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Home My WebLink About174-024~ STATE OF ALASKA ~ ~~ ~/~`s~D ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETiON REPORT AND LOG 1a. Well Status: Oil ~ Gas ~ Plugged ~ Abandoned 0 Suspended ~ 20AAC25.105 ' zon.ac2s.iio GINJ^ WINJ^ WDSPL^ WAG ^ Other^ No. of Completions: 1b. Well Class: Development ^~ • Exploratory^ Service ^ Stratigraphic Test^ 2. Operator Name: Marathon Alaska Production, LLC 5, mp., Susp., or Aband.: 8/4/2009 • 12. Permit to Drill Numb r: • 174-024 3~ -/~ ~ 3. Address: P.O. Box 196168, Anchorage, AK 99519-3043 6. Date Spudded: 6/13/1974 Redrill 13. API Number: 50-733-20172-01-00 • 4a. Location of Well (Gov rnmental Section): Surface: 2606' F , 2492' FEL, Sec. 26, T10N, R13W, SM • 7. Date TD Reached: 7/11/1974 Redrill 14. Weil Name and Number: North Trading Bay Unit S-02RD • Top of Productive Horizo .~jd-~ q`Q~~1 8. KB (ft above MSL): Ground (ft MSL): 15. Field/Pool(s): Undefined Gas Total Depth: 1057' FNL, 221' FEL, Sec. 34, T10N, R13W, SM 9. Plug Back Depth(MD+TVD): 162 WLM, 47' BML G-NE/Hemlock-NE Oil ' 4b. Locatio of Well (State Base Plane inates, NAD 27): Surfac ~ ~ x-~66-928~'S't ~~ --1~~ 353 _ j~ Zone-.1~ Z ~s~'f7 10. Total Depth (MD + TVD): , 11352 MD, 10132 TVD . 16. Property Designation: ADL0018776 . • TPI: Q~ x- G~~Z~ . e,~ ~Ei70 SR75' y 2S30~ga65~Zone-L~ Total Depth~ x- 60.91843311 y- -151.5472263 Zone-~ 11. SSSV Depth (MD+TVD): 593 MD 17. Land Use Permit: 18. Directional Survey: Yes ~ No ~ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: (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 SI AMOUNT FT TOP BOTTOM TOP BOTTOM ZE CEMENTING RECORD pULLED 13-3/8 61 J55 0 2055 0 1926 18 875 sk G w/10% Gel 400 sk 9-5/8 47 N, P 0 7370 0 6827 12-1/4 1000 sk 7 7167 11341 10123 8-1/2 1175 sk G 23. Open to production or injection? Yes ~ No ~• 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) 2-3/8" 600-9227' Baker HB C~3 9200' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. '' ;, , r. ' r' t r~(" ~t~~4 DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED ` 162 WLM - 575 MD ( ) 41 bbls 124 sk 1.132 d) 15.9 ( y ppg G Neat 575-600 CIBP in 9-5/8" csg on top of 2-3/8" tbg 6481-7267 25 bbis (124 sk 1.132 yd) 15.9 ppg G Neat 7440-9867 26 bbls (128.9 sk 1.132 yd) 15.9 ppg G Neat 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. ~tJC~ J.~j~11 LZ~~~ ~ '~-~"al~ ,r . ~E~~~~~~ ~ SEP 0 $ ~ 2009 ~~~~ ~~~. ;r ~ r 2~0~ ~ ~~ _a~~ '~. Alaska Oil & Gas Cons. Cor~mission Anch Form 10-407 Revised 2/2007 CONTINUED ON REVERSE ~`~~o~~ /' ~~' "~ % ~ ~ ~ 2II. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ^ Yes ^ No If yes list intervals and formations tested , , briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top 0 0 needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base 0 0 BELUGA i ,450 1,446 TYONEK 3,709 3,492 MIOCENE, GAS SANDS 5,038 4,672 TOP HEMLOCK 10,790 9,686 TOP W. FORELANDS 11,233 10,037 Formation at total depth: W. FORELANDS 11,233 10,037 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 Compiiance Representative r Signature: ~ Phone: 907-565-3043 Date: 9/2/2009 ~~ 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 ia: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Suppiy for /njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool compietely segregated. Each segregated pool is a completion. 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 weli should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersibie, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervais cored and the corresponding formations, ar~d a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Rem 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. ; orm 1 Q-407 Revised 2/2007 ~ STATE OF ALASKA ~ n,~ ~ 5-09 ~r~ ;~y~~r~~~ [.~il ~ ALASK IL AND GAS CONSERVATION COMMIS N ~ ~s x.~~ ~ ~ ~ ~< z,t ~ . - WELL COMPLETION QR RECOMPLETION REPORT AND I~(~~ ,"e 1a. Well Status: Oil~ Gas~ Plugged ~ Abandoned ~ Suspended ~ 20AAC 25.105 20AAC 25.110 GINJ^ WINJ^ WDSPL~ WAG^ Other^ No.ofCompletions: 1b. Well Class: Development ^ Exploratory^ Service ^ StratigraphicTest^ 2. Operator Name: Marathon Alaska Production, LLC 5. Date Comp., Susp., or Aband.: 8/4/2009 12. Permit to Dril~ Number: 174-024 3. Address: P.O. Box 196168, Anchorage, AK 99519-3043 6. Date Spudded: 6/13/1974 Redrili 13. API Number:. 50-733-20172-01-00 4a. Location of Well (Governmental Section): Surface: 2606' FNL, 2492' FEL, Sec. 26, T10N, R13W, SM 7. Date TD Reached: j/s' 7/11/1974 Redrill 14. Well Name and Number: North Trading Bay Unit S-02RD Top of Productive Horizon: 8. KB (ft above MSL): Ground (ft MSL): 15. Field/Pool(s): Undefined Gas Total Depth: 1057' FNL, 221' FEL, Sec. 34, T10N, R13W, SM 9. Piug Back Depth(MD+TVD): 162 WLM, 47' BML G-NE/Hemlock-NE Oil ' 4b. Location of Well (State Base Piane Coordinates, NAD 27): Surface: x- y- Zone- 10. Total Depth (MD + TVD): 11352 MD, 10132 TVD 16. Property Designation: ADL0018776 • TPI: x- y- Zone- Total Depth: x- y- Zone- 11. SSSV Depth (MD + TVD): 593 MD 17. Land Use Permit: 18. Directional Survey: Yes ~ No [~ (Submit electronic and printed information per 20 AAC 25A50) 19. Water Depth, if Offshore: ~rQ ~ (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 CEMENTING RECORD AMOUNT FT TOP BOTTOM TOP BOTTOM PULLED 13-3/8 61 J55 0 2055 0 1926 18 875 sk G w/10% Gel 400 sk 9-5/8 47 N, P 0 7370 0 6827 12-1/4 1000 sk 7 7167 11341 10123 8-1/2 1175 sk G 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) 2-3/8" 600-9227' Baker HB Q 9200' 25. ACfD, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 162 (WLM) - 575 MD 41 bbls (124 sk 1.132 yd) 15.9 ppg G Neat 575-600 CIBP in 9-5/8" csg on top of 2-3/8" tbg 6481-7267 25 bbls (124 sk 1.132 yd) 15.9 ppg G Neat 7440-9867 26 bbls (128.9 sk 1.132 yd) 15.9 ppg G Neat 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 analyticai results per 20 AAC 25.071. kru~; ri ~LTi~~ ~~ ~ ~~~ ~ ~ ~ j ' ~ ~.~..w,....t•..,w,,,~,~ i k-.~,. . . .+..-r..n.x .~:1 Form 10-407 Revised 2/2007 CONTINUED ON REVERSE 28. GEOLOGIC MARKERS (List all formations and rnarkers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ^ No If yes list intervals and formations tested , , briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base 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: sc~ ~%`~ Phone: 907-565-3043 Date: 8/19/2009 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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. lfem ia: ClassificaYion of Service weAs: Gas lnjection, Water Injecfion, Water-Alternating-Gas lnjection, Salt Water Disposal, Water Supply for lnjection, 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 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 suppiemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, 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 analytical laboratory information required by 20 AAC 25.071. f Form 10-407 Revised ?_/2007 ~ ~ t r i• l~t1~~AT~t£Itl~ ~~ WATER DEPTH @ 60' KB ABOVE MSL @ 115' ANGLE @ KOP 23.5 deg @ 7375' TMD @ 11352' ND C~ 10132' MASTP 3000 psi MIT 5/7/09 API # 50-733-20172-01 Surtace Casing - @ 2055' 13 3/s" 61 ppf J55 Buttress CMT 2000 sks CTOC @ Surface / Gauge Hole TOL @ 7167' Squeezed W/ 100 SX "G" Testto 2500 psi "HELD" 8-5-74 Intermediate Casin~ - 7370' 9 5/a" 47 ppf N80 Buttress CMT 1000 sks CTOC @ 4056' Gauge Hole Marathon Oil Company North Trading Bay Unit Spark Platform Well S-2RD "FINAL P&A CONFIGURATION" COIL TUBING @ 9227' 2 3/s" 3.215 ppf, precision HS-70 cm 60000# yield EOT 9227' ACTIVE PERFORATIONS: (MD~ BF1; 9580' - 9590' 4 SPF (11/22/97) BF2; 9623' - 9633' 4 SPF (11/22/97) 9650' - 9665' 4 SPF (11/22/97) G-ZON E: UG1; 9772' - 9787' 4 SPF (11/22/97) UG2; 9852' - 9867' 4 SPF (11/22/97) 135' OF 2 3/s" COIL TUBING SC2-PAH PACKER & TAIL PIPE @ 10345' MD BRIDGE PLUG @ 10387' MD BAKER FB-1 PACKER @ 10426' BELL GUIDE @ 10439' DIL (4.00" ID) BAKER HALF-CUT MULE SHOE @ 10501', 2.406" ID CEMENT @ 10497' CMT FILL @ 10719' CMT TOC (7.21 GAL) @ 10822' DIL 1.22 GAL SAND COVERING THRU-TUBING B.P. @ 10832' DIL Production Liner @ 11341' 7" 29 ppf N-80 BTC Liner 6.184" ID .0371 bbl/ft CMT 1175 sks CTOC @ 693' Gauge Hole Calculations MARATHON SPARK S-2RD FINAL P&A CONFIGURATION ~ All Depths measured RKB to top of equipmer All depths are RKB unless otherwise noted I 8/4/2009 I AOGCC Witnessed TOC TAG @~47' BML 8/1/2009 ~353' SURFACE CEMENT PLUG 95/a"and95/e"X133/s"=--41bblSlurry : Mixed and Pumped 41 bbis 15.9 ppg "G" BOC @ ~575' RKB TOC @ ~222' RKB 7/28/2009 Pertorated 95/a' @ ~575' RKB Set 9 5/a' CIBP @~575' RKB Pulled 2 3/8 Out of Hole and Laid Down Cut 2 3/e" @ ~600' Tagged Intermediate Plug @ ~6481' RKB 7/23/2009 ~786' Intermediate Cement Plug BOC C~ ~7267' RKB ~100' Below LL M&P ~25 bbls 15.9 ppg "G" CMT Displaced TOC to -6481' RKB 7/16/2009 Pertorated 23/a' Q~7267' RKB ~100 BLL 1000 psi Test 9 5/a° Casing Tagged TOC Squeeze Plug C~ ~7440' RKB 7/14/2009 ~2447' Bottom Hole Cement Squeeze Plug M&P ~26 bbls 15.9 ppg "G" CMT TOC C~ ~7440' RKB BOC -9867' RKB ~~~~ ~~ ~~~°'~"~~ 13' OF CEMENT @ 9,901' MD ~*~a~`~~ ~ ~~;~ ~ , ~~ ~~~p ~~ ~~a ~°_~ Posi-Set BRIDGE PLUG @ 9,914' MD Completion Fluid 3% KCL ~~~~~~~ ~y ~~~„u Fill C~ 9825' Pollard WLM 5/07/09 PLUGGED PERFS: TMD 11352' PAGE 1 G-2 THRU H-1 @ 10560' - 10822' PLUGGED PERFS: H-2 THRU H-4 @ 10840' -11145' TOP OF FILL @ 11201' DIL PBTD @ 11300' (CEMENT ABOVE FLOAT COLLAR) 8/10/2009 Marathon Well Status Matrix WELL # Gauge Ring Depth RKB Injection 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 COMMENTS 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 Perf at 575 RKB S-1 300' FiNISHED Tag @ 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 GR to 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 C~ 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 N 8 2009 GR to 1017' RKB Pre- 575' RKB 7/20/09 Existin Perf at 575 RKB S- 3 Pre-existing Pre-existing N/A 300' FINISHED 575' to 275' RKB 7/20/2009 7/20/2009 7/20/2009 Tag TOC - 57' BML 1000 si 1000 si 400 si 8 1 2009 Tag CIBP @ 9351' 9/2/2009 9/4/2009 9/4/2009 7/24/2009 575' RKB 9/9/09 Dmp Bail - 25'-CIBP 2282' RKB 1932' RKB/ 25 bbl 600' RKB Perf at 575 RKB S- 4 9/3/2009 300' FINISHED Sqeeze - 33 bbis 575' to 275' RKB 2.5 BPM 9/4/2009 9/4/2009 9/31/2009 9/5/2009 545' Ta TOC - 57' BML 2500 si 1000 si a-4205' 1000 si 350 si 100~ si N 9 12 2009 GR to 10776' RKB 9/13/2009 S-5 Tag Q 10440' RKB 200 bbls/2200 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'- 9/11/0 Ta @ 9912' RKB 7900' RKB 7600' RKB/24 bbls 1010' RKB Perf at 1005' RKB Tested to 1000 psi - 9/12/09 S_~ 7/24/2009 Tag - 7533' RKB TOC C~ 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 Q 575-275' 9/12/09 45 bbi 0 si cs - Failed cs - Failed 500 si tb -1000 cs -failed 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 C~ 9885' RKB 2185' RKB 1835' RKB/24 bbl 600' RKB Perf at 574' RKB S_8 350' Bal Ptu Tag TOC @ 1797' 300' FINISHED Ta Q 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' Ta TOC- 51' BML at 3000 si 1500 si 1500 i 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 si 1000 PSI N 9 2 2009 9/15/2009 M ~ Report Date: 8/4/2009 Well # S- 2RD PROSERV OFFSHORE DAILY ACTIVITY REPORT & COSTS Proj Team Leader: Jeff Thompson Field Sup.: PIC Site: Todd Paxton PLATFORM: Spark PROIECT NUMBER: 29052-21 WELL NUMBER: S- 2RD PROJECT: Marathon Oil Co. - P&A Day 44 B ~ ~ Praseru ost & Activity Date: $/4/2009 T1ME 10:00 R/U slickline and RIH with 1.5 G.R. to 162' WLM (47' BML) and tag TOC. POOH. 11:00 Move over to well # S- 3 CREW NAME HOURS CFtE`Vlf NAME H{?IJR.S Jeff Thompson 1 Randy Lafleur 1 Gene Hess 1 Mathew Boudreaux 1 Cyprian Ukudi 1 Page 1 of 2 ~ C~ Report Date: 8/1/2009 Well # S- 2RD PROSERV OFFSHORE DAILY ACTIVITY REPORT & COSTS Proj Team Leader: Jeff Thompson Field Sup.: PIC Site: Todd Pa~on PLATFORM: Spark PROJECT NUMBER: 29052-21 WELL NUMBER: S- 2RD PROJECT: Marathon Oil Co. - P&A Day 41 A ~~ ~ ~ Proseru ost & Activity Date: 8/1/2009 TIME 6:00 Travel to Spark platform. 6:30 Neld safety meeting and JSA on mixing & pumping cement and crane operations. 7:00 Circulate dye around in well and establish full capacity of displacement. $:45 M/P 41 bbls,124 sks of 15.9 ppg, 1.132 yield, class "G" Neat cement for a 300' cmt balance plug in both the 9-5/8" and the 13-3/8"x 9-5/8" casings, from t 575' RKB to t 275' RKB. 11:00 clean all equipment and work deck. 12:00 Move over to well S- 3 ` CREW NAME HtHlIt~S CREW NAME HOUF~.S' Jeff Thompson 6 Randy Lafleur 6 Gene Hess 6 Mathew Boudreaux 6 Cyprian Ukudi 6 Page 1 of 2 ~ L~ Report Date: 7/28/2009 Well # S- 2RD Day 37 B PROSERV OFFSHORE ~ DAILY ACTIVITY REPORT & COSTS ~ Proseru Proj Team Leader: Jeff Thompson Field Sup.: PIC Site: Todd Pa~on PLATFORM: Spark Cost & Activity Date: 7/2$/2009 PROJECT NUMBER: 29052-21 WELL NUMBER: S- 2RD PROJECT: Marathon Oil Co. - P&A TIME DESCRtPT10N OF AC1'1'VtTIES 12:00 R/U e- line and RIH with 7.710" gauge ring to 600' and tag tubing. POOH 13:00 M/U CIBP for 9-5/8" csg and RIN to 575' RKB and set. POOH 13:45 N/U tree on well while M/U pert guns. 14:45 RIN with 2 ft@ 4 spf perforating guns for 9-5/8" csg to tag tubing. PerForate casing and POOH. 15:30 R/D e- line and begin to circulate at 600 psi down the 9-5/8" and returning up the 13-3/$" casing. Returns were pure oil for 15 bbls and beginning to clear up. 16:30 Shut down and secure wells and equipment because of heavy fog rolling in. 17:00 Fly back to XTO platform. Work Scope for 7-29-09 S- 4 Re-perforate injection zone. S-1RD Set intermediate cement balance plug depending on disposability of returned well fluid. ; CREW AIAME HOURS CREW `t~AA~ ' `Ht~JRS'; 1eff Thompson 6 Randy Lafleur 6 Gene Hess 6 Mathew Boudreaux 6 Cyprian Ukudi 6 Page 1 of 2 ~ ~ Report Date: 7/27/2009 Well # S- 2RD Day 36 B PROSERV OFFSHORE ~ DAILY ACTIVITY REPORT & COSTS ~ Proseru Proj Team Leader: Jeff Thompson Field Sup.: PIC Site: Todd Pa~on PLATFORM: Spark Cost & Activity Date: 7/27/2009 PROJECT NUMBER: 29052-21 WELL NUMBER: S- 2RD PROJECT: Marathon Oil Co. - P&A TIME ~ESGRIP'SiCMI OF AC'fiY1'~'IES 12:00 N/D and remove tree. 14:00 R/U spear for 2-3/8" tbg hanger and 1 joint of 3-1/2" work pipe and all handling tools. 15:00 Pull up to 15,000 Ibs on tbg with crane and nothing moved. Worked several times and pulled free at 30,000 Ibs 16:00 POOH with coiled tbg and lay down same. 18:45 Secure wells and equipment. 19:00 Shut down for the day. Work Scope for 7-28-09 S-1RD Set intermediate cement balance plug depending on disposability of returned well fluid. S- 2RD Set CIBP and perforate for top cement job. CREW NEUTAE HOURS CREW , NAME MQt)I~` Jeff Thompson 7 Randy Lafleur 7 Gene Hess 7 Mathew Boudreaux 7 Cyprian Ukudi 7 Page 1 of 2 r ~ Report Date: 7/24/2009 Well # S- 2RD 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-2RD PROJECT: Marathon Oil Co. - P8cA Day 33 B .~~ ~ ~ Proseru ost & Activity Date: 7/24/2009 TtME DESCRiPTION dF AGTIVITtES 13:00 Test intermediate plug in tbg and 9-5/8" csg and chart 15 minutes. Good test 13:30 R/U e- line with 2-3/8" tbe cutter and RIH to 6481' RKB and tag TOC. Pull up to 600' RKB and cut tbg. POOH 15:00 N/D tree while offloading cement, tools and supplies from workboat. 16:00 Move to well # 7RD Work Scope for 7-25-09 S- 2RD POOH with tubing. S- 7RD Spot 300' cmt plug from 8962' RKB to 8662' RKB in the 9-5/$" csg GRE1A1 `NAME MOURS GRE1M- NAJ+AE `Ht3tlRS, Jeff Thompson 3 Randy Lafleur 3 Gene Hess 3 Mathew Boudreaux 3 G~rprian Ukudi 3 Page 1 of 2 r ~ Report Date: 7/23/2009 Well # S- 2RD Day 32 PROSERV OFFSHORE DAILY ACTIVITY REPORT & COSTS P~oSeru Proj Team Leader: Jeff Thompson Field Sup.: PIC Site: Todd Paxton PLATFORM: Spark Cost & Activity Date: 7/23/2009 PROIECT NUMBER: 29052-21 WELL NUMBER: S-2RD PROJECT: Marathon Oil Co. - P&A TIME DESCftIPI`IQN OF AGt'11tIT1ES `. 6:00 Travel to Spark platForm. 6:30 Held safety meeting and JSA on running e- line and M/P cement. 7:00 Re-arrange work deck. 8:00 Prepare for cmt job and mix 34 bbls of 3% KCL. 9:30 MJP 25 bbls, 124 sks of 1.132 yield, 15.9 ppg, class "G" Neat cement down tbg, taking returns out of 9-5/8" csg, displacing cmt to 6867" RKB, leaving 400' cmt balance plug from 7267' RKB to 6867' RKB in both the 2-3/8" tbg and the 9-5/8" x 2-3/8" annulus. WOC 11:00 Clean cement equipment and pmp disposat fluid down S- 4. 13:00 Move over to wetl # S-1RD CREW NAME HOURS CREW' NAME HOUi2S: 1eff Thompson 7 Randy Lafleur 7 Gene Hess 7 Mathew Boudreaux 7 Cyprian Ukudi 7 Page 1 of 2 r ~ Report Date: 7/20/2009 Well # S- 2RD Day 29 C PROSERV OFFSHORE ~ DAILY ACTIVITY REPORT & COSTS ~ Proseru Proj Team Leader: Jeff Thompson Field Sup.: PIC Site: Todd Paxton PLATFORM: Spark Cost & Activity Date: 7/20/2009 PROJECT NUMBER: 29052-21 WELL NUMBER: S- 2RD PROJECT: Marathon Oil Co. - P&A TIME `DESCRIP7'ION OF ACTIVITIES 15:00 R/U pmp hoses on tbg and 9-5/8" csg. 15:45 Circulate down tbg 55 bbfs and got back clean returns. 17:30 Shut down. Secure wells and equipment. 18:00 Shut down for the day. Work Scope for 7-21-09 S-1RD Tag TOC and perforate for intermediate cmt balance plug. Circulate in preparation for cmt job. S- 3 Tag top of CIBP, pull up & perforate csg. Test for circulation in preparation for top cmt job. Boat Offload cement and tools for job. S- 2RD Install intermediate cmt balance plug. CR EW NAMf HQtJRS ' CREW ` T~f1ME NtHlRS; Jeff Thompson 3 Randy Lafleur 3 Gene Hess 3 Mathew Boudreaux 3 Cyprian Ukudi 3 Pa~e 1 of 2 ~~ r~ Report Date: 7/16/2009 Well # S- 2RD Day 25 B PROSERV OFFSHORE DAILY ACTIVITY REPORT & COSTS Proseru Proj Team Leader: Jeff Thompson Field Sup.: PIC Site: Todd Paxton PLATFORM: Spark Cost & Activity Date: 7/16/2009 PROJECT NUMBER: 29052-21 WELL NUMBER: S- 2RD PROJECT: Marathon Oil Co. - P&A TfME DESCRiPT10N QF ACTiVIT1ES 13:00 Open tree with 750 psi on well and 200 psi on 9-5/8" csg. Bleed to 0 psi and tested tbg to 1000 psi while bubble testing 9-5/8" csg. Charted test for 15 minutes. Good test. 14:15 R/U E- line with 2 ft of 1-11/16" perf shot gun @4 SPF and test lubricator to 1500 psi. 15:30 RIM with perf gun and tag cmt at 7440' RKB (7380' WLM). Pull up the hole to 7267' RKB (7207' WLM) and fire pertorating gun with 1000 psi on tbg. Pressure fell to 0 psi. 16:45 POOH with E- line. 18:00 Shut down for the day. Work Scope for 7-17-09 S-1 RD Retrieve hold open tool from SCSSV & go set CIBP on top of cmt. Dump bail 25-50 ft of cmt on top of CIBP. WOC S-2 RD Attempt to circulate in preparation for cmt balance plug. CREW NAME MpUF~a GRE1N ; NAME Ht~.lRS Jeff Thompson 5 Randy Lafleur 5 Gene Hess 5 Mathew Boudreaux 5 Gyprian Ukudi 5 Page 1 of 2 r ~ Report Date: 7/14/2009 Well # S- 2RD Day 23 A PROSERV OFFSHORE DAILY ACTIVITY REPORT & COSTS ~ ~ Proseru Proj Team Leader: Jeff Thompson Field Sup.: PIC Site: Todd Paxton PLATFORM: Spark Cost & Activity Date: 7/14/2009 PROJECT NUMBER: 29052-21 WELL NUMBER: S - 2RD PROJECT: Marathon Oil Co. - P&A TlME pES~fttPTl4(d QFACTNiT1ES 6:00 Travel to Spark platform. 6:30 Held safety meeting and JSA on mixing and pumping cement and testing csg. 7:00 Check that SCSSV is open. Open 13-3/8" casing showing 400 psi & bled off gas thru gas buster to 0 psi. Fill csg with 73 bbls of water. (1,181 ft.) 8:30 Test 13-3/8; csg to 250 psi and charted same for 15 min. Good test. 9:00 Open tbg showing 2100 psi. R/U e- line & RIH to SCSSV and verify measurement of RKB. Correct 10:30 Pump 70 bbls of water @ 2.5 bpm @ 2800 psi and shut down, showing ISIP of 1500 psi. 11:00 Rig up cmt mixing equipment and cmt from upper deck. 11:45 Mix and pump 26 bbls, 128.9 sks, of 1.132 yd, 15.9 ppg class G neat cement, followed by 39 bbl of fresh water. Pump pressure had climbed to 3600 psi and after shutting down, pressure remained at 3000 psi. Shut well in with 3000 psi on it. WOC 13:30 Clean up all cement equipment. Dispose of 5 bbls of clean up water down S- 4RD, followed with 110 bbls of water. 15:00 R/D off of S-2RD and Move over to S-1RD. CREW ' NAME HflURS CREW NAME l~RS Jeff Thompson 9 Randy Lafleur 9 Gene Hess 9 Mathew Boudreaux 9 Cyprian Ukudi 9 Page 1 of 2 ~ r~ Report Date: 7/10/2009 Well # S 2RD Day 19 ~~. PROSERV OFFSHORE DAILY ACTIVITY REPORT & COSTS ~ ~1 Proseru Proj Team Leader: Jeff Thompson Field Sup.: PIC Site: Todd Pa~on PLATFORM: Spark Cast & Activity Date: 7/10/2009 PROJECT NUMBER: 29052-21 WELL NUMBER: N/A PROJECT: Marathon Oil Co. - P&A TIME DESGftIFT10N,C?F ACTIV~TiES 6:00 Travel to Spark platForm. 6:30 Held safety meeting and JSA on rigging up slickline and testing csg. 7:00 R/U slickline while function testing all cement equipment. 9:30 Test lubricator to 3000 psi and open well. Well had 2000 psi on it. RIH to 571' and tagged ice. 10:30 Pumped 3 gallons of ethanol and let sit 10 minutes then pumped 5 bbls water, 11:00 RIH, seeing water level at 130', to 9227' with 1.70" gauge ring. 12:45 POOH and R/D slickline. 13:00 R/U pump lines to 9-5/8" csg. Csg valve leaked. Pumped valve grease into valve and valve held. 14:00 Finished rigging up on csg valve. 14:30 Opened csg valve to 500 psi on csg. Bleed csg down to 0 psi thru gas buster. 