: measured See Attachment #1 true vertical feet feet Plugs (measured) 10,265' ' 10,541' CMT Junk(measured) 10,060' Top of fish Cemented Measured depth True Vertical depth 800 sx 1000 sx 2,006' 10,484' 2,006' 10,003' Tubing (size, grade and measured depth) Pac ke3 r'?a/n2;' S9S§V2 ~{t y~%% dtbmge ~s u~re9d '2e4p t21~) Baker DB Packer @ 9,750' RECEIVED JAN 2 0 1987 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Naslm 0il & Gas Cons. Commission Anchorage 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 9/21/86 19 87 377 700 Subsequent to operation 12/08/86 11 N/A 550 1040 Tubing Pressure 60 65 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 District Operations Engineer Title Date Form 10-404 Rev. 12-1-85 , Submit in Duplicate G-1 G-2 G-3 G-4 G-5 H-1 H-2 H-2 ATTACHMENT #1 Spark Well S-3 Perforations 9,944' - 10,006' MD 10,022' _ 10,070' MD I0,083' - 10,102' MD 10,112' - 10,140' MD 10,152' _ 10,190' MD 10,208' - I0,258' MD 10,258' - i0,265' MD 10,265' _ 10,344' MD 9,613' - 9,624' TVD 9,640' - 9,684' TVD 9,696' - 9,714' TVD 9,724' - 9,750' TVD 9,761' - 9,797' TVD 9,814' - 9,861' TVD 9,861' - 9,867' TVD 9,867' - 9,942' TVD MRO/em/39A/Sundr2 Cemented off RECEIVED JAN 2 0 1987 Alaska 011 & Gas Cons, Commission Anchorage Attachment #2 NTBU Well S-3 Daily Operations 1986 11-12-86 11-13-86 11-14-86 11-15-86 11-16-86 11-17-86 11-18-86 11-19-86 11-20-86 11-21-86 10,541' TD The Spark Platform drilling rig is being activated to workover NTBU Wells S-3 and S-9. Parker Drilling on board 11 November 86 to begin activation. Continued rig activation. Continued rig activation. SI S-3. RU to 9-5/8" x 3-1/2" annulus and bled lift gas pressure. Began to fill annulus w/fresh water. Finished filling annulus w/fresh water. RU WL. RIH w/2' perf gun & perforated tbg @ 9764'. POOH & RD WL. Displaced hole w/3% KCL workover fluid. Circulated to kill well. Checked well for flow - dead. Set BPV. ND X-mas tree. NU BOPE. Tested BOPE - could not test pipe rams or annular BOP due to tubing hanger leak. Attempted to release hydraulic packer - would not pull loose w/maximum pull of 215,000#. RU WL. RIH w/jet cutter and cut tubing @ 9728' WLM. POOH & RD WL. Circ BU twice. Started pulling 3-1/2" tbg - 196 its pulled @ 0600. Finished LD 3-1/2" tbg. LD total of 9680'. Tested pipe rams to 3000 psi. MU kelly, swivel & kelly bushing. MU overshot dressed for 3-1/2" tbg. RIH PU DP. RIH PU DP to 9693'. Circ BU. Tagged TOF @ 9723'. Worked overshot over fish. Jarred packer loose w/maximum pull of 310,000#. POOH & LD fishing tools and fish - 3/12" jts of tbg, packer, gas lift mandrel and Q-nipple. MU boot basket and 8-1/2" bit and RIH. Cleaned out fill from 9925' to 10,020'. Cleaned out fill in 9-5/8" csg f/10,020' to 10,028'. ROP decreased and torque increased last 2' - suspected junk in hole. POOH to 5352' - hole taking 12 bph. RIH & spotted hi vis pill across perforations. POOH. RIH w/junk mill. Milled on junk f/10,028' to 10,031'. Page 2 11-22-86 11-23-86 11-24-86 11-25-86 11-26-86 NTBU Well S-3 Daily Operations (continued) Milled on junk w/8-1/2" mill f/lO,031' to 10,033'. POOH w/mill. Rig down 19 hours w/electrical problems. 10,541' TD Fin POOH w/8-1/2" mill. RIH w/8-1/2" bit to 10,O33'. Drilled on junk f/10,033' to 10,040'. POOH w/8-1/2" bit. RIH w/8-3/8" mill to 9996'. Washed and reamed f/9996' to 10,028' - could not work mill past 10,028'. Attempted without success to work 8-3/8" mill past 10,028'. POOH. Tested BOPE. MU 6" mill and RIH. Tagged @ 10,027'. Worked mill past 10,028' and down to 10,040'. Milled on junk f/10,040' to 10,041'. POOH w/6" mill. PU 6" flat btm mill. RIH. Work mill thru tight spot @ 10,027'. Mill 10,041'-10,049'. Mill quit. POH. Mill completely worn. PU 6" bull nose mill. RIH. Work mill 10,030'-10,049'. Mill 10,049'-10,052'. Very high torque. POH. Mill worn on outer edge 2" in. No wear in center. Fin POH. Mill worn 1-1/2" from outer edge. Very little wear in center. PU 6" flat btm mill and 8-1/2" string mill. RIH. Mill bad casing 10,027'.-10,028'. Ream to 10,052'. High torque - ~ P. OH. Flat btm mill worn 1/4" from outer edge. PU r~\~\B~L1/2'' flat btm mill and 2 junk bskts. RIH. Ream thru tight spot 10,027'-10,028'. Ream w/very high torque 10~036'-10,038'. Steady very smooth reaming to 10,054'. Mill quit. POH. Recovered coal and sand in junk bskts. See some coal over shakers. 11-27-86 11-28-86 Fin CBU. POH. LD 8-1/2" flat btm mill. PU 8-1/2" bit. RIH. Ream 10,038'-10,054'. Had to rotate thru ledge @ 10,042'. Clean out 9-5/8" csg 10,054'-10,096'. CBU. POH. PU 8-1/2" bit. RIH. Fin RIH w/8-1/2" bit. Clean out 9-5/8" csg 10,096'-10,218'. POH 15 stds. Hole taking fluid @ rate of 10 BPH. RIH to 10,184'. Pipe became stuck while PU kelly. Had no indication of pipe becoming stuck. Work stuck pipe. Jarred w/350,000#. No movement. Suspect differential sticking. SD pumps - allow fluid level to drop 5 hours. Work stuck pipe to 350,000#. CBU. No movement. Page 3 NTBU Well S-3 Daily Operations (continued) 11-29-86 11-30-86 12-01-86 12-02-86 12-03-86 12-04-86 12-05-86 10,541' TD Spot 25 bbl diesel pill around BHA. Work stuck pipe 6 hours while diesel soaked. No movement. Attempt to free pipe by pressuring annulus to 500# and 1000# and bleeding pressure quickly. No success. RUN2 to kill line. Displace hole to 2500'. Bled N2. Upper 1/2 of BHA became free - recovered jar action. No further movement. RU WL and free point indicator. Fin running FPI. BHA 100% stuck from btm of oil jars down. BHA consist of bit, 2 junk bskts, BS, 3 DC's, XO, bumper sub, oil jars, XO, 3 DC's, XO. Total length 216.91'. RIH w/string shot. Fired shot between jars & bumper sub. No backoff. Lost jar action. Run FPI. Top DC stuck. Fire string shot @ 9938' WLM. POH w/DP. Left entire BHA in hole. TOF @ 9967' DPM. MU fishing BHA. RIH. Screw into fish. Could not circ. Jar on stuck DP. Jars quit. RIH w/string shot to back off @ 9938' WLM. Fire string shot. Achieve backoff. POH. Rec all of fishing BHA. TOF @ 9967' DPM. Drilled hole in screw in sub for circ ports. RIH w/fishing BHA. Screw into fish. Work stuck pipe. RUN., on annulus. Displace hole down to 3200'. Bleed ~? press. Jar on stuck DP. Upper part of BHA became ~ree. Recovered lower jar action. RU string shot. RIH. Attempt backoff @ btm of lower jars - no success. MU new string shot. RIH w/string shot. RIH w/string shot. Backoff @ connection above oil jars. POH. Left XO on top of oil jars. Rec XO and 3 DC's. TOF @ 10,060' DPM. RIH w/bit & scraper. Tag TOF @ 10,060'. Circ hole clean. Circ hole clean w/high vis sweep. RU DA. Run DIL correlation log. RU to pump WO fluid to prod. Displ fluid in hole w/fresh H20 w/bit @ 9928'. Will spot 100 bbls 3% KCL fluid on btm. Prep to complete well. Fin displacing WO fluid w/fresh water. Spotted 90 bbl water w/3% KCL on bottom. POOH. MU permanent production packer on drill pipe. RIH and set packer at 9750' DPM. Tested packer and 9-5/8" csg to 2500 psi for 30 min - OK. POOH LD DP. Cont POOH laying down drill pipe. Change rams to 3-1/2" & RU to run 3-1/2" tubing. Page 4 12-06-86 10,541' TD 12-07-86 " 12-08-86 " 12-09-86 " MRO/em/39A/Sundr2 NTBU Well S-3 Daily Operations (continued) Finished running 3-1/2" production tbg. Installed BPV. ND BOPE. NU X-mas tree and tested to 3000 psi - OK. Pulled BPV. Began unloading water from well with gas lift. Continued unloading water from well with gas lift. 820 bbl unloaded at 0600. Finished unloading water with gas lift. Tested well for 23 hours. Tested S-3 an additional 5 hours: 552 BFPD, 11BOPD, 98% water. SI S-3 and bled pressure from tbg and tbg/csg annulus. Filled tbg w/45 bbl water. Filled casing w/661 bbl water. RU WL. RIH & perfed tbg @ 9670'. POOH & RD WL. Circulated water to production system. RECEIVED JAN 2 0 ]987 Naska 0il & Gas Cons, Commission Anchorage STATE OF ALASKA ALAS( OIL AND GAS CONSERVATION COMI~ ~SION 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 102380 Anchorage, AK 99510 4. Location of well at surface Leg ~ t;ond. #6 spark ?iacfo~_,,, 2,613' FSL, 2,495' FEL, Sec. 26-10N-13W-SM At top of productive interval 2,074' FSL, 4,443' FEL, Sec. 26-10N-13W-SM At effective depth 2,055' FSL, 4,539' FEL, Sec. 26-10N-13W-SM At total depth 2,031' FSL, 4,627' FEL, Sec. 26-10N-13W-SM 5. Datum elevation (DF or KB) 115' KB above MSL Feet 6. Unit or Property name North Tra~ing Bay Unit 7. Well number S-3 8. Approval number 639 (also see 563) 9. APl number 50-- 133-20175 10. Pool Hemlock & G-Zone 11. Present well condition summary Total depth: measured true vertical Effective depth: measured 9,645 ' feet true vertical 9,287 ' feet Casing Length Size Cemented Structural Conductor Surface Intermediate Production Liner 10,541 ' feet Plugs (measured) 10,127 ' feet 2,006' 13 3/8" 10,484 9 5/8" Perforation depth: measured See Attachment #1 true vertical Junk (measured) 9,645' - 9,695' CMT 9,697' - 10,218' CMT 10,265' - 10,541' CMT 10,060' Top of fish 10,218' - 10,265' Fill Measured depth ~ue Verticaldepth 800 sx 2,006' 2,006' 1000 sx 10,484' 10,003' Tubing (size, grade and measured depth) No tubin~ currently in well Packers and SSSV (type and measured depth) Baker DB Packer @ 9,750' 12. Stimulation or cement squeeze summary See Attachment #2 and #3 Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED .JAN 2 0 !987 Naska 0il & Gas Cons. Commission Anchorage 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 12/08/86 11 N/A 550 1040 12/11/86 Operations temporarily suspended Tubing Pressure 65 14. Attachments #2 & #3 Daily Report of Well Operations E~ Copies of Logs and Surveys Run [] 15.1 hereby certify that the foregoing is true and correct to the best of my knowledge ~ /,~. /~".-. ~'~,. Signed ,~..~/~'~¢'7 ~_/~ Title District Operations Engineer Date Form 10-404 Rev. 12-1-85 Submit in Duplicate G-1 G-2 G-3 G-4 G-5 H-1 H-2 H-2 ATTACHMENT # 1 Spark Well S-3 Perforations 9,944' - 10,006' MD 10,022' - 10,070' MD 10,083' - 10,102' MD 10,112' - 10,140' MD 10,152' - 10,190' MD 10,208' - 10,258' MD 10,258' - 10,265' MD 10,265' - 10,344' MD 9,613' - 9,624' TVD 9,640' - 9,684' TVD 9,696' - 9,714' TVD 9,724' - 9,750' TVD 9,761' - 9,797' TVD 9,814' - 9,861' TVD 9,861' - 9,867' TVD 9,867' - 9,942' TVD Cemented off ,, MRO/em/39B/Sundr2 RECEIVED JAN 2 0 1987 Naska 0ii & Gas Cons. Commission Anchorage Attachment #2 NTBU Well S-3 Daily Operations 12-10-86 12-11-86 " 12-12-86 " 10,541' TD Circulated one hole volume to production system, then one hole volume to mud pits. Observed well - dead. Set BPV. ND X-mas tree. N~ BOPE. Tested BOPE. LD tbg hanger. Circulated one hole volume. POOH w/and LD 3-1/2" production tbg and completion jewelry. Changed to 5" pipe rams. Installed wear bushing. PU DP and-RIH w/cement retainer. Set retainer @ 9695'. RU cementers. Established injection rate into perforations @ 2 bbl/min @ 3000 psi. Squeezed perforations w/175 sx cement. POOH 8 stands. Reversed DP clean. POOH & LD DP. Fin LD DP. k~ BOPE. NU dry hole tree. Released rig to S-9 workover at 1800 hrs, 11 December 1986. FINAL REPORT. MRO/em/39B/Sundr2 ~ Attachment #3 SPARK PLATFO~ Well S-3 12-11-86 Dry HoleTree 2006' 13-3/8" 61~ Inlet Water ALL PERFS DIL (Squeezed 12-10-86) G-1 9994' - 10,006' G-2 10,022' - 10,070' G-3 10,083' - 10,102' G-4 10,112' 10,140 ' G-5 10,152' - 10,190' H-1 & H-2 10,208' - 10,344' 9645' Top of Cement 12-10-86 9695' Baker 9-5/8" Mod "K-i" Cement Retainer 9750' Baker 9-5/8" MOD. "DB" Packer 10,061' TOF 12-01-86 XO Sub 1.10' Oil Jars 7.80' Bumper Jars 9.05' XO Sub 1.12' 3 - 6-1/4" D.C. 93.47' Bit Sub 2.22' 2 - Junk Sub 6.87' 8-1/2" Bit .50' 122.13' Gas Lift Valve 10,218' Fill < 10,265' Cement Plug 10,484' 9-5/8" 47~ STATE OF ALASKA ALA~'~ . OIL AND GAS CONSERVATION CON{'" 3SION 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 Leg 5 Cond. #6 Spark. Platform 2,613' FSL, 2,495' FEL, Sec. 26-10N-13W-SM At top of productive interval 2,074' FSL, 4,443' FEL, Sec. 26-10N-13W-SM At effective depth 2,055' FSL, 4,539' FEL, Sec. 26-10N-13W-SM At total depth 2,031' FSL, 4,627' FEL, Sec. 26-10N-13W-SM 5. Datum elevation (DF or KB) 115' KB above MSL feet 6. Unit or Property name North Trading Bay Unit 7. Well number S-3 8. Permit number 69-11 9. APl number 50-- 133-20175 10. Pool Hemlock & G-Zone 11. Present well condition summary Total depth: measured true vertical 10,541 ' feet Plugs (measured) 10,127 ' feet 10,265' - 10,394' CMT,, 10,394' - 10,541' Effective depth: measured 10,265 ' true vertical 9,867 ' Casing Length Size Structural Conductor Surface 2,006 ' 13 3/8" Intermediate Production 10,484 9 5/8" Liner Perforation depth: measured See Attachment #1 true vertical feet feet Junk(measured) 10,005' - 10,265' Fill 10,036' Top of drill collar fish Cemented Measured depth True Vertical depth 800 sx 2,006' 2,006' 1000 sx 10,484' 10,003' RECEIVED Tubing (size, grade and measured depth) No tubin~ currently in well. Packers and SSSV (type andmeasured depth) Baker DB Packer @ 9,750' .... 1 6 1986 Alaska 0ii & Gas Corm. C0mm~$s~t)n 12.Attachments< #2 & Description summary of proposal ~ Detailed operations program [] BOP sketch [] #3 13. Estimated date for commencing operation December 1986 14. If proposal was verbally approved Name of approver Russ Douglas Date approved 12/8/86 15. I hereby.certify that the foregoing is true and correct to the best of my knowledge Signed /..~/C~--~ ~-/'~~ Title District .Operations Engineer Commission Use Only Conditions of approval Notify commission so representative may witness I Approva, No. [] Plug integrity [] BOP Test [] Location clearance by order of Commissioner the commission Date Approved by Form 10-403 Rev 12-1-85 Submit in triplicate G-1 G-2 G-3 G-5 H-1 H-2 H-2 ATTACfIMENT #1 Spark Well S-3 Perforations 9~944' - 10,006' MD 10,022' - 10,070' MD 10,083' - 10,102' MD 10,112' - 10,140' MD 10,152' - 10,190' MD 10,208' - 10,258' MD 10,258' - 10,344' MD 10,265' - 10,344' MD .. · 9,613' - 9,624' TVD 9,640' - 9,684' TVD 9,696' - 9,714' TVD 9,724' - 9,750' TVD 9,761' - 9,797' TVD 9,814' - 9,861' TVD 9,861' - 9,942' TVD cemented off MDC / em/39 / Sundry . mo . . Attachment #2 Operation Shutdown Procedure Spark Well S-3 Kill well w/inlet water. POOH w/ and LD 3 1/2" prod'n tbg and jewelry. RIH w/cmt retainer on DP. Set retainer @ ±9,700'. Pump 130 sx cement below retainer. Spot 20 sx on top of retainer (±50' cement). ~.. 5. LD DP . Install dry hole tree on S-3. Release rig. . MDC/em/39/Sundry Attachment #3 Spark Well S-3 Operation Shutdown (Current) 2,006' 13 3/8" 61# (Proposed) All Perfs DIL G-1 9,994'~10,006' ~ 0-2 10,022'~10,070' (i-3 10,083' - 10,102' 0-4 10,112' -~10,140' G-5 10,152' - 10,190' H-I &H-2 10,208' - 10,344' · Permanent packer @ 9,750' . ~10,036' Drill collar fish I0,200' Top of fill 10,265' cement plug 10,394' PBTD 10,484' 9 5/8" 47# 10,541' TD All Perfs DIL G-1 9,994' - 10,006' G-2 10,022' - 10,070' (;-3 10,083' - 10,102' (;-4 10,112' - 10,140' G-5 10,152' - 10,190' H-I & H-2 10,208' - 10,344' ~ 9,650' cement plug ~ 9,700' cement retaineI Permanent packer @ 9,75C Squeezed w/175 sx cement 10,200' Top of fill - 10,265' cement plug 10,394' PBTD 10,484' 9 5/8" 47# - 10,541' TD I~AKER PACKERS DIVISI('~N WELL NO. ~ ' '~ LEASE 12" g -'~3 g. FORM NO. 20-27 (6/76) STATE OF ALASKA 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 I~ Other [] 2. Name of Operator Marathon Oil Company 3. Address P.0. Box 102380 Anchorage, AK 99510 4. Location of well at surface Leg 3 Cond. #6 Spark Piar. fo~.,,, 2,613' FSL, 2,495' FEL, Sec. 26-10N-13W-SM At top of productive interval 2,074' FSL, 4,443' FEL, Sec. 26-10N-13W-SM At effective depth 2,055' FSL, 4,539' FEL, Sec. 26-10N-13W-SM At total depth 2,031' YSL, 4,627' FEL, Sec. 26-10N-13W-SM 5. Datum elevation (DF or KB) 115' KB above MSL feet 6. Unit or Property name North Trading Bay Unit 7. Well number S-3 8. Permit number 69-11 9. APl number 50-- 133-20175 10. Pool Hemlock & G-Zone 11. Present well condition summary Total depth: measured true vertical 10,541 ' feet Plugs (measured) 10,127' feet 10,265' 10,394' - 10,394' CMT - 10,541' CMT Effective depth: measured 10,265 ' true vertical 9,867' feet Junk (measured) feet 10,005' - 10,265' Fill Casing Length Size Structural Conductor Surface 2,006' 13 3/8" Intermediate Production 10,484 9 5/8" Liner Perforation depth: measured See Attachment #1 true vertical Cemented Measured depth Tubing (size, grade and measured depth) 3 1/2" 9.2# N-80 tbg. @ 9,942' Packers and SSSV(type and measured depth) Brown RHSP Packer @ 9,910' Camco BV @ 253' True Vertical depth 800 sx 2,006' 2,006' 1000 sx 10,484' 10,003' RECEIVED NOV 1 0 !986 Alaska 0ii & Gas ConS. Commission Anch0raga 12.Attachments #2 & 3 Description summary of proposal~l~ Detailed operations program [] BOP sketch [] Attachment #4 13. Estimated date for commencing operation November 1986 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 /~.)/~c,3~ ~ Title District Operations Engineer Date li/tc/~ Commission Use Only Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Commissioner J Approval No. ~.._~/ Subsequent Worl~ .aepor~ l the commission Date //'/~-f~ ] Form 10-403 Rev 12-1-85 Submit in triplicate G-1 G-2 G-3 G-4 G-5 H-2 H-2 Spark Weld S-3 Perforations 9,944' _ 10,006' MD 10,022' _ 10,070' MD 10,083' - 10,102' MD 10,112' _ 10,140' MD 10,152' . 10,190' MD 10,208' _ 10,258' MD 10,258' _ 10,344' MD 10,265' _ 10,344' MD 9,613' - 9,624' TVD 9,640' - 9,684' T~D 9,696' - 9,714' TVD 9,724' - 9,750' TVD 9,761' _ 9,797' TVD 9,814' - 9,B61' T~D 9,861' _ 9,942' TVD cemented off MDclem1391Sundry RECEIVED Alaska Oil & Gas Cons, Commission Anchorage ATTACHMENT #2 S-3 Workover Procedure 1. Skid rig #80 over Well S-3. 2. Fill tubing and annulus w/ 3% KCL fluid. 3. RU W.L. RIH and perf circ holes @ ± 9,800'. POH RD WL. 4. Circ until dead. 5. Set BPV ND tree NU and test BOPE. 6. POH & LD tubing and completion equipment. 7. PU & RIH w/ 8½" Bit and D.P. Clean well out to 10,265'. POH. 8. RIH w/ 9 5/8" casing scraper. Circ. well clean. POH. 9. RIH w/ RBP to 9,800 - set RBP, test Csg. POH. 10. M/U 5" tubing conveyed perf guns RIH. Perforate the following intervals 4SPF, 90° phasing with 32 gm or greater charges. Interval DIL Depth Length G-1 9,994' - 10,006' (12') G-2 10,022' - 10,070' (48') G-3 10,083' - 10,102' (19') G-4 10,112' - 10,140' (28') G-5 10,152' - 10,190' (38') H-1 10,208' - 10,247' (38') H-2 10,247' - 10,260' (13') 11. POH L/D TCP equipment. 12. RIH w/ Perm packer on drill pipe. Set and test packer at ± 9,800'. POH LD DP. 13. RIH w/ completion equipment. 14. Set BPV ND BOPE NU & test tree. 15. Unload & test well. Release rig. 16. After well has stabilized, run GLS, PBU, and production logs. * Static bottom hole pressure 3,450 psi RECE. IVED MDC/em/39/Sundry NOV 1 o lSSS Alaska Oil & Gas Cons. Commissio;~ Anchorage North Trading Bay Unit Spark Well S-3 (Current) 253' Camco BV Attachment f/3 ~ ~-- 2,006' 13 3/8" 61# 3 i/2" 9.2# N-80 tbg. North Trading Bay Unit Spark Well S-3 (Proposed) , 250' TRBV ~' ~'- 2,006' 13 3/8" 61# 3 1/2" 9.2# N-80 tbg. All Perfs DIL C,-1 9,994' ~0,006' C~-2 L0,022' - 10,070' [0,083' - 10,102' .0,112' ~-~0,140' .0,152' ~-]'0,190' H-I & H-2 ~0,208' - 10,344' ,, 9,910' Brown PdiSP packerl 9,942' Otis "Q" Nipple 10,005' Fill (5/16/80) ( 10,225' 1 I/2" GLV ~ 10,265' cement plug < 10,394' PBTD ~------ 10,484' 9 5/8" 47# < 10,541' TD Ail Perfs DIL 9,994' - 10,006' G-2 10,022' - 10,070' 10,083' - 10,102' G-4 10,112' - 10,140' 10,152' H-1 10,208' 0-5 14 ---~0,190' &_ H-2 10,344' -- ; 4------ i 9,800' permanent packt -+ 9,865' WL reentry gui~ < - I0,265' cement plug <------- I0,394' PBTD "~-----' 10,484' 9 5/8" 47# NOV1 o 1585 · Alaska OJ~ & ~as Cons. Commi~s[o~ Anchorag~ Attachment #4 MARATHON OIL COMPANY SPARK PLATFORM MUD PAN [~.~ FLOWLIN E DRILLING NIPPLE U i j 1 3 5/8'x5,000,~ ANNULAR PREVENTER (HYDRIL) CLAMP CONNECTOR r-'l "~ r-m CHOKE LINE 3'X5 000,~, · DRILL DECK FLOOR CLAMP CONNECTOR RECEIVED NOV l 0 ,o,~ Oil & 6as Cons. Co~missio~ Anchorage, ARCO Oil and Ga{ ~pany Alaska Dist ri~.L Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 28, 1980 Mr. Hoyle Hamilton, Chairman Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99501 IFIlIU~. _ Re: Spark Platform, S-3 Well Dear Mr. Hamilton' Enclosed are two copies of the Sundry Notice of the clean-out and reperforation work and two copies of the Monthly Report of Drilling and Workover Operations on the S-3 well. Sincerely, · . Knowles District Drilling Superintendent CRK/LAE/dac Enclosures (4) File: UCI 3.4 ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form 10~03 REV. 1-10-73 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) O,L ~ GAS r-1 WELLI,~.I WELLU OTHER 2. NAME OF OPERATOR ARCO Oil & Gas Company 3. ADDRESS OF OPERATOR P. 0. Box 360, Anchorage, Alaska 99510 2613'N & 2495'W from SE Corner, Sec 26, T1ON, R13W, SM 4. LOCATION OF WELL At surface Spark P1 atform' 13. ELEVATIONS (Show whether DF, RT, GR, etc.) llS' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-2(1175 6. LEASE DESIGNATION AND SERIAL NO. ADL 35431 7. IF INDIAN, ALLOTTEE OR TRIBE NAME , 8. UNIT, FARM OR LEASE NAME North Trading Bay Un11: 9. WELL NO. S-3 (13-26) 10. FIELD AND POOL, OR WILDCAT Trading Bay NE "G", Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 26, T1ON, R13W, SM 12. PERMIT NO. 69-11 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS , SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING, CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) Clean-out & reperforate (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and 9ive pertinent dates, including estimated date of starting any proposed work. On 5/10/80, RU Otis snubbing equipment and tested BOPE - OK. Drilled hard sand fill from 9935: - 10,032' As POH to change mills, twisted off & left junk in hole. Fished unsuccessfuily. Released well to production department @ 1400 hrs, 5/17/80. 24 hour test, 5/22/80, 1038 BFPD: 42 BOPD, 996 BWPD (96% cut). RECEIVED 16. I hereby_certify that the foregoing is true and correct TIT Disi; Drlg Sup1; DATE May 29. 1980 (This space for State office use) APPROVED BY ,, CONDITIONS OF APPROVAL, IF ANY: TITLE ,, , DATE See Instructions On Reverse Side' F~tm No. P.--4 REV. 3- I-?O STATE O~' ALASKA OIL AND GAS CONSERVATION COMMI"ri'EE MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS SUBMIT IN DUPLICATE 5. Alii N1J~{I~.R/CAL CODE 50-133-20175 6 LF~kSE DESIGNATION AND SEI~IAL NO, ADL 35431 1. '~ IF INDIA~. ALOTTEE O~ TRIBE NAIF. 0IL ~ G~. ~ ~LL ~LL O~B~R 8. L~IT F.~{ OR LEA$~ N~E :2. NAME OF OPERATOR ARCO Oil & Gas Company P. O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL Spark Platform- .2613'N & 2495'W from SE Corner, Sec 26, TION, R13W, SM North Tradinq Bay Uni.t 9. WELL .NO S-3 (13-26) 10. I"~-A..'ND POOL. OR ~.VILDCA.T Tradina 2av NF "G" H~_mlnck . Sec 26~ TION, RI3W~ SM 1~., PERMIT NO. 6q-ll "113. REPORT TOTAL DEPTH AT END OF MONTH, CHA~NOES IN HOLE SIZE, CASING A!NTD CE!ViENTING JOBS INCL~JDING DEPTH SET AND VOLIYlVI~ USE"D, Pgl:~OP. ATIONS, TESTS A_N-D RESULTS, FISHING JOB~, JLrNK I/~ HOL~. AND SIDE-TRACKED HOL~E A~TD A_NY OTHER SIGNIFICANT CHANG~ IN HOL~ CONDITIONS. On May 10, 1980, RU Otis snubbing equipment and tested BOPE - OK. Drilled hard sand fill from 9935' - 10,032' As POH to change mills, twisted off and left junk in hole. Fished unsuccessfullY. Released well to production department @ 1400 hrs, 5/17/80. 24 hour test, 5/22/80: 1,038 BFPD' 42 BOPD, 996 BWPD (96% cut). 1--4' i hJreby ~Tt~he ~rue and °°rrect TL'E~ ' ' ' SmN~D · ~ F)i,~. rlrlg S~!pt n~ May ?q.. lqSO, i i (%)' IL ' I II I l II I I I I NOTE~'--Report on this form ts required for .each cqlendor months regardless of the status of operations~ and must be filed 'in duplicate with the oil and gas conservation committee by the ISth of the succeeding month, unless Otherwise directed. May 29', 1980 Mr. Jim Shaginoff Spar k Platform Box 3~400 Kenai, Alaska 9961! Mr. shaginoff: On Ma~ 22, 1980 you talked with Hoyle Ham~lt°n concerning the S-3 well. You wanted to knOw. if another no-flow test would be required on this we1! since the well had been reperforated. We have looked at the production h~st°ry pri°r to reperforation and compared .that to your present well production. On the basis of these data we have determined that the well is still incapable of unassisted flow and therefore the subsurface safety va!ye requirement for this well remains waived without an additional no-flow test. The S-1RD has also been recently reperforated. After reviewing the 10-403 form of May 14, 1980 and the previous production history this well also retains its no-flow status. Your s truly, Russell A. Douglass Petroleum Engineer May 29, 1980 Mr. Jim Shaginoff Spar k Platform Box 1400 Kenai, Alaska 9.9611 Re = ARCO Spar Mr. Shaginoff~ On May 22, 1980 you talked with Hoyle Hamilton concerning the S-3 well. You wanted to know if another no-flow test would be required on this well since the wel! had been reperforated. We have looked at the production h/story prior to reperforation and compared that to your present well production. On the basis of these data we have determined that the well is still incapable of unassisted flow and therefore the subsurface safety valve requirement for this well remains waived without an additional no-flow test. The S-1RD has also been recently reperforated. After reviewing the 10-403 form of May 14, 1980 and tb~ previous production history this well also retains its no-flow status. Yours truly, Russell A. Douglass Petroleum Engineer ARCO Oil and Gas~r pany South Alask'~ strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 22, 1980 Mr. Hoyle Hamilton Chairman Alaska Oil & Gas Conservation Commission State of Alaska 3001 Porcupine Drive Anchorage, 'Ak 99501 _._ i COMM COMM RE[:; } 1 ENG I ~'ENG I 3 J 4 FILF: Re: Sundry Notice, Spark Platform S-9, S-1 & S-3 Dear Mr. Hamilton: Transmitted herewith are three (3) separate Sundry Notices (in triplicate) filed by ARCO Oil & Gas Company, requesting an approval for the subject workovers. In the event your office shOuld need additional infor- mation in conjunction with this matter, please do not hesitate to contact us. C. R. Knowles Dist. Drlg. Supt. CRK/KUP/dac Enclosures ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form 10-403 ... Submit "1 ntentions' in Triplicate REV. 1-10~73 ( & "Subsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) 5. APl NUMERICAL CODE 50-133-20175 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Ak 99510 6. LEASE DESIGNATION AND SERIAL NO. ADL 35431 7. i~ ,ND,AN, A-'O~EE OR TR,BE .AME 1. O,L I-'il GAs r-I WEmLLAJ WELL L...J OTHER 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME ARCO 0il & Gas Company North Trading Bay Unit · LOCATION OF WELL Atsu.a¢, Spark Platf0rm, 2613' N & 2495' Sec 26, T10N. R13W, SR. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) ll5' RKB W from SE Cr. 14. Check Appropriate Box To Indicate Nature of Notice, Re 9. WELL NO. S-3 (13-26) 10. FIELD AND POOL, OR WILDCAT Tradin9 Bay NE "G" Hemlock Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 26, TlON, R13W, SM 12- PERMIT NO, }orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF E~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Clean-out fill & reperforate SUBSEQUENT REPORT OF: WATER SHUT-OFF' ~ REPAI RING WELL FRACTURE TREATMENT ALTER lnG CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form,) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all I~ertinent details, and give pertinent dates, including estimated date of starting any proposed work. This well was completed in March 1969 as a "G"-Hemlock producer, and the production is restricted by plugged tubing scales @ +9750' MD. AOGC intends to clean-out the tubing scales and fills using Otis 4-1/16" hydraulic workover unit and Dril-S work- over fluid with full returns to the mud pit. This hydraulic workover unit contains 10,000# BOP stack with shear rams, safety rams, stripper rams and equalizing rams. Upon completion of clean-out operation, all Hemlock Zones will be reperforated. The operation will commence on or about May 7, 1980, uponcompletion of S-9 & S-1. 16. I hereby certify that the foregolrlg is true and .correct (This space for State o~ APPROVED BY TITLE Dist Drlg Supt COMMISSIONER DATE- April 22, !980 See Instructions On Reverse Side DATE Approved Copy Returned Form P--3 S~ibrntt "Intentk REV. 9-30-69 & "Subseque..nt STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELl (Do not use this form for proposals to drill or to decpen Use "APP-LICATION 'FOR PEt~I'i'~.' 'for such . . 1, 01L ~ GAS [] WELL WELL OTHER 2. NA)JE OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360, Anchorage, .g2. aska 99501 4. LOCATION OF WELL At surface 2613'N & 2495'W fr SE cr Sec. 26, T10N, R13W, 13. ELEVATIONS (Show whether DF, RT, GR, etc. 115' KB 14. Check Appropriate Box To Indicate N, ature of NOtice, Rei J C. ENG [~. API NUblF-.RICA. L CODE ~ J 3 ENG.][__JJ ADA 35~13 "i ~' ENG 'i J ~ GEOL J' s.u~~oR~s~ ~3 GEOL J~'~ Trading Bay Unit $ S~C i ~ ~. ~ ~ ~, o~ ~%~ 0i~ Poo~ C~FER: Tradin~ Bay Field; Hemlock and 11. SEC., T., R., ~., (BO~O~ ~ ,,~, ~ O~E~IVE) Sec. 26, T10N, R13W, SM I~. PE~T ~O. 69-11 NOTICE OF INTENTION TO: TEST WATER BHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPI,ETE ABANDON* CHANGE PLANS ~Other) SUBSEQUENT REPORT OF: FRACTURE TREATMENT I ALTERING CASING SHOOTING OR ACIDIZINO , ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) !5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, includin~ estimated date of starting any proposed work. On 7-7-70 we rigged up and started killing well w/63# Invermul mud. After killing we pulled the 4 1/2" completion assembly and RIH with tbg. We spotted a cement plug w/tbg ~ 10,365'. Cmt in place 10:30 AM 7-12-70. The plug was dressed off from 10,227' to 10,26'5' and the Hemlock was reperforated as follows with 2 1/2" shots per foot: 10,022' - 070' 10,114' - 140' 10,152' - 190' 10,208' - 258' A 3 1/2" gas lift completion assembly was run with the packer at 9910' and the tbg tail at 9942'. We installed and tested the tree with 5000 psi. OK. The packer was set and the rig released 6:00 PM 7-22-70. :,RECE!VED DIViSiON 07 OiL/,.NJ) GAS ANCHORAGI~ 16. I hereby certify that the fo~~ct SIGNED '~~ - // (Thl! spa~e ~or ~tRte 0~) TITLE Dist. Drlg. Supvr. APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side Approved Copy AtlanticRichfieldCompany North Amer 'roducing Division ., Alaska Distrr Post Office B~,x 360 Anchorage, Alaska 99501 Telephone 907 277 5637 HLB - OKG ..... HWK FILE , , June 17, 1970 State of Alaska Department of Natural Resources 3001 Porcupine Drive Anchorage, Alaska Attention: Mr. Homer Burrell Re: North Trading Bay Unit State S-3 Dear Sir: Enclosed please find our P-1 application to plug back the subject well along with the $100.00 fee for this permit. Yours truly, C. R. Knowles Senior Drilling Engineer CRK:jm Attachment F~rrn BEV. 9-30-67 STATE O'F ALASKA Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate OIL AND GAS CONSERVATION: COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a diffierent reservoir. Use "APPLICATION FOR PERlVIIT--" for such proposals.) 1. OiL [] G,s ~ WELL WELL OTHER 2. NAME OF OPEP,~TOR Atlantic Richfield Company 3.ADDRESS OF OPERATOR P. 0. Box 360, Anchorage, Alaska 99501 4. LOCATION O,F WELL Atsurface 2613' N & 2495' W Fr SE cf, Sec 26, T10N, R13W,S5 13. ELEVATIONS (Show whether DF, I~T, GR, etc. 115' KB 14. Check Appropriate Box To I, nd, i'cafe Niature of N~ti'c'e, Re, NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING FRACTURE TREAT .MULTIPLE COMPI,ETE SHOOT OR ACIDIZE ABANDONs REPAIR WELL CHANOE PLANS (0ther) 5. API lXr[/NIEuRICAL CODE API 20-133-20175 $. LdT.~SE DESIGNA~'iON A_ND SERL~L NO. ADL-35413 7. IF INI)I~N, Aff~LK)'l-r~ OR ~qlBE NA_NLE 8. UNIT, FA~B/VI OR LEa%SE NAi~IE Trading Bay Unit 9. W~L NO. S-3 (13-16) 10. · '" .A2XTD L, .W ~ ~:l. Dg'~v~a2~,,c~i~-z~; ~Hemlock & NE 0m_L .~,OO±'~ 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 26; T10N, R13W, SM 12, PER1ViIT NO. 67-1l ~ort, or Other 'Data SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMEN'T* (Other) r NOTE; Report results'of multiple completion on Well ompletion or Recompletion Report and ,Log form.) 15. DESCRIBE I'nOPOSED OR COMPLETED OPERATIONS (Clearly state all pertlneut details, and give pertinent dates, including estimated date of starting an,y proposed work. We propose to shut off bottom water influx by spotting a 100' plug of cement from 10365' to 10265'. The following ~intervals will be reperforated with casing guns at 2 spf: 10022' - 10070' 10114' - 10140' 10152' - 10190' 10208' - 10258' 16. I hereby certify that .tbs foreso~ is trj~e and correct SIGNED ._~~~I"/.~./~~/f TITLE Dist. Drilling Supervisor *Co-mingled in ~ell bore. ~ [ns}r~ions On Rever~ S.i~e DATE June 18, 1970 DATE Approved Copy Returned AtlanticRichfieldCompany North Amer("~ ,-'roducing Division Alaska District Post Office Box 360 Anchorage, Alaska 99501 Telephone 907 277-5637 May 14, 1969 Mr. Homer L. Burrell, Director State of Alaska Department of Natural Resources Division of Oil and Gas 3007 Porcupine Drive Anchorage, Alaska Dear Mr. Burrell: OKG HWK ..... REL Re: North Trading Bay State No. S-3 Thank you for informing us that you had not received all the reports and information you need on our TradingBay Field S-3 well. I have taken steps which will, I hope, assv~e our prompt issuance of this information in the future. You showed that you did not receive a blueline, co~ ~ of the ~~l~~ow mf mt was not recemved and I'll see that you g~t a copy. I have ordered a sepia for your files which I shall forward to you as soon as it comes in. Please find enclosed two copies each of the Directional Survey and the Well History. R. W. McCleskey RWM:tll enos RECEIVED M ,Y 15 1969 DIVISION OF OIL AND GAS DXVT, SXOH ~ OX1, ~ ~ ~th Tred~ Sa~ St:ate # So3 DI¥ISI~ OF OIL RND GAS 26, 1969 Apparent Violation of Section 2:154 Ataska 0iI and Gas Conservation Reoulations Bar Str: A revte~ of the ~'letton report and electrtc log of the Atlantic Richfield Company well $-3 Tra~ttq 8Ry Ffeld t~tcates that the Middle ~I interval, from 9,~'-10,00~' bas been ~e se~ violation of Sect~ 21~ of ~e 0tl a~ ~s ~r ~, ~9 ~1~ of t~ Tr~tq gay ~G~ NE 0~1 Pool and ~e Trading 8~. HE 0tl ~oL but thts ~le does ~co~er c~t:qltq H~le ~e~.t p~ctton ~cept for the ~G NE 0~1 Poal. Please sbo~ c~se ~it. bln seven days ~y t~ts ~ell shou'ld not be s~t tn for violation of a regulation, C~ittee AtlanticRichfieldCompany North Ame ,~,. ducing Division Alaska District Post Office Box 360 Anchorage, Alaska 99501 Telephone 907 277-5637 April 29, 1969 HLB ~ T'RM ~ /¢LV ~ HW~ ~ State of Alaska Department of Natural Resources .Oil & Gas Division 3001 Porcupine Drive Anchorage, Alaska Attention: Mr. T. R. Marshall., Jr. Gentlemen: Find enclosed corrected copy of Form P-7, Well Completion Report, for Trading Bay Field S-3 well. Very truly yours, R. D. J~nstone RWM: tll encs F. orm P--7 : SUBMIT IN DUP STATE OF ALASKA (See other in- structions on OIL AND GAS CONSERVATION COMMITTEE I ~ 1L I WELL coMPLETION OR RECOMPLETION REPORT AND ~OG. * I la. TYPE OF ~ELL: i iiii ~l~l '~ ; -"~1 .......T 7 T'l ...... i WELL ~ W~.LL DaY Ot . '.b. TYPE OF COMPLE~ON: ~. ~g o~ Atlantic Richfield ~9mpa~y .......... " ' ~. ADD~E~ O~ OPE~ATOI ~.' O. Box 360, hnchorago, '4. Loc,~O~ o~ WZL~ ( Re~ort location c~earlv and in accorganoe with an~ ~t~e r~quire~e~t, )* "' ~t,~613~ & 2495~ fr SE Ct. ,Sec. 26 , At top prod. interval reported below 2074'N & 4443W from SE Cr., Sec. 26,: T10N,:~R13W, SM 50-133-20175 -~.~IN~'d.~,6ODE ' " ADL 35431 6. L~=~. E DESIGNATION AND SERIAL NO. ?. IF IN/)IA_N, ALLOTT]~ OR TI:~IBE NAi~ 8. UNIT,FJtI~N~ OR LEASE NA/~I~ Trading Bay Field 9. WELL NO. ' S-3 4~13-26 10. FIELD A~D POOL; OR W1L~CAT Trading Bay Heml-sck NE 05_1 Pool* 11. SEC., T., R.,'M,; (BOTTOM HOLE OBJECTIVE) Sec'. 26', T10N,R13W,SM , At total depth i ., ; y :. . : 2031N & 4627W fr SE Cr., Sec. 26, T10..~, R13W,SM ' 6,-'11 ,~ ....... ~,~-:n',"r"'r"'~ ~r;.;r-'.y';f..';..5 . .'Y:t_"Y"i"..'t'ii.~T.i" ~['.t_"f~2 T-30-69 { 3-4-69 :~ { 3-10-69 18: T~ D~H, ~ & TVD~9. ~LUG ~dK MD & ~. 10[,541MD(10,127~D) 10,394~ (98}9VD) 9992 ~-(9612VD)~10~510MD (10,089 VD): Comingled. ,,G"& Hemlock...~:-: Yes ' DIL, FDC, BSL'~ H~ '- : ' ~ CASING RECORD (Report all strings set DEPTH S~T (M~) 2oo ' .. 800SX "' " ... m L 26 LINER :i SIZE TOP (MD), 26.~PEl~FOP~TIONS OPEH TO (ln%erval, size and number) 9,994 - 10,006~ .0,022-10,070; 10 08 3 10 .2 ~ :10 114-10 140; 0~ 1 :;, 152 - 10,190~ ~:i0,208~-10,344 ~ota. 1 279', 4 shoal/ft. A : ,'. .:t T~IBING RECORD .' .... (NID) SACKS CEMENT* SCREE~ D~H~, SET~, (MD), PA, CKEI% sET (IViD) i .... :, PRODUCTION .i . ' ~0. ; "~ :i DATE FIRST Pr~ODUC~ON I PRODUCTION METI-IO'D (Flowh~g, gas Iii.t. pump~--size and~tYpe of p~p) ' ~a~ch ~2 ~969 Gas Lift 3~13-69 , ! 23; ::':i Open I ~ J2037; :"i 470' :'- ":i '403" 231'~' ~. I ~ ~ :~ ~ l~-~°u~ ~ '~ ~ = · ~u i~uu .' :~l - ;' Fu' ~ I ~80 I 411 { 34.6 Fuel, Ga~ Lift & .Flare J Rufus Murray "~. c~s~ o, X~',c~,'~'~s , ~ "~ ' : 33. I hereb~ eert~ t~t the ~ore~of~ ~n~ ~tt~ehed Information ~e ~mplete ~nQ':~ eo~re~ ~ ~etermlne~ ~rom ~ll:~v~ll~ble records ;' ~Sei//- Instr.cfions ~ng S~ces for A~difio"~l Oa~ on Reverse · CO-mingled in well bo~e ~ith Trading Bay "G" HE Oil 9oo~ Zone -. INSTRUCTIONS Gener. ah This form is designed for submitting ~/.coml~lete and correct well c.ompletion report and log all types of lan.ds :and leases in Al,~ska. , ..Item: '16: Indicate which elevation is bsed as r'~.ference (where~ not otherwise shown) f~r' del~{.hmeasure~_.-_. - merits.given in ether spaces on'this form ~nd in any. a,ttachment~:. ,, . Items 20, nnd 22:: If this well is co~npleted.'{or .separa.to production from more than' one in~erg'~:l~: .... (multiple completion), so state in ite~i ~-_~ j' ' 20~ :and': ,n item 22' sh~w 'the p}cducing' -inter,~aJ ~r-. inibi~vals,-, lop(s), bottom(s)and name (~)(if.aqY)ifor i.o..~ly .the inti, rval i-ep~ted' in'item 30L.ii'iS~Jbmit (page) on this form, adequatel~:;[dentified;,~"for e~ch additiohaljinte, val?t0 be seperately'produce¢l, ;... . : ( -.,.,' : ...... ..,.~ .,, -. ing the adlditional data pertinent to. s0ch i:h'terv~.. : E, ' I~m26.. "S~¢ks Cement": Attached supplemental:: records for this well should show the details of any' tiple sta~e cementing and the ~oCation' of the c&menting tool. ~em 28: Submit a separate completion report on:this form for ~ach. interval to be separately produc-'~:l. {,~e instruction for items 20 and":29 above). . · ,, 34. SUMMA_RY OF I~OI~fATION T~-S'I~ INCLUDIN(~ INT~V~L ~D, P~URE DATA ~ ~OV~ .OF OIL. G~. . WA~ AND MUD ~'" z-'; ' ~'~ 35. -~' G~GI~ :~MAR~ ': , . .... . -. { ,~ il :,, I;I ... .~(,: ,..~ ' : ','. : ...,. : . . . . ..;: . :.....-. , .J',. .,.- . , ' .'.' .' ' DJ J . ;;.~ " .... ~ ' · ' ' ' '.. ' : ' ' , : ~ . , . . ~ ~ ~:~ ',., . , . .. _ . -. ... :-:., ...,:-, . ,,. .· . ' . :. ~ : :'. , ,. '~.' . . .: : , ~ .- i_. · ....... . :.. - L,., ~ ~,... '.:: · : ... , , '. . . :~ :_ , : ;. : :.'~' ~',') _:' .., :/~ ~ .~::'~: : , ?. I ' ~ ~.. ~' . ',,' : ~. ~o~ DA~A, A~A~U ~m~ D~IB~0~S 0~ LITHOLOOY. POROSITY. FnAC~n~. "'AP~N~ ~i~' : ANO O~C~'[l) ill.Wi O[ OiL. O~' OR WA]. '': "' · : ~ , , , , i , - C)-, '-. . . .- . . r, ~ ...~ '. · . . . ~' . ' . · , ,"-. ~ " - . - ... , . ~ . -. ~ · .-, ~- .:' , . .~;,~ · ~ , ~ ~ : .. . ~ ~ ,. .-., .; .,. - ., ~,._: ., ~-....: ' :~ r.. ~:.: : ~ ~ -..: . ,; : , ;.:.. , · i i,,. - ..... ATLANTIC RICHFIELD COMPANY N,TeBeS, NO. 13-26 $-3 PLATFORM SPARK LEG 3 SLOT 6 JOB NO. A~-693 RECORD OF SURVEY ALL CALCULATZONS PERFORNED BY IBM ELECTRONIC CONPUTER TRUE NEA5, DRIFT VERTICAL SUB DRIFT TOTAL COORDINATES C L 0 5 U R E S' DEPTH ANGLE DEPTH SEA DIREC DISTANCE ANGLE D N DEG, D H 5 DOG LEG SEVERITY DEG/IOOFT SECTION D I STANCE 63 0 0 63,00 88 0 0 88,00 113 0 0 113,00 138 0 IO 137,99 163 0 10 162,99 188 0 15 187.99 213 0 30' 212,99 238 0 40 237,99 263 0 15 262.99 288 0 15 287,99 313 0 lO 312.99 338 0 4 337.99 363 0 10 362.99 388 0 15 387,99 ~13 0 30 412,99 ~25 0 30 424,99 -51,99 N 0 E -26.99 N 0 E -1.99 N 0 E 22.99 N 88 W 47,99 5 84 W 72,99 5 88 W 97,99 S 82 W 122,99 N 8? W 147.99 5 70 W 172.99 & 72 ~ 197.99 N 89 W 222,99 N 53 W 247.99 N 40 W 272,99 N 14 W 297.99 N 34 W 309.99 N 63 W 2.55 N 3.61 2,55 N 3.61 2,55 N 3,61 2.55 N 3,68 2,54 N 3.75 2,54 N 3,86 2,51 N 4,08 2,52 N 4,37 2,48 N 4,4? 2,45 N 4.58 2,45 N '4.65 2,47 N 4,68 2.53 N 4,73 2,63 N 4,75 2.82 N 4.87 2.86 N 4.97 4,41N 5~ ~5 ~9 W 4.48 N 55 17 0 W 4.53 N 55 53 39 W ~,62 N 56 41 25 W 4,79 N 58 24 43 W 5,0~ N 59 59 55 W ~.12 N 60 ~6 0 W 5,19 N 6~ 48 50 W 5,26 N 62 10 58 W 5,29 N 62 ? 21W 5.36 N 61 ~9 2? ~ 5,44 N 60 58 22 W 5,63 N 59 58 ~ W 5,7~ N 60 I 20 W 0,000 0,000 O,OOO 0.680 0,09~ 0.325 ~.01~ 0,~12 1.802 0,03~ 0,420 0,~75 0.490 1,114 2,0~ 2,81 2,81 2,96 3,06 ~.66 3,77 3,84 3,90 3,97 ABOVE INFORNATION FROM SPERRY SUN GYRO SURVEY NO, 5U-3-16356 522 0 15 521.99 406.99 N 84 W 647 1 0 646.97 531.97 N 33 W 771 1 15 770.9~ 655,94 N 32 W 926 1 45 925.87 810,87 N 41W 1113 0 30 1112,86 997,86 N 21W 1351 I 30 ~350.78 1235.78 S 85 W 1555 0 ~5 155~,76 1439,76 S 77 ~ .1803 0 30 1802.7S 1687,75 S 70 W 2052 0 30 2051.7~ le36,7~ N 88 W 2360 0 30 2359,73 22~4.73 S 86 W 2668 0 15 2667,73 2~52,73 S 59 W '2,91 N 5.39 4,74 N 6,58 7,03 N 8,01 10,60 N ll.iA 12.13 N 11.70 11,58 N 17,91 10e98 N 20e51 10,24 N 22.54 10,32 N 2~.71 10.13 N 27,40 9,4~ N 28,55 6,12 N 61 37 ~+8 W 8.11 .N 54 13 36 W 10,66 N 48 ~3 16 W 15.36 N 46 20 58 W 16.85 N 43 58 28 W 21.33 N 5'1 5 45 W 23,27 N 61 49 25 W 2~,76 N 65 33 26 W 26,78 N 67 19 5~ W 3OEO7 N 71 41 4~ W 0.290 0.692 0,202 0,356 0,691 0,607 0,375 0.077' 0.017 0,097 7,95 8,12 16,92 19,07 23,7U 2984 0 45 Z983,70 2868.70 N 76 W 3334 0 45 3333.67 3216.67 N go W 3740 ! 0 3739.$1 3624+61 N 86 W 3973 1 15 3972,55 3857.55 N 87 W ~553 3 30 4552,2! 4~37,21 $ 50 W 4594 5 0 4593.05 4a78.05 $ 53 ~ 4650 6 45 4648.66 4533.66 $ 50 W 4914 12 0 ~907.69 4792.69 S 55 ~ ,, , 51~ 16 0 5099.94 ~984,94 S 66 ~ 520~ 15 0 5185.53 5070.53 S 69 ~ 5~* 20 15 5410.70 5295.70 5 73 W 5694 21 15 5643,70 5528.70 $ 72 ~ 6185 22 ~5 6098.~4 598~.~ $ 72 ~ 6377 22 30 6275.53 6160.53 $ 73 ~ 6585 22 45 6467.35 6352.35 73 W $ 6818 22 45 6682.22 6567.22 S 73 W 7091 23 30 6932e58 6817.58 S 73 W 7230 23 30 7060.05 69~5.05 $ 74 W 7~25 23 30 7238.87 7123,87 $ 73 W 763~ 24 0 7~29.81 731~.81 $ 74 W 7823 23 45 7602.80 7487.80 S 74 ~ 79~$ 23 0 7717.86 7602.86 S 75 ~ 8272 22 45 8016.66 7901.66 S 76 W 8a3! 23 15 8162.7~ 80~7.7~ S 77 ~ 8577 22 ~5 8297.38 8~82.38 $ 77 W 8722 22 ~5 8a3~.10 8316.10 S 77 ~ 8866 22 ~5 8564.38 8449,38 $ 77 W 90~5 22 0 8730.35 8615.35 5 77 W 9~42 2! 45 9099.08 8984,08 5 77 W 9536 22 0 9186.24 907~.2~ 5 77 W 9675 2! 30 93!5.57 9200.57 $ 77 w 987! 2~ 0 9498,55 9383.55 5 79 W 10088 2i 0 970~.~ 9586.~4 5 77 W 15.37 N 6~,83 W 13.29 N 67,~1 W Il,la N 70,16 W 14.22 S 102.2B W 56,14 $ 192.20 W 80,~3 S 271.64 W 34.19 N 72 13 0 W 38.58 N 74 17 41W 45,~4 N 76 6 12 W 50,54 N 77 1~ 33 W 66.6~ N 76 39 4? W 68,61N 78 49 51W 71,04 N 80 58 4~ W 75.52 N 84 ~5 ~ W 103.24 5 82 4 58 W 1~8.29 $ 78 24 ~5 W 172,53 $ ?4 28 28 W 200,24 $ 73 42 54 W 28},30 $ 73 30 19 W 108,~3 $ ~ 357,81 W ' 373,88 $ 73 8 26 W 165.88 $ 53~,63 W 187,35 $ 60~,90 W 210.88 S 681.82 W 237,23 $ 767.98 W 269~05 S~' 872.09 W 28~.~3 S 925,~7 W 307.06 $ 999.72 W 330.50 S 1081,44 W 36~.12 $ 1201.79 W ~94,43 S ~152~.36 W 421.25 S 1~39,53 W ~33,86 $ 1494.16 W 461,21 $ 161£.63 W 49~,30 $ 1735.97 W 502.23 5 1790,28 W 513.69 5x. 1839,92 W 527,09 $ 1908,87 W 54~.58 5 1984,64 W 579,43 5 2135.60 W 559,78 $ 72 45 42 W 63~,25 5 72 67 22 W 713.69 5 72 48 47 W 803,79 S 72 ~0 3 W 912.65 5 72 5~ 14 W 968.06 $ 72 ~5 10 W 1045,82 5 72 ~ 31W 11~0.81 $ 73 0 22 W 1206.92 $ 73 4 8 W 125D.?~ $ 7~ 8 38 W 1380.89 S 73 24 11 W 1~3,~ 5 73 3~ 33 W 1555,88 5 73 48 29 W 1610,32 5 73 ~4 57 w 1677.29 5 7~ 2 2i W 1859.39 5 74 19 46 W 1910.28 5 7~ 24 Z w ZOO8.00 $ 74 39 20 w Z21Z.81 ~ 74 49 11 w . ABOVE INFORMATION FRON SPERRY SUN 5INGLE SHOT SURVEY5 BOTTOMHOLE CLOSURE 2212.81 FEET AT S 74 49 11 w 0.190 28,69 0,052 0,06~ ~9,aO 0,112 ~.~30 ~,697 64.80 3,172 2,394 172.5~ 1.OS~ 283,22 U.42~ 373e7Z 0,20~ 559,~2 042~7 0,12U 713.25 O,OOU 803.~1 0,287 967.5~ Oe20~ lO~e2~ 0,307 A1~0,25 0,1~2 1206.~6 0.679 12~5.20 0.399 I~3e19 0.000 0.347 O.l~O 1~77.13 0.063 1824.13 O.2bb 1~59e~2 0,360 1910,23 0o~49 1~0.~ 0,330 2057,~9 0,221.. 2£1~,8i ~ - ~ - ~ ..... j [ , INSTRUCTIONS: Prepare and submit the FINAL REPORT on the first Wednesday after allowable bas been aaaisned or well is Pluige~ Abandoned, or Sold. FINAL REPORT should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official cost is hOC required Upon completion, report completion and representative teat data in blocks provided. The FINAL REPORT form may be used for reporting the entire operation if space ia available. DAILY WELL HISTORY - FINAL REPORT District. A~k~ County or Parish State Alaska Field_ North Trading Bay Hemlock Lease or Unit TBS 8-3 Well No.13:26 Auth. or W.0. No L_ 19-73~3 Title __. Drill Development Well From Soark P!atfor$ Operato~ Spudded or W.O. Begun.. Atlantic Richfield Comoany Spuddqd Date 1/30/69 TARCO'S W.I. lOO % Prior Status Hour'2.O_uQ_Q~if a W.O. Date & Depth · as of 8:00 A.M. 3-11-69 10,541TD 10,394 PBD 3-13-69 3-24-69 3-31-69 Complete Record for Each Day Reported (9-5/8" @ 10,484) Pulled Otis dunm~y sleeve in ball valve, ran 3-1/2" Otis "Q" plug, set Brovm H-1 SP pl~. w/3000 psi, pulled "Q" plug, tested plc~, w/~.000 psi. OK. Perforated 4 holes/ft. 10,344-10,208; 10,190-10,152, 10,140-10,i14, .10,102- 10-083, 10,070-10,022, 10,006-9,994, w/Dresser-Atlas. Released rig @ G:00 p.m. 3-10-69. Production test @ 7:00 a.m'. 3-13-69: 2119 BOPD, 20% BS&W, 30.40 APi; 100#' FTP, 820# CP. Continuing ~o unload by gas lift, Moved in rig over conductor @ 5:00 p,m, 3-22-69, (9-5/8" @10,484) Reperforated w/2 1/2" holes/ft. 10,310-10,208, 10,140-10,114, 10,102-10,083, and 10,070-10,022 for a total of 390 holes'. Finished perforating @ 3:30 a.m. 3-2~-69. T.P. after 1st run 500 psi, T.P.~ after 3rd run 600 psi, ~.P. ,fter 4th run 800 psi'. Bled tbg. off to 250 psi between runs on last 3 runs Released rig to S-2 6:00 a.m. 3-23-69. @ 3-30-69. 5005 BOPD, 1800 MCFPD, 155 BWPD, InJ. 2930, TP 190#, CP 1070, APl 32.0° Old TD New TI)_ 10,~41 Released Rig 6:00 a.m. Classifications (Oil, Gas, etc.)_ Oil . _Date 3-2~-69 PB Depth 10~394 Kind of Rig . Rota~'¥ Type Completion (Single, .Dual, etc.) Producing Method ~'~ !ffting Potential Test Data: . Official Reservoir Name(s) ,, , WELL NO. DATE RESERVOIR PRODUCING INTERVAL OIL OR TEST TIME PRODUCTION, GAS OIL ON TEST GAS PER DAY ,,, ,, , , ,, , , , _13-26 3-13-69 ~r~lock 10,022-10,310 Oil 24 hrs 5005 1800 MCFD , ,, PUMP SIZE, SPM X LENGTH CHOKE SIZE T. P. C. P. WATER ~ COB GRAVITY ALLOWABLE EFFECTIVE DATE COBBECTED 190 1070 , stributx, on: Orig.: Drilling Section - Dallas cc:- District Office Engineering Division - (720) Co-Owner(s) - As Appropriate Regional Office, Well Record File PAGE The Above is Correct: _(NUMBER ALL DALLY WELL HISTORY FORMS CONSECUTIVELY AS THEY ABE PREPARED FOB EACH WELL. ) DATE RECEIVED INSTRUCTIONS: This form is used during drilling or workover operations. If testing, coring., or perforating, show formation ~ame in describing work performed° NumBer all drill stem tests sequentially. Attach description of all cores, Work per- formed by Producing Section will be reported on "INTERIM" sheets until final completion. ~eport official or representative test on "FINAL" form. (1) Submit "INTERIM" sheets when filled out buc not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for worhovers and folIowin8 settin8 of oil string until completion. DAILY WELL HISTORY - INTERIM District ~.~__,._ County .or Parish State Field ~:~,,.~+~, . ....... ~.,~_ ~ .... ~..~_~ Lease or Unit Wel 1 No Date & Depth at 8:00 A.M. ,~-10-69 10,541 TI) Complete Record for each Day While Drilling or Workover in Progress , ,, ¢co{t. ) ~694, 8142, 7~17, ?0~0, 626~, 5~02~ 4007 & 210~. Ott~ b~ll valve @ 4~3', OCT tb~o han~er ~ .~§. }Iun~ tbg. on OCT han~or, removed 13-~/8" r1~er & BOFE. Inst- alled OCT Xmas Tree, tested tree ~nd lines to 5000 Dst. Tests OEo D1spl2ce Sea wa~er w/?10 bbls. diesel o~1 tn 4 hrs. 45 min. Distribution: Orig.: Drilling Section - Dallas cc:- District Office Engineering Division - (720) Co-Owner(s) - As Appropriate Regional Office, Well Record File The Above is Correct: SIGNATURE J .Di?..~?.t_ Dr~.!!Ing Su~rv~_~e- TITLE DATE 'RE¢[IV[D PAGE NO. - (NUMBER ALL DAILY WELL HISTORY FORMS CONSECUTIVELY AS THEY ARE PREPARED FOB EACH WELL, ) ° MAY 15 Printed USA DIVISION OF OIL AND OMI INSTBUCTIONS: This form is used during drilling or -orkover operations. If tenting, coring., or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work per- formed by Producing Section will be reported on "INTERIM" sheets until final completion. Report official or representative test on "FINAL" form. (1)Submit "INTERIM" sheets when filled out but not less frequently than every 30 days, or (2)on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. DAILY WELL HISTORY - INTERIM District Alaska County or Parish Field North Tz~ding Bay Ifemlock Lease or Unit TBS S-3 State Alaska .~13-26 Well No. .. Date & Depth at 8:00 A.M. 2-27-69 9442 2-28-69 9472 3-3-69 10,088 3-4-69 10,353 3-5-69 10,841 3-6-69 10,541 ' 3-7-69 10,541 TI) 3-10-69 Complete Record for each Day While Drilling or Workover in Progress .. (cont.) w/425,0004~. went down. · not stay on. Mixed dry job. Stood back Kelly, pulled 20'. Turbine By-pass'shutdown lite, started turbine. Turbine will Now 3 stands off bottom. (30) Drilling. (t3-3/8" ~ 2006) Mud 76%, Vis. 40", WL 5.1cc. Pulled bit %33 using Cat.electric system. Put gas turbine engine' on system. Drilled 12%" hole 9442~ 9472'. Reamed w/bit ~44 9342-9442'. Tested'CSO & pipe rams w/3000 psi and Hydril w/2000 psi, OK. Survey: 9442' 21-3/4° S77W, VD 9097.71, S493.96, W1753.96. (616) Changing bits. (13-3/8" ~ 2006) Mud 769, Vis. 42", WL 4.1cc. Directionally drilled 12¼" hole 9472- 10,088'. Survey: 10,088' 21° S77W, VD 9699.30, S544.51, W1983.78. (265) Drilling. (13-3/8" @ 2006) Mud 76#, Vis. 41" WL 5.2 cc Diroctionally drilled 12-1/4" hole 10,088-10,353 ' · (188) Running Sonic Log. (13-3/8" @ 2006) Mud 76#, Vis. 43", WL 5cc. Dlrectionally drilled 12-1/4" hole 10,353-10,541. Made 25 std. wiper run. OK. Circ. 1 hr. on btm. Mess. out of hole OK. RU Schl. _ 3:30 a.m., Ran DIL 10,524-2006; SIH w/Sonic log ~!7:00 a.m. Eur'vey: 10','54"1', 20~, S'77i7," VD i0,12'~'.'98,~5~7:9~-3'~, W2134,75. (0) Rill w/bit to condition for casing or dtpmeter. (13-3/8" @ 2006) Finished BHC Sonic ~ 11:00 a.m., Ran FDC. ttad two miss runs. Ran dipmeter to 10,524. Logged btm. 150'. Tool failed, Repeated but tool failed again. Ran new FEC 10,524-8500. Pulled tight @ 9200. Finished logging @ 3:00 asS. Running casing. (13-3/8" @ 200~) Mud 76# Vis. 52 , ~L 5cc. Ran in with 12-1/4" bit, ctv~. & goad, mud ~ 10,541,. Insta!l~d 9-5/8" rams, ran 53 its, 2197,. of 9-5/8"~47#:~110 b~ttress csgo' w/Baker diff. fill-up shoo and diff. collar & 201 its,, 8244, bf 9-5/8" 47# N-80 buttress csg, total 10,481, including landing Jr. I~nnded csg. on OCT head w/315,000# shoe @10,484. Diff. collar @ 10,396. Circ. & prep. for emi. PAGE NO. 4 (NUMBER ALL DAILY WELL HISTORY FORMS CONSECUTIVELY AS THEY ARE PREPARED FOR EACH WELL. ) MAY-1 1969 3B-459-2 Printed U SA D~I$ION OF OI/AND 0,~ ' DATE / '/ Distribution: Orig.: Drilling Section - Dallas cc:- District Office Engineering Division - (720) Co-Owner(s) - As Appropriate Begional.Office, Well Becord File Prep to set Pkr. (9-5/8" @10,484) _Ran .a.nd c_m~t'd 9,-.5/.8._"; C?_~~4.. Ran,&cmt'd 9-5/8" csg. (~ 10,484 47~ r-llO (2197') & 47# N-80 (8244') buttress csg. w/1000 sxs Class "G" cmt, premixod w/l% CFR-2 (1115 cu.. ft.)~ll8#/cu, fi. slurry, displaced w/~74 cu. ft. mud tn 62 min. B~uped top plug w/2000 pst. ClP ~ 10:15 a.m. 3-7-69. Used 1 top ~ 1 btm. rubber plugs, Had good circ. throughout. Calc. top cst. ~7310. Installed paCk-off tested W/5000 psi. Stood cmt'd, laid do~ drlg. Set up ~ sq, stabilizers. RII{ w/8-1/2" bit w/9-5/8" Baker csg. scrape~ on }I%~P ~11:00 p.m. 3-7-69, top cst, ~ 10,389. CO cst. to ~ ~ 10,394. Circ. ~/4 hr., closed and tested csg. w/1700 pst. OK. Displaced mud w/sea water, pulling ~DP. DP & }B{DP, Ran Dresser-Atlas CBL casing collar log from 10,360-4500. Top of cst. 6~7700. Finished ~ 4:30 a.m; 3-9~69. Installed 4-1/2" tbg. rams, Ran 322 its. 4-1/2" 12.6 N-80 buttress thc. ~ 9938 w/Otis 3-1/2" "Q" nipple ~3 9937, 9-a/8" x v ~ro~ lt-iSP pkr. G' 9900. l0 Camco gas iif~ mandrels ~ 9745, 9219, The Above is Correct: INSTBUCTIONS: This form is used during drilling or workover operations. If testing, coring., or perforating, show formation name in describing work performed. Number all drill stem tests sequentially, Attach description of all cores. Work per- formed by Producing Section will be reported on "INTEBIM" sheets until final completion. Report official or representative test on "FINAL" formo (1) Submit "INTERIM" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set, Submit weekly for workovera and £ollowing setting o£ .oil string until completion, DAILY WELL HISTORY - INTERIM District Alaska , , County or Parish Field North Trading Ba~ Hemlock Lease or Unit .State Alaaka :1;~3.3 -26 TBS ' $-3 Well No. Date & Depth at 8:00 A.M. 2-20 -69 8780 2-24-69 9258 · 2-25-69 9258 2-26-69 9258 2-27-69 9442 Complete Record for each Day While Drilling or Workover in Progress (203) Drilling. (!3-3/8" ~ 2006) Mud 75~, Vis. 38", WL 5.7cc. Directimally drilled 12~g'' hole 8577- 8780'. Survey: 8722' 22-3/4° S77W, VD 84Z1.13, S4'33.94,. W1504.02.. (478) GIH. (13-3/8" e 2006)' 'Mud 76~., Vis. 42", WL 5.1cc. Directionally drilled 12¼" hole 87S0- 9258'. SCR unit failed ~ 6:00 Al4 2-22-69. While drlg ~.. 9258 2-23-69, a 20 pin connector burned out on SCR ~4 and SCR ~5, arched across burning off an oil line. Started out of hole. PO 54 stds very slowly with SCR l, 2 and 3. Lost SCR :~%2 and 3, repaired ~5, pulled 2 stands and lost SCR ~5, pulled into shoe w/SCR 4~1. Stand- ing ~ 13-3/8" shoe waiting on parts. Parts arrived about 1:00 PM 2-23-69. Changed oil and repaired SCR ~1, 2, 3 & 5. Finished POH. Ran 54 stds in hole. Blew 2 fuses in SCR .~i. Pulled up into shoe. 20 fuses blown since trouble started Saturday morning. Now out of fuses. (0) SI foz repairs 'to electrical system. (13-3/8" @ 2006) SI 24 hrs for repairs. Ran 54 stds into hole, lost 2 fuses in SCR unit. Pulled bit into 13-3/8" csg shoe. Waiting on parts and Bay- lot representative since 8:00 AM 2-24-69 (no flying weather). Switched to' diesel turbine and now running .platform on diesel. Re- paired SCR units No. 1, 2, 3, and 4. Rewinding motor on oil pump on SCR ~5. (0) Waiting on repairs to electrical system. (13-3/8" @ 2006) MCR units Nos. 1, 2, 3, 4, 5. running. Testing on surface. Blew 4 fuses on SCR 4~1. No replacements. Found contaminants in oil. Changed oil. Found some carbon, .scale sand--small amounts. Got 14 fuses, 7 drums transformer oil. Installed fuses. Putting in SCR oil ~ 6:00 AM. Units Nos. 1, 3, 4 & 5 working OK. (184) Down working on turbine. (1.3-3/8" .~ 2006) Mud 779, Vis. 41", }FL 6.4cc. Tested and adjusted SCR system. Start- ed in hole 11:00 ~uM 2-26-69. Circ@ 5000 and 7000'. }lad no fill or, , ~5 firing package faulty Blew 2 fuses and btm. Drilled 1 hr SCR . · 1 SCR,~horted across SCR ~3 and blew 6 fuses a~ 2 SCR units. Could not repair all SCR units. Robbed ~5 to get others running. Drilled w/units ~1, 2, 3 and 4. Drilled 2 hrs. Diesel turbine went off, by-passed shutdown ].ights on turbine and ~illed to 9442'. Pipe stuck on btm while rotating, worked pipe free in 10 rain w/360,000~. Rotated back to btm and pipe stuck, worked pipe for 30 rain @ 360,0~ in Pos. 1, Range 1. SCR ~1 in drwks; 4~2 and 3 Mud pump ~2; ::~4 in rotary table; could not free pipe. Changed to Pos. 3, Range 1. Put SCM -i~l and 2 on drwks; ~3 and 4 on Mud pump ~2. Pulled pipe loose Distribution: Orig.: Drilling Section - Dallas cc:- District Office Engineering Division - (720) Co-Owner(s) - As Appropriate Regional Office, Well Record File The Above is Correct: PAGE NO. q (NUMBER ALL DAILY WELL HISTORY FORMS CONSECUTIVELY AS THEY ARE PREPARED FOR EACH WELL. ) P rin?ed U $ A SIGNATURE ~//~'. DATE -- -- INSTRUCTIONS: This form is used during drilling or workover operations. If testing, coring., or perforating, show formation name in describing work performed, Number all drill stem tests sequentially, Attach description of all cores, Work per- formed by Producing Section will he reported on "INTERIM" sheets until final completion. Report official or representative teat on "FINAL" form, (1) Submit "INTERIM" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion, DAILY WELL HISTORY - INTERIM District Alaska County or Parish Field ~-]orth ~Iiadinq Bays'.H~-~mlock Lease or Unit State Alaska :~13 -26 TBS S-3 Well No ..... Date & Depth at 8:00 A.M. 2-10-69 6377 2-11-69 6670 2-12-69 7070 2-13-69 7320 2-14-69 7535 2-17-69 8195 2-18 -69 8400 2-19'69 8577 Complete Record for each Day While Drilling or Workover in Progress (1122) POH w/bit. (13-3/8" ~ 2006) ' Mud 74'.~, Vis. 44", WL 4.9cc. Directionally drilled 12%" hole 5255- 6377'· Gas turbine went off @ 2:20 PM 2-8-69· Found fuel regulator pressure valve showed open when it was actually closed· found stem broken in valve. Replaced. valve from diesel turbine. Started tur- bine ~% 7:30 PM. Replaced fuses in SCR unit. RU @ 8:00 PM 2-8-69. When trying to start diesel turbine, found it would not go thru starting cycle· Starting system was locked Out, external light was on in control panel. Poor contact of module in control panel. Lo- cated poor contact. Diesel turbine~vill now start. Down 9 hrs 2~-69. Put in new breaker in SCR system after breaker installation had to adjust system. Survey: 7377' 22t~° S73W, VD 6274·55, S189.35, W601.73. (293) Drilling. (13-3/8" ~ 2006) . . Mud 75~, Vis. 40", WL 5.2cc. Directionally drilled 12~4" hole 6377- 6670'. Tested CSO, 5" DP rams and manifold w/3000 psi, OK. Hydril w/2000 psi, OK. Survey: 65'85' 22-3/4° S73W, VD 6466.37, S212.89, W677.64. (400) Drilling. (13-3/8" ~ 2006) Mud 74%, Vis. 42", WL 4.8cc. Directionally drilled 12¼" hole 6670- 7070'. Survey: 6818' 22-3/4° S73W, VD 6681.24, S239.23, W763.81. (250) Drilling. (13-3/8" @ 2006) Mud 75~, Vis. 41" WL 4 7cc. Directional ly drilled 7070-7320' · · · Survey.- 7230' 23%° S74W, VD 7059.09, S287.34, W921.17. (215) GIH. (13~3/8" O 2006) Mud 75~, Vis. 40", WL 4.4cc. Directidnally drilled 12¼" hole 7320- 7535'. Survey: 7425' 23½° S73W, VD 7238.92, S307,08, W999.67. (660) GIH w/bit. (13-3/8" @ 2006) Mud 76~, Vis. 41"· WL 5.1cc. Directionally drilled 12¼" hole 7535- 8195'. One test CSO & Pipe rams w/3000 psi, OK. Hydril w/2000 psi, OK. Survey: 7948' 23° $75W, VD 7717·89, S364.13, W1201.66. (205) Drilling. (13-3/8" ~. 2006) Mud 76~, Vis. 40", WL 6.4cc. Dire ct ional ly drilled 12!I" hole 8195- 8400'. Survey: 8272' 22-3/4° S76W, VD 8015.68, S394.50, W1323.23. (177) POH w/bit. (13-3/8" ~ 2006) Mud 76~, Vis. 39", WL 6.3cc. Directionally drilled 12.~4'' hole 8400- 8577'· Survey: 8431' 23%° S77W, VD 8162·77· S408.62, W1394..38. Distribution: Orig.: Drilling Section - Dallas cc:- District Office Engineering Division - (720) Co-Owner(s} - As Appropriate Regional Office, Well Record File The Above is Correct: // Distri~ft Drillinq'-- Supervisor INSTRUCTIONS: Prepare and submit the INITIAL REPORT on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. DALLY WELL HISTORY-'INITIAL REPORT District Ala~ca County or Parish FieldNO,Tradin<]vBay. 5. ,:~,::,; Hemlock Lease or Unit TBS S--3 .Alaska State -~?L 3-?6 Well No. - Drill development well .from Spark Auth. or W.O. No. 19--7363 Title P1 a t form. Operator Dtlantic Richfield Company Spudded or W.0. Begun Spudded Date , 1-30-69 TARCO' S W.I. Prior. Status Hourl0:00Ablf a W. O. 100% Date & Depth as of 8:00 A.M. 1-30-69 1-31-69 1396 2-3-69 2106 2-4-6 9 3740 2-5-69 4500 2-6-69 4000' 2-7 -69 5255 Complete Record for each Day Reported Moving rig on location. (1396) GIH w/bit. o , r~_ .10~. ..... bIud 6°''~'~ Vis 62", ~<L 14 6cc. sou. al.ed ~ C0 Al'.,: 1-~0-69 CO conductor 430-4$0'. RIH w/12~" bit and drilled to 1396'. Rotary table froze up ~ 1396'~ POH, checked rotary table, working OK. Surv. y: 1315' 1~" S85W. (710) GIll w/bit. (13-3/8" ~ 2006) b: (~ 7~'~ Vis. 55'~ ',TL 12 6cc Directionmlly drilled 12'~g'' t%ole !396-2052'. Opened !2~" hole to 18" 440-2052'. Measured out of -'"" ']-'~ K-55 5uttre, Gs hole OK. RIH to btm OK. Ran and cmtd ~?~_~_~_~~.' w/875 Class "G" cat mixed w/10% cdel fo].lowet~ w/400 Neat Class "G" cat. Displaced w/1745 cu. ft. mud. Bumped plug w/1500 psi. Float did not hold. Shut in w/5C0 psi. CIP'O.6:00 AM 2-2-69. Had good circ throughout w/50 cu. ft. cat retvrns. Used one top & one bottom plug. Removed 20" riser & hydril, in- stalled 13-3/8" OCT unihead 13-5/8" riser and DOPE 'tested riser & ROPE manifold w/5000pox-', OK.. RIH w/l'¼'',~ bit, cleaned out cat 1940-2052' Direct ionally drilled 12TM hole 2052-2106 ' Survey: 205'2' %o N88W, VD 2050 78, N8.35, W20 70. (1634) Dril'lincj. (13-3/8" ~ 2006) Mud 72~, Vis. 37" WL 13 2cc. DireCtiona].ly drilled 12~:'' holc 2106-3740'. Survey: 3334 3/4° West, VD 3332.72, N8.48, ~t33.11. (760) GIH w./Dynadrill ,;~.1. (13-3/8" ~. 2006) ~n~.,, hole Mud 73~:, Vis. 41", WL 12.6cc. Directionally drilled 3740-4500'. Ran Sperry Sun Gyro Directional Survey on 13-3/8" csg 2006-0'. Survey: 4500' 1-3/4° N75W, VD 4498.33, N13.39, W60.68. (300) Drilling. (13-3/8"@ 2006) ]kuc~ 74.~.~:, Vis. 43 , '~'~L ii..3cc. Directionally drilled 12:~ hole 4500-4800 '. Survey: 4650' 6-3/4° SSOW, VD 4647.68, N4.93, W71.06. (455) Drilling. (13-3/8" @ 2006) Mud 74~, Vis. 43", %~L 9.4cc. Directionally drilled 12[{" hole 4800' ,~.. 06. -5255'. Survey. 5204' 18° S69W, VD ~194.57, ~ . -,,. · Distribution: Orig.: Drilling Section- Dallas cc:- District Office Engineerin8 Division - (720) Co-Owner(s) - As. Appropriate Regional Office, Well Record File PAGE NO ...... ! . (NUMBER ALL DALLY WELL HISTORY FORMS CONSECUTIVELY AS THEY ARE PREPARED FOR EACH WELL.) The Above is Correct: SIGNATURE // -- ' DATE Distrlc:t~/' DrJ.!linq S~.pervisor RECEIVED AtlanticRichfieldCompany North Ame~i *oducing Division Alaska District Post Office Box 360 Anchorage, Alaska 99501 Telephone 907 277-5637 April 23, 1969 State of Alaska Department of Natural Resources Oil & Gas Division 3001 Porcupine Drive Anchorage, Alaska Gentlemen: Attention: Mr. T. R. Marshall, Jr. Find enclosed one copy each of the DIL Log for well numbers K-15 a~._-~3, ~requlred as a part of the Completion RepO'f~2''~'~J Very truly yours, Robert W. McCleskey RWM:tll encs (2) DIVISION OF Oi;. AND GAS ANCHOr. GE DIVISIOit OF OIL mD ~ April 23, 1969 Re: Trading Trading Pay Un Atlaattc Richfield Company, Operator ~h-. Rebert kL )lcCleskey Senior Engineer Atlaatic Richfield Company ggr~l De~r .~. ~cCles.~y-. Eaclosed are the complettoa reports (Form P-7) on yeur S-3 ara~ Bay UNit I-1.5 ~ells ~tch are I tea 12 Mt fi lled out on either. Item ~ fro- K-15 ~s not check ~tth the perforatteas ~.~ ~ted on the Monthly Report of Operations. I~ 18 'is mt filled, ia on S~3, If perforattans t'~ were not cantt~s ~ 9,994' to 10,344' as s~ i~ Item 28, you ~tll please sba~ t~he detailed iat~als. to assure t~t fer~ardt~ ~. have saaeo~ check these forms required are filled in before ~V Ver~ truly yau~, / Karl L. VonderAhe Petroleu~ Engineer £nclesures AtlahticRich'fieldCompany North Ameri( 'roducing Division Alaska District Post Office Box 360 Anchorage, Alaska 99501 Telephone 907 277-5637 April 21, 1969 State of Alaska, Department of Natural Resources Oil & Gas Division 3001 Porcupine Drive Anchorage,. Alaska Gentlemen: · Find enclosed the Well Completion Report for our Trading Field well No. S-3 (13-26). · A copy of the DIL Log will be furnished as soon as we receive the final prints. Very truly yours, TRM -.-~,, ...... - OKG ~ KL¥ H\¥K REL FILE RWM:tll enc For'~ No. P---4 R~v, s-~ STATE OF ALASKA OIL AND OAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 2. NAME OF OPI~,ATOR Atlantic Richfield Company 3. ADDREss OF OPEi%ATOR SUBMIT IN I]UPLIC~%TE AP1 NUA~ERICA3~ CODE 50-133-20175 6. LEASE DESiGNA ~--ION AND SEEIAL NO. ADL-35431 ?. IF INDIA]~, ALOT'r'EE OR TRIBE NAME 8. L~IT,F.~RA{ OR LEASE N.~ME North Trading Bay State g. WELL NO. P. 0. Box 360, Anchorage, Alaska 99501 4. DCA~ON OF WELL 2613'N and 2495'W from SE Corner of Section 26, T10N, R13W, SM S-3 (13-26) 10. FIF_J~ A-ND POOL, OR %VILDC~T North Trading Bay State 11. SEC., T., R., M., (BOTTOM HOI~E o~ Sec. 26, T10N, R13W, SM 12. PERlViIT NO. 69-11 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET ~ VOLUATES USED, PEP~FO.RATIONS, TESTS ~ RESULTS, FISHING JOBS, JUNK IN HOLE A/~D SIDE-TI~ACKED HOLE ,~ND A.NY OTHER SIGNIFICANT CH2%N,~ES IN HOI~ CONDITIONS. ~. Trading. Bay .state s-3 (.13-26) March., 1.9.69_ Directionally drilled 12¼" hole 10,088~. - 10,541. Ran Schlumberger DIL 10,52~ 2006, BHC, Sonic, & FDC 10,524-8500. Ran & cemented. 53 Jts. 9-5/8" 47~ P-110 & 201 Jts. 9-5/8" 47~ N-80 Casing at 10,484' (collar at 10,396') w/1000. Sxs Class "G" cmt treated w/l% CFR-2. CIP ~ 10:15 AM 3-7-69. Installed & Tested OCT Pack-off w/5000 PSI with 9-5/8" casing scraper on 8~" 2 bit found top of cement $ 10,389. CO cmt. to float collar $ 10,394. Tested casing with 1700 psi. OK. Displaced mud with sea water. Ran Dresser-Atlas CBL from 10,360- 4500. Top of Cmt. ~ 7700' Ran & hung 4~" 12 6~ N-80 Tbg ~ 9938 w/Otis 3½" ~.~ ........... i,, .... ~ ..... i,u,,, ) 1,~,,~ ' ., ' "Q" nipPle ~ 9937, 9-5/8" x 5" Brown H-lSP Pkr. ~ 9900. 10 Camco Gas Lift Mandrels ~ 9745, 9219, 8694, 8142, 7617, 7060, 6263, 5302, 4007 & 2103. Otis Ball Valve $ 433'. Removed BOPE. Installed Xmas Tree. Tested tree to 5000 PSI. OK. Displaced sea water w/Diesel oil. Set PKR w/3000 PSI. Tested · Pkr. w/2000 PSI. OK. Perforated 4 holes/ft. 10,344-10,208, 10,190-10,152, 10,140-10,114, 10,102-10,083, 10,070-10,022, 10,006-9,994. Released rig $ 6:00 PM 3-10-69 ItF. CE D 111969 DIVISION OF OiL AND GAS 14. I hel'eby ee~~Eoreu~.~e and correct smrrsn . '- .~/ ~TLE Dist. Drlg. Supv. NOTE--Reportfn~his form is required for each calendar month, regardless of the status of operations, and must be filecl in duplicate with the Division of~Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. Robert T. Anderson District Land Manager Union Oil Company of California '2805 Denali Str~' Telephone (907) 2/7-1 April 1, 1969 chorage, Alaska 99503 481 KLV -- HWK REL ~ Gentlemen: Division of Oil and Gas 300t Porcupine Drive Anchorage, Alaska Attention: Il/fr. Thomas R. Marshall, Ir. Re- APPLICATION FOR PERil/fITS TO DRILL S-1 ~14-26, a S-3 Reference is made to Atlantic Richfield Company's letter dated 1Vfarch 18, 1969, concerning their application for permit to drill ~vells S-1 ~14-26, and S-3 ~13-26. In accordance with Section 2060 of the State Oil and Gas Conservation Regulations, this is to advise you that Union Oil Company of California, as an affected operator, has no objection to the above wells as set forth in said applications. RTA/nr CC' Atlantic Richfield Company Attention R. D. [ohnstone Yours very truly, Robert T. Anderson Form 401 ANC-A(New 7/67) PIiTROL,EUM PI~ODU~/~ March 25, 1969 HWK REL TEXACO INC. P. O. BOX 664 2UNCHOI~AGE. ALASKA FiLE APPLICATIONS FOR PERMIT TO D~ WELLS S-i ~14-26, S-2 ~11-35 an~S. SJ~]~13-26 ATLANTIC RICHFIELD SPARK PLATFORM State of Alaska Division of Oil and Gas 3001 Porcupine Anchorage, Alaska 99501 Attention: Mr. Homer Burrell Gentlemen: Reference is made to the subject applications for permit to drill three wells by Atlantic Richfield from their Spark Platform in the Trading Bay Field. Copies of these appli- cations were furnished us by Atlantic Richfield by letter dated March 18, 1969. Please be advised that Texaco as an affected operator has no objection to the drilling of said wells. Yours very truly, TE>L~CO Inc. District Landman Crib: spc Cc - Atlantic Richfield Company P. O. Box 360 Anchorage, Alaska 99501 Attention: Mr. R. D. Johns Form No. P~4 REV. STATE OF ALASKA OIL AND OAS CONSERVATION COMMITTEE SUBMIT IN I)UPLICATE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS '5. AP1 NUA{ERiCAL CODE 50-133-20175 6. LEASE DESIGNATION AND SERIAL NO. ADL-35431 1. T. IF IZqDIA)~. ALOTTEE O~ TRIBE NANIE OIL ~-] GAS Q W,LL WELL OTHE, 8. L~IT,F.~RA~ OR LEASE NAME North Trading Bay State 9. WELL NO, S-3 (13-26) 2. NAME OF OPERATOR Atlantic Richfield Company 3, ADDRESS OF OPEP..A. TOR P. O. Box 360, Anchorage, Alaska 99501 4. ~CA~ON OF WELL 2613'N and 2495'W from SE Corner, Section 26, T10N, R13W, SM 10. FIELD AND P~L. OR %VILDCAT North Trading Bay State 11. SEC.. T., R., M.. (BO'I'FOM HOLE o~ Sec. 26, T10N, R13W, SM 12. PERMIT NO. 69-11 13. REPORT TOTAL DEPTH AT END OF MONTH, CI-I_A_NGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET ~ VOLU/VFES USED, PERFORATIONS, TESTS ~ RESULTS. FISHING JOt~S, JU/~K IN HOLE AND SIDE-TRACKED HOLE ~ ANY OTI-IER SIGNIFICA~qT CH~kN~ IN HOL~ CONT)ITIONS. Trading Bay State..S-3 (!~.3..,26) -Feb.~uar¥, ,1,96,9 Ran and cmt'd 13-3/8" casing ~ 2006' w/875 sacks Class G. Cmt mixed w/10% Gel, followed w/400 sx Neat Class "G". Installed BOPE. Tested BOPE Manifold w/5,000 psi, OK., CSO w/1500 psi, OK., and Hydril w/1500 psi OK. DirectionallY drilled 12-1/4" hole 2052-10,088. i, ii 14. I hereby certify that the for ing is true and correct sm~~ ~~ =~ Dist. Drlg. Supv. D^~ ~ -/~? NOTE--Rep'/on this form is required for each calendar month, regardless of the status of operations, ancl must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. l~orm No. P--4 REV. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS SUBMIT IN DUPLICATE ~i ~PI NLrlIERICAL CODE 50-133-20175 '6. LEASE DESIGNATION AXD SEFiIAL NO. ADL 35431 1. 7.IF INDIA]~,ALOTTEE OR TRIBE NAME OIL ~ GAB [] v,'ELL WELL OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPEP~TOR P. 0. Box 360~ Anchorage~ AK 99501 4. IX)CATION OF WELL 2613'N and 2q95'W from SE Corner, Section 26~ TION~ R13W~ SM 8. L,~IT,F.~=,A~I OR LEASE North Tradi_n~' Bav State 9. WELL NO. ~ S-3 (13-26) 10. FIELD A.ND POOL, OR WILDCAT North Trading Bay State ,, 11. SEC., T., R., M.. (BO'I"I'OM HOLE ommc--rrv~ Sec 26, TION, R13W, SM 12. PERMIT NO. 69-11 13. REPORT TOTAL DKPTH AT END oF MONTH, CHANGES IN HOLE SIZE,CASING A/hrDCE1ViENTING JOBSINCLUDING DEPTH SET ~ VOLU~ USED, PF~O.P~ATIONS, I-F~STS ;~xUf) RESULTS, FISHING JOlhS, JUNK IN HOI2g ~D SIDE-T]R.~CKED HOLE A_ND A_NY OTHER SIGNIFICANT CHANGES IN HOL~ CONDITIONS. N. Trading ,Bay State S-3 (13926)...- JanuarM, 1969 ,Spud,deal @ 10:00 A.M. 1-30-69. Drilled 12-1/4" hole.440-2052. CO conductor 430-440'. RECBVm · FEB7 1969 DIVISION Of OIL AND GAS ANC~AOE 14.1 hereby certi£y that the f~..nl~ru.~ and correct s~awm.~f~ ~~-~-~ ~ Dist. Drlg. Supv. ri^yE February 5, 1969 NOTE--Repo~/et~ this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division~f' Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. . D~IOS OF OIL A~D ~ North Trading ]hry St. aCe S-3 ~13-26 A~Lanctc R/chfteld Company, operacor Je4mo~ Box 360 Deer This vel1 rill not be al~ ~:o prod~ un~tl ~he Tr~dtug FORM SA- I B MEMORANDUM FROM: State of Alaska D/VISIOll 01~ OIL &ill) DATE : SUBJECT: JJmJ~ 31, 1969 Ifor~ Trmlb~ hy State ~z~2e FORM SA - I B MEMORANDUM TO: j-- FROM: State of Alaska DXVXSXOH Oil OJl. ABI) GAS DATE : SUBJECT: ~ :]r~J, 1969 #13-26 AtlanticRichfieldCompany North Amer~ Producing Division Alaska Di~ Post Offic~ ~ox 360 Anchorage, Alaska 99501 Telephone 907 279 1411 January 27, 1969 State of Alaska Department of Natural Resources Oil and Gas Division 3001 Porcupine Drive Anchorage, Alaska 99504 Attn: Mr. T. R. Marshall, Jr. Re: North Trading Bay State S-3 ~13-26 Section 26, T10N, R13W, SM Gentlemen: Enclosed please find. the Application for Permit to Drill in triplicate together with a plat of the location and a check in the amount of $50.00 to cover the filing fee. Yours truly, R. D. ~o/nst~one Distri~ Drilling Supervisor RDJ/pd Enclosures Form P--I B~EV. STATE OF ALASKA A.P ....I. f! 50-133-20175 SUBMIT INi'' ATE (Other instru~ ns on reverse side) OIL AND GAS CONSERVATION ,COMMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK IR. TYPE OF WORK DRILL [] DEEPEN [--] PLUG BACK. [] OIL [] 0A8 ~'~ SINGLE[] MULTIPLE ~_~ WELL WELL OTHER ZONE ZONE 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS O~ OPERATOR Atlantic Richfield Company 4'LOCATION2~V~N~ & 2495W fr SE cr, At surface-- - Sec 26, T10N, R13W, SM At proposed prod. zone 1940N & 1050E fr SW cr, Sec 26, T10N, R13W, SM 13. DISTANCE IN MILES AND DIRECTION F~%OM NEAREST TOWN OR'POST OFFICE* 28 Miles NW from Kenai, Alaska 8. UNIT FARi~ OR LEASE NA-NI~ ~or~h Trading Bay State 9. WELL NO. S-3 ~13- 26 10, FIELD AND POOL, OR WILDCAT North Trading Bay State 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 26, T10N, R13W, SM 12. 14. B~N,D I.NFOR~A,TION: ~tatewlae TYPE Surety and/or No. 15. DISTANCE FROM PROPOSED* LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) Federal Insurance Co. ~8011-38-40 t 16. NO. OF ACRES IN LEASE 1050' 320 19. PROPOSED DEPTH 10,500 ' 18. DISTANCE FROM PROPOSED LOCATION* TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 1460 ' 21. ELEVATIONS (Show whether DF, RT, C-R, etc.) 115 ' ':' K.B. o . $100,000 17. NO. ACRES ASSIGNED TO ~s WELL 8 0 20, ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START* January 27, 1969 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING} WEIGHT PER FO°T GRAI)E t SETTING DEPTH ' ~ ' · QUANTITy OF CEMENT 18" I 13-3/8" 12~4'' 9-5/8" 47% N-80 10,.500' 700 sx f;//9 z<~ .~, · , , Verbally approved by telephone R. of January 27, 1969. D. Johnstone to Mr. ~Logging ~ TD Completion zones'will be Upper Kenai and Hemlock 20" Hydril on 20" casing 13-3/8" double gate w/CSO and 5" rams on 13-3/8" and Hydril C. VonderAhe morning DW~S casSng CesCed ~o 5000 IN ABOVE SPACE DESCR/BE PI%O~P'OSET) PROGRA/~: If proposal is ~o deepen or plug beck, give data on present produ.ctive zone and proposed r~ew productive zof~e. If pro,posal is to drill or deepen direct ~onally, give pertinent data on s~bsurface locations and measured and true vertical depths. Give blowoat preventer program. 24. I hereby certify that the ~oing~ T~..f~,~..Correct (This space for State offi~s/ CONDITIONS OF A/~PROVAL, IF ANY: OTITER RE-~U~TS: SAMPLES AND CORE CHllmS REQUIRED [] YES ~ NO 1969 Dist. Drlg. Super~ DIRECTIONAL SURVEY REQUIRED /~ YES [] NO A.P.I. NLrNIERICAL CODE ~, ~,~H~L 1-30-69 APPROVD B~ ' /~ Tz~.Alosko Oil & Gas DA~ ~ , *See In~ucfion, On~M~i~°mmit*~[- , . :%on' of.~. ,, r' '' Subject to provisions of Conservation Order No. 69. I TION-RI3W ~ ] TION-RI2W ~ 22' 23 27 O~ / / / / / / / / / / / / / / 34 / / / / / / / / / t! / / / ! / / / / / ' ~'~,TEXACO-_0 / I! \ \ \ \ \ \ b q- "SPARK PLATFORM" . S-3 _ _ ----' .~6 · /" / / / / / /' / / / / $-I ~/ / C)/ / / TB. ST I /// ? 35 24 25 19 30 ATL ANTtCRICH.FIE L DCOMPANY ALASKA DISTRICT WELL LOCATION MAP NORTH TRADING BAY STATE S-3 (13-26) H SCALE I"= 2000' I1-6~ Well History File APPENDIX Information of detailed nature that is not particUlarly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History.file.and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information.