15:00 Pumped 47 bbls and pressured up csg to 1000 psi and charted same for 15 minutes. Good test. 16:00 R/D pump line from 9-5/8" csg and R/U on 13-3/8" csg. 17:00 Shut down in order to fly back to XTO platform because of heavy fog rolling in fast. GREW NAMf WOURS ; CREW NAM~ ; ttClUF~ Jeff Thompson 12 Randy Lafleur 12 Gene Hess 12 Mathew Boudreaux 12 Cyprian Ukudi 12 Page 1 of 2 ~ r~ Report Date: 7/9/2009 Well # S-2RD Day 1$ B PROSERV OFFSHORE DAILY ACTIVITY REPORT & COSTS ~ ~I Praseru Proj Team Leader: Jeff Thompson Field Sup.: PIC Site: Todd Pa~on PLATFORM: Spark Cost & Activity Date: 7/9/2009 PROJECT NUMBER: 29052-21 WELL NUMBER: N/A PROJECT: Marathon Oil Co. - P&A ` TIME' DESCRfRTION OFAGTlVITIES 14:00 R/U pump in sub and pump and flowback lines onto production tbg. 15:30 Open wetl to show 500 psi. Bleed gas down to 0 psi. 16:00 Pump 5 bbls freshwater down tbg when pressure came up to 2800 psi on pump. Continued pumping at 1.5 bpm with pressure slowly dropping. After pumping tbe capacity of 42 bbls, pump pressure leveled out and quit falling at 500 psi. 18:00 Shut down for the day. CREW NRME ' WUURS CREW `NAME H4tiF~.S Jeff Thompson 4 Randy Lafleur 4 Gene Hess 4 Mathew Boudreaux 4 Gyprian Ukudi 4 Page 1 of 2 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~~~ ~~~(~~ 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-02RD ~ Spark Platform PTD #174-024; Sundry #309-139 ~ 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-02RD in the North Trading Bay Unit. A 1.5-inch gauge ring was run into the well on W.L. to a depth of 162' 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 222' R.K.B. (elevation 60') or 162 W.L.M. (T.H.F.). Attachments: None Non-Confidential ~~~~~ Y d'~3 ~st ~ ' i~~ - ~ ~ ~ 1.' ~. ~„~ G~~ r i-' - ` ~ Wellbore Plug TBU Spark S-2 08-04-09 LG.doc 1 of 1 - � Marathon as oN ® Alaska Production LLC vick f- 62� Alaska Asset Team P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/565-3076 August 3, 2009 n,n kP(' � 1 Cathy Foerster State of Alaska Alaska Oil and Gas Conservation Commission 333 W. 7"' Avenue, Suite 100 SET Anchorage, AK 99501-3539 Rc: 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 Ibele 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 wu i IjLNh-'IAL Timing lWell I Permit No. IPad 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 WF1-21rd 193-183 West Fork WF2-21 192-010 West Fork ~ ~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~3~~, `~~ d~~~~ DATE: July 16, 2009 P. I. Supervisor </ ~:,~~~'~~ ~i~,l ~- ~'~ ~~~`~ FROM: Bob Noble SUBJECT: Abandonment Plug Test Petroleum Inspector NTBU S-02RD Marathon Oil Company PTD 174-024 Julv 16, 2009: I traveled to Marathon's Spark Platform to witness a pressure test and a tag on the bottom plug on NTBU S-02RD. Upon arrival I met with Marathon's rep. Dan Byrd. Julv 15, 2009 Marathon had pumped and displaced 26 BBLs of class G 15.9 ppg cement Julv 16, 2009 I witnessed Marathon perform a 1300 psi pressure test on the tubing for 15 min. There was 0 psi pressure loss. An eline tag was performed and TOC was found to be at 7435' RKB. The procedure called for the TOC to be located at 9100' RKB. Summarv: I witnessed successful tag and pressure test of bottom abandonment cement plug in NTBU S-02RD. Attachments: none 2009-0716 P&A_bottom~lug_NTBU S-02RD bn.doc • • ~~~ ~~ ~ ~ ~~ 6 ~ ~ ~ ~ ~~~ ~ ~~ s ~ ~~ ~~ ~~~ ~~ ~~ ~!k ~~ '~ ~ ~ ~`~~~ ~~~ ~~~ ~ ~~ ~p ~T ~ ~ ~~ ` ~~ ~ ~ ~ ~ ~ ~ SARAH PAL/N, GOVERNOR ~~ ~ ~. ~ ~ t~i~t~~7~A Da~y ~D ~-7 ~ 333 W. 7th AVENUE, SUITE 100 COI~TSERQA7`I011T COAil-~IISSIOI~T ~ ANCHORAGE,ALASKA 99501-3539 y PHONE (907) 279-1433 L FAX (907) 276-7542 'I`iffany Stebbins Regulatory Compliance Rep. Marathon Oil Company P.O. Box 190168 Anchorage, Alaska 99519-6168 ~ ~~ . ~~/ Re: Undefined Gas, G-NE/Hemlock-NE Oil ~ North 'IYacling Bay Unit S-02RD Sundry Number: 309-139 ~~~~ '` ~U~. ~ ~ ZOQ~ 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 Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Conunission grants for good cause shown, a person affected by it may file with the Cominission 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 ne~ working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~ Chair ~'L DATED this ~ day of July, 2009 Encl. 0~ • ~~ti a e~.. t»s ~... i~r i.. w ~~'} ,~~~ STATE OF ALASKA '-' ~~ ~~ 2Q0~ ~I ~54LAS~OIL AND GAS CONSERVATION COMMI• N , i~.w~4 ~:s~ :~ ~;~~ ~;ans. Commission APPLICATION FOR SUNDRY APPROVALS , 20 AAC 25.280 ~r~ct~t,rage 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 Weli Class: 5. Permit to Drill Number: Marathon Oil Company Development ~ Exploratory ~ 174-024-0 ' 3. Address: Stratigraphic ~ Service ~ 6. API Number: P.O. Box 190168, Anchorage, AK 99519-6168 50-733-20172-01-00 • 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: NOI'th TI'ading Bay Ulllt S-02RD . Spacing Exception Required? Yes ^ No ^ Spark platform 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): , ADL018776 ' RKB-MSL 115' • UNDEFINED GAS; 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): 11,352' • iQ,~i~' ~~; ~~ ~~~~c~ 11,300' 10;99~0~ ~~Za~ Il~! /~~~ ~,~ 9,901 / 10,497 / 11,300' 10,345' Casing Length Size MD ND Burst Collapse Structural Conductor Surface 2,055' 133/8" 2,055' 1,926' Intermediate 7,370' 9 5/8" 7,370' 6,827' Production Liner 4,174' 7" 11,341' 10,123' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9,580 - 9,867' 8,722 - 8,960' 2 3/8" HS-70, CM Coiled Tubing 9,22T Packers and SSSV Type: Camco TRDP-4A SCSSV w/ FC's Packers and SSSV MD (ft): 593' Baker HB 9,200' 13. Attachments: Description Summary of Proposal ~ 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 Q 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 D te 907-565-3043 - v ~Q ~ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~~ g~ ~~ ~ Plug Integrity ~ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other: ~ ee.~„~ ~~~ /4.~ e...e„~ a. pP~o ~~~~ ~s ~rer ~~C- zS, ~I Z,(~) ~ ,/~ ~~~^ ~ i Subsequent Form Required: J t3 °- ~~~ G]~ APPROVED BY ~ ~~ Approved by: COMMISSIONER THE COMMISSION Date: 1 Form 10-4b3'R2v~s~d'b~/~b0~ ~'. ~ ~~„ ~ ~/~t ~v `f ~~ ~ 1~~~ ~~ ~t ~~ ~~ 2009 ~,ti Submit i~ t~~~r u • MARATHON OIL COMPANY NORTH TRADING BAY UNIT SPARK PLATFORM WELL S-2RD TEMPORARYABANDONMENT PROCEDURE 03/31/09 WELL DATA API# 50-733-20172-01 Elevation: 115" RKB - MSL Water Depth: 60' Total Depth: 11,341' Surface Casing: 13 3/s" 61 ppf J55 @ 2055' (cement to surtace) 12.451" ID, .1521 bbl/ft Intermediate Casing: 9 5/s" 47 ppf N80 C~ 7370' 8.681" ID, .0732 bbl/ft (12 ~/2" Hole Cemented 2000 sks) Production Liner: 7" 29 ppf N-80, BTC, TOL @ 7167', BOL 11341' 6.184" ID, .0371 bbl/ft (8 ~/2" Hole cement 1175 sks) Tubing: 2 3/a", 3.215 ppf, HS-70, CM Coiled Tubing @ 9227' 2.170" ID, .00431 bbi/ft SCSSV: Camco TRDP-4A @ 593' W/ FC's Nipple: Camco "X" Q 9188' (ID 1.875") Camco "X" C~ 9217' pD 1.875") Packer: Baker "HB" @ 9200' PerForations BF-1: 9580' - 9590' Active: BF-2: 9623' - 9633' 9650' - 9665' UG-1: 9772' - 9787' UG-2: 9852' - 9867' PBTD: 11300' / 9901' Current S~wH~'°= a90o p~~, CURRENTSTATUS ~~'~ G-~~~a j The well has no further utility and is to be temporarily abandoned following the procedure be{ow. NOTE: The well History indicates a substance similar to paraffin may be found in the wellbore Tubulars. This substance was successfully treated with a"XYLENE" based solvent in the past. ABANDONMENT PROCEDURE 1. Mobilize tree technician to location to ensure 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 tubing and casings for pressure. Bleed off through gas buster. Fill and test casings with weighted fluid and record results. 35°° 4. PerForm JSA for proper wireline operations. Rig up slick line lubricator and test to~96-~si. Pressure up SCSSV control line and lock SCSSV open. RIH with gauge ring to the end of tubing at 9227' pull wire line plugs as needed. POOH RD wireline. 3Sao ~s~ G;4 5. Perform JSA on pressure pumping. Rig up pump and Jines on tubing. Test lines to .2~'6 psi. Establish an injection rate. Monitor 9 5/a" casing for possible communication. Record rate and pressure. 6. Perform JSA on mixing cement. Mix and pump 26 bbls of cement and squeeze perForations. Squeeze to 1000 psi over injection pressure or until cement is displaced to a depth of 9227' RKB. 7. WOC and test to 1000 psi. Record results on a continuous pressure chart recorder. 8. Pertorm JSA for safe electric line operation and explosive handling. Rig up electric line lubricator and test to 1500 psi. RIH with pertorating guns loaded with 2 ft of 4 SPF tubing punch run in hole and tag TOC for bottom hole plug @ 9227' RKB and record results. Pick up to 7267' RKB and shoot tubing. POOH. Spark Well S-2RD Page 1 ~ ~ 4/17/2009 ~ • 9. Perform JSA for cement mixing and pressure pumping. Rig up cement pump and lines. Test lines to 1500 psi. Break circulation down 2 3/a" tubing taking returns up the 9 5/g" casing annulus. Mix and pump 19 bbl cement slurry for a 300' intermediate cement plug from 7267' RKB - 6967' RKB in the tubing and the 9 5/s" casing annulus, leaving 200' cement above and 100' cement below the 7" X 9 5/s" °Liner Lap". Displace with weighted fluid. 10. WOC and test to 1000 psi and document results using a continuous pressure chart recorder. 11. PerForm JSA on electric line operation and explosive handling. Rig up electric line lubricator and test to 1000 psi. RIH with 2 3/s" jet cutter and tag TOC for intermediate weil bore plug @ 6967' RKB and record results. Pick up to 600' RKB and cut 2 3/s" tubing. POOH. ~2. Rig down tree. 13. PerForm JSA on proper pipe handing procedures. Pull tubing and check for N.O.R.M. 14. Perform JSA for safe electric line operation and explosive handling. RIH with 9 5/a" gauge ring and tag top of tubing stub at - 600' RKB. POOH. 15. RIH with 9 5/s° CIBP tag top of tubing stub @ 600' RKB, pick up to 575' RKB and set CIBP. POOH. 16. RIH.with perforating gun armed with 2 ft of 4 SPF casing punch, tag CIBP @ 575' RKB and fire guns. POOH. RD electric line. 17. Perform JSA on cement mixing and pressure pumping. RU pump and lines. Test 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/s" x 13 3/s" casing annulus from 575' - 275' RKB. B)If unable to circulate the 9 5/a" 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' - 275' RKB in the 9 5/s" casing only. 18. Pick up work-string 20' above TOC and circulate clean. POOH. 19. WOC. Perform JSA for wire line operations. Run in hole with blind box and tag top of surface cement plug @ 275' RKB and record results. POOH. 20. RD. Well is temporarily abandoned. Spark Well S-2RD ~ Page 2 4/17/2009 , . Marathon Oil Company • ~ North Trading Bay Unit ~a~TM~~ Spark Platform Well S-2RD "CURRENT" WATER DEPTH @ 62' ( AT MLLW) KB ABOVE MSL @ 115' API # 50-733-20172-01 FMC TC-IA-ENS-SPCL TUBING HANGER @ 35' Surtace Casing - @ 2055' 13 3/8" 61 ppf J55 BUTTRESS 17 1/2" HOLE CTOC = "SURFACE" 2000 SKS All Depths measured RKB to top of equipment All depths are RKB unless otherwise noted Camco TRDP-4A @ 593' w/ FC's Top of Liner @ 7167' Intermediate Casing - 7370' 9 5/8" 47 ppf N80 BUTTRESS 12 1/2" HOLE CMT w/1000 SKS COIL TUBING @ 9227' 2 3/8", 3.215 ppf, percision hs-70 cm 60000# yield (ID=2.107') 13' OF CEMENT @ 9,901' MD ABOVE A SCHLUMBERGER THROUGH-TUBING POSI-SET BRIDGE PLUG @ 9,914' MD BRIDGE PLUG @ 10,387' MD BAKER FB-1 PACKER @ 10,426' BELL GUIDE @ 10,439' (4.00" ID) PLUGGED PERFS: G-2 THRU H-1 @ 10560' - 10822' CEMENT @ 10,497' CTMKG FILL @ 10,719' CTMKG TOC (7.21 GAL) @ 10,822' DIL 1.22 GAL SAND COVERING THRU-TUBING B.P. @ 10,832' DIL PLUGGED PERFS: H-2 THRU H-4 @ 10840' -11145' Production Liner C~ 11341' 7" 29# N-80 BTC Liner (8 1/2" HOLE CMT w/ 1175 SKS) TOP OF FILL @ 11,201' DIL ANGLE @ KOP AND M DEPTH: 23.5 DEG @ 7375' CAMCO X NIPPLE @ 9,188' (ID=1.875") BAKER HB BACKER SET @ 9,200' MD CAMCO X NIPPLE @ 9,217' (ID=1.875") Wireline Entry Guide @ 9,227' ACTIVE PERFORATIONS: (MD~ BF 19580' - 9590' 4 SPF (11/22/97) BF 2 9623' - 9633' 4 SPF (11/22/97) 9650' - 9665' 4 SPF (11/22/97) -ZONE: UG19772' - 9787' 4 SPF (11/22/97) UG2 9852' - 9867' 4 SPF (11/22/97) 135' OF 2 3/8" COIL TUBING SC2-PAH PACKER & TAIL PIPE @ 10,345' MD 2-7/8" N-80 TUBING CUT @ 10,406' MD BAKER "80-40" LOCATOR (3.00" ID) @ 10,430' BAKER "4.00 X 3.00" SEAL ASSY. @ 10,431' (10' LONG) BAKER HALF-CUT MULE SHOE @ 10,501' (2.406" ID) PERFORATIONS (DIL~ 10560' - 10618' G-2 10640' - 10668' G-3 10694' - 10714' G-4 10730' - 10762' G-5 10790' - 10822' H-1 DEVIATION = 36 DEG. 10840' - 10910' H-2 10933' - 10965' H-2 10995' - 11058' H-3 10078' - 11098' H-3 11125' - 11145' H-4 PBTD @ 11,300' (CEMENT ABOVE FLOAT COLLAR) TD 11,352' . ~ ~athon Oil Company ~ North Trading Bay Unit ~t~a~~rtFOn Spark Platform Well S-2RD "PROPOSED" WATER DEPTH @ 62' ( AT MLLW) KB ABOVE MSL @ 115' ANGLE @ KOP 23.5 deg @ 7375' API # 50-733-20172-01 Surtace Casing - @ 2055' 13 3/s" 61 ppf J55 BUTTRESS 17 1h" HOLE CTOC = "SURFACE" 2000 SKS All Depths measured RKB to top of equipment All depths are RKB unless otherwise noted 300' SURFACE CEMENT PLUG 95/a"and95/a°X133/s"=41bblSlurry 9 5/a" only = 22 bbl Slurry 575' RKB - 275' RKB Pertorate 9 5/a" Casing @ 575' RKB CIBP @ 575' RKB TOL @ 7167' Intermediate Casing - 7370' 9 5/a" 47 ppf N80 BUTTRESS 12 1/2" HOLE CMT w/1000 SKS COIL TUBING @ 9227' 2 3/s", 3.215 ppf, percision hs-70 cm 2.107" ID .004312 bbl/ft 60000# yield EOT 922 ACTIVE PERFORATIONS: (MD~ BF 19580' - 9590' 4 SPF (11/22/9 ~ BF 2 9623' - 9633' 4 SPF (11/22/9 ~ 9650' - 9665' 4 SPF (11/22/9 G-ZON E: UG19772' - 9787' 4 SPF (11/22/9 i UG2 9852' - 9867' 4 SPF (11/22/9 i 135' OF 2 3/8" COIL TUBING SC2-PAI PACKER & TAIL PIPE @ 10,345' MD BRIDGE PLUG @ 10,387' MD BAKER FB-1 PACKER @ 10,426' BELL GUIDE @ 10,439' DIL (4.00" ID) CEMENT @ 10,497' CTMKG FILL @ 10,719' CTMKG TOC (7.21 GAL) @ 10,822' DIL 1.22 GAL SAND COVERING THRU-TUBING B.P. @ 10,832' DIL Production Liner @ 11341' 7" 29# N-80 BTC Liner 6.184" ID, .0371 bbl/ft .2085 ft3/ft (8 1/2" HOLE CMT w/ 1175 SKS) TOP OF FILL @ 11,201' DIL INTERMEDIATE CEMENT PLUG 7267' RKB - 6967' RKB 100' Below and 200' Above Liner Lap 100' x.0262 bbl/ft = 2.62 bbls 200' x.0622 bbl/ft = 12.44 bbls Total Cement Slurry = 15.06 bbls BOTTOM HOLE CEMENT PLUG 9867' RKB - 9227' RKB 640' X.0371 bbl/ft = 23.744 bbls Total Cement Slurry = 23.744 bbls JGGED PERFS: ' THRU H-1 @ 10560' - 10822' JGGED PERFS: THRU H-4 @ 10840' - 11145' ~ @ 11,300' ~ENT ABOVE FLOAT COLLAR) TD 11,352' • ~ Spark Platform Abandonment Review North Trading Bay Unit Marathon Oil Company Well NTBU S-O1RD (PTD174-005) - Sundry Application 309-138 '~~Vell NTBU S-02RD (PTD174-024) - Sundry Application 309-139 Well 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 AppGcation 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 we11s 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. Tn 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 also 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 Ju1y 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" wells 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 SO 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. • • ~ ~ a • ~ - - ~~ ~~s~ ~~ ~ ~ ~ ~,.~ ~a, ... . b O Ci : 0.0783624 A.e. . . . . . . . . . . . qi .. : 286.357 bbVd ~ ti :0131/1982 - . . . . . te :02/282014 Fnel F7ate : 49.9199 6Wd ~ GLm Rod. : 17508.9 ML W lo CLm ~te : O7/31/7992 . . . .. . Fiasen/es :~096.35Nt~bl . . F~serves Oate : 0228./2014 . . . a42 : 789W2 M~UI . ~ ~ Farecast Fntled 9Y : F~te . . . . . . ~B Farecest Cffie : NX Seved ~ . .. F~serva Type : f~bne 10'~ i t . ~ ~ ~~~ . . ~ . ~ i, ~~ : ~ . . . . _ . . , ~.~ ~'i a _ jr ~ . 1 . . . ~ t, y ~o'~ . ~``~'"°^•~. ~"°... ~o'-,Tr~ - -- - ~~96407~ 72T3 7475 76 77 78'7980 81 82 83 8485 8687 88 8990 81 92 9394 95 9897 9894000t 02 03 04 0508 07 08 09~0111213~14 04TE 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. ~ ' D.S. Rob~~~'~-' Sr. Reservoir~ngineer Apri123, 2009 - Revised July 2, 2009 • W. 11~n Production Manaaer Alaska Region ~ Domestic ProducUOn ~ Marathon MAiATMON Oil Company P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 March 23, 1992 Mr. Harold Heinze, Commissioner Department of Natural Resources 400 Willoughby Avenue, 5th Floor Juneau AK 99801-1796 Dear Commissioner: SUSPENSION OF PROOUCTION OR OPERATIONS Enclosed for processing is an appiication for suspension of production or operations and a fiiing fee of ~,50. 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 l, 1992. The leases affected are ADL-17597, ADL-18776, and ADL-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 Unocal 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 ;ZO per barrel not including the cost of investment recoupment through DD&A. Since reserves are defined as economically producible, no oil reserves can be assigned to Spark with an oil price below ~ZO. The Unit does have economic gas reserves which could be developed from Spark. Gas reserves have been proved with a down structure fuel gas well on the Spurr Platform which has recovered 3.5 BCF. Current plans cail for developing remaining gas reserves by recompleting Spark Platform Wells A subsidiary oi USX Corooration ' `. Mr. Haroid Heinz~ ~ ° ' March 23, 1992 Page 2 S-2RD and S-8 uphoie 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 reserves are committed to both Unocal and Marathon con- tracts. Because both companies currently have sufficient deliverability to C~ _meet contract demand, it is not economicaily 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 dispiace '~ • gas sales from other fields which have already been deveioped. In the mid-1990's, Marathon will begin to need additional 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 g1.0 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 S20 per barrel, not including DD&A costs. Therefore, no oil reserves can be attributed to Spurr. Spurr does have one gas well, TS-3RD, completed in gas sands. It is currently shut in because of down hole mechanicai problems. :~ '0k~r 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 `l include the substantial ~onies required to stay in compliance with oil ~ spill and process hazard management regulations recentiy 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 deveioped by Spurr was thought to contain significant undeveloped reserves. Evaluation of 3-D seismic and the performance of Monopod Platform Well A-28RD now indicates no further economic development 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 wiil be evaluated as part of the overall deveiopment scheme. Marathon's Plans Durin4 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 evaiuates supply and demand. Marathon will also monitor oil 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. Naroid Hein~ # ~ March 23, 1992 Page 3 A major undertaking during this suspension period wiil be the evaluation of abandonment options for Spark, Spurr and Granite Point Production Facility. This evaluation wiil attempt to optimize method and timing of abandonment. As no piatform has been abandoned in the Cook Iniet 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 possible resumption at Spurr. A revised plan of development reflecting 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, ~4 ^'~, , ~. `' ~ `~.. ~ \ ~ W. WdtS011 cc: Mr. James Eason Department of Naturai Resources Division of Oil and Gas P. 0. Box 107034 Anchorage AK 99510-7034 A:LAND2/MH07/BGP • NORTH TRAOING BAY UNIT BOUNDARY QR~aR TO AUGUST 2. 19T6 + EtiHIBIT 1 ATTACHED ANO MADE A PART OF UNIT AGRE~~IENT FOR THE flEVELOPMENT AND OPEflATiON OF THE NORTH TRADING 8AY UNIT AREA + . ~ 27~ 26 '~... T 10 ~i R 13 11ti// T9N R13W btARATHON ~~~\ \ aot~~se~~ ~ ~ ~ ~ ~ NORTH TRADING BAY UNIT BOUNO AND HEMLOCK 3 'G' FORMATIO'. PARTiClPATING AREA BOUNDAR I EF~ECTIVE AUGUST 2, 1976 ~ 34 \35 ~ ARATHp ~ UNION MARATHON ADL•T7597~ \ ADl 18776 \ ` ~ MAPSOURCE DIVISION OF IANOS PiiOTRACTION SHEET, GRID NO. S•1]•5 STATE Oll ANO GAS LEASES AOL•17597, ADL•18776, QOL•J5431 LEGENO O ~~ TRAC7 NO. PARTIC1PATfNG AFiEA NORTH TRADING 3AY UNIT AAEA HE~ILOCK & ~G~ PARTiC1PATiNG aREA ~ ~ COOK INLET, ALASKA PARTiCIPATiNG AREA LATEST CONTRACTION DATE: AUGUST 2, ~ g76 ' ~WNERSHIP AS OF:SEPT. 1, 1988 RAA~A~'~~~ ~iL C~4iiPA~Y i a. . • • ~ 17597 ~ - - ~ae :.aee ~.aee ~.eee .aee :.zae _.zae ~' SdARA?HON OIL C;,1~pNy ' , ''ae~ ~.eae ~oKrtt rx,-nuvc a~Y ~-~Tr " ~XHIBlT _ I .~DL ~s.ss~ ' ` ?OYALTY P,EDUC'",OY i ' m ~' 9 ~ m I ~ r A i m ~ ; ~, ~i --_C '~ c ~, ~~f8~ . ```, ~~ ~~~ ~; ` ~~ ~; ~ 91 9~ 9 L al 91 91 ,~ , ;' / '~~ ~',• °9~3 ti i .u ~ ~ ~~ I ~~ ~' ~-`~ ~.~g _ ~~~~~~ i ~~ ,\' ~6B i as2~/ .-. j . ~ '; ~ y ^ \ ~ ~ ~ / ~ r1 \ ' ~' / ~.~ I ,' ,~_~/, ~44li ' ~ • ~ :4aa~ ly~o ~ .,.J'J y ~5~i :2Tll ~ .a _ a ~"~. .~•[~E --c1:,g '• I ~-~Dy'~~•;i"~~~~ _-~~*j ':'z .' , ~~! ' ~ _aa r, ~ ~ ~ _`Rn1 I - ' ~'~ '--'.~" -~_, -S~ , ~ ~ ~~5~ ~ ~~ ~~ : / 1cT85-! ~. 'S~ ~~a~ s ~ : aZ/i~ n , ?':ON-R13W .aea 3.aea ~ ai~3 '. ; ~ P.4RK • ~ ~ , ; - ~ I ~ ~ ) ~5-9 I ~d~~ • . j..'• 1 I / /t~ ~ ' ~r, 6~H ,~ ~~:8~ ~ :~.~ ,i ~ %~f'__ a~~ ! -~, , ~RCO ,~• j ~/ '-1 ; '~~~./~ ~5~~ '~ •, ~ ~aszs ' '~' ~' ~' /~ ~ . t// :28l5 ' ~ ~ ~ :2i50 r ~ ti • i ~ r r~ . ~I ,~~ • :( .` Pr ~~P~`-~~~s ~ ~ , , ; ~-_~ f ^ _ °' ~ .4DL 18776 ..aae a.eae ..aea z:aae .~.eae a.aae m _~ 9 ;m ~m ~^ ~ ;m 0 ~m I ~m i 9 ' 9 ~ m ~ _m ~ :m ~v Im N Is ,m _m ~~ IN r Im ~9 I~ i N la ~m iv I~ I ~ ~ .aas Marathon Oil ~ 1N~Tf: ~S-2RD ~ Field:~SpaPlC ~05-07-2009 ~ Pressure (psia) 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 0 Pressure-Temperature Profile 1. Going in hole to 9825' MD 1000 2 Well Shut-In 2000 3000 - 4000 ~ ~ w `~ 5000 -- - t ~-. G. d ~ 6000 - - 7000 ---- - y i , 8000 9000 - --- - - 10000 30 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 Temperature (Deg. F) - Pressure - Perfs 13 3/8" 9 5/8" 7" ~-°---- TBG Temperature · AlaSka. Team Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/565-3076 RECEIV'ED September 12,2007 SEP 1 3 2007 Alaska Oil & Gas Cons. Commission Anchorage Mr. John K. Norman Chairman Alaska Oil and Gas Conservation Commission 333 W. ih Ave, Suite 100 Anchorage, AK 99501-3539 ðl\' \<\~O Re: North Trading Bay Unit, Well S-02RD Sundry Number: 307-248 SG.ANN~ SEP 1 3 2007 Dear Mr. Norman, Marathon is in receipt of your letter of August 14,2007, denying the request to vent the referenced well on the Spark Platform to atmosphere. It is n..Qt Marathon's intention to appeal this denial at this time; however, we would like to comment on a few items in your notice to deny this activity. As you are likely aware, the NTBU Spark and Spurr platforms were essentially mothballed and shut-in during 1991 and 1992. Since that time, there have been several attempts to establish gas production on the Spark, but these have met with little success. A number of upgrades, additions and improvements have been made to the Spark facilities in the past several years, including production fluid handling facilities, gas dehydration facilities, a PLC upgrade, an upgraded fire and gas system, and a large-scale clean-up effort, to name a few. Other than these efforts which were largely focused on the gas-process related facilities and areas required to support those activities, there have been no plans or efforts to reactivate the oil production-related facilities since deactivation some 15 years ago. In that sense, it would not be unexpected for the condition of some portions of the facility to be labeled as "poor." Nonetheless, Marathon appreciates the Commission's concerns about safety, and agrees wholeheartedly that any operations on the platform need to first and foremost be safe and environmentally- responsible. Your notice stated that "corrosion protection for the platform legs has been out of service for some time." Following failure ofthe anode sleds as diagnosed in the summer of . . 2006, Marathon ordered replacements, which have been installed and are being commissioned. Your notice also reflected that the safety valve system was not fully functional, this was due to a problem with remote communications from onshore on the day of the last test, though the on-site system worked as intended. We are evaluating the implications of poor remote communications prior to making a decision on whether or not to again attempt to re-establish production from the S-2rd well. Finally, your notice made mention of housekeeping standards on the platform. It is acknowledged that some areas of the platform required attention on the date of the Commission inspector's visit. However, that visit occurred in early summer during a work program to address gratings and railings, general maintenance and clean up activities. Many issues referred to have been addressed, while others will be by the end of the current program. I would also point out that some areas shown in the photographs are not normally accessed, and those areas contain equipment isolated from the production system and are therefore not maintained by design. Some are also used to stockpile obsolete parts and debris until it can be ultimately removed from the platform prior to abandonment. Such equipment, parts and debris are out ofharm's way and do not present a hazard or risk to work in the operating areas of the platform. Again, we appreciate the Commission's concern for safety, and wish to reiterate Marathon's commitment for a safe work place as well. Regards, ~,r Ä B Schoffmann Operations Manager Cc: T M Little L C Ibe1e TIC File: S-2rd TIC File: AOGCC Correspondence Kenai Well File: S-2rd . ~V&\VŒ (ID~ &\~&\~æ&\ . AI.ASIiA. OIL AND GAS CONSERVATION COmoSSION SARAH PAUN, GOVERNOR Mr. Kevin Skiba Marathon Oil Company P.O. Box 1949 Kenai, AK 99611-1949 333 W. 7th AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 sCANNED AUG 1 .4 î007 Re: North Trading Bay Unit, Well S-02RD Sundry Number: 307-248 \ 1 L\- J 0 'J.!+ Dear Mr. Skiba: The Commission denies the enclosed Application for Sundry Approval relating to the above-referenced well located on the unmanned Spark Platform within the North Trading Bay Unit, Cook Inlet. The reason for this denial is platform conditions that are inconsistent with good oilfield engineering practice. During recent Commission inspections, the following were observed: Overall platform condition can best be described as poor; Corrosion protection for the platform legs has been out of service for an indeterminate amount of time; and Safety valve system associated with remotely operated Well S-02RD has not passed all aspects of Commission required testing. The Commission is particularly troubled with the poor housekeeping practices on the platform. Piles of debris and junk, trip hazards, and improperly maintained equipment were observed. Attached are several photos representative of what a Commission Inspector witnessed regarding the general condition of the platform during a June 5, 2007 visit to the Spark platform. This denial is without prejudice to your right to resubmit an application in the future if you believe your proposed operation then meets the applicable standards under the Commission's regulations. As provided in AS 31.05.080(a), within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may me with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission eCl ion to Superior Court unless rehearing has been requested. DATED this ¡g.aay of August, 2007 Enclosures . (. ~) Marathon MARATHON Oil Company July 24, 2007 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W ih Ave Anchorage, Alaska 99501 Reference: 10-403 Sundry Notice Field: North Trading Bay Unit Well: Spark 2RD Dear Mr. Maunder: . Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1 1 Fax 907/283-1350 JUL 2 5 2007 Alaska Oil & Gas Cons. Cammission Anchorage Enclosed please find an Application for Sund Approvals form 10-403 for the S-2RD well located on the Spark Platform. Wet pe orations were recently isolated to reduce excessive water from entering the well bo . Marathon is currently attempting to unload this well and establish a continuous gas ow. This unloading, or cleaning up period, / requires the well to be vented to the a osphere until enough gas volume is achieved to flow the well into the Cook Inlet Gas athering pipeline system. The duration of this venting operation is dependent up n reservoir pressures, permeability, water level, and water production. The well has t responded to previous venting attempts, which lasted less than 3 hours. Due to the certainty of how much time will be required to unload water from the S-2RD well bo e, this request is for periodic venting, not to exceed of 36 hours per period, with a ma mum vent volume during each period of 6 MMCF of ,/ methane gas. If you have any ques ons or need further information please call me at (907) 283-1371. Sincerely, 10-403 Sundry Notice Venting Procedure cc: AOGCC Houston Well File Kenai Well File KJS · STATE OF ALASKA .. ALASKA Oil AND GAS CONSERVATION COM~ION APPLICATION FOR SUNDRY APPROVALS 20 MC 25 280 III. .1. na o. (', ro. ~ Operational shutdown 0 Perforate U -.. WÄTVër~~,' Other 0 Plug Perforations 0 Stimulate 0 Time Extens¡9RTsge Vent Gas Perforate New Pool 0 Re-enter Suspended Well 0 4. Current Well Class: 5. Permit to Drill Nyl'ftber: Development 0 Exploratory 0 ..174-024 ' 3. Address: Stratigraphic 0 Service 0 6. API Numb". PO Box 1949, Kenai Alaska, 99611-1949 ¢"-733-20172-01-0(Y' 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: #~ Spacing Exception Required? Yes 0 No 0 S - 02RD 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): / ADL - 18776 ,f 115' KB above MSL ~ North Traø(ng Bay Unit I G-Zone (Tyonek) "" PRESENT WELL CONDITION SUMMARY / Effective Depth MD (ft): Effective Depth TVD (ft): Ylugs (measured): 9,901' 8,987' I 9,901' /10,497' /11,300' T)'D / / I ~05~' J I 1,926' \) , \ 'I ,\}I 7,370'IJ~ \V\ ~1,~ I~ lirlg~ize: ." / 8,722' - 8,960' Gross D 2-3/8:'¡V / r'\. Baker HB packer ~FJaCk ~ S1 Camco TRDP - 4A SCS~ "Ii ( 13. Attachments: Description Summary of Proposal lJ V / 14. V\\ell C a after proposed work: Detailed Operations Program 0 BOP Sketch cr / / EXPIO~ \0 Development 0 15. Estimated Date for ./ 1// 16. Well Statbs after proposed work: Commencing Operations: 8/6/2007 / Oil 0 Gas 0 Plugged 17. Verbal Approval: Date: / WAG 0 GINJ 0 WINJ Com mission Representative: Abandon 0 Alter casing 0 Change approved program 0 2. Operator Name: Suspend 0 Repair well 0 Pull Tubing 0 1. Type of Request: Marathon Oil Company 12. Total Depth MD (ft): Total Depth TVD (ft): 11,500' ./ 10,290' Length MD / Casing Structural Size /"'... Conductor / Surface 2,055' 13-3/8 " Intermediate Production 7,370' 9-5/8" Liner 4,174' 7" Perforation Depth MD (ft): Perforation Depth TVD (ft): 9,580' - 9,867' Gross Packers and SSSV Type: RECEIVED JUL 2 5 2007 Junk (measured): 10,345' Burst Collapse 3,090 psi 1,540 psi 6,827' 6,870 psi 4,750 psi 10,123' 8,160 psi 7,020 psi Tubing Grade: Tubing MD (ft): HS-70, 3.215 ppf, 0.109 WT 9,227' V MD (ft): Packer at 9,200' MD SCSSV at 593' MD Service o o o Abandoned o o WDSPL 18. I hereby certify that the foregoing is true and correct to thfbest of my knowledge. Contact Printed Name Kevin Skiba / Title Production Technician Signature 1/., . _ 'A . 11. ~ ...-<" J / Î Ph.¢'ne Date f) -fl1 FI/IJ 11-, '-J Ie ~I (907) 283-1371 U / COMMISSION USE ONLY Conditions of approval: Notify Commission so t at a representative may witness Plug Integrity 0 BOP Test Mechanical Integrity Test 0 Other: Subsequent Form Required: '--. Approved by: COMMISSIONER Form 10-403 Revised 06/2006 0 R , G \ N A L Kevin Skiba (907) 283-1371 7/24/2007 Sundry Number: 80 7- ~'-J8 Location Clearance 0 RBDMS 8Fl AUG 1 4 10U7 APPROVED BY THE COMMISSION Date: SUbmiti~~¡ j " J . . . ~ MARATHON OIL COMPANY ALASKA REGION Subject: Spark Platform Venting Well To Atmosphere Objective: Vent well bore gas from production string through process piping to atmosphere with hopes of achieving minimum unloading velocities. Propose is to vent-water build up in the production string to re-establish production. Pre-Checks: I. Check wind direction for ignition sources that maybe over head, i.e. Crane, or Aircraft. 2. Make sure that the production system is not in PSD/ESD status and all alarms are clear. 3. Check waste water injection pump and waste water system for leaks and system readiness. Procedure: For venting gas from well bore through the production system. 1. Secure production pipe from pipeline system by closing block valve on the discharge side of contactor (eliminates potential back flow of gas from the pipeline system). 2. Adjust low pressure shut-down set points below estimated draw down pressures. This will eliminate actuated valves from closing when pressures are below normal system pressures. 3. If system doesn't already have one, give the PLC a permissive to allow flow control valve (automated choke) to adjust with given set points by the Production Operator. 4. If the flow control valve isn't already closed, give a 0% output to the control valve. 5. Open up I" block valve on vent bypass piping just below contactor inlet line PSV. 6. Slowly open up 1" gate valve on vent bypass piping just below the contactor inlet line PSV (gate valve is inline with lower I" block valve). 7. Increase % outputs to flow control valve until desired lift rate is established and adjust as needed. 8. Monitor well/water rates from SCADNPLC system. Procedure: For returning the system back to normal once desired water is removed from well bore or system pressure/flow has been established. 1. Slowly close 1" gate valve on the ventlPSV bypass piping. 2. Close 1" block valve on vent/PSV bypass piping. 3. Once well head pressure has equalized with system pressure, open block valve on the discharge side of contactor. 4. Adjust flow control valve as needed until desired rates and pressures are established. 5. Adjust shut down set points within reasonable operating limits of normal system pressure. 6. Make notification through gas marketing Nomination process of flow rates from Platform to pipeline gathering system. 1 . . 'ð \q~1 /þ~ ~~ ~/ ~"~ AOGCC Memorandum Date: August 6, 2007 To: From: Jim Regg, Petroleum Engineer 'Kcf? 'f>/bf07 Subject: Sundry 307-248 N. Trading Bay Unit S-02RD Request for Approval to Vent Gas Marathon has requested approval to vent gas from NTBU S-02RD (PTD 174-024) up to 36 hours with a max volume of 6 MMcf. This well has problems sustaining flow because of water influx; unloading the well may allow continuous gas flow. There are some concerns that need to be addressed by Marathon before the Commission approves the sundry application. AOGCC has visited this well, located on the Spark Platform, several times during the past 2 months to witness safety valve system testing. Spark is an unmanned facility and is remotely operated from the Kenai Gas Field control board. To date Marathon has not successfully demonstrated an operable SVS consistent with a remotely operated facility. Failures of the SSSV actuation have been the predominant failure each time an inspector has been present for test witness - copies of inspection reports are attached. Several other deficiencies were noted during AOGCC inspections: 1) Corrosion protection (anode system) for the platform legs has been out of service for an indeterminate amount of time; 2) The platform is in poor condition - rust and corrosion evident all over the facility; 3) Fire fighting capability on the platform is virtually nonexistent - Inspector observed five 20 lb extinguishers and no fire water capability in service; 4) Platform shutdown capability has been upgraded with new fire eyes and gas detection systems but these have not been tested; 5) Poor housekeeping observed with piles of junk indicates the platform has not been cleaned for an extended period of time. I have also attached a sampling of photos taken by one of our inspectors documenting the platform's condition. 1:.<;.~:re"Q\N1 ~\~....~\.> (..t~(,:.Q.r\'$~~ '\r'J'~\$t ~fc:~'\'\"'~ \-...\~( h~ ,0. \,,~-G~Y'4:\~\"t..~ ,.\~ '\¡-..,:. ~\ \ ,-\\~. t$'"·\Ç:,(;....~ (¡,f CA\~, Ys.~~<t.~ " \\J \t. <:.J.:.;.." S~\:::~ -\ \~~ <>~ "Sj" '"1 bc....L"'-~t SQ. ,~0 4 \ Ç,.\\Q, \ i <t'''\l>:\ \ ~.;I ~7-\' \I',. ) -\. \'-U.. \. . --\ N' C" ~'CL\-"'> ~ c~~.~'">~J, /e..'~f)I}}1/1.' .' AJþ ( ~/', Safety Valve & Well Pressures Test Report Pad: TBF_SPARK_PLATF Insp Dt 5/14/2007 Inspected by JeffJones Field Name TRADING BAY Operator MARATHON OIL CO Interval InspNo svsJJ070517072719 Operator Rep Todd Paxton Related Insp: SVSOP000004053 Reason Miscellaneous Src: Inspector Well Number Permit Number Separ Set LIP Test Test Test PSI PSI Trip Code Code Code Date SI Oil,WAG,GINJ, Inner GAS,CYCLE, SI PSI I-GAS Outer PSI Tubing PSI Yes/No Yes/No [ S-02RD [ 1740240 PLC controlled pilot 1 ! functioned the SVS properly when manually activated but failed to activate the SVS on . low pressure & will require repair. The SSV & SSSV were not successfully tested today because the well head I I appeared to be plugged with I I grease. ~-.J Comments Performance I Wells Componen" I I S-02RD pilot is a PLC controlled shut down device (PSD). When manually activated it closes the SSV, line heater valve, downstream FCY. The SSSV is activated on 60 second delay after the SSV closes. The remote KGF manual PSD was successfully tested today. Failures Failure Rat~ 100% . Monday, August 06, 2007 Safety Valve & Well Pressures Test Report Pad: TBF _SPARK]LATF Insp Dt 5/25/2007 Inspected by Jeff Jones Field Name TRADING BAY Operator MARATHON OIL CO Interval InspNo svsJJ070606182951 Operator Rep C. Johnson Related Insp: SVSOP000004056 Reason Retest Src: Inspector Date SI Tubing PSI Well Permit Separ Set LIP Test Test Test Number Number PSI PSI Trip Code Code Code [__~-~:~ T~40~~0'---t~51 705'- 705 I pip I 43 J Oil,WAG,GINJ, GAS,CYCLE, SI Inner PSI Outer PSI Yes/No J I-~--'--¡-- I _l_--------.L.....__ I-GAS Yes/No Although the SSSV passed the pressure test, it did not close automatically when the pilot tripped. I . Comments Performance The SSSV did not trip automatically with the pilot & SSV; it only tripped closed when manually activated from the KGF gas field or the platform control screen. Inspection revealed the platform to be messy and in a state of disrepair and deterioration, Wells Components Failures 3 ~onday,August06,2007 Failure Rate l I I 33.33% =---J . Safety Valve & Well Pressures Test Report Interval Pad: TBF_SPARK]LATF Insp Dt 6/5/2007 Inspected by JeffJones Field Name TRADING BAY Operator MARATHON OIL CO InspNo svsJJ070613112344 Operator Rep C. Johnson Related Insp: SVSOP000004185 Reason Retest Src: Inspector Well Permit Separ Set Number Number PSI PSI ¡S=02RD~I~~~~ 450 LIP Test Test Test Trip Code Code Code 4961~ Date SI Inner Outer PSI PSI Tubing PSI Oil,WAG,GINJ, GAS.CYCLE, SI I-GAS Yes/No IL Yes/No During the test today, the SSSV on gas well S-02RD failed to close when the pilot tripped. The SSV & SSSV on this well also failed to close when a remote platform shutdown (PSD) command was initiated from the Kenai Gas Field (KGF) control board. Equipment and personnel capable of testing the fire & gas PSD systems were not on board today. The anode corrosion protection system for the platform's legs has been out of service for some time and should be restored ASAP. The poor condition of this platform indicates it has not been properly cleaned or maintained for an extended period of time. . . Comments Performance Successful demonstration of the recently installed fire & gas platform shutdown (PSD) system and the remote PSD capability from the Kenai Gas Field should be required prior to further unmanned operation of this platform. Wells Components Failures Failure Rate 3 33.33% Monday, August 06, 2007 . . Alaska Business Unit Marathon Oil Company P.O. Box 1949 Kenai, AK 99611-1949 Telephone 907/283-1311 Fax 907/283-6175 RECEIVED June 20, 2007 JUN 2 2 2007 Tom Maunder AOGCC 333 West ih Ave Suite 100 Anchorage, AK 99501 i~ Jut 1 ,1) ZOW Alaska Oil & Gas Cons. Commission Anchorage Dear Mr. Maunder: Attached and submitted for your records is the Form 10-404 sundry for work recently concluded on the S-2rd well located on the Spark Platform (NTBU). Excessively wet perforations were isolated with a bridge plug and cement via wireline under AOGCC approval #305-347 on the Form 10-403 submission. Marathon is currently attempting to unload this wellbore and establish continuous gas flow from the well. Also attached for your records is the current well schematic, work history for this event, and two copies of correlation logs recorded to verify the top of cement after placement. The logs are satisfaction of an agreement between Marathon and Jim Regg, with the AOGCC, that Marathon would record the tag in lieu of having an AOGCC representative witness the tag. If you would like any other information, please contact me at 394-3060 or kdwalsh@marathonoil.com. -r- \ ~. _ ...... c..o~~r~ ( '~~~T ~~ Q q,C\ . /&. ~ 'î lID -Oì ...\'1\~1 6WV Sincerely, I~ h. W~ Ken D. Walsh Senior Production Engineer Enclosures: 10-404 Sundry Well Schematic Operations Summary cc: Houston Well File Kenai Well File KDW KJS J (1-o~£..( . . 1. Operations Abandon U RepairWell U Plug Perforations l:j Stimulate U Other U ~ Performed: Alter Casing D Pull Tubing D Perforate New Pool D WaiverD Time Extension D Change Approved Program D Operat. Shutdown D Perforate D Re-enter Suspended Well D 2. Operator Marathon Oil Company 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory D 174-024 - 3. Address: Stratigraphic D Service D 6. API Number: - PO Box 1949, Kenai Alaska, 99611-1949 50-733-20172-01-00 7. KB Elevation (ft): 9. Well Name and Number: 115' KB above MSL 5 - 02RD - 8. Property Designation: 10. Field/Pool(s): - ADL - 18776 North Trading Bay Unit I G-Zone (Tvonek) 11. Present Well Condition Summary: Total Depth measured 11,500' feet Plugs (measured) 9,901'/10,497'/11,300' true vertical 10,290' feet Junk (measured) 10,345' Effective Depth measured 9,901' feet true vertical 8,987' feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,055' 13-3/8" 2,055' 1,926' 3,090 psi 1,540 psi Intermediate Production 7,370' 9-5/8" 7,370' 6,827' 6,870 psi 4,750 psi Liner 4,174' 7" 11,341' 10,123' 8,160 psi 7,020 psi Perforation depth: Measured depth: 9,580' - 9,867' Gross True Vertical depth: 8,722' - 8,960' Gross Tubing: (size, grade, and measured depth) 2-3/8" HS-70, 3.215 ppf, 0.109 WT 9,227' Packers and SSSV (type and measured depth) Baker HB packer Camco TRDP - 4A SCSSV at 9,200' MD at 593' MD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: NA 0 0 0 2,950 Subsequent to operation: NA 0 0 0 1,800 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Gamma Ray 1 CCl Exploratory D Development 0 Service D Daily Report of Well Operations Operations Summary 16. Well Status after work: oilD Gas 0 WAG D GINJ D WINJ D WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: 305-347 Contact Kevin Skiba (907) 283-1371 Printed Name Ken D. Walsh Title Senior Production Engineer Signature _I~ b , W~ Phone (907) 283-1311 Date (.p /2..0 /"LOO 7 . . t'tH1 JM."Oo\ 6t"L JUL 0 6 2007 . STATE OF ALASKA . ALAS'ð'OIL AND GAS CONSERVATION COMM ON REPORT OF SUNDRY WELL OPERATIONS Form 10-404 Revised 04/2006 0 RI G \ N A L ~~ RECEIVED ,JUN 2 2 2007 Alaska Oil & Gas Cons. Commissi ~""lv Submit Original Only API #: 50-733-20172-01-00 Permit #: 174-024 KB above MSL: 115' Property Des: ADL-18776 KOP: 7,375' Surface location: 2,606' FNL, 2,492' FEL, See 26-10N-13W, S.M. S.. 2 D Spark Platform North Trading Bay Unit FMC TC-IA-ENS-SPCL Tubing Hanger @ 35' 3-1/8" 4SAM2-LH top x 2-3/8" EU bottom Camco TRDP - 4A SCSSV @ 593' w/flow couplings, 10 = 1.875" 13-3/8" J-55 MD 0' TVD 0' 1,926' Active Perforations: (MD) BF1 9,580'- 9,590' 4spf (11/1997) BF2 9,623' - 9,633' 4 spf (11/1997) BF2 9,650' - 9,665' 4 spf (11/1997) G Zone: UG1 9,772'- 9,787' 4spf (11/1997) UG2 9,852' - 9,867' 4 spf (11/1997) UG-3 9.925 - 9,940' 4 spf (11/1997) UG 9,935' - 9,995' 6 spf (8/1994) UG-4 9,984 - 9.994' 4 spf (11/1997) UG-5 10.045' - 10,075' 6 spf (8/1994) UG-5 10,050' - 10.090' 6 spf (8/1994) G Zone: G2 10,315' - 10,750' sqz G2 10,560' -10,570' 4 spf (7/1981) G2 10,563' - 10,618' 4 spf (7/1974) G2 10.570' - 10,590' 4 spf (12/1976) G2 10,572' - 10,588' 4 spf (12/1980) G2 10,598' - 10,618' 4 spf (12/1976) G3 10,643' -10,668' 4 spf (7/1974) G3 10,643'-10,668' 4spf (7/1981) G3 10,646' - 10,666' 4 spf (12/1976) G4 10,694' - 10,714' 4 spf (7/1974) G4 10,694' -10,714' 4 spf (7/1981) G5 10,733' - 10,758' 4 spf (7/1974) G5 10,733' 10,743' 4 spf (12/1980) G5 10,737' -10.762' 4 spf (7/1981) Hemlock Zone: H1 10.790' - 10,822' 4 spf (8/1985) H1 10,798' - 10,814' 4 spf (12/1980) H1 10.800' - 10,820' 4 spf (12/1976) H2 10,840' - 10,872' 4 spf (8/1985) H2 10,878' - 10,910' 4 spf (8/1985) H2 10,933' - 10,965' 4 spf (8/1985) H3 11,000' - 11.032' 4 spf (8/1985) H3 11.002' - 11,012' 4 spf (7/1981) H3 11,008' -11,058' 4 spf (7/1974) H3 11,010'-11,030' 4spf (12/1976) H3 11,078'-11,098' 4spf (7/1974) H3 11,078'-11,098' 4spf (7/1981) H3 11.078'-11,098' 4spf (12/1976) H4 11,125'-11,145' 4spf (7/1974) H4 11,125' -11,145' 4 spf (12/1976) West Forlands Zone: 11.266' - 11 ,356' sqz (6/14/1974) Well Name & Number: County or Parish: Perforations: (MO) Angle/Perfs Date Completed: Prepared By: Camco "X" Nipples @ 9,188' MD & 9,217' MD 10 = 1.875" 17-1/2" hole, Cmt w/ 2,000 sks Production Casinq 9-5/8" 1'.1-80 Baker HB Packer 9,200' MD MD 0' TVD 0' 47 ppf Bottom 7,370' 6,827' 12-1/4" hole, Cmt w/ 1,000 sks 13' of cement @ 9,901' MD above Schlumberger Through-Tubing PosiSet Bridge Plug 9.914' MD Liner 7" 11I-80 29 ppf MD 1,167' TVD 6,611' 10,123' 8-1/2" hole, Cmt w/ 1,175 sks 135' of 2-3/8' Coil Tubing, SC2 PAH Packer and Tail Pipe @ 10,345' MD 10,396' MD 2-7/8" N-80 Tubing Cement 10,497' CTMKB 1 .22 gal Sand Covering Fill 10,719' CTMKB 7.2 gal Cement 10,822' DIL PBm - 11,300' Cement above Float Collar State/Provo 9,580' - 9,987' Angle @ KOP and M Depth 23.5° Last Revision Date: Coil Tubinq Strina 2-3/13" 3.215 ppf Precision HS-70 CM 60,000# yeild ID = 2.101" MD TVD 8,430' Baker HB Packer @ 9,200' 115' . . Marathon Oil Company Page 1 of 2 Operati()n$ SummaryiReport Legal Well Name: S-2RD Common Well Name: NTSU S-2RD Spud Date: 6/13/1974 Event Name: WORKOVER Start: 4/24/2007 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code Sub Phase Description of Operations Code 4/25/2007 06:30 - 08:00 1.50 WAlTON EQIP PLUGAB Transport MOC and Schlumberger Wireline crew to the Spark Platform via ERA Helicopter from the OSK Dock. Project Intent: Set BP and dump bail cement to isolate the excessive water bearing perfs below the UG2 perf interval to return the well to gas sales. SITP was 2200 psi. 08:00 - 09:00 1.00 SAFETY MTG_ PLUGAB Hold PJSM to review job-specific JSA and Safe Work Permit. Perform platform orientation with wireline crew and Udelhoven crane operator. 09:00 - 14:15 5.25 RURD - ELEC PLUGAB MIRU Schlumberger Wireline to tree. Pressure tested wireline lubricator to 350/3500 psi with methanol. 14:15 - 16:45 2.50 RUNPUL ELEC PLUGAB PU and RIH with 1-11/16" Pressure-Temperature-CCL-GR tool string with two 6' long hevi-wt weight bars on wireline. Tagged up at 160' MD and could not pass. Suspect possible hydrate plug. POOH with considerable amount of valve grease on tools. Noted the temperature probe on tools string of 31.8 deg F at 160' MD. 16:45 -17:15 0.50 RURD - ELEC PLUGAB RD off of tree leaving well shut in and tree capped. 17:15 - 18:30 1.25 WAlTON EQIP PLUGAB Transported wireline crew from platform to shore by helicopter. 4/26/2007 06:30 - 07:30 1.00 WAlTON EQIP PLUGAB Transport MOC and Schlumberger Wireline crew to the Spark Platform via ERA Helicopter from the OSK Dock. Note: Jim Regg with the ~ )1 AOGCC was contacted by telephone today and waived witness of the work to set the BP, dump bail cement, and tag the cement top. 07:30 - 08:15 0.75 SAFETY MTG_ PLUGAB Hold PJSM to review job-specific JSA and Safe Work Permit. 08:15 - 10:15 2.00 RURD - ELEC PLUGAB MIRU Schlumberger Wireline to tree. Pressure tested wireline lubricator to 350/3500 psi with methanol. 10:15 - 16:00 5.75 RUNPUL ELEC PLUGAB PU and RIH with 1-11/16" Pressure-Temperature-CCL-GR tool string with two 6' long hevi-wt weight bars on wireline. Tagged up at 10,070' MD. Logged static fluid level at 9780' MD (middle of UG-1 perfs). Logged P- T with GR/CCL from 10065' to 9100' MD after correlating depth with PL T log run 06-Sept-03. POOH with logging tools. 16:00 - 17:00 1.00 RURD - ELEC PLUGAB RD Schlumberger for the day. 17:00 - 18:30 1.50 WAlTON EQIP PLUGAB Transported wireline crew from platform to shore by helicopter. 4/27/2007 06:30 - 07:30 1.00 WAlTON EQIP PLUGAB Transport MOC and Schlumberger Wireline crew to the Spark Platform via ERA Helicopter from the OSK Dock. 07:30 - 08:00 0.50 SAFETY MTG PLUGAB Hold PJSM to review job-specific JSA and Safe Work Permit. 08:00 - 09:30 1.50 RURD - ELEC PLUGAB MIRU Schlumberger Wireline to tree. Pressure tested wireline lubricator to 350/3500 psi with methanol. 09:30 - 14:00 4.50 RUNPUL ELEC PLUGAB PU and RIH with 1-11/16" Schlumberger Posi-set BP and setting tool on tool string on wireline. Correlated depth with PDS PL T log run 06-Sept-03. Set top of Posi-Set BP element at 9914' MD. PUH and then RIH and tagged BP at proper setting depth. POOH with wireline and BHA. 14:00 - 14:45 0.75 RURD ELEC PLUGAB Rigged up tools to run cement dump bailer. 14:45 -18:50 4.08 DUMPBl CMT_ PLUGAB Made two dump bailer runs with cement on top of BP to bring cement top to roughly 9909' MD. 18:50 - 20:00 1.17 RURD - ELEC PLUGAB RD Schlumberger for the day. 20:00 - 20:30 0.50 WAlTON EQIP PLUGAB Transported wireline crew from platform to shore by helicopter. 4/28/2007 06:30 - 07:30 1.00 WAlTON EQIP PLUGAB Transport MOC and Schlumberger Wireline crew to the Spark Platform via ERA Helicopter from the OSK Dock. 07:30 - 08:15 0.75 SAFETY MTG PLUGAB Hold PJSM to review job-specific JSA and Safe Work Permit. 08:15 - 09:15 1.00 RURD - ELEC PLUGAB MIRU Schlumberger Wireline to tree. 09:15 - 15:45 6.50 RURD - ELEC PLUGAB Made three dump bailer runs with cement on top of BP to bring cement top from 9909' to 9901' MD. Calculated differential is 5600 psi across BP and cement. 15:45 - 16:30 0.75 RURD - ELEC PLUGAB RD Schlumberger for the day. 1\ (\¥' f., Printed: 6/20/2007 10:'.4:23 AM J " , .. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . . Page 2 of 2 Marathon Oil Company OperationsSummêiry Report S-2RD NTBU S-2RD WORKOVER Date Code Sub Phase COde 4/28/2007 16:30 - 17:00 0.50 WAlTON EOIP PLUGAB 5/1/2007 07:30 - 08:30 1.00 WAlTON EOIP PLUGAB 08:30 - 09:00 0.50 SAFETY MTG - PLUGAB 09:00 - 09:45 0.75 RURD - ELEC PLUGAS 09:45 - 13:30 3.75 RURD - ELEC PLUGAB 13:30 - 15:00 1.50 RURD - ELEC PLUGAB 15:00 - 15:30 0.50 WAlTON EOIP PLUGAB Start: 4/24/2007 Rig Release: Rig Number: Spud Date: 6/13/1974 End: Group: Q~~ription of Opera~ns Transported wireline crew from platform to shore by helicopter. Transport MOC and Schlumberger Wireline crew to the Spark Platform via ERA Helicopter from the OSK Dock. Hold PJSM to review job-specific JSA and Safe Work Permit. MIRU Schlumberger Wireline to tree. RIH with Press-Temp-GR-CCL tool and tagged top of dump-bailed cement at 9901' MD (13' of cement on top of BP set at 9914' MD). RDMO Schlumberger - Finished Job. Transported wireline crew from platform to shore by helicopter. Printed: 6/20/2007 10:14:23 AM Re: S-2RD . . Marathon may flow Spark Platform Well S-2RD based on my conversation with the Inspector and our phone conversation yesterday following the email message below regarding completed repairs. The SVS must be function tested before restarting the well and a performance retest must be conducted within 48 hours of commencing production (not required to be witnessed by the Commission). It will not be necessary to shut in the well if the performance testing passes. Results of tests done on May 14 and the performance test done after commencing production (presumably within the next few days) must be provided to the Commission per the normal test report procedure. Please make arrangements to have Commission Inspector Jeff Jones witness a SVS test on S-02RD upon his return from the North Slope. Jim Regg AOGCC sCANNED MA'< ·2 9 2007 Paxton, Todd D. wrote: Jim, You've probably heard from Jeff Jones concerning his visit to the Spark on Monday, the 14th; if not, here's a summary and how wè·Wbuld like to proceed: We brought Jeff out Monday with an IISCO instrument tech to witness the safety valve (both SSV and SSSV) tests and also witness the sales meter calibration. There were three primary objectives concerning the safety valves; 1) Prove they both close when remotely commanded from Kenai Gas Field and by local push-button, which they did; 2) Prove they close on a low-pressure trip, which they didn't due to a PLC logic problem that has since been corrected and verified to function properly; 3) conduct a differential pressure test across each safety valve, which we couldn't complete due to excessive valve grease in the flowline from previous valve servicing. I have since cleared the grease from the flowline and we will be able to conduct this test now. We would like to flow S-2RD tomorrow, May 17th, to further ensure all safety systems function as designed prior to bringing another AOGCC Inspector out to witness the valve tests. The platform will be manned and the well closely monitored while the well is flowing, and will be S/I upon completion of our function-testing at the end of the day. Upon the successful completion of our testing, we would need to schedule an Inspector's visit through your office prior to continuing production from the well. Please advise. Thanks, Todd Paxton Marathon Oil Company Alaska Asset Team 394-1322 10f2 5/17/20072:59 PM Re: S-2RD 20f2 . . Jim Regg <jim rcgg(c~admin.statc.ak.us> Petroleum Engineer AOGCC 5/17/20072:59 PM [Fwd: Spark S-2RD Waive Witness] . . fyi \lL\-ad-~ -------- Original Message -------- Subject: Spark S-2RD Waive Witness Date: Wed, 25 Apr 2007 18:41:12 -0500 From: Walsh, Ken <kdwalsh@marathonoil.com> To: j irn regg@adrnirl:-s-tate-:-ãk:us----------------- CC: Paxton, Todd D. .:':..t.£9:?S:t::g,r:¡~'~E9:t::Þ:'?:r?:'?_tL:c:::?¡:n_::., Ibele, Lyndon <lcibele@marathonoil.com>, Szalkowski, Scott <dszalkowski@marathonoil.com>, Scott, Clyde M .<:_c.:;yq~§~ot t::~!.1:19-E~t::Þ:'?:r?:9~.!:..:_c:::g,!,? Jim, Please consider this email as confirmation of our conversation over the telephone today regarding the North Trading Bay Unit Well S-2rd. Operations are currently underway on the Spark Platform to set a Posi-set bridge plug in the 7" casing at 9914' KB to shut off excessive water from open perforations below the UG2 under the AOGCC approval granted per Sundry number 305-347. Notice was given to you today that Marathon planned to set the bridge plug and dump bail cement tomorrow, April 26. Marathon plans to run in the well with wireline and tag the top of the dump-bailed cement on April 27. You waived the AOGCC intention to witness this work with the understanding that Marathon would provide to the AOGCC a wireline log that verifies the top of the cement that is tagged with wireline tools. Thank you for your help in this matter. Best Regards, */Ken//// /* *Ken D. Walsh* *Senior Production Engineer* *Marathon Oil Company-Alaska Asset Team* *907-283-1311 (office)* *907-394-3060 (cell)* SCANNED APR 2 6 2007 ,. .....,1111.,~ ..--,."-"'...-..~..."...'.... 1 of 1 4/26/2007 11:01 AM Re: NTBU Spark S-2rd: Sundry Number 305-347 and PTD #174-024 . . Ken, Thanks much for your notice with regard to doing the work on Spark S-2rd. You have provided the needed information, specifically that the conditions are still the same. Proceeding is acceptable. I will put this note in the file. Good luck with the operations. Tom Maunder, PE AOGCC SCANNED APR 1 7 2007 Walsh, Ken wrote, On 4/13/2007 12:09 PM: Tom Marathon requested and was granted Form 10-403 approval to set a bridge plug in the S-2rd well bore in early November 2005. The sundry number issued for the approval was 305-347 on November 8,2005. Marathon never did perform this work but wishes to do so at this time. Neither the well bore configuration nor the intended work procedure have changed. Can Marathon proceed with the intended work to set a Posi-set BP in the 7" casing at 9914' KB to shut off excessive water from open perforations below the UG2 under the AOGCC app,roval granted per Sundry number 305-347? We would like to get started with the wellwork in mid-April 2007. Best Regards, Ken Ken D. Walsh Senior Production Engineer Marathon Oil Company-Alaska Asset Team 907-283-1311 (office) 907 -394-3060 (cell) 1 of 1 4/13/20072:46 PM n', ~~',í7ìŒ" \.~, l' [ ,: l , ¡\ !. ¡ " ' ~ I 11 ' I II 1 . I I I í 1 II, I, i!· ,I W!· W [' ) ¡fñ1 rI: l,~i,¡ \ 11 J,A \,~ (-~. ' 11/\7 /þ\\)'.\ : I r ! ¡ 1 tP ~ r I ! H ,\, ¡ ~ 1\ i.il \~) iJ U\ [b!' \ æ... d\.1! / II. ) A.I,A.SKA. OIL AlWD GAS CONSERVATION COMMISSION 'I ! FRANK H. MURKOWSKI, GOVERNOR Denise M. Titus Production Engineer Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 333 W. pH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 .. /0 '}4' \\~ Re: G-Zone (Tyonek) S-2rd Sundry Number: 305-347 $c;MNED) NOV 0 9 2005 Dear Ms. Titus: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. o Chairman DATED thisØ day of November, 2005 Sincerely, Enc!. NOV-07-2005 MON 03:56 PM MARATHON OIL COMPANY ) FAX NO. 907 )283 6175 ( .---~ . l..·) MêH"a'HÌll:m \~T~O.~i Oi~ (C~)mp~~ny Fax Cover Sheet ----"/. . ,. - -, --,' DA Tt::__Jl.JJ./ Ii ,~ ,W"'.,\!WW'..II....,,.._._._a-_ TIME:. / Lt.~Q.Q.~ . '-,' TO~ I I ¡ " , i I NAME: ~-J~~lJ3Lil(\{if I{" COMPANY: --_J\:D.(;lf:¡~ F/\x:____.-'~à;;:.:¡J_.,~~~J 7(¿/ -~_:l!Ú".~I.;}.:~~ FROM: ,-" ~"I NAME: _J)¡,;,v,¡ ~~t JJ10~ r·IHONE: -'~'V~ZJ~, dJ53 .- /11-3.:1__,.,."._ --"""""",,,~"-I'I,.III· . f; AX: """. ..,~..._._9D] "? 8 3 ~6J..7 .5...__...... PAGES SENT (Including Coví:;r Sheet) & [ 1 Re~;;pons0 Requested [) Immediate [] I n'fonnDtion Only P. 01 Ki~n¡:¡ï G(JS Field PO Box 1 ~49 l<.enaì, AK 996'11-11349 T~~h::¡~hone (907) 283-1300 ¡~¡.:n~ (S07) :283-6"175 ',f il·.·. ,. I r·U:MAI~KS~. I 0/1'71" /) j~ I :Jr! j J ,') ~. /:.~, f L· A "S -::) '. ') ¡, ..... ._..._.__+_._.I " ) I. ~u...,_.{. J~ (' (,'-_~ !ll..f;~......drÜtll v,/ .s..: ¿,_~ o{ {- (..' p.... J?___.f..t_.o:f_.L__ _.____._ .~_ - LrL-lMLJlJL!'l ci::...._~CJ.d... vt 0 if I ~t·11I..}th h ~ (!l1 (J~ ~'-r____ :"-:.~=~~- __._==-"'r~~Vik=_ ,~-' __..... .--_...----- NOV-07-2005 MON 03:56 PM MARATHON OIL COMPANY ) , FAX NO, 907.283 6175 ) P. 02 li~ Marathon ~~~:HON~ I Oil Company' Alaska Asset ream Northern Business Unit P.O. Box 196168 Anchorage, AK 99519~6168 Telephone 907/561-5311 Fax 907/565-3076 Novnmber 7, 2005 Mr. Torn Maunder Alaska on & (3a8 Conservation Commission :3~33 W ih Ave Anchoragø, Alaska 99501 ..~t{~~~~ Røferencc:): NT8U Spark S..2RD Døar Mr. Maunder: E-:nclosed ;$ the 1 O~403 Application for Sundry Approvals for S-2RD. The proposed work is to set a through t~b¡nÇ] piuq to isolate water production. A production log obtained in SØptOl11bHr 2003 indicates that 100% of the water is produced by the UG-3 z.one. The plug will c()vÐrthe wet UG<i, and the deeper UG..4 and UG-5 Zones. Cement~!Lee dump bailed on top of1he mechanical plug to improve its differential pressure rating. A tank¡ choke! and g~1S buster wi!1 be rigged up to permit well unloading if required to restore gas production. This work is expected to begin in mjduNovember If you need any additional inform2)tíon, I Gan be rE,~~~ched ;~t 907-283'·1333 or bye-mail atdmtitus@marathonoil.com. C' I Ylll~~ore y~ ). \~\ ..'! /1 ,.-.{... :~., )"\ )tA'/~Y ~\¡ ~.' vl L' '¡' '!U' '." ~.. Df~nlse M. Titus Production Engin(~cr Enclosures: 10-403 Sundry Application Perforation Attachrnent Well Procndure 'Nel! Schørnatic .. NOV-07-2005 MON 03: 56 PM MAH)ATHON 0 I L COMPANY FAX NO, 907 f83,/~175 ~ ,', ., [:'~e}t: f;),.' , ~ I~~~) ~. STATE OF ALASKA 1)P:f t,1PðOV n ll¡ ALASKA OIL AND GAS CONSERVA"fJON COMMISSION IfJ /-" ~ APPLICATION FOR SUNDRY APPROVALS ,!',,:. 20 Me 25.280 "1·.~(};I;~~or'r~'~:~1~;'~·;t-"'"'~···- -^~ñ-dMT~r·-&I;P~ñêO-~··Ö pcr~! I,ion~ìšhlltd C)wn" [ J AI!eI' oH~~ing [J f~\;1p3jr Wwll [] Plu!) PûrfC)ratiolls 0 Ch~~r\9~1 iJpprov('d pr091'0tì'1 [J rLlIl1'LJbÎr~Ð rJ PDrforéllt¡! New Pool LJ ~T,C:J¡~~;::;'t(;r'·Ñ:\~~.::'- ,.".....__.._._._,....W"_.-~'r'..._--~"'~~--~r~¡:-èLJ rl'~nt wê¡¡-cl~:-;I;i: Othõro M:¡f.111101l Oil COl1lro.ny Development :.~:"^,'i;JI·¿~;¡:-··-·,·.." ...".,___'"...M"____.,--.,.''.~"._.....~~..,__,..."__ 8(rali91'\1phi c 'PO ['\ù.{ 1;Xl'Hìtì, AMfH)mgc', AK !WG19-G168 f?:Î<:Ü'1 ';.;V;;i't1öïî· (IÖ:---- ",'.'~' ~~_~·"w.. ~-' Perföratc LJ -- wâiVcr-o-"'" Stirnu::¡(e [] Tirne Extcns10r'J [] Re,c;(1l~t Suspendod Well 0 "g:"Pctmil to' briJYNuml1êí';" 0" 174·024 ,/ ExplQr.:\lory [J 6. API Nüm'bo~: o [] -Service SO-'7~J-20172~01-00 ~/ ,.rl¡Wj_..i_-,-.,.~'/"'II\"'__ 9. Well N[¡;~10 ¡'.Jf1c Numbet: 'I1!¡' AtIOVI.; M::::L. S-2rd ~~~·F)i~:;lr~~;:'1 Y.J15(~~;·~)·i~{'itõ~1:"~-"--··~~·" _I~WU~ -- _·~·~W\u " 1 ô:F ic Id/FQÓfš( s ): 11.J1)!'th 1 r'r.hjìr'I(J ß':IY lIl'lil G"ZÚTl0 (Tyonük) 11.~ ~...,.~....~:..:~~ '.- - Pf{~SENT 'WELl. CONr:)jT~ON SUMMA~V lï,~i;';¡'"i3;;'p'~h"'Ml'i'(ïlF"w""-,, -Ïò"'Gì'5~~p'lh "rvõ(tl~----Ë¡{eèÜvc Dl:plh Mï5' (ft): EtFective Depth fVD (ft): "PlUgs (ni~~5ü¡'ed): '-'Jliñk (Ini.i~'~~ur0d): 113;~1 '10132 11300 10090 10.515/10,832/10,387 10,~¿10/10.3M)' ".., -.""" l: ;;-~;;ñ'T'--"'''''---'-- --~'L:;ngtll--'~""" "---~S¡~--~"'""~~ M ¡j~'~ TVD 13 urst ---" '~ëõUëtpae ..... 1'!'~.¡'¡"~~fi~~l~r,::~111"'¡' I ...____...-~.I\.~_-·'I'IIV\_....___·~'UI\II"____~".,.. ." . ,1'ØI1AoI'1 , .~..,.~¿~ l'lC',:/cT¿\r-'--'-- ~"'''"..,-,."._-~~'''~".................... --~.~.~.,---~,~.~ ..-~-". ."'" E, l:iiY.it:;)-·-~·"! 2·:¡)55-;-~~'"'~"·--·~13~g.;--·'""w,.- :2 ,Ö55' f.-~"'~·ï;W¡~i17.;;·ï¡:::ia'" ...-'------" ..,...._-~,,-,._~-"'''~---~,- . . .~liIooo.I---..-.~.....oI-- 1,926' 3,õê()---"....~ 1 ,5~O ..._", ·-f;r;~iL;;:;¡¡(.);I-_·_·'7.31õï··--~····~-0=5ìs~t' ""-M""~" D;,i~-··_··,.....·"·..rri1;--.~"'..~~-"'ro.F ' ,'f;:;rf'õi~j¡lõ;~ -r5~;;i';lh·Mï)W~- ._-~\ L}t' [<.1 r~;~;~n"D;J p th TVD(ft): 500 Atl(l(;h¡;'1(1 S~::o AU,·Iï.:hcd ,_"1.."11.&..__.,........." '7,370' L~..~ ]'41 ' T\JbíIlO SiZ0: 2-3/8" C'í '-""-6,827' 6,R7Ó' . 10,1.7.3' 8,160 Tubing Grãdê: Tub'ina Mb (Il): HS-70, 3,215ppf, O,109WT 9227' PJck,,:r$ ana- SSSV MD (rt): PKR @ 9~QrfMD I SCSSV^'@ 5Q~' MD "'(75õ -;,02Q fl,~ Z"k7.;¡ ¡'¡r1cf'\§ ~f8 V ·rÿi;(.;;"· ".-'-.- £k:1 hC~;' i~"Ã~ì¡;:r-·~....v,·~--"'_·, G.JrY1CO TRCJP-4A SCSSV ~1!~i\'iTî(h~~i\~';~k: D"..~·;cripliol.¡ (~lJi1I'llary of Prc)PQz.J! . [...IT' . '1':3. Well Cias$ ·¡:¡.fter proposed work:' Oü,r.\1il(>d (J:I('H,¡tiol1c, Pr()~¡r,'lrn 0 ßOP $1\~!tch 0 Expomtô~y [J DcvclopT11ent [iJ Scrv¡ec LJ T;t'8:iir:\7Iíc;c¡"'[)::ït~~-for--Y"""~'--'-~~~"'~~ '_··-·--~'-~~~'-1·S. W~¡I[ statlls <lflcr propô'scd w(~rk; CnnUT1Q¡,¡cÏl¡!J O')()r'.·,¡tion¡;: 11/15/2005 Oil [J Gas [2] PluggØd [J Abandonüd [] 1~L'Vcïf':;¡-Ã~~;';'(')V:1ì:"-~"---'~""~--~-'""6'J~--"'M~~' WAG 0 GINJ 0 WINJ 0 WDSPL [] CClm 11'\¡!~ "It)l1 f;:(?pn.:~il.1nl;ll¡w: "ìY~TT,(~'~;'~y (;;~.~11'¡'jÿ¡j-;;ttJ,;;-f~·I~ÕgO¡i\g¡S~lrï7ôM~;a'tõÏhc þ ~ $to'tmy kr'áwleaÐ'é. ~"CQI'ì lact ~ 'PfiIlitHt Niltlle [~~~:~~. M. :J,~~,.;f "_.,,~.___~,,_~ TiLlø !rodLJClìon .,::~ccr "__ ~~¡~J11('IIIr,:: ll,," 1J!¿l ·a::-~7"r'·:;~.:::' PI\óf1~~ 907-283-1333 Dale II " v-" l· " " "....."'''",...,._____......."".j.,,~_.. .,""'~~(."..f,L._..-~,,".,,___~.........~~,.. .. ,. . ",-- COMMISSION USE ONLY - . Denise M, TiÜA5 . ~-"-"'IoI__ 11/7/2005 I"'I..._..__~~ __\~'" '1111I....... _..___....__·~~·'.....,y,l~'- "··....·.'h..............._.,_"'IIII..".._ condilionG (f í'JpprQV,'1!: N,)tiry CQmmi,L:;~ìjon :f,Q 1hL,t Ll r0pl~~s~llt~Üivc (Y\t~y witn~s!> Sundr~ Nu~.bcr: òc:f) -;;+ 1 f'ltl~ 111lc1]rilY !. "J soP Test IJ f\,k!ch."1nic<l1 II \lc:grily Test 0 Loc¡;¡lion Cle:::lrDncG 0 f,.)lh,.~r: '3 5aC) pcÇ\ ~,S<? . ~ .~'S \c, Ù~ ~\o""Zð , ßQ Ç>«(çy~\ ~~~,.\" \?~ \ dO ~ ~<-d--S-l Ò ~.~ -"G/ - oKTGíN°ASLN~~ ¡:~órfT110-40:J H()v¡~;f'd 07/2005 V' ~otê: #(..__ RBDMS 8ft NOV 0 g 2005 APPROVED BY THE COMMISSION Submit in D~plicc\lo NTBU Spark S-2rd Perf Summary RðIJ; £,Q N E; ß/lD Dill NET §PF Current Perfs 11/22/1997 BF·1 ~~580'-9590' 8722'-8730' 10· 4 11/22/1991 BF-2 9623'"96331 8758'..8766j 10' 4 1'1/22/199l BF~2 9650'-9665' 8780'-8792' 15' 4 11/22/1997 UG-1 9772'-9787' 88811-8893' 15' 4 ß'? 1(\C>."~l'.~ ..-:t- 11/22/1997 UG~2 9852'-9861' 894 T-8960' 15' 4 UG-3 ~. 99251-9940' - 9008'~9021' 11/22/1997 15' 4 e C\ C\ \ L\ 11/22/1987 UG-4 99841-9994' 9057'-90661 10' 4 Aug..94 UG-5 1 0050'~1 0090' 9071'·9087' 40' 6 tit1W\ I..... _..J PluSJged Peres G-2 lhru H-1 10560'-10822' H-2 thru H-4 10840'·11145' if P, 04 FAX NO. 907'f83 6175 NOV-07-2005 MON 03:56 PM MARATHON OIL COMPANY ) NOV-07-2005 MON 03:56 PM MARATHON OIL COMPANY , ) FAX NO, 907 )283 6175 P, 05 MÎ~n~thon Oil Company Ah...ska Asset Tc~un ~0 8.. 2 no NTBU, Spark Platfornt E-line Procedur~ 'WBS # WO.05.12980.EXP Histot"y: Sp~'rk wdl S-2RD wü~ recently capable of flowing over 2MMcfd with a water rate of 200~300 B\VPD, A produçtion.log obtained in 2003 indicates that ~11 or most of the water ~~OlÜúS from tlw l.JO,"3 ~on0 (]I'd fhnn boU()m). The well would l"lot flow after the 1110St recent shut down and scv~t~)1 attempts to rü~Ulrt production have been lnade with no success. SlTP=2950p~i OhJ(~C'tivc~ Set a p1ug to i~()lMc tho bOtt0I11 1hrco 1:<)ne8. B10w the we11 down as IlGcdcd to r\~sto ¡J S ~2RD produttiøll. r~,,·()c~..rlnn::: 1) Mob 8LH f..'lectric line cLllripmcnt and MOC flowback iron to tho Spark PlrHform. 2) rid~ equipment and tank !l-om b~.rge onto Spark deck and RU wjrelinc lInit t:mc1 nowback 1ank to \\11".'11 h~):1d v/ J) PU 1 ~ 11/16;1 GR, Pn.:sSlJfC test c~1inc lubri~Í'1tor with lllcthanol test pump 350/3500 p:)i. Open ,vl..~ll dumping 1ncthnnoJ downhole and RUt Drift tubing string, Üìggtng tiH boron~ roo It, \. ß V If' ~"'~ ~ "--1' \>","'Ú ~ '-0",," ';>L '. %" -.. t;,. i c¡:: ~9?1t1 4) PU .Posi ~sct brìdg~ plug ,md R fH (note rostriciions~ 10·1.875" at. 9188' & 921 T). h~ 5) Corrdnk (ltld sel plug at 9914' per SLB procedure. POOH. Ô) 'r--.,1;lkc ccnwnt dump 1x1Ìl runs as I'ecomI110nded bymfr.---" <-Q.~Q:.\j'\-',> ~\"~~,,'-\. \-D " V'... <:...~C~ <è ~ "{'~~ K. '" \-, '"'- \ 7) Rig\1ackE-HrJC\J1\iL C..3.1\,""\;'o.\:,\¡. h-)l1I1 8) ^tlcmpt l~) kick ~)Jlo[Ldud well. Vent to atmosphore via ga~ bustcr and open top tank if (V 8 IlCç¡;Ssaty. \Vatd'L we.ll closely and turn to systcnl wh~n ~blc to sustain t1ow. , I)) l~nlVíO E~1.im,' Llllit [lnd blowJown cqu1prncnt. , ' NOV-07-2005 MON 03:56 PM MARATHON OIL COMPANY ') FAX NO. 907.283 6175 ) P, Oß, No! th TradIng Bay UnIt ,,!~tÎj!tÍ:tii ' "'",,', . Spark Platform, Well S-2rd Marathon Oil Co., Alaska Region I' \\ ¡ C' ..If" ~ ,¡. ~ II 1.1 \ 11 I '/ ~ '11""""-1 . ....,--.-.-- -,---------,--------,--,-~ -.-.~.."".. ~;::::""..'" ... ,~."." ..,~""" ':;';'l'('~' ';.¡ ",' .:~ ('> '" \'r't'1... c.......v-...., = .~ t ~ \)\1..'.) l;MC ï'C-rA-.ENS-~l)CL Tubing Thngcr@ 35' J"lIgll 4SAM1-LII h.'p X 2-3/811 EU bottom ~ ('IIi 1 1('0 'fRDJ"~A SC~~V (ji) 59:V \vl now couplings " JI) ~" t .875'1 'i'nbizlf:; ,~ld(\g: 2-3/8\ 3.115H I C()'i1 tllhlng, Pwcì¡,¡in1} ]1:)·-70 CM, óOOOOif Yidcl jl) ~: 2J07" C:,¡mco IIX" Nipple. @ 9188' 10 = l,R75" C~)HI~O "x 'I N¡Ilpl~ @ 92 l"/ 1D.: 1.8'7311 I rl~r(·I\. \ : {'1!n'elll ht1o..: (1-11/16'1 strIp g1m:~~ EJ-TIf) 0° phase) "'" "[H~~ l' ~5~OI " ~)5 ~O' 'rDT (4 spf, 1l/22/97) l1F~2 !J623'" 9633' TrY!' (II spC i l/22/97) 965()1· 9G65f TDT (4 spf, 11/12/(7) HO..] 9772'· 97'Ö7' TDT ("1 ~pf, 11/22/97) 11(J~2 9852' - ~(Š671 TUT (-1 spf, J 1/22/97) n('i"';~ 99151. ~9,10' 'n,)'1' (rt spf, 11/2119'7) Ulì-tt 9!)81~ - 99~),11 TDT (4 spf> 11122N7) UG·5 1 0050' ~ I n090' 'rUT (6 sp[¡ 8/9,t) 'J ( j :i:, ,') '.: ,r IA I' ".II"A,' j ~(~, (IJ,I_, ) ,J',\ t"¡, '(':' i1' , ~ ., I, I ¡ <.r pj\l~~nl~\ll'C'r[':.; ..... ",of",.1 /" h\ G-2. 1lm,] II-I, @ J 056{)1 w 108221 C~~lr'~1t l0515'nn" ~ 10706' WUvI FiH 107%' W'L:M - 108221 r>1L Ccm~~nt lOS2'2! nn, - 10832' DIL J ~,II.I~~tl J Y¡:rr~ H-2 thru I(.-1 (i~ lOR··IO' ~ 11145' TQP oCHIl @ 1120 II Dll \ \ \ , \ fl~',t I~CV: J(m" 11.129,f97 x: ~ ~J(~ ~,~)<;~ "~?' .::::~- ...~ 1 ~ ''h I ".. ., " JW L~:J'~ .~ ~) / '"''''''1 .~_.... -=:-:_. .1- --.- - .:."';'_.-:.~-:.....-.::: ..!.II\I- 1-''':-:'': '~~;~~: "Io,,~ ,/"J' ".", ... '~''''\I\ YI :;-.. ---.-." J -~"'- () 0'" Ö'-'û- v 0 --,-.() 00 0 0 0 _.Q...9-.~? 0 r~ ()Q.s.P~,~ '-... _.." .........:...1-- ...... "" "'"' ',,: ~, ',,- --:~ ) -: "" .J \. _1.'..,.....-.....·-""'" _--'_ o (~O o-öï5(,) 0 (,¡ - ~ .S~ _~:::."~~:~~~, ...........,-.- "... -'---- 1......:.:....___.... " .-- .....~:=-- r-:--;::-- "---'-'- ('::'-' A--2~-:',~,~;' ) _~_~- ~It.. TD ::: ] 1352' ~ 13·3/8'" ó I H 0 J~55. HTC Casing @2055' x Top 017' Liner @ 7167' .., 9-5/8'\ 47#, N~80. Bull Csg @ 7370' Büker Moud flu P~1('k~I' @ 9ì.Où' WireIj,tlc Re-Enl¡y Guide @ 9227' Cut 2-3/8" Coil T1.1bging @ 10110' Jllnk SC2-P A H Packer & Tail PipG @ 1 03~ 51 Bridge P!ug @ 10387' Î-~7/8" Cut Tubing @ 104061 B:1ker 80-40 l,ocalor w/4.00Q" X 3.00011 st;al USi:ìY (10' long) @ 10430' Bn"ker FR-] Packer wilD' SHE, bell guide (4,00" lD) @ 10431' Ilalr-cut Mute Slll)t; @ 105011 ID = 2,40611 lbru-T1.1biug Bridge Plug @ 10832' 7",29#, N-80. BTC Liner @ 11341' ~ ) ~ ~ Marathon·i \atRATHO~) Oil Company Alaska Asset Team ) Northern Business Unit P.o. Box 196168 Anchorage, AK 99519-6168 Telephone 907-561-6311 Fax 907-565-3076 October 10, 2005 F"""" .f='" .":", r-~' . r') ....'*' ~ ~~~'~t:,5,.15~Lf. . ~~ ,-;,,:) ..::; .:J Mr. Mark Myers, Director State of Alaska, Dept. Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 800 Anchorage, AK 99501-3560 VIA COURIER Re: North Trading Bay Unit Thirty-third Plan of Development and Operations ~ r', \~ r~ \ 'Iv ""\- \ CLU -\- \ e: Dear Mr. Myers: Marathon Oil Company, as the Operator of the North Trading Bay Unit (NTBU), submits the Thirty- third Plan of Development and Operations in compliance with Article 10 of the North Trading Bay Unit Agreement. This plan is for the period January 1,2006 through December 31,2006, and includes both the Basal-F/Upper-G gas sands and the G-Zone/Hemlock oil reservoir. Marathon Oil Company is Operator of the facilities used to develop the NTBU oil and gas reseNes. The facilities include the Spark Platform, Spurr Platform (formerly Texaco "An) and the Granite Point Production Facility (GPPF). Spark Platform oil production was shut-in on Jahüary 26, 1992. Spurr Platform oil production was shut-in on July 16, 1992. The Granite Point Production Facility has been inactive since the shut-in of all oil production (July 16, 1992). The NTBU was operating under a Suspension of Production approved through December 31, 2003. Gas production from well S-2rd resumed in July 2003 as Marathon advised in a letter dated September 12, 2003. L.-. \~.'-\ ~ 0 è} ~ S" 0-- " ~ ~ -- d- a l\~ d- - 0 \ OPERATIONS COMPLETED UNDER PRIOR PLAN (32nd PLAN) 1. The surface facilities on Spark platform were modified to accommodate remote operations and the installation of dehydration facilities. Dehydration facilities were installed by November 2004 and production was re-established. 2. The S-2rd wellbore was returned to production in November 2004. After a few shut downs for facility adjustments, the well produced continually from February to September 2005. The average rate during that time was approximately 1.9 MMSCFD with a FTP of 1 ,000 psig and 353 BWPD. Production ceased in September due to water loading problems. Attempts will be made to re-establish production during the remainder of Year 2005. Produced gas is sold into the CIGGS system and produced water is re-injected into Well #S-5 (010 #15). '--1 \(Q~-C)~~ 50 -~ ~ ~ -d-C~)\ <6'<0 ~- oC) ~ANNED OCT 3 1 2005 North Trading Bay Unit '''' 33rd Plan of Development and ( )ations October 1 2005 Page 2 ) THIRTY-THIRD PLAN OF PRODUCTION AND OPERATIONS ANTICIPATED ACTIVITIES 1. The Plan shall be effective from January 1,2006 through December 31,2006. 2. Upon evaluation of the recent production data, a workover of the S-2rd to set a bride plug will be considered. The purpose of the workover will be to shut off zones that are believed to be high water producing intervals. 3. No developmental drilling is planned. 4. No platform abandonments or permanent well abandonments are planned. 5. Reservoir engineering studies will be furthered. The purpose of these studies are to understand the source of water production from Well #S-2rd, determine possible remedies, review remaining recoverable hydrocarbon volumes, and evaluate economic impact of the work proposed. NTBU S-02RD MCF S-051 BW Injected 73,830 Production Period 1/1/05 thru 08/31/05 395,979 Marathon and its working interest partner, Unocal, are committed to finding the most economic means to maximize recovery of NTBU gas reserves in a timely manner. Marathon Oil Company, as Unit Operator, reseNes the right to modify or supplement this Plan of Development and Operations. No changes will be made without the ADNR's approval. Marathon's contact is Clyde Scott, 713-296-2336. Sincere~ ~. Barnes ~ Alaska Asset Team Leader n :\callups\NTBU _33POD .DOC Via Courier cc: C. M. Scott. Marathon John Zager, Unocal Winton Aubert, AOGCC, CEF 811.1b ~.ïf\Kl\...ïK.D':'':'U~C 1 C':' 1 VO"::'VV.J pi v;:' LU.l\.I;:' I have changed the separator pressure and set point numbers. I think this is how the report should be. Do you agree?? Tom Content-Type: application/msexcel 1_SPARKPRESSURETEST082003 pres LG.xls Content-Encoding: base64 Re: Spark SCSSV safety checks Hi Wayne, This report should be sent to Bob Fleckenstein as well. From what I understand, the type of well should be gas (the entry says WAG which is an injection well). The MIT may be working its way throughout the processing. Our engineering commissioner is out of town right now and the report form might be on his desk. With regard to the actual SSSV test. You note that the separator pressure is 2900 psi, but your set point is 3400 psi and the trip was at 800 psi. Do you have both a HP and LP pilot on the well?? My understanding of the passing criteria for a LP pilot is that the pilot should trip atnot less than 50% of the primary separator pressure or 25% of the flowing tubing pressure which ever is greater. It would appear that the trip pressure does not meet this criteria. Give me a call and we can discuss. Tom "Cissell, Wayne E." wrote: Tom, I have attached the form that Don Eynon had sent to me. I filled it out and did not know if I need to do anything else but e-mail the results to you. If there is anything else I need to do for documentation please let me know. I have not seen anything on the MIT that Jeff and myself had done earlier on the Spark. Thanks again. Wayne «SPARKPRESSURETEST082003 pres LG.xls» \Vay11C C:isscll 'Neci sse! l(?DMarathonoí I. com ~t'-~~ '1 ..{)ì ~ ~~ {)to ~~~ Page 1 of]2_SPARKPRESSURETEST082003 pres LG.xls wee 8/1/2003 Remarks: 0.00% D 90 Dc Failure Rate: o 3 Failures: Components: Wells: Test Code p Test Code p Test Code p LIP Trip 800 Set PSI 800 Well Permit Separ Number ~umber PSI S-2RD 74-24 1000 GINJ, GAS, Date Tested and or Passed Retest or SI \Yayne Cissell Date: 8/1/2003 North Trading Bay Unit! Spark Platfonn LPS 800 HPS 3400 Marathon Oil Cor8ubmitted By: Wayne Cissell FieldlUnitlPad: N/A Separator psi: Operator: perator Rep: OGCC Rep: A!o..."...(a Oil and Gas Conservation Comm\..-lon Safety Valve System Test Report g:\cmn\drlg\kgflwells\ku14-321\Spark_S20720031.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Stimulate__ Plugging__ Perforate Pull Tubing Alter Casing Repair Well Other X 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 2606 FNL, 2492' FEL, Sec 26-10N-13W, S.M. At top of Productive Interval 326' FNL, 259' FWL, Sec 35-10N-13W, S.M. @ 10050' MD At Effective Depth At Total Depth 1507' FNL, 221' FEL, Sec 34-10N-13W, S.M. @ 11353' MD 5. Type of Well: Development X Exploratory Stratigraphic Service 6. Datum Elevation (DF or KB) 115' KB above MSL feet 7. Unit or Property Name North Trading Bay Unit 8. Well Number S-2 RD 9. Permit Number 74-24 10. APl Number 50-733-20172-01 11. Field/Pool G-Zone (Tyonek) 12. Present Well Condition Summary Total Depth: measured true vertical Effective Depth: measured true vertical 11352' feet Plugs (measured) 10132' feet 11300' feet Junk (measured) 10090' feet 10515'- 10737' DIL (cement) 10832' DIL (throughtubing bridgeplug) 10387' DIL (bridgeplug) Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: Length Size Cemented Measured Depth True Vertical Depth 2055 13 3/8" 2000sx 2055' 1926' Tubing (size, grade, and measured depth) 2 3/8", 3.215#, coiled tubing, precision HS-70, 2.107"1.D., set at 9227' MD Packers and SSSV (type and measured depth) Baker HB packer @ 9200' MD Camco TRDP-4A SCSSV @ 593' MD Comments: 7370 9 5/8" 1000sx 7370' 6827' 4174' 7" 1175sx 11341' 10123' measured · 9580' 9550', 9623'-9633', 9650'-9665', 9772'-9787', 9852'-9867', 9925'-9940', 9984'-9994', 10050'-10090' true vertical 8722'-8730', 8758'-8766', 8780'-8792', 8881'-8893', 8947'-8960', 9008'-9021', 9057'-9066', 9071'-9087' We started the well production on 7-18.2003. The rate was at 2.8 MMCFD and dropped back to 1.3 MMCFD after 5 hOurs on" production. The well flowed for 4 days and was shut in on 7-'14-2003. We plan to reestablish the well to production on Monday the 21st of July. The well produced 1'100 BBLs of water during this flow period. 14. Oil~Bbl Representative Daily Average Production or Iniection Data Gas-Mcf Water-Bbl Casing Pressure Prior to Well Operation 0 0 Subsequent to Operation 0 0 Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of Well Classification as: Oil Gas X Suspended__ Service 17. I hereby certify t,h, at the foregoing is true and correct to the best of my knowledge. Signed ~ Title Production Engineering Technician Form 10-404 Rev. 06,15,88 ORIGINAL Date 7/25/2003 Submit in Duplicate Marathon Oil Company May 8, 1998 Alaska Reu,O,~ Domestic Production P.O. Box 196168 Anchorage, AK 9,9519-6168 Telephone 907/561-5311 ! Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK '99513-7599 Reference: Spark $-2rd Dear Mr. Wondzell: Marathon Oil Company requests that Rule 4 of Disposal Injection Order No. 13 for well S-4 in the NTBU be revised to allow for annual average daily disposal rates of 200 bbls/day. The increase in water production from well S-2rd following perforating was unexpected, and the existing allowable disposal rate of 5 bbls/day is inadequate to produce well S-2rd effectively. The attached report by Gary Eller shows that: The S-4 disposa/well is easily handling the increased water volumes. Increasing the allowable disposal rate to 200 bbls/day will not allow fluids to escape from the disposal zone. Without increasing the disposal rate in well S-4, it is likely that reserve recovery from well S-2rd will be greatly diminished. It is likely that water production from well S-2rd will continue to decrease if the well is continuously produced. There is Iow probability of success and nominal economic justification in attempting remedial squeeze work in well S-2rd. At current production rates, well S-2rd will have to be shut-in within seven days to keep from exceeding the 5 bbl/day average disposal allowable. Crossflow of water during a shut-in will be detrimental to the producibility of well S-2rd. Since any shut-in of well S-2rd threatens the recovery of reserves from that well, Marathon requests that this matter be acted upon quickly by the Oil & Gas Commission. Sincerely, W. C. Barron Operations Superintendent JGE/nrs H :\WI~OPNS98~JGE58 Attachments A subsidiary of USX Corporation Environmentally aware for the long run. INTRA COMPANY CORRESPONDENCE TO: W.C. Ban'on DATE: OFFICE: Anchorage, Alaska FROM: SUBJECT: Spark S-2rd Water Production OFFICE: May6, 1998 ~,\ J.G. Eller~~ .~ Anchorage, ~ Well S-2rd in the NTBU has shown a large increase in water production since being returned to production May 1, 1998. The likely source is one of the seven sand bodies that were perforated for production in late November1997. The annular disposal well S-4 has had no difficulty keeping up with the increase in water production. However, the AOGCC disposal limitation of 5 bbls/day threatens reserve recovery in well S-2rd. I recommend that we ask the AOGCC to increase the allowed average annual injection volume to 200 bbls/day. The test of May 4 showed that well S-2rd made 104 bbl of water and 3,619 MCF in 24 hours. The well has produced nearly 700 bbl of water since being returned to production on May 1. Compare this with it's average rate of 2 bbls/day and 4,038 MCFD in mid February when the well was last produced consistently. The most plausible scenario for the increased water is that during March and April, while S-2rd was shut-in, water crossflowed from one of the newly opened sands into a partially depleted, high permeability sand. This is supported by the generally improving water ratio as the well continues to produce. As this high permeability sand unloads, it's likely that produced water volumes will continue to drop. But in the future it will be necessary to keep well S-2rd online as much as possible to assist the well in cleaning up and to prevent water from accumulating again. The annular disposal well S-4 has had no difficulty keeping up with the increase in water production. Current injection pressure is approximately 450 psig, and shut-in pressure on the disposal well was approximately 220 psig before well S-2rd was brought back online. The allowable disposal volume in well S-4 should be .increased immediately, or production from well S-2rd will be threatened. AOGCC Disposal Injection Order No. 13 stipulates that the average daily disposal rate shall not exceed 5 bbls/day, which equates to 1,825 bbls/year. As of May 7, we have disposed of 915 bbls in well S-4 in 1998. Unless the AOGCC's order is changed, the injection limitation on well S-4 will soon cause us to have to shut-in well S-2rd. This will likely have a detrimental effect on the ultimate recovery of gas reserves from well S-2rd because of flooding-out of productive zones and limiting producing time. I do not recommend asking for an increase in the current allowed 300 bbls/day maximum injection rate. That will assure that we do not hydraulically fracture out of zone, as per the findings in Disposal Order No. 13. Spark S-2rd Water Production May 7, 1998 Page 2 Remedial action to reduce the amount of produced water from well S-2rd will be difficult and expensive, and is possibly not economically justifiable. The well is completed with 2%" tubing inside 7", 29 ppf casing. The first step would be to determine which sand(s) is producing the water, which could be a tricky evaluation given that crossflow into gas productive zones is probable. Shutting offthe water source would entail mobilizing 1½" coil tubing and performing a cement or gel squeeze. It's likely that a squeeze will have to be performed more than once given the number of open sands and likelihood of crossflow in the wellbore. Adding greatly to the complexity and cost of the operation is the condition of the Spark Platform itself, which has no facilities to store completion fluid, no fresh water source, minimal crew facilities, etc. I would use $300,000 to $400,000 as a first-look estimate for the cost of shutting off.the water in well S-2rd. Conclusions & Recommendations . . . . . All indications to date show that the disposal well is handling the increased water volumes just fine. The injection pressure is where we expect it to be given recent injection history. There is no reason to believe that an increase in water disposal volumes in the annulus of well S-4 will cause future problems. I expect the produced water volumes will continue to fall if we consistently produce well S-2rd. Remedial action to shut off.the water in well S-2rd will be expensive and difficult to perform, and economic incentive is low. Without increasing the allowable injection rate in well S-4 or shutting off. the source of water, the recovery of reserves from well S-2rd will be greatly diminished. I recommend that we ask the AOGCC to increase the annual average permissible injection volume from 5 bbls/day to 200 bbls/day. I would leave the peak permissible injection rate at its current 300 bbls/day maximum. If approval is given to inject more water, I recommend that we keep well S-2rd online continually to prevent water accumulation in high perm sands. Attachments c: Lyndon Ibele Spark S-2rd 1998 Daily Production 12,000 50.00 10,000 ~ 8,000 6,ooo t 4,000 2,000 1-Jan-98 31-Jan-98 Gas Volume Water Content 2-Mar-98 2-Apr-98 2-May-98 45.00 40.00 35.00 30.00 25.00 20.00 15.00 10.00 5.00 5/8/98, 12:31 PM Well S-2rd, Spark Platform, NTBU Gas Date MCF 1-Jan-98 4,616 2-Jan-98 9,990 3-Jan-98 11,385 4-Jan-98 11,148 5-Jan-98 11,281 6-Jan-98 7,462 7-Jan-98 30 8-Jan-98 616 9-Jan-98 1,529 10-Jan-98 1,598 11-Jan-98 1,745 12-Jan-98 666 13-Jan-98 225 14-Jan-98 298 15-Jan-98 0 16-Jan-98 150 17-Jan-98 3,240 18-Jan-98 0 19-J a n-98 5,346 20-Jan-98 5,770 21 -Ja n-98 10,600 22-Jan-98 5,748 23-Jan-98 6,780 24-Jan-98 6,224 25-Jan-98 5,230 26-Jan-98 2,413 27-Jan-98 5,929 28-Jan-98 7,534 29-Ja n-98 4,130 30-Jan-98 6,117 31-Jan-98 3,632 1-Feb-98 3,700 2-Feb-98 1,586 3-Feb-98 1,897 4-Feb-98 1,920 5-Feb-98 1,944 6-Feb-98 2,237 7-Feb-98 5,234 8-Feb-98 5,286 9-Feb-98 5,263 10-Feb-98 4,711 11-Feb-98 4,726 12-Feb-98 4,726 13-Feb-98 4,514 14:Feb-98 3,704 15-Feb-98 4,343 16-Feb-98 1,628 17-Feb-98 2,725 Spark Well S-2rd 1998 Gas Water Production Water bbl 1.3 6 17 17 5 1 0.5 0.5 0.5 0.5 0.5 0.4 0.2 0.2 0 0 0 0 0 0 0 9.1 16.3 19 8 1.5 10.2 32.6 4 4 2 2 0 0 2 2 1 0 0 1.4 4.3 5 5 0 1 1.5 0.5 1 Water Ratio bbl/MMCF 0.28 0.60 1.49 1.52 0.44 0.13 16.67 0.81 0.33 0.31 0.29 0.60 0.89 0.67 . 1.58 2.40 3.05 1.53 0.62 1.72 4.33 0.97 0.65 0.55 0.54 1.04 1.03 '0.45 0.27 0.91 1.06 1.06 0.27 0.35 0.31 0.37 Page I Well S-2rd, Spark Platform, NTBU Gas Date MCF 18-Feb-98 0 19-Feb-98 500 20-Feb-98 166 21-Feb-98 0 22-Feb-98 0 23-Feb-98 3,166 24-Feb-98 5,071 25-Feb-98 4,372 26-Feb-98 2,980 27-Feb-98 0 28-Feb-98 0 1-Mar-98 0 2-Mar-98 0 3-Mar-98 4,388 4-Mar-98 4,388 5-Mar-98 0 6-Mar-98 0 7-Mar-98 0 8-Mar-98 945 9-Mar-98 0 10-Mar-98 0 11-Mar-98 0 12-Mar-98 0 13-Mar-98 0 14-Mar-98 10 15-Mar-98 0 16-Mar-98 0 17-Mar-98 0 18-Mar-98 0 19-Mar-98 0 20-Mar-98 0 21-Mar-98 0 23-Mar-98 0 24-Mar-98 0 25-Mar-98 790 26-Mar-98 0 27-Mar-98 0 28-Mar-98 0 29-Mar-98 0 30-Mar-98 0 31-Mar-98 0 1 -Apr-98 0 2-Apr-98 0 3-Apr-98 0 4-Apr-98 0 5-Apr-98 0 6-Apr-98 203 7-Apr-98 0 Spark Well S-2rd 1998 Gas Water Production Water bbl 0 0 0 0 '0 0 2 0 0 0 0 15 21 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Water Ratio bbI/MMCF . . 0.67 3.42 4.79 Page 2 Well S-2rd, Spark Platform, NTBU Gas Date 8-A 3r-98 9-A :)r-98 10-A 3r-98 11-A 3r-98 12-A 3r-98 13-A 3r-98 14-A 3r-98 15-A3r-98 16-A 3r-98 17-A 3r-98 18-A 3r-98 19-A 3r-98 20-A 3r-98 21-A 3r-98 22-A 3r-98 23-A 3r-98 24-A ~r-98 25-A )r-98 26-A 3r-98 27-A 3r-98 28-A 3r-98 29-A3r-98 30-A 3r-98 1-May-98 2-May-98 3-May-98 4-May-98 5-May-98 6-May-98 7-May-98 8-May-98 Total MCF 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 2 757 2091 2.651 3.619 3713 3 725 3 727 0 251,753 Spark Well S-2rd 1998 Gas Water Production Water bbl 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 37.3 99.2 99.1 104.3 118 119 116 0 915 Water Ratio bblIMMCF . 13.53 47.44 37.38 28.82 31.78 31.95 31.12 Page 3 North Trading Bay Unit Spark Platform, Well S-2rd Marathon Oil Co., Alaska Region FMC TC-IA-ENS-SPCL Tubing Hanger (~ 35' 3-1/8" 4SAM2-LH top x 2-3/8" EU b/Jttoinj Camco TRDP.4A SCSSV (~} 593' w/flow couplings ID = 1.875" Tubing String: 2-3/8", 3.215#, Coil tubing, Precision HS-70 CM, 60000# Yield ID = 2.107" Camco "X" Nipple (~ 9188' ID = 1.875" Cmnco "X" Nipple (q) 9217' ID = 1.875" Current Perforatiol(fl-1 !/16" strip gUlls, EJ-1TI, 0 deg) BF-1 9580'- 9590' TDT (4 spt; 11/22/97) BF-2 9623'- 9633' TDT (4 spt; 1-1/22/97) 9650'- 9665' TDT (4 spt; 11/22/97) UG-1 9772' - 9787' TDT (4 spt; 11/22/97) UG-2 9852' - 9867' TDT (4 spt; 11/22/97) UG-3 9925' - 9940' TDT (4 spf, 11/22/97) UG-4 9984' - 9994' TDT (4 spf, 11/22/97) UG-5 10050' - 10090' TDT (6 spf, 8/94) Plugged Perfs G-2 tlu'u H-1 (¢ 10560'- 10822' Cement 10515' DIL - 10796' WLM Fill 10796' WLM - 10822' DIL Cement 10822' DIL - 10832' DIL Plugged Perfs H-2 tlum H-4 (~ I0840'- 11145' Top of Fill (9 11201' DIL -- o '-'o--~-~' &~ 0 0 0 0 O0 0 0 0 TD= 11352' l 13-3/8", 61#, J-55, BTC Casing (L3~2055' Top of 7" Liner ((~ 7167' I~ 9-5/8", 47#, N-80, Butt Csg ((3, 7370' Baker Model I-ti3 Packer (q) 9200' Wireline Re-Entry Guide (~ 9227' Cut 2-3/8" Coil Tubging @ 10210' Junk SC2-PAH Packer & Tail Pipe (.q) 10345' Bridge Plug ((3 10387 2-7/8" Cut Tubing ((~ 10406' Baker 80-40 Locator w/4.000" x 3.000" seal assy (10' long) @ 10430' Baker FB-I Packer w/10' SBE, bell guide (4.00" ID) (~ 10431' Halt-cut Mule Shoe @ 1050 !' ID = 2.406" TN-u-Tubing Bridge Plug @ 10832' 7", 29#, N-80, BTC Lhler (£3 11341' Last Rev: JGE, 12/29/97 North Trading Bay Unit Spark Platform, Well S-4 Marathon Oil Co., Alaska Region Water Disposal Via 4-1/2" x 9-5/8" Annulus 11/28/97 Tubing: 4-1/2", 12.6#, N-80, Butt. 4" Camco KBM Gas Lift Mandrels (all dummied) 2489' 4715' 6531' 7909' 8694' 8231' 9798' Fish: 21'x 1-11/16" w/3.789" gauge ring (11/23/97) 3-1/2", 9.2#, N-80, Butt. Tubing 10093'- 10341' Plugged Perforations G-1 10126'- 10138' (4 spf) G-2 10149'- 1021Y (4 spf) G-3/4/5 10226'- 10337' (4 spt') Plugged Perforations H-I/2U 10356'- 10476' (4 spf) H-2L/3 10484'- 10553' (4 spf) H-3 10561'- 10592' (4 spt') TI)= 10770' SCSSV - Otis ball Valve (~ 269' lk 13-3/8", 61#, J-55, BTC Casing @ 2132' Tubing - Casing Per~ 4594'-4624' DII. 4654'-4684' DIL 5428'-5438' DIL 552Y-554Y DII. 5937'-5967' DII. Tubing Restriction Aroung GLM @ 9231' Tubing Bridge Plug@9245' Otis"XO"Sliding Sleeve(~10057' ID= 3.813" Baker Retrieva-D Packer @ 10341' Crossover (4-1/2" x 3-1/2") ~ 1009Y Portco "X" Nipple @ 10308' ID -- 2.750" Portco "X" Nipple @ 10341' ID = 2.750" BakerRetrieva-DPacker@ 10341' Otis"Q" Nipple@10364' ID= 2.635" 9-5/8", 47#, N-80, BTC Casing @ 10744' Last Rev.: JGE, 12/29/97 g:~crnn~drlg~spark~s-2rd\S2_404.XLS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Stimulate Plugging Perforate X Pull Tubing Alter Casing ... Repair Well Other 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 2606' FNL, 2492' FEL, Sec 26-10N-13W, S.M. At top of Productive Interval 326' FNL, 259' FWL, Sec 35-10N-13W, S.M. @ 10050' MD At Effective Depth At Total Depth 1507' FNL, 221' FEL, Sec 34-10N-13W, S.M. @ 11353' MD 5. Type of Well: Development X Exploratory .. Stratigraphic ~ Service 6. Datum Elevation (DF or KB) 115' KB above MSL feet 7. Unit or Property Name North Trading Bay Unit 8. Well Number S-2rd · 9.Permit Number 74-24 10. APl Number 50-- 733-20172-01 11. Field/Pool G-zone (Tyonek) 12. Present Well Condition Summary Total Depth: measured true vertical Effective Depth: measured true vertical 11352' feet Plugs (measured) 10132' feet 11300' feet Junk (measured) 10090' feet 10515'-10737' DIL (CEMENT) 10832' DIL (THROUGH TUBING BRIDGEPLUG) 10387' DIL (BRIDGEPLUG) ORIGINAl Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: Length Size Cemented Measured Depth True Vertical Depth 2055 13~3/8" 2000sx 2055' 1926' 7370 9-~8" 1000sx 7370' 6827' 4174 7" 1175sx 11341' 10123' measured 9580'-9590',9623'-9633', 9650'-9665', 9772'-9787', 9852'-9867', 9925'-9940', 998~-999~,10050-10090' true vertical 8722'-8730', 8758'-8766', 8780'-8792', 8881'-8893',8947'-8960',9008'-9021',9057'-9066',9071-9087' Tubing (size, grade, and measured depth) 2-3/8", 3.215~, Coiled Tubing, Precision HS-70, 2.107" ID, set at 9227' MD Packers and SSSV (type and measured depth) Baker HB packer @ 9200' MD Camco TRDP-4A scssv @ 593' MD RECEIVED DFC 16 1997 13. Stimulation or Cement Squeeze Summary Intervals Treated (measured) Added perfs 9580'-9590', 9623'-9633', 9650'-9665', 9772'-9787', 9852'-9867', 9925'-9940', 9984'-9994' TDT 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 8800 7 0 1 400 Subsequent to Operation 0 8800 7 0 2077 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of Well Classification as: Oil... Gas X Suspended__ Service 17. I here~,~ th~ Signed Form 10-404 Rev. 0611 8~ ~e foregoing is true ~t to the best of my knowledge. Title Production Engineer . Date 15-Dec-97 Submit in Duplicate ./ M,~RATHON OIL COMPANY DALLY WELL OPERATIONS REP~' PAGE 1 OF 1 DATE: 11/22/97 FI LL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: PROBLEMS: Day #2 Add perfs FIELD: N. Trading Bay Unit WELL #: Spark S-2rd TUBING: 2-3/8" CASING: TREE CONDITION: BENCHES OPEN: SUMMARY OF OPERATIONS 0600 1130 .2215 11/21/97 Helicopters unable to fly to Spark platform due to weather. 11/22/97 Fly to platform and finish RU. Test lubricator to 3,500 psig and lock out SCSSV. RIH w/1-11/16", 4 spf, 0° phase strip guns w/8 gm charges. SITP = 2,500 psig, SICP = 950 psig. Tie into TDT log of 9/94. Perforate as follows (four runs total): Interval Initial SITP Final SITP 9,984' - 9,994' TDT 2500 psig 2870 psig 9,925' - 9,940' TDT 2870 psig 2890 psig 9,852' - 9.867' TDT Guns did not fire 9,772' 9,~87' TDT 2890 psig 2900 psig 9,650' - 9,665' TDT 2900 psig 2990 psig 9,623' - 9,633' TDT 2990 psig 3080 psig 9,852' - 9,867' TDT 3030 psig 3090 psig 9,580'- 9,590' TDT 3090 psig 3100 psig POOH. Secure well, RD Schlumberger. Will move to well S-4 tomorrow. ---FINAL REPORT--- Vendor Equipment Daily Cost Cumulative Cost Schlumberger Electric line $19,900 $19,900 Helicopters $1,000 $2,000 APC Roustabouts $400 $1,600 Misc $500 $1,000 DALLY COST: $ 21,800 CUM: $ 28,800 REPORTED BY: J.G. Eller NARATHDN OIL CrqMPANY NORTH TRADING BAY UNIT SPARK PLATFORH WELL S-SRO COMPLETED 8/50/94 1 1 o o o All measurements ore RKO to %oD oF eQuqsmen.t Comole~ion String: ~-35' FblC "TC-iA-FN$-SPCL" TDg Hgr 3-1/8" 4SAM2-LH to~ x 2-3/8" Ed bO~om 585' 2-5/8" 4 7~ EU Pup 587' 2-3/8" Flow Couolina 593' C~mco 'TRDP-4A' ~C~'/ (1.875' Bore) 601' 2-3/8" 4.7~ EU Pup 2,055' 13-5/8°, 6lin, J-55 Butt C$g Tubing 0'-9,227' 2-3/~', 3.215"-, Coite0i Tulo;ng ProotuC.t,on S.trlng, Precision HS-70 CH, 2.]07' I.D.. 66,000" Yieto 7.167' Top of Liner Winolow Mitred 'to 7,370 in 9-5/S', 471~. N-SO But.t Csg. 9.188' 9,200' 9,217' 9.227' Camco 'x' N~ppie (1.875" 8ore) Baker HB Packer Camco 'X' NiDole (1.875" Bore) Wiretine Entry Guide 10.210' 10,345' Cut 2-3/8" Coiled Tubing Junk SC2-PAH Porn<er and Toil Pipe 10,,387' Bridge Plug 10,406' 2-7/8" Tubing Cut 10,4.30' Baker "80-40" Locator, w/ 4.00" x .3.00" Seal Assy. (10' Long} 10,431' (10,486' DIL) B~ker 'r.:-I P~c~er w/ lO' SBE. Bell Gu,de (4.00' I.D.) Two Jts. Tbg. w/ sp. ct. cptgs., P.44]' I.D. 10,501' 10,515' DIL TOC PLUGGED PERFORATIONS (DIL) 0-2 Thru H-1 10,560' - 10,822' I0,796' WLM Fill Togged 9/22/89 10,822' DtL TOC 10,8.32' OIL Thru-Tbg. B.P. PLUG(~ED PEPFDRAT[DNS H-2 Thru H-4 10.840' - 11.14~' Boker Hot?-Cut Mute Shoe, 2,406' 11,201' DIL Too of Fill 2/4/87 PBTD = ]1,300' TI) : 11,352' ]].34]' 7', Pg#, N-80 Butt Cs_..3. Line," Revision Dote: 9/27/94 Revised By. dCM/eva Reason' New Completion Previous Revision: 9/14/94 SENT BY:Narathon 0tl Company '11- 4-97 'lO:09gbt ' Anchora~e~ - ,. 007 276 7542'# STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon~ Suspen~l ~ Operation Shutdown .--. Re-enter Suspend~l Well Alter Casing ~ Repair Well__ Plugging ~ Time F..xten=ion ~ Stimulate_... Change Approved Program __ Pull Tubing ~ Variance Perforate X Other..__ Z. Name of Operator ........... $. Typ~i'~ ~elii .... ~, Datum Eleva~ion (OF or'kB) MARATHON OIL COMP^HY Development ~X 1 lS' KB alx~m M6L feet 3. Address Exploratory__ 7.' Unit Or Property Name P. O. Box 196168, Anchorape. Al< 9~iD-ele8 Slratigraphle__ North Trading pay UniL 4. Loc,~ion of Well at Surface ....... Service 8. Welt Number ~:_ 2606' FN[, 2492' FEL. SaG 28-10N-13W, $.M. S-2rd IIII At top of Productive Interval g. Permit Number 326' FHL, 259' FWL, $~ 35-10H-13W, $,M. ~ 10050' MD 74-24 -- i I I II ,Al Effective Depth lO. APl Number ' ' 50- 733-20172-01 i · At Total Depth ~ ~, Field/Pool 1607 FNL. 221' FEL, Oeo 34-10N-lOW, S.M. { 113,53' MD g-=one (Tyonek) iiiiii 1~. Present Well Condition ,Summary Total Depth: measured 11352' feet Plugs (measured) 10515'-10737' DIL (CEMENT) tru, vertical 10132 feet 1083Z DIL (THROUGH TUBING BRIDOEPLU~) f 0387' DIL (BRIDGI=PLU6) Effective Depth: measured 11300' feet Junk (measured) true vertical 100Off feet Casing Length Size Cemented Measured Depth True Vertioal Depth Conductor Surface 2055 13-3/~" Z000r, x 2055' 1 Intermediate Produotion 7370 9-,5/8" 1000~x 7370' 6827' Liner 4174 1" 1175~ 11341' 10123' Perforation Depth: measured 10050-10090' .. " true vertical Tubing {size, grade, andgmOTm 'aa-L0~m~7"d depth)ORIGINAL 2-3/8". 3.2~5~, Coiled Tubing, Precisioo H$-70, 2.107' ID, ~iet at 9227' MD P~¢kars and $88V (typ, and measur,d de,h) Baker HB packer ~ 9200' MI:) Camco TRDP-aA $c~v ~ 593' MD 13· Attachments ....... Description SUmmary of Proposal .., Detailed Oper~io~ program .... BOP Sketol~ ...... --. ,...... , , , , 14, E,timeted Date for Oommencln~l Operatlo~ l~i, StatU$'~ Well Clas~ifl~atlon as: .......... 15. If Proposal wa~ VeCeelly Approved OI!__ G~,$ X. Suspended N~me of Approver Date Approved Service ..................... ~?. I h~reby ceftin, that/hq fOrel;Iolng I, true and correct ~ the be,t of my knowledge. /' N ................ \ .... ~'~O,~m~o. u~ o.~Y Plug Integrity...._. BOP Test ~ Location ck, amnee._.~, A9~ IV~hanlcet Integrity T~t~ Sul~equent F(N?T~ RequiTed lO- Original Signe~ By ' w. SENT BY:~tarathon Oil Company :11- 4-97 :IO:09A1VI ; Anchorage~ 907 276 7~42:# 4/ 9 SPARK PLATFORM, WELL S-2RD TRADING BAY FIELD ADD PERFORATIONS IN BF-1,2 & UG-1,2,3,4 Obieetive: Add perforations in the BF-1,2 & UG-1,2,3,4 Sands Procedure: 1. M1RU electric line. Test lubricator to 4,000 psig. Lock out SCSSV. 2. K1H w/OR/CCL to 10,050' MD. Tie in and run strip log. 3. KIH w/1-11/16", 4 spf, ±45° strip guns and perforate as follows: 9582'-9592' DIL 9625'-9635' DIL 9652'-9667' DIL 9775'-9790' DIL 9855'-9870'DII, 9928'-9943' DIL 9988'-9998' DIL (10', BF-1 Sand) (10', BF-2 Sand) (15', BF-2 Sand) (15', UG-I Sand) 5', UG-2 Sand) (15', UG-3 Sand) 0', UO-4 Sand) 4. RDMO electric line. Produce well as per Production Foreman. /GE October 29, 1997 {';:~,MN~I-)R ! .G\.~PAR TG.%2R D\AY}I")PI;.Rb'.~. SENT BY:Marathon Oil Company :11-4-97 :lO:09AI~ : Anchorage~ MARATHON ElL CCMPANY N~R'TH TRADIN~ BAY UNI1 SPARK PLATFORM WELL S-2RD 907 276 7542;# COMPLETED ~55' FMC "TC-IA-ENS-SPCL" Tbg Hqr. 3-1/~" 4SA~2-I.t4 top x 2-3/8" Et.I bottom 585' 7-~/~" 4.7~ [U Pup 587' 2-3/8" Flow Couolin(~ 2-5/8" 4.7~ EU Pup ~,055' 13..-5/I..'~', Gl.u, J-$b Bu'l;t Czg. Tubina :'-9,P. 27' 3,21511. Coite:l l ublng Prn~luCt:;On $'tr'ing, P~"ecision HS-70 CH, 8.107' [.~l., 66,0(1(1.~ YiF.,'ld 7,167' Top of liner W ndo~" M~tl~,et 'tn 7,370 ;n 9-5/8' 47~, N-80 ~utt 9,188' Camco 'X' Nipole ('1.875" Bore) ... 9,200' Baker HB Pecker' . , , .' 9,217' Camco 'X' NipDIc (~.B75" Bore) g,22'Z' Wtreiine Entry 6uide ~ " . . · .: .... = B/50/04 TDT LOg) UG-5 I0,050' - 10.090' 40' (I-I1/1G", Edr, I, 6SPF, O Deg, Phased) 10,2!0' Cut 2-5/8" Coiled Tubin9 10,345' Junk SC2-PAN Packer ~na Toil Pipe ]0,387' Bridge Plu~ 10,406' z-7/a" Tubin~ Cut 10.430' Baker "80-40" Lace[or, w/ 4,00" x 3,00" Seal Assy. (10' 1~,4~41' (I~.47G' /1~1 ) B6k~r 'FB.I PacRer w/ 10' S~E, Boil Guide (4,00' I.D.) Two J~. Tb9. w/ ~p. Cl. cPt95., ~.441' 10,515' OIL TOC ~LUGGED PERFDRATIDNS G-2 Thr[, H-1 10,560' - 10,822' 10,796' WLM F~II Tnqg~¢ 9/22/89 10,~22' DIL TOC 10,832' DIL Thru-~g. PLUGGED PFEFR~ATIDN~ H-Z Thru H-4 ~0,840' - Raw,ion ~t~,, 9/27/94 1~,201' DIL Top of Fill 2/4/87 ~,vi~eM By: JOM/evo Re~sO~ New Completion T3 ~ 11,35E' /" %- 11,341' 7'. ~9~, N-BO ~uft Czg. Line,- SENT BY:Marathon Oil Company '11- 4-97 'lO'08Abl · Anchorage~ Alaska Hegion Domestic Production 907 276 7.542;# 2/ 9 Marathon Oil Company P.O. Box lg6168 Anchorage, AK 99519-6168 Telephone 907/5§ 1-5311 November 4, 1997 · Mr. Blair Wondzeil Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99513-7599 Reference: North Trading Bay Unit, Spark Platform, Well S-2rd Dear Mr. Wondzell: Please find attached a procedure for adding perforations in well S-2rd in the North Trading Bay Unit. This work is expected to commence sometime in November 1997. Please contact me if further information is needed. Sincerely, j~.~l~pr~cti r~on Engineer H:~WI~OPI~Ib'ff/~IOliDI 141. A subsidiary of USX Corporation Environmentally aware for the long run. ... , ,,"""~ STATE OF ALASKA ~ ALAS,: OIL AND GAS CONSERVATION COMM,. ;ON ~---','[~ . GAS WELL OPEN FLOW POTENTIAL TEST REPORT.........~ , /,'~ON STABILIZED la. TEST: ANNUALINITIAL r__X lb. MULTIPOINTTYpE TEST CONSTANT TIME SPECIAL OTHER ( ISOCHRONAL 2. Name of Operator 7. Pe~i~LNm'""~ Marathon Oil Company 3. Address 8. AP~ 3201 C Street, Ste. 800, Anchorage, Alaska 99503-3934 50- 733-20172-01 4. Location of Well 9. Unit or Lease Name At surface North Trading Bay Unit Leg 3 Cond. ~4 Spark Platform 10. Well Number 2606' FNL, 2492' FWL S-2RD Section 26, T10N, R13W, S.M. 11. Field and Pool G-Zone (Tyonek) 5. Elevation in feet (KB, DF etc.) 16. Lease Designation and Serial No. 115' KB above MSLI ADL-18776 12. Completion Date 113. Total Depth 114. Plugback T.D. 115. Type Completion (Describe) 7/94 11353 MD 10,387MD (BP) Single tbg. string/cased hole 16. Csg. Size Weight per foot, lb. I.D. in inches Set at ft. Perforations: From To 7 29 6.184 7167 10,050 10,090 17. Tbg. Size Weight per foot, lb. I.D. in inches Set at ft. 2.375" CT 3.215 2.107 9227 18. Packer set at ft. 119. GOR cf/bbl. 120. APl Liquid Hydrocarbons 21. Specific Gravity Flowing fluid (G) 9200I ....I 0.6047 22. Producing thru: Reservoir Temp. °F. Mean Annual Temp. °F. Barometric Pressure (Pa), psia Tbg. [~ Csg.~ 170 33 14.73 23. Length offlow channel (L)9227 I Vertical Depth (")18390 Ga. %c°'10.216 % H2S I Pr°ver Meter rani Taps0 X 24. Flow Data Tubing Data Casing Data Choke Prover Orifice Line Size X Size Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. (in.) (in.) psig hw °F. psig °F. psig °F. Hr. 1. 3 X 45/64 450 80 80 1768 66.8 .... 6.117 2. 3 X 41/64 300 57 90 2243 71.0 - -- 5.564 3. 3 X 39/64 240 43 88 2461 71.7 .... 4.947 4. 3 X 36/64 180 32 102 2567 71.6 .... 3.008 5. X Basic Coefficient ~ (24-Hour) hwPm Pressure Flow Temp. Factor Gravity Factor Super Comp. Factor Rate of Flow No. Fb or Fp Pm Ft Fg Fpv Q, Mcfd 1. 46.9 189.7 464.7 0.9831 1.286 1.0908 8,900 2. 52.8 130.8 314.7 0.9723 1.286 1.0894 6,900 3. 48.2 101.6 254.7 0.9741 1.286 1.0905 4,900 4. 47.4 75.9 194.7 0.9600 1.286 I 1.0793 3,600 5. Fig 3-30 GPSA Temperature for Separator Gas for Flowing Fluid No. Pr T Tr Z Gg G 1 .I 0.6641 540 1.419 0.8404 0.6047 2. ! 0.4427 550 1.445 0.8426 3. 0.3542 548 1.440 0.8409 Cdtical Pressure 677.58 4. 0.2656 562 1,477 0.8585 Critical Temperature 380.54 5. Form 10-421 Rev. 7-1-80 kz~AOGCCGAS.XLS CONTINUED ON REVERSE SIDE Submit in duplicate Pc 2,725 PC= 7,425,625 Pf Pf= 0 No. ' Pt '" Pi2 Pc= - Pt2''' Pw Pw2 i~c~ - Pw2 Ps Ps2 Pff -'Ps'~ '1. ' ~,768 3,125,824 4,299,801 ..... 0 '' 0 '' 2. 2,243 5,031,0~'9 "2,394,~'~6 '" _. "''_ "'' .. ' '0 ' ' 0 3. 2,461 6,056,521 "' 1,369',104 ...... ' ' 0 0 4. 2,567 6,589,489 836,136 '.'_ ' ~. '"'_. 0 ' 0 .......... 5. 0 0 25. AOF (Mcfd) 12,112 n 0.56123 Remarks: Test dates 8/31/94 to 9/1/94. Tests performed and recorded by Production Testing Services, Anchorage, AK (562-2044) 4-point analysis performed using surface data recorded by PTS. I hereby certify that the foregoing i~s ~e and correct to the best of my knowledge. DEFINITIONS OF SYMBOLS AOF Fb Fp Fg Fpv Ft G Gg GOR hw H L n Pa Pc Pf Pm Pr Ps Pt Pw Q Tr T Z Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia. Basic orifice factor Mcfd/ '~ hw/Pm Basic critical flow prover or positive choke factor Mcfd/psia Specific gravity factor, dimensionless Super compressibility factor = ~/ 1/Z dimensionless Flowing temperature factor, dimensionless Specific gravity of flowing fluid (air = 1.00), dimensionless Specific Gravity of separator gas (air=1.00), dimensionless Gas-oil ratio, cu. ft. of gas (14.65 psia and 60° F.) per barrel oil (60° F) Meter differential pressure, inches of water Vertical depth corresponding to L, feet (TVD) Length of flow channel, feet (MD) Exponent (slope) of back-pressure equiation, dimensionless Field barometric pressure, psia Shut-in wellhead pressure, psia Shut-in pressure at vertical depth H, psia Static presssure at point of gas measurement, psia Reduced pressure, dimensionless Flowing pressure at vertical depth H, psia Flowing wellhead pressure, psia Static column wellhead pressure corresponding to Pt, psia Rate of flow, Mcfd (14.65 psia and 60°F.) Reduced temperature, dimensionless Absolute temperature, degrees Rankin Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the MANUAL OF BACK-PRESSURE TESTING OF GAS WELLS, Interstate Oil Compact Commission, Oklahoma City, Oklahoma Form 10-421 Rev. 7-1-80 kz~AOGCCGAS. XLS CONTINUED ON REVERSE SIDE Submit in duplicate ,,.~.,,, STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMM. 41ON GAS WELL OPEN FLOW POTENTIAL TEST REPORT la. TEST: INITIAL X lb. TYPE TEST STABLILIZED NON STABILIZED ANNUAL MULTIPOINT X , CONSTANT TIME SPECIAL OTHER ISOCHRONAL 2. Name of Operator 7. Permit No. Marathon Oil Company 74-24 3. Address 8. APl Number 3201 C Street, Ste. 800, Anchorage, Alaska 99503-3934 50- 733-20172-01 4. Location of Well 9. Unit or Lease Name At surface North Trading Bay Unit Leg 3 Cond. #.4 Spark Platform 10. Well Number 2606' FNL, 2492' FWL S-2RD Section 26, T10N, R13W, S.M. 11. Field and Pool G-Zone (Tyonek) 5. Elevation in feet (KB. DF etc.) 16. Lease Designation and Serial No. 115' KB above MSLI ADL-18776 12. Completion Date 113. Total Depth 114. Plugback T.D- 115. Type Completion (Describe) 7/94 11353 MD 10,387MD (BP) Single tbg. string/cased hole 16. Csg. Size Weight per foot, lb. I.D. in inches Set at ft. Perforations: From To 7 29 6.184 7167 10,050 10,090 17. Tbg. Size Weight per foot, lb. I.D. in inches Set at ft. 2.375" CT 3.215 2.107 9227 18. Packer set at ft. 119. GOR cf/bbl. 120. APl Liquid Hydrocarbons 21. Specific Gravity Flowing fluid (G) 9200I -I -- 0.6047 22. Producing thru: Reservoir Temp. °F. Mean Annual Temp. °F. Barometric Pressure (Pa), psia Tbg. !X Csg. i 170 33 14.73 ,, 23. Length of flow channel (L)9227 I Vertical Depth (H)18390 Ga. 10.216 % H2S I Pr°ver0 Meter rani TapSx 24. Flow Data Tubing Data Casing Data Choke Prover Orifice Line Size X Size Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. (in.) (in.) psig hw °F. psig °F. psig °F. Hr. 1. 3 X 45~64 450 80 80 1768 66.8 - -- 6.117 2. 3 X 41/64 300 57 90 2243 71.0 - -- 5.564 3. 3 X 39~64 240 43 88 2461 71.7 - -- 4.947 4. 3 X 36/64 180 32 102 2567 71.6 - -- 3.008 5. X Basic Coefficient ~/ (24-Hour) hwPm Pressure Flow Temp. Factor Gravity Factor Super Comp. Factor Rate of Flow No. Fb or Fp Pm Ft Fg Fpv Q, Mcfd 1. 46.9 189.7 464.7 0.9831 1.286 1.0908 8,900 2. 52.8 130.8 314.7 0.9723 1.286 1.0894 6,900 3. 48.2 101.6 254.7 0.9741 1.286 1.0905 4,900 4. 47.4 75.9 194.7 0.9600 1.286 1.0793 3,600 5. Fig 3-30 GPSA Temperature for Separator Gas for Flowing Fluid No. Pr T Tr Z Gg G 1. 0.6641 540 1.419 0.8404 0.6047 2. 0.4427 550 1.445 0.8426 i 0.3542 548 1.440 0.8409 Cdtical Pressure 677.58 0,2050 562 1.477 0.8585 Critical Temperature 380.54 5. Form 10-421 Rev. 7-1-80 kz~AOGCCGAS.XLS CONTINUED ON REVERSE SIDE Submit in duplicate Pc 2,725 Pc~ 7,425,625 Pf Pf~ 0 No. Pt .... Pt' '" Pc~- PF Pw Pw' P~- PW2 'Ps PS" ' I~P'- Pi' i 1,768 3,125,824 4,~99,'8~1 - -- "' -- ' .... 0 '" 0 2. 2,243" 5,031,049 2,394,576 .... - ..... ' ..... 0 '0 ....... 3. 2,461 6,056,521 1,369,104 ...... 0 .... 0' " 4. 2,567 6,589,4~ 836,136 -~ " -- - "(~ ' 0 5. 0 0 25. AOF (Mcfd) 12,112 n 0.56123 , , Remarks: Test dates 8/31/94 to 9/1/94. Tests performed and recorded by Production Testing Services, Anchorage, AK (562-2044) 4-point analysis performed using surface data recorded by PTS. I hereby certify that the foregoing !~s t~e and correct to the best of my knowledge. Signed .~'"/_.~.~~ Title Reservoir Engineer Date 4/1/97 L~ndon C. Ib~l~ '" .... ,, DEFINITIONS OF SYMBOLS AOF Fb Fp Fg Fpv Ft G Gg GOR hw H L n Pa Pc Pf Pm Pr Ps Pt Pw Q Tr T Z Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia. Basic orifice factor Mcfd/ ~J hw/Pm Basic critical flow prover or positive choke factor Mcfd/psia Specific gravity factor, dimensionless Super compressibility factor = ~ I/Z dimensionless Flowing temperature factor, dimensionless Specific gravity of flowing fluid (air = 1.00), dimensionless Specific Gravity of separator gas (air=1.00), dimensionless Gas-oil ratio, cu. ft. of gas (14.65 psia and 60° F.) per barrel oil (60° F) Meter differential pressure, inches of water Vertical depth corresponding to L, feet (TVD) Length of flow channel, feet (MD) Exponent (slope) of back-pressure equiation, dimensionless Field barometric pressure, psia Shut-in wellhead pressure, psia Shut-in pressure at vertical depth H, psia Static presssure at point of gas measurement, psia Reduced pressure, dimensionless Flowing pressure at vertical depth H, psia Flowing wellhead pressure, psia Static column wellhead pressure corresponding to Pt, psia Rate of flow, Mcfd (14.65 psia and 60°F.) Reduced temperature, dimensionless Absolute temperature, degrees Rankin Compressibility factor, dimensionless 2 1997 Recommended procedures for tests and calculations may be found in the MANUAL OF BAC~PRESS~RE .T,E_ST, I.NG OF GAS WELLS, Interstate Oil Compact Commission, Oklahoma City, Oklahoma Ancl 0rage Form 10-421 Rev. 7-1-80 kz~AOGCCGAS.XLS CONTINUED ON REVERSE SIDE Submit in duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL~-~ GAS~ SUSPENDED~-~ ABANDONED~ SERVICEE~ 2. Name of Operator 7. Permit Number MARATHON OIL COMPANY 95-74 ,, 3. Address 8. APl Number P. O. Box 196168, Anchorage, AK 99519-6168 '.~- - 50-733-20172-01 4. Location of Well at Surface ~~ 9. Unit or Lease Name 2606' FNL, 2492' FEL, Sec. 26-10N-13W, S.M. ,,_~~~_., North Trading Bay Unit At top of Producing Interval i~Jl,l~ ' 10. Well Number 326' FNL, 259 FWL, Sec. 35-10N-13W, S.M. @ 10050' md ~~ S-2rd At Total Depth 11. Field and P0ol ' 1507' FNL, 221' FEL, Sec. 34-10N-13W, S.M. @ 11353' md G-Zone (Tyonek) , 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. 115' KB above MSLI ADL- 18776 12. Date Spuddedjune, 1994 13. Date T.D. Reachedjuly, 1994 14' Date C°mp" Susp' °r Aband' 115' Water Depth' if °ffshorejuly, 1994 ~ O" feet MSL 116' NO' °f c°mpleti°nsl 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey~ ~-] ]20. Depth whore SSSV sot 121. Thickness of Permafrost 11353'md/10132'tvd 10387'md/9354'tvd Yes ~ No ~_~ 593' feet MD N/A 22. Type Electric or Other Logs Run None 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 61# J-55 0' 2055' 17-1/2" 2000 SX 9-5/8" 47# N-80 0' 7370' 12-1/4" 1000 SX 7" 29~ N-80 7167' 11341' 8-1/2" 1175 SX 24. Perforations open to Production (MD'+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET IMD) 2-3/8" 9227' 9200' 10050-10090' md, 9071-9087' tvd, 6 spf, 1-11/16 E J3 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL US.ED 10560-10737' 15 bbls cement 2:~. PRODUCTION' TEST " Date First Production I Method of Operation (Flowing, gas lift, etc.) N/A I Flowin~l D'~te of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL cHoKE SIZE IGAS-OIL RATIO 8/31/94 22 TEST PERIOD --~ 5000 5 32-45" I Flow Tubing Casing Pressure iCALCULATED-- OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl ((~orr)" Press. 1620-2630 200-620psig 24-HOURRATE--~ 5580 6 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None APR 2 1997 41as Oil & 6as Cons. C0mmiss ,, ,, ~ nnF' ..... Form 10.407 i~'a§~mit in Triplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS Include interval tested, pressure data, all fluids recovered NAME MEAS. DEPTH TRUE VERT. DEPTH and gravity, GOR, and time of each phase. Basil "F" sands 9574' 9026' Upper "G" sands 9764' 9183' Test Interval: Upper G-5 10050' 9421' Perf 10050 - 10090', 8.9 mmscfpd, 1750 psig FWHP, 3398 psig SBHP 31. LIST OF ATTACHMENTS Operations Summary Report, Wellbore Diagram 32. I hereby certify that the foregoing is true and correct, o the best of my knowledge Signed.~ Title Production En~lineer Date 4/1/97 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.) Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other- explain. Form 10-407 H:\EXCEL\NRSFORMS~AOGCOMPL.XLW Operations Summary Report S-2rd Coiled Tubing Recompletion Sundry Approval No. 94-095, 94-130, and 94-178 S-2rd was recompleted from an oil producer to a gas producer. This work was performed June through August, 1994. The following is a brief summary of this work - Well was killed by bullheading FIW. - The G-zone was squeezed w/15 bbls of cement using 1-3/4" CT. Cement plug was tested to 2,500 psi. TOC at 10,515'. - Cut 2-7/8" tubing string at 10,406' and POOH using a hydraulic jacks. - Set BP ~ 10,387'. - Run 2-3/8" CT completion. Tubing was inadvertently cut, dropping completion to the bottom of the well. Left 135' of 2-3/8" CT, packer and tailpipe assembly on bottom. - Rerun 2-3/8" CT. Set packer at 9,200' w/tubing tail at 9,227'. - Perforate UG-5 zone from 10,050-10,090' w/1-11/16" EJ3 strip guns. - Perform multi-rate test using downhole gauges. - SI well pending installation of surface production equipment. :!~,i:~R 2 1997 Alaska 0il & (las Cons. Con]miss,,. Anchorage ~ARATHFIN F.,'iL CF1~PANY N,qRTH TRADII'X-"(BAY UNIT 'cPAP,,K PLATFORM X,/ELL COMPLETED 8/30/94- A(/ meo,sur'emen1:s ome RKO 'to zop of equiomen-~ Comptetion St~in9, FMC "TC-IA-ENS-SPCL" Tbs Hgr 5-!/8" ~SAM2-LH to~ x 2-5 '~" [U bolton: 585' 2-3/8" 4.7~ EU PuD 587' s-s/8" Fio~ Couplina 593' C~mco 'TRDP-4A' SCSSV (1.875' Bore., 601' 2-3/8" 4.7W EU Pup 2,055' i3-5/8' 61~,, J-55 Butt Csg. Tubinq 0'-9,227' 2-3/8", 3.215~, Coifed TuE4n9 Production ~xl:rin9. Precision HS-70 Ch1, 2.107' i.D., 66,000~ ¥ietct 7.16.7' Top of Liner Winolow Miti. ed 1:o 7,370 in 9-5/S', 47~. N-SO Butt Cscj 9,188' 9,200' 9.217' 9.227' Camco 'X' N~pple (1.875" Bore) Baker HB Packer Camco 'X' Nipple (1.875" Bore) Wireline Entrv Guide CURRI~NT PERFORATIONS (Ref. 8/30/94 TDT Log) UG-5 10.050' - 10.090' 40' (1-11/16", EJIll, 6SPF,0 Deg. Phased) 10,210' 10.345' Cut 2-3/8" Coiled Tubing Junk SC2-PAH Packer (]nd Toil Pipe 10,587' Bridae Plug 10,406' 2-7/8" Tubing Cut 10,430' Baker "80-40" Locotor. w/ 4.00" x 3.00" Seal Assy. (10' Long) 10,431' (10,4~'6' DIL) Bo,kef 'r~-I Po,c~<e,- w/ lO' S~E, Bert Ouioe (4.00' I.D.) Two Jts. Tb9. w/ sp. ct. cptgs., 2.441' I.D. 10,50]' 10,515' DIL TOC Pt. UGGED PERFORATIONS (OIL) 0-2 Thru H-I 10.560' - 10.822' 10,796' WLM Fill 'fagged 9/22/89 10.822' DtL TOC 10.832' DIL Thru-Tbcl. B.P. PLUGGED PERFORATIONS (OIL', Bo,kef Ho(F-Cu.t Mute Shoe, B.406' Thru H-4 t0.840' - 11,145' 11,201' DIL -fop of Fill 2/4/87 PBTD = 11,300' TD = 11,352' 11,341' 7', 29~. N-80 But% CsQ. Line,- Revision Do,to: 9/27/9= E:evised By; dCM/eva Rea, son: New Completion Previous Revision: 9/14/94 SE~NT BY'~larathon 011 Company '11-21-96 ' 2:47P~ ' Anchorage-~ Alaska Re0~on - ' Domestic Production. 907 276 7542'# 2/ 2 Marathon Oil Company William Van Dyke Division of Oil & Gas Department of Natural Resources Mr. Van Dyke, P.O, Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 On November20 at 8:45 am well S-2RD on the Spark Platform flowed gas as part of its commissioning process. Approximately 400 MCF was flowed on' that date. It is anticipated that additional testing will be done prior to commencing normal well operations. Gary Laughlin Marathon Oil Co. CC: Alaska Oil & Gas ConServation Commission Jack Hartz RECEIVED NOV 2 ] 19~t; Alaska 011 & !~as Cons. Commission Anchorage A subsidiary of USX Corporation Environmentally aware for the long run. MEMORANDU,..' State ot laska Alaska Oil and Gas Conservation Commission TO: · David John~~ Chairman DATE: July 5, 1994 THRU: Blair Wondzell, ~ P. I. Supervisor FROM: '{L"~u Grimaldi, SUBJECT: Petroleum Inspector FILE NO: AU9JGEBD.doc BOP Test Marathon Spark # S-2rd McArthur River Field PTD # 74-24 Sundry #94-095 .Thursday, June 30, 1994: I traveled to Marathon's Spark platform to witness the initial BOP test on the Dowell pulling rig which is being used in place of a conventional workover rig. The rig was not ready when I arrived. I made a cursory inspection of the BOPE equipment. The Choke manifold was tested with all valves passing. By this time the rest of the BOP equipment was ready to be tested. Due to a bad tubing hanger seal the BOP equipment had to be tested against the cement plug in the casing. Upon the initial pressure up the lock-down screws on the casing head started leaking and although numerous attempts were made to stop the leakage this necessitated bringing out a tree hand the following morning to service the casing head. .Friday, July. 1, 1994: After the tree hand replaced the packing on the holdown screws the Blind rams were tested, at this point a major mishap occurred, the Iockdown screws for the tubing hanger were left backed out and when the test pressure was bled off from the top of the tubing hanger a differential was drawn across it forcing it out of the seat. This was not discovered until the installation of the test joint was attempted several times with no success. Draining the stack revealed that the hanger had lodged itself in the area of the bottom set of rams at a 20 degree angle. A inspection through one of the Iockdown holes revealed that the tubing directly below the hanger had parted and fell down hole. After several attempts at moving the hanger from the top side it was decided to bring a fishing hand out. I returned home to await the outcome of the fishing job. Saturday, July.2, 1994: Approximately mid afternoon I received 'a call from John McMullen (Marathon Engnr.) informing me that they had been successful in retrieving the hanger and were standing by to test the pipe rams and annular preventer. I permitted him to test these without my presence after discussing the procedure with him. I spoke with Mr. McMullen later that day to check on their progress which he reported favorably. (Continuation of AU9J,~ '~BD. DOC page 2 of 2) Tuesday, July 5~ 1994: I returned this day to observe the tubing pulling operation. I found a impressive operation and see some future utilizing this type of equipment. Being that this was the fii'st job of this kind attempted in Alaska there were a few rough spots but these should be ironed out in time. The dedication and commitment of the personnel were at the highest level and the few suggestions I made were taken seriously and acted upon quickly. Summary: I witneSsed the Initial BOP test on the Dowell tu.b, ing pulling rig working over the S-2 well on Marathons Spark platform '~ Attachment: AU9JGEBD.XLS cc: Mark Sinclair (Marathon drlg supt.) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Workover: X Drlg Contractor: Dowell/Pool Arctic Operator: Marathon Well Name: S-2rd Casing Size: Set ~ Test: Initial X Weekly Rig No. Other DATE: I PTD # 74-24 Rig Ph.# Rep.: John McMullen Rig Rep.: Paul Bahr Location: Sec. T. R. 7/2/94 776-6551 Meridian Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) Reserve Pit N/AI Well Sign OK Drl. Rig OK BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Test Quan. Pressure P/F 1 250/2500 P* I 250/2500 P* 0 250/2500 I 250/2500 2 250/2500 I 250/2500 2 250/2500 N/A N/A N/A P P P P N/AI MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators N/A N/A Flow Indicator P P Gas Detectors P P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. 0 0 1 1 Pressure 250/2500 250/2500 250/2500 250/2500 P/F N/A N/A ,, P P CHOKE MANIFOLD: No. Valves 16 No. Flanges 38 Manual Chokes 2 Hydraulic Chokes I Test Pressure 250/2500 250/2500 P/F P P P P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 2 Blind Switch Covers: Master: Nitgn. Btl's: Four Bottles 2300 psi average 3,000 I 1,850 minutes 58 sec. minutes 15 sec. X Remote: X Psig. Number of Failures: 0 ,Test Time: 5 Hours. Number of valves tested 28 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659.3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Annular Preventer and Pipe rams not witnessewd by AOGCC. Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c- Inspector FI-021L (Rev. 2/93) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: WRnessed By: AU5JGEBD,XLS Louis R Grimaldi Alaska. ~ )n DomestiC r'roduction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 June 30, 1994 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 FAXED RE: Sundry 94-095 Spark Well S-2RD Recompletion Dear Mr. Wondzell: As a follow-up to our telephone conversation today, attached is a variance approval request for plugging regulation 20 AAC 25.105 (h) (1) for Spark Well S-2RD. Referring to the attached "Summary of Cement Plugback Operations," cement was placed June 19, 1994, the top of cement was tagged at 45 feet above the top perforation, and the plug was pressure tested to 2500 psi (3200 psi differential across plug) with 150 psi loss in 10 hours. To complete the plugging operation, Marathon requests approval to set a bridge plug at about 10,400' DIL, without additional cement. If you have any questions, please call me at 564-6550. Sincerely, J. C. McMullen Production Engineer JCM/cah Enclosures H:\wp\Sundry RECEIVED JUL - 1 1994 Alaska 0il & Gas Cons. Commission Anchorage A subsidiary of USX Corporation Environmentally aware for the long run. ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation shutdownm Re-enter suspended well Alter casing Repair well__ Plugging m Time extension Stimulate Change approved program X.X. Pull Tubing ~ Variance ~ Perforate ~ Other ~ 2. Name of Operator Marathon Oil Company 3. Address P. O. Box 196168 Anchorage, AK 99519 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 2606' FNL, 2492' *FEL, Sec. 26-10N-13W-SM At top of productive interval 701' FNL, 91' FWL, Sec. 35-10N-13W-SM At effective depth 875' FSL, 185' FEL, Sec. 34-10N-13W-SM At total depth !057' FNL, 221' FEL, Sec. 34-10N-13W-SM Leg 3 Cond. #4 Spark Platform ORIGINAL 6. Datum elevation (DF or KB) 115' KB above MSL 7. unit or Property name Trading Bay Unit 8. Well number S-2RD 9. Permit number/approval number 74-24 10. APl number 50- 733-20172-01 11. Field/Pool Hemlock & G-Zone feet 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 11,352' ~ 10,132' ~ 11,300' ~ 10,090' feet ~ngth Plugs (measured) Junk (measured) 10,515' - 10,737' DIL (Cement) 10,832' DIL (Through tubing BP) true vertical 13. Size Cemented Measured depth True vertical depth 2,055' 13-3/8" 2,000 sx 7,370' 4,174' 2,055' 1,926' 9-5/8" 1,000 sx 7,370' 6,827' 7" 1,175 sx 11,341' 10,123' No intervals currently open to production Tubing (size, grade, and measured depth) 2-7/8", N-80, @ 10,501' Packers and SSSV (type and measured depth) FB-1 Packer @ 10,426', "TRDP-1A-SSA" TRSV ~ 315' Attachments Description summary of proposal ~ GL - 1 ~994 Gas Cons. Commission Anchorage Detailed operations program ~ BOP sketch Estimated date of commencing operation If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil SI Gas Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. _Dri 11 .ing _Sup. eri oten~dent Title ~l~l~e~i~X~',~xF~l~W~{~X~~y,i~r~ Date 7-1-94 FOR COMMISSION USE ONLY IApprova, No. Approved ~PYReturn~I ~ ~ ~ ~ ~~ Commissioner Date 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 Commision ORIGi~ SIGNED BY RUSSE~.~,,,,eOUaLASS Form 10-403 Rev 06115/88 SUMMARY OF CEMENT PLUGBACK OPERATIONS SPARK S-2RD RECOMPLETION 6/19/94 1) Utilizing coiled tubing, place continuous cement plug from fill @ 10,737' DIL to tubing tail @ 10,501' DIL. Cement circulated in place with 1200 psi back pressure on returns. 2) POOH to 10,000'. SI returns and pressure cement top to 2500 psi. Hold for one hour. RIH to 10,495' DIL. CBU with 1200 psi back pressure on returns. POOH while circulating. 6/24/94 3) RIH with slickline. Tag cement top @ 10,515' DIL (45' above top perforation). 6/25,26/94 4) Pressure test cement plug to 2500 psi surface pressure (3200 psi differential across cement plug). Pressure bled to 2350 psi in 10 hours. PROPOSAL TO COMPLETE PLUGGING OPERATION 1) Set bridge plug (10,000 psi differential rating) at about 10,400' DIL, without additional cement. 6/30/94 JCM h:\wp\Sundry\S-2RD RECEIVED JUL - 1 '~994 A~,~ska- Oil & Gas Cons. Commissio~ Anchorage '7///.7"' Ftu,. .~,' ~ ~ska Oil & Gas Cons. Commissio~ Anchorage Alaska .~ion Domeshc'.~roduction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 May 19, 1994 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 RE: Spark Well S-2RD Dear Mr. Wondzell' Attached for your approval is the AOGCC "Application for Sundry Approvals" for S~.@rk Well S-2RD. This Sundry covers well testing and flaring of gas associated with Spark Well S-2RD recompletion. This notice is as required by 20 AAC 25.255 and 25.235(2), and accompanies Sundry #94-095 which was approved on April 19, 1994. Should you have any questions regarding this application, please contact me or Mr. Ed Oberts at (907) 564-6436. ~ell~Si.nce~. 'i Operations Engineer Supervisor LCI/TAM/cah Enclosures H:\wp\Sundry ~A¥ 2. 0 1994 N~s~ 0il .& Gas Cons. Commission ~ch0rage A subsidiary of USX Corporation Environmentally aware for the long run. ~' ' STATE OF ALASKA ' ALA~..~, OIL AND GAS CONSERVATION COMh,,..~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Alter casing~ Repair well~ Change approved program~ 2. Name of Operator Marathon Oil Company Operation shutdown Re-enter suspended well Plugging ~ Time extension Stimulate Pull Tubing m Variance__ P'"'~rforate ~ Oth'~' X.~. 5. Type of Well: 6. Datum elevation (DF or KB) Development X 115' KB above MSL Exploratory -- Stratigraphic ~ 7. Service ~ 3. Address P. O. Box 196168 Anchorage, AK 99519 4. Location of well at surface Leg 3 Cond. #4 Spark Platform 2606' FNL, 2492' FEL, Sec. 26-10N-13W-SM At top of productive interval 701' FNL, 91' FWL, Sec. 35-10N-13W-SM At effective depth 875' FSL, 185' FEL, Sec. 34-10N-13W-SM At total depth 1057' FNL, 221' FEL, Sec. 34-10N-13W-SM OR/G/A/AL Unit or Property name North Trading Bay Unit Well number S-2RD 9. Permit number/approval number 74-24 10. APl number 50- 733-20172-01 12. Present well condition summary Total Depth: measured true vertical 1 1,352' feet 1 O, 13 2' feet Plugs (measured) 11. Field/Pool Homlock & G-Zone feet 315' Camco 'C' Circ Plug 10,832' Through tubing BP Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 1 1,300' feet 10,090' feet Length Size Junk (measured) Cemented Measured depth 2,055' 13-3/8" 2,000 sx 2,055' 1,000 sx 1,175 sx 7,370' 9-5/8" 4,174' 7" See Attachment #1 True vertical depth 1,926' 7,370' 11,341' 6,827' 10,123' RECEIVED 13. Tubing (size, grade, and measured depth) 2-7~8", N-80, (~ 10,501' Packers and SSSV (type and measured depth) FB-1 Packer (f~ 10,426', "TRDP-1A-SSA" TRSV ~ 315' Attachments Description summary of proposal X.~ MAY 20 1994 Alaska 0il & Gas Cons. Commission Anchorage Detailed operations program m BOP sketch X Estimated date of commencing operation June 15, 1994 If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Suspended S~l Service 7. I hereby certify that thee forego~'mg is/t~.a~d correct to the best of my knowledge. Signed-~~-~'~_ Title Operations Engineering Supervisor FOR COMMISSION USE ONLY Conditions of ~pmval: Noti~ Commission ~ mpm~ntative may ~ne~ Plug integr~ ~ BOP Test L~ati~ clearance ~ M~hanical Integr~ Test__ ~u~quent form r~uir~ 1~ ~ 7 . Approved by order of the Commision Original Signed By David W. Johnston Approved Copy Returned J / commissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE G-Zone G-2 G-3 G-4 G-5 S-2RD PERFORATION RECORD Attachment #1 "Current" M__D 10,560' - 10,618' 10,640' - 10,668' 10,694' - 10,714' 10,730'- 10,762' TVA 9,498' - g,545' 9,563' - g,586' g,608' - g,626' 9,637' - g,664' Hemlock H-1 H-2 H-2 H-3 H-3 H-4 10,790' - 10,822' 10,840' - 10,910' 10,933' - 10,965' 10,995' - 11,058' 11,078' - 11,098' 11,125' - 11,145' TVD 9,687' - 9,712' 9,728' - g,738' 9,801' - 9,826' 9,850' - g,8gg' 9,915' - 97931' 9,952' - 9,968' Below BP II II II II MRO/em/'29A/Sundr2 RECEIVED MAY 20 1994 Alaska Oil & Gas Cons. Commission Anchorage rROPOSED S-2RD PERFORATIONS SPARK (S-2) GAS WELL INITIAL COMPLETION Four of the eight sand perffed upon completion Sand Interval Gross Potential Total Estimated DIL Thickness perfs DIL Perf Pressure BF-1 9580-9600 20 9582-9598 16 3800 UG-2 9840-9895 55 9850-9880 30 3910 UG-4 9980-10025 45 9990-10014 24 3960 UG-5 10050-10130 80 10056-10120 64 3995 , TOTAL PERFS ~ 134 THESE SANDS ARE CURRENTLY AT VIRGIN RESERVIOR PRESSURE RECEIVED G~s Cons. Commission Anchorage CAR/5/19/94/SPARK3. XLS · · e 0 · · · 10. 11. 12. S-2RD Well Test Procedure RU testing equipment and PT to working pressure of all lines (5000 psi upstream of choke, 2000 psi downstream of choke). RU E-line and PT lubricator to 4500 psi. Complete explosives safety checklist and arm 1-11/16" perf guns. RIH and perforate UG-5 gas sand. Immediately after firing guns, begin unloading well through production test equipment (guns below tubing tail). Flow well until producing dry gas (up to 2 hours) at 6 to 8 MMSCFD or 104 drawdown limit. S/I well and POOHw/ guns. Arm and fire second perf gun in UG-5. POOH, RD E-line. RU slickline and PT lubricator to 4500 psi. Program tandem electronic memory gauges. RIH to 20' below UG-5 perfs. Close WL BOP on wire. Return well to flow at 6 to 8 MMSCFD, stabilize for 12 hours. Record ~/water production. Four-point test (record pressure, rate, choke size, temperature, and measured gas properties) as follows: a. First point is stabilized rate from step 6. b. Second rate at 3 MMSCFD until stabilized (up to 4 hours). c. Third rate at 4 MMCFD for same amount of time as second rate. d. Fourth rate at 6 MMCFD for same amount of time as second rate. Obtain two 20 liter gas samples for lab analysis. Collect in DOT approved pressure vessels. S/I well and record PBU until stable. Calculate permeability and skin. POOH w/ gauges and download data. RD slickline. RD surface testing equipment. Secure well. Send flare summary under Form 10-422 and well test summary under Form 10-421 to AOGCC. Estimated total flare volume during test -- 6.9 MMSCF in 26 hours of flow. h :wp\test. sun RECEIVED MAY 20 1994 Ataska Oil & Gas Cons. Commission Anchorage /~HARATHBN BIL CBMPANY iRTH TRADING BAY UNIT SPARK PLATFORM WELL S-SRO 75ROPOSEDI PROPOSED COMPLETION All meosurements ore RKO to top oF equipment Completion String: 18' FMC "TC-IA-EN" Tbg Hgr. 4-1/2" Butt. top x 2-3/8" box bottom 294' Coreco 6' Flow Coupling 1.90" I.D. 300' CaMco 'TRDP-4A* TRSV, 8-3/8' EUE 8rd t x b, 1,875' I,D, 8,055' 13-5/8', 61~f, J-55 Butt Cs9, 0'-9,450' 2--3/8', 3.2#, HS-70 CoRed Tubing Production Strln9 7,167' Top of Liner Window MilLed to 7,370 in 9-5/8', 47~, N-80 Butt Csg, 9,450' 9,480' 9,490' Boker SC-2 PAH Hydroulic Retrievoble Pocker w/ Annulor Releose Anchor Seel Assy. 1.875" X Nipple Wireline Entry Guide PROPOSED PERFORATIONS (OIL) BF-1 9,582' - 9,598' 16' UO-2 9,850' - 9,880' .50' UG-4 9,990' - 10,014' 24' UO-5 10,056' - 10,120' 64' 10,420' Top of Cement, 2-5/8' Tubing Cut 10,4,50' Boker "80-40" Locotor, w/ 4.00" x 5.00" Seol Assy. (10' Long) 10,431' (10,486' DIL) BoNer 'FB-1 Packer w/ lO' SBE, Bell Guide (4,00' I,D,) Two Jts. Tbg. w/ sp, ct. cptgs., 8.441' I.D. 10,501' Baker HalF-Cut MuLe Shoe, 8,406' PERFORATIONS (OIL) (;-2 10,560' - 10,618' 0-5 10,640' - 10,668' G-4 10,694' - 10,714' (;-5 10,730' - 10,762' H-1 10,790' - 10,822' 10,796' WLM Fill Tagged 9/22/89 10,822' DIL TOC 10,832' DIL Thru-Tbg. B.P. H-2 10,840' - 10,910' H-2 10,93,.5' - 10,965' H-5 10,995' - 11,058' H-3 11,078' - 11,098' H-4 11,125' - 11,145' 11,201' DIL Top of Fill 2/4/87 PBTD = 11,300' TD = 11,358' 11,341' 7', 89~, N-80 Butt Cs9, Liner RECEIVED MAY 2 0 1994 Alaska Oil & Gas Corls. Commission Anchorage Revision ,,Date, 4/.6/94 Revised uy~ TAM/evo Reasom Proposed Completion Previous Revision, 4/5/94 SPARK PLATFO- M· Wireline Lubricator w/Associated BOPE ~GREASE HEAD (Hydraulically Activated) LUBRICATOR MANUALLY OPERATED BOP PUMP IN SUB. SINGLE COMPLETION GATE VALVE G~ Cons. Commiss~o~ Anchorage Marathon Oil Company Alaska [ Domestic, .,r)duction P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 April 11, 1994 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 RE: Spark Well S-2RD Dear Mr. Wondzell' 'Attached for your approval is the AOGCC "Application for Sundry Approvals" to workover Spark Well S-2RD. Should you have any questions regarding this application, please contact me or Mr. Ed Oberts at (907) 564-6436. Sincerely, ,--,,~ /~ )~.. C. ~bele Operations Engineering Supervisor LCI/EVO/cah Enclosure /~PR 1 2 1994 Gas Cons. Commission Anchorage A subsidiary of USX Corporation Environmentally aware for the long run. 1. Type of Request: ~ '~ STATE OF ALASKA ALASI~,,~ OIL AND GAS CONSERVATION COMb .... ~ION A PzI: ,L. ICATION FOR SUNDRY APPROVALS AbandonJ~'Jll~',~.~spend Operation shutdown Re-enter suspended well X stimula-'~' Alter casing Repair well Change approved program Plugging.~ j~ Time extension ~ Pull Tubing X ,~'1.{, Variance Perforate · Other 2. Name of Oberator Marathon Oil Company 3. Address P. O. Box 196168 Anchorage, AK 99519 5. Type of Well: Development X.~ Exploratory Stratigraphic Service ~ 4. Location of well at surface 2606' FNL, 2492' FEL, Sec. 26-10W-13W-SM At top of productive interval 701' FNL, 91' FWL, Sec. 35-10N-13W-SM At effective depth 875' FSL, 185' FEL, Sec. 34-10N-13W-SM Leg 3 Cond. ~ Spark Platform ORIGIN4L At total depth 1057' FNL, 9:)1' FEL, Sec. 34-10N-13W-SM 6. Datum elevation (DF or KB) 115' KB above MSL feet 7. Unit or Property name NorthTrading Bay Unit 8. Well number S-2RD 9. Permit number/approval number 74-24 10. APl number 50- 733-201 72 11. Field/Pool Hemlock & G-Zone 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 11,352' feet 10,13 2' feet 11,300' feet 10,090' feet Length Size Plugs (measured) Junk (measured) Cemented 2,055' 13-3/8" 2,000 sx 7,370' 9-5/8" 4,174' 7" See Attachment #1 315' Camco 'C' Circ Plug 10,832' Thur-tubing BP Measured depth True vertical depth 2,055' 1,926' 1,000 sx 7,370' 6,827' 1,175 sx 11,341' 10,123' RECEIVED Tubing (size, grade, and measured depth) 2-7/8", N-80, @ 10,501' Packers and SSSV (type and measured depth) F-5-I Packer ~ 10,426', "TRDP-1A-SSA" TRSV ~. 315' 13. Attachments Description summary of proposal X APR 1 2 1994 At,~ska Oii& Gas Cons. Commi~l~ Anchorag(~ Detailed operations program~ BOP sketch X Estimated date of commencing operation May 15, 1994 If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Suspended X.~ Service 7. I hereby certify that the foregoing is,~fl~and correct to the best of my knowledge. ~~ ~.'~, ~,~ Title Operations Engineering Supervisor Date ~/~7/~' Signed ! FORCOMMISSlON USE ONLY ' ' Conditions of al::~roval: N~gtify Commission so.representative may witness ImAppr°val No. ~, ~ .._~ ~ ~ Plug integrity/~, BOP Test ~ Location clearance ~ Uechanical/l~tegrity Test__ Subsequent form required 10- ! Approved Copy Returned Approved by order of the Commision Original Signed By David W. Johnston .... Cy Commissioner Form 10-403 Rev 06/15/88 SUBMIT I II~LICATE , ~ S-2RD PERFORATION RECORD Attachment //1 G-Zone G-2 G-3 G-4 G-5 MD 10,560' - 10,618' 10,640' - 10,668' 10,694' - 10,714' 10,730'- 10,762' TVD 9,498' - 9,545' 9,563' - 9,586' 9,608' - 9,626' 9,637' - 9,664' Hem lock H-1 H-2 H-2 H-3 H-3 H-4 MD 10,790' - 10,822' 10,840' - 10,910' 10,933' - 10,965' 10,995' - 11,058' 11,078' - 11,098' 11,125' - 11,145' TVD 9,687' - 9,712' 9,728' - 9,738' 9,801' - 9,826' 9,850' - 9,899' 9,915' - 9,931' 9,952' - 9,968' Below BP I! II I! II MRO/em/29A/Sundr2 RECEIVED APR 1 2 1994 Uil & Gas Cons. Commission Anchorage S-2RD WORKOVER PROCEDURE . RU slickline, PT to 2,000 psi. Pull circulating plug. Run gauge ring to tag fill. RD. . . . . RU 1-3/4" CTU. Pressure test BOPE to 5,000 psi. Bullhead tubing and casing volumes to formation. RIH, lay cement abandonment plug from fill to 9,800' and squeeze to 1,500 psi. Wash cement down to ~p of cur~ = 10,560' DIL). POOH and WOC 12-hours. PT Ce~--~nt to-~r,500 psi. RD CT. - RU E-line unit. PT BOPE to 5,000 psi. ~.omplete ESC. Arm and RIH w/2-7/8" jet tubing cutter. Cu! tubing @ 10,400'. POOH and RD E-line. Set BPV and RD tree. RU 13-5/8" BOP stack, function and PT to 5,000 psi. RU hydraulic jacks. Pull BPV. Unseat hanger and pull one joint of tubing. . Circulate tubing and casing clean (approximately 600 bbls.). . POOH laying down tubing and jewelry. Fill hole each five joints. . . RU 1-3/4" CTU and PT to 5,000 psi. RIH w/6" mill and motor. Polish 7" Liner to packer setting depth at 9450'. POOH. RD 1-3/4" CT. Close blind rams, C/O 2- 7/8" BOPE w/2-3/8". P~ to 5,000 psi. MU p~ilpipea_ss¥, t__9o._2~3/8_"_~T. Continue RIH. RIH to _9 1~50', cut CT and install SCSSV. 10. 11. At 9,450' cut 2-3/8" CT, MU and land hanger. Test neck seals. Circulate packer fluid, drop ball and set packer. Test annulus to 1,500 psi. 12. 13. 14. Run BPV and ND BOPE, NU and test tree. Pull BPV. ~£¢~-'-~ T¢-sr-~'z2 RU 1-3/4" CTU PT to 5,000 psi. RIH. Load hole with 2% KCI. POOH and plug end of 1-3/4" CT~ RIH to 1,600' to displace_for~underbalance. P._OOH, RD CT. · RU E-line and production testing equipment. PT all equipment to 4,500'psi. Perforate select gas intervals between 9585' and 10,140' DIL. Flow well immediately after firing guns to unload water. RD E-line. Complete production test as requested by Reservoir group. RD testers. 3/31/94 TAM H:\WP\Workover\S2RD Secure well by closing SCSSV, setting BPV, and blind flanging wing and casing valves. RECEIVED ,~RATHON OIL COMPANY .~TH TRADING BAY UNIT SPARK PLATFORM WELL S-2RD URRENTI .< L CoMpleted 8/21/85 All MeasureMents are RKB to top oF equipment CoMpletion Strln§: FMC'UN-TC-IAEN" Tbg Hgr. 4-1/2" Butt. t x b X-Over 4-1/2" Butt. b x 2-7/8" EUE pin 315' C~mco 'TRDP-1A-SSA' TRSV, 2-7/8' EUE 8rd t x b, 2.313' I.D. 0'-10,501' 2-7/8', 6.5#, N-80 EUE 8rd Tb9, 2,055' 13-5/8', 61#, J-55 Butt Cs9. gas lift Mandrels ore McMurry 'PSID-SD' 1-1/8' 'UR-Std' w/ 'RK' VR Latches, 2.313 I.D. 7,167' Top of Liner Window Milled to 7,370 In 9-5/8; 47#, N-80 Butt Csg. Denth V~lve# 2,398' 1 4,203' 2 5,460' 3 6,371' 4 7,052' 5 7,598' 6 8,087' 7 8,611' 8 9,012' 9 9,434' 10 9,7`]8' 11 ~ 10,045' 12 10,,]55' 1`] 10,450' Baker "80-40" Locator, w/ 4.00" x `].00" Seal Assy. (10' Long) 10,431' (10,426' ]]IL) Baker 'FB-1 Packer w/ 10' SBE, Bell Guide (4,00' I,D,) 10,501' Two Jts, Tho, w/ sp, cl, cplos,, 2,441' I,D, B(~ker H(~[F-Cut Mule Shoe, 2.406' PERFORATIONS (DIL) (;-2 10,560' - 10,618' (;-`] 10,640' - 10,668' G-4 10,694' - 10,714' (;-5 10,730' - 10,762' H-1 10,790' - 10,822' 10,796' WLM Fill Tagged 9/22/89 10,822' DIL TOC 10,8`]2' DIL Thru-Tbg. B.P. H-2 10,840' - 10,910' h-2 10,9`]~' - 10,965' H-`] 10,995' - 11,058' H-`] 11,078' - 11,098' H-4 11,125' - 11,145' 11,201' nIL Top of Fill 2/4/87 Revis;on Date~ 3/.31/94 Revised By: TAM/eva PBTD = 11,300' Re~son, TD = 11,352' Previous Revision: 9/87 7', 29#, N-80 Butt Cs§. Liner 11,341' RECEIVED 12 1994 m~Ka u,~ ~. Gas Cons. Commissioa Anch0ra.q~. ~-,~,RATHDN DIL CDMPANY RTH TRADING BAY UNIT SPARK PLATFORN ~ELL S-SRD ROPOSED PROPOSED COMPLETION All measurements are RKB to top oF equipment Completion String: 18' FMC "TC-IA-EN" Tbg Hgt. 4-1/2" Butt. top x 2-,]/8" box bottom 294' Camco 6' Flow Coupling 1.90" I.D, 300' Camco 'TRDP-4A' TRSV, 8-3/8' EUE 8rd t x b, 1,875' I,D, 8,055' 13-5/8', 61#, J-55 Butt Csg, 0'-9,450' 2-3/8', 3.2#, HS:-70 Coiied Tubing Production String 7,167' Top of Liner Window Mil. ted to 7,370 In 9-5/8', 47#, N-80 Butt Cs9, 9,450' 9,480' 9,490' Baker SC-2 PAH Hydraulic Retrievable Packer w/ Annular Release Anchor Seal Assy. 1.875" X Nipple Wireline Entry Guide PROPOSE]) PERFORATIONS (DIL) BF-1 9,582' - 9,598' 16' UG-2 9,850' - 9,880' 30' UG-4 9,990' - 10,014' 24' UG-5 10,056' - 10,120' 64' 10,420' Top of Cement, 2-3/8" Tubing Cut 10,430' Boker "80-40" Locotor, w/ 4.00" x 3.00" Seol Assy. (10' Long) 10,431' (10,426' ])IL) Baker 'FB-1 P(zcker w/ lO' SBE, Bott Guide (4.00' I,D.) Two J-ts. Tb9. w/ sp. ct. cplgs., 8.441' I.D. 10,501' 0-2 0-3 G-4 0-5 H-1 B6ker HarP-Cut MuLe Shoe, 2.406' PERFORATIBNS <DIL) 10,560' - 10,618' 10,640' - 10,668' 10,694' - 10,714' 10,730' - 10,762' 10,790' - 10,822' 10,796' WLM Fill Tagged 9/22/89 10,822' DIL TOC 10,832' DIL Thru-Tbg. B.P. H-2 10,840' - 10,910' H-2 10,933' - 10,965' H-3 10,995' - 11,058' H-3 11,078' - 11,098' H-4 11,125' - 11,145' 11,201' DIL Top of Fill 2/4/87 PBTD = 11,300' TD = 11,352' 11,341' 7', 89#, N-80 Butt Cs9, Liner RECEIVED APR 1 2 1994 A,~aska U~t & Gas Cons. Commission Anchorage Revision Dote, 4/.6/94 Revised By: TAM/eva Re(~son, Proposed Completion Previous Revision: 4/5/94 1D:BSAM DOWELL SCHLUHBER~ER 907P_GIB5~S9 Rev A ' COILED TUBING ~,:;: OPERATORS MANUAL March ~ ~@2 - P.2 2 FEATURES The BOP commonly found on Doweli Schlumberger (DS) coiled tubing units (CTUs) is manufactured by Texas Oil Tools (TOT). This is available in a range of sizes (bore), pressure ratings and services (e,g,, HaS, Arctic or Standard servbe). The model most commonly used ts the 3-in,, 10,000-psi Working Pressure, HaS service Quad BOP, It is this mode! on wl~icn the diagrams and text in this section are based. The following components are identified in Figure 1 ama 2, · BOP aody · Blinci Rams · Shear Rams · Slip Rams - Pipe Rams Stud-Up Flange Top Connection,,~ Side Port (Kilt Port) Pipe-Ram Equally-lng Valve PresIure Port 81in0-Ram Equ&lizing V~lve Manua! Lock He, ndle (Ram No, t) ,- (Ram No, 2) Slip Rams (Ram No. :3) ---' - ..... Pipe Rams (Ram No, 4) Hydraulio Actuator with Ram PoIition Indioator Bottom Flange Connection Figure 1, TYl~i~al features efa quad BOP .-front view. DOWELL SCHLUMBERGER CONFIDENTIAL RECEIVED APR ] 2 1994 Ai~ska 0it & Gas Cons. Commissior: Anchorage Rig Floor SPARK PLATFORM S-2RD RECOMPLETION BOP SCHEMATIC NOT TO SCALE 13-5/8'x5M annular Kill Line . ' 13-5/8" x 5M Double gate 3-1/8' x 5M Manual Gate Valve t ~ ii 4-1/16' x 5M Manual Gate Valve I J 13-5/8" x 5M Single gate 13-5/8" x 5M Flange x Hub Adapter FMC Type II Unihead I RECEIVED APR 1 2 1994 Alaska Oil & Gas Cons. Commission Anchorage Wireline "~'SPARK PLATFO R~' Lubricator w/Associated BOPE ~GREASE HEAD (Hydraulically Activated) LUBRICATOR MANUALLY OPERATED BOP PUMP IN SUB. SINGLE COMPLETION GATE VALVE RECEIVED APR 1 2 1994 A. iaska 0il & Gas Cons. Commissto~ Anchorage co.s..v^T,O, co..,ss,o. REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Pull tubing Alter casing __ 2. Name of Operator / Marathon Oil Company 3. Address P.O. Box 190168 Anchorage, 9951 4. Location of well at surface 2,606' FSL, 2,492' FEL At top of productive interval ' 701' FNL, 91' FWL, At effective depth 875' FSL, 185' FEL, At total depth · 1,057' FNL, 221' FEL, Stimulate Plugging __ Repair well __ 5. Type of Well: Development X Exploratory __ Stratigraphic AK Leg 3 Cond. #4 Spark Sec. 26-10N-13W-SM Sec. 35-10N-13W-SM Sec. 34-10N-13W-SM Sec. 34-10N-13W-SM Perforate __ Other Service P1 at form 6. Datum elevation (DF or KB) 115' KB above MSL feet_ 7. Unit or Property name North Tradin~l Bay Unit 8. Well number (c_?Dr) -9. ~er~nit number/approval number 91-408/~¢~,,, ;~ 10. APl number 5o/33-20172-~1 11. Field/Pool Hemlock & G-Zone 12. Present well condition sUmmary Total depth: measured true vertical 11,352' feet 10,132' feet Effective depth: measured true vertical Casing Length Structural Conductor Surface 2,055' Intermediate 7,370' Produotion Liner 4,174' Perforation depth: measured See Attachment #1 true vertical 11,300' feet 10,090' feet Size Plugs (measured) Junk (measured) Tubing (size, grade, and measured depth) 2 7/8", N-80, 10,501' Packers and SSSV (type and measured depth) FB-1 Packer ca 10:426': "TRDP 13. Stimulation or cement squeeze summary Cemented 10,832' Thru-tubing BP 11,300' - 11,352' CMT 10,796' 11,188' Measured depth - 10,832' Fill - 11,300' Fill True vertical depth 13 3/8" 2,000 sx 2,055' 1,926' 9 5/8" 1,000 sx 7,370' 6,827' 7" 1,175 sx 11,341' 10,123' - lA - SSA" TRSV ca 315' RECEIVED APR 1 ? 199?- ~h0rage Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-MCf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 93 0 580 1000 95 Subsequent to operation 0 0 0 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run __ I Daily Report of Well Operations -X. Oil ~ Gas __ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. :';nme:o.4~'4 R~e~ 06~/1;,8~ Service Operations Engineering Supv. Title Date ¢~/'~' Z~ SUBMIT IN DUPLICATE SPARK PLATFORM WELL S-2RD Daily Summary of Operations 1/16/92 Well flowing to production. Attempted to close SCSSV. No indication that valve closed. Well continued to flow. Attempted to work valve by applying and relieving control line pressure. Indications are that valve is stuck open. 1/25/92 Shut well in. Begin bleeding casing and tub/nO pressure to production. 1/27/92 RU to pump down tubing. PT lines to 2500 psi. Pump filtered inlet water (FIW) down tubing at I BPM, pressure increasing from 1200 psi to 2000 psi. RU higher pressure rated tree connection. PT to 4000 psi. Pump 3 bbls FIW down tubing and pressure broke back from 2450 psi to 100 psi. Continued pumping FIW down tubing at 3 BPM and 100 psi. Pumped total of 174 bbls. FIW with last 87 bbls treated with corrosion inhibitor. RD off tubing and RU to pump down 9-5/8" casing/tubing annulus. Fill annulus to surface with 107 bbls. treated FIW. Bleed TP and CP to 50 psi. Monitor TP and CP. RD pump equipment. 1/28/92 TP = 10 psi. CP = 0 psi. RU to pump down 9-5/8" casing/tubing annulus. Pump 3 bbls. inhibited FIW down annulus. Casing full. RD pump equipment. Monitor pressures. TP = 30 psi. CP = 0 psi. Stable, no buildup. 1/29/92 RU w/reline. PT lubricator to 1500 psi - OK. Work 2.35" gauge ring through tight spots to 315' (SCSSV at 315'). Run 2.31" gauge ring to 315', could not work through SCSSV. Run 2.26" gauge ring to 400'. Set Camco 'C' circulating plug in SCSSV profile at 315'. RU to pump down 9-5/8" casing/tubing annulus. 1/30/92 Begin filling casing. TP decreased from 30 psi to vacuum with only 5 bbls pumped down annulus (suspect tubing-casing communication above SCSSV). Fill casing w/ 125 bbls inhibited FIW. CP and TP increased at same time to 140 psi. Shut down and bled off casing to 0 psi, TP decreased to 0 psi also. RU to pump down tubing. Pump 22 bbls down tubing. TP and CP increased to 500 psi. Bleed back tubing pressure to 0 psi, CP decreased to 0 psi also. Tubing and casing in communication above SCSSV, unable to test plug from below. TP = 0 psi, CP = 0 psi. No pressure buildup. RD pump equipment and w/reline. RECEIVED APR 1 ? 1992 Alaska Oil & Gas Cons. (~omm'~ss'~on Anchorage 'Spark Platform Wei ~-ZRD Daily Summary of Operations Page 2 1/31/92 TP = 12 psi. CP = 5 psi. 2/1/92 TP = 12 psi. CP = 0 psi. Bleed TP to 0 psi. 2/2/92 through 2/5/92 TP and CP remained at 0 psi. No pressure buildup. Disconnect gas lift line and flow line. Install blind flanges. 2/22/92 TP and CP = 0 psi. Close all tree valves. FINAL REPORT. \Spark\S2RD.doc RECEIVED APR 1 1 1992 Alaska Oil & Gas Cons. ~ommissio~ Anchorage S-2RD PERFORATION RECORD Attachment #1 G-Zone G-2 G-3 G-4 G-5 MD 10,560' - 10,618' 10,640' - 10,668' 10,694' - 10,714' 10,730' - 10,762' TVD 9,498' - 9,545' 9,563' - 9,586' 9,608' - 9,626' 9,637' - 9,664' Hemlock H-1 H-2 H-2 H-3 H-3 H-4 MD 10,790' - 10,822' 10,840' - 10,910' 10,933' - 10,965' 10,995' - 11,058' 11,078' - 11,098' 11,125' - 11,145' TVD 9,687' - 9,712' 9,728' - 9,738' 9,801' - 9,826' 9,850' - 9,899' 9,915' - 9,931' 9,952' - 9,968' Below BP II II II II MRO/em/29A/Sundr2 RECEIVED APR 1 ? t992 Alaska .Oil & Gas Cons, Anchorage Si)AlU', i~ I, ATf'OlU4 " ' N'r~U WBLL, $-~ ' ~IBLLflORB OXAGIb~ · .,' ' ' C0m'~Tf:O a/aX/aS. .-! .... 3150 Cm~ -~p-LA-SS~' T~V, 2-~/8" ~Ua ,rd ~ ~ b, 2.313" lO Camco' 'C' Circ Plug in - . · ' · SCSSV profile 4;2o3' '~ 2-~/9', 6.51N-80 S,46Q* 13 7,052' 15 471N-80 7,~70' __ B&ker "FB-I" Pkr. 10,426' DZL w/LO' SBE, BeLl GeLd. L0,439* OZL (4.00~ RlmmrvoL: Datult 11,08S' lid 7"° 291 HoBO Butt. ll.14l' ~uLnq . 7,598* I$ 8,087' 9,012' 9,434 :.9,738' 10,045 . L0~3530 10,430' 10,S01' . P~NPORATXOHS (OZL) 17 18 ' II0 S&ker "90-40" r.,oc&tor, 3.00" IO BaJ(ar "4.00 x 3.00° Seal Aoey. (10' 1.fig) Tv. }ea. tbq. w/ sp. ¢1. cpLgS., 2.441" ~O Baker hal£-cuC mule shoe. 2.406" lC 10,$60' - 10,618' G-2 : 10~&40~ - L0~&94t - 10,730' - ~0,762° G-S 10,790' - ~0,840' - L0,9~0' 11-2 10,933' - 10,96S' 10~9950 - 1~,058' 11-3 ~Le1250 - ~,L4S' 11-4 ..., ~4qfJ.&*'j. on · 36 ' ~1,300' PB'rD :'' ' WEC 2/89 O,^L^S,^ 0 R I ALASKA OIL AND GAS CONSERVATION COMMI3SION APPLICATION FOR SUNDRY APPROVALS GIN 1. Type of Request: Abandon __ Suspend __ Operation shutdown ~ Re-enter suspended well __ Alter casing __ Repair well ~ Plugging __ Time ex'tens,on __ Stimulate w Change approved program ~ Pull tubing ~ Variance ~ Perforate ~ Other _.~ 2. Name of Operator . ~ 5. Type of Well: 6. Datum elevation (DF or KB) Marathon Oil Company l Development X__. 115' KB above MSL Exploratory ~ 3. Address Stratigraphic ~ 7. Unit or Property name P.O. Box 190168 Anchorage, AK 9951 Service__ North Trading Bay 4. Location of well at surface Leg 3 Cond. #4 Spark 2,606' FSL, 2,492' FEL, Sec. 26-10N-13W-SM At top of productive interval 701' FNL, 91' FWL, Sec. 35-10N-13W-SM At effective depth 875' FSL, 185' FEL, Sec. 34-10N-13W-SM At total depth 1,057' FNL, 221' FEL, Sec. 34-10N-13W-SM Platform 8. Welt number S-2RD 9. Permit number 74-24 10. APl number 5o/-33-20172-1 11. Field/Pool Hemlock & 6-Zone feet Unit 12. Present well condition summary Total depth: measured true vertical 11,352 10,132 Effective depth: measured 11,300 true vertical 10,090 Casing Length Structural Conductor Surface 2,055' Intermediate 7,370' Production Liner 4,174' Perforation depth: measured See Attachment #1 true vertical 13 9 feet Plugs (measured) feet feet Junk (measur. ed) feet ..... Size Cemented 10,832' 11,300' , 10,796' 11,188' Measured depth 3/8" 2,000 sx 2,055' 5/8" 1,000 sx 7,370' 7" 1,175 sx 11,341' Thru-tubing BP - 11,352' CMT - 10,832' Fill - 11,300' Fill True vertical depth 1,926' 6,827' 10,123' RECEIVED Tubing (size, grade, and measured depth) 2 7/8", N-80, 10,501' Packers and SSSV (type and measured depth) FB-1 Packer @ 10,426' "TRDP - lA - SSA" TRSV @ 315' D £0 1 7 ,991 Alaska 0il & Gas Cons. C0mmis', Anchorage 13. Attachments 1, 2, Description summary of proposal ..~ &3 Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operatiOn 15. Status of well classification as: January 2, 1992 16. If proposal was verbally approved Oil ....~S [ Name of approver Date approved Service 17. I hereby certify that the fore_going is true and Correct to the best of my knowledge. Signed ..~,~4 ,~¢U~ Title Operations Engineering Superv. Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity m BOP Test m location clearance Mechanical Integrity Test __ Subsequent form required 1'~77- .....~i~¢-'~''' Approved by order 'of the Commission ORIGINAl SIGNED BY LONNIE C. SMITH Form 10-403 Rev 06/15/88 Gas __ Suspended SUBMIT IN TRIPLICATE Approval No. ..,kpprOVed~ 0o~¥ Commissioner , S-2RD PERFORATION RECORD Attachment #1 G-Zone G-2 G-3 G-4 G-5 MD 10,560' - 10,618' 10,640' - 10,668' 10,694' - 10,714' 10,730' - 10,762' TVD 9,498' - 9,545' 9,563' - 9,586' 9,608' - 9,626' 9,637' - 9,664' Hemlock H-1 H-2 H-2 H-3 H-3 H-4 MD 10,790' - 10,822' 10,840' - 10,910' 10,933' - 10,965' 10,995' - 11,058' 11,078' - 11,098' 11,125' - 11,145' TVD 9,687' - 9,712' 9,728' - 9,738' 9,801' - 9,826' 9,850' - 9,899' 9,915' - 9,931' 9,952' - 9,968' Below BP II II II II MRO/em/29A/Sundr2 RECEIVED DEO 1 ? 1991 Alaska Oil & Gas Cons. Commission Anchorage Attachment #2 SPARK PLATFORM WELL S-2RL WELL SECURING PROCEDURE 1. Hold safety/operational meeting. e Close SCSSV. Bleed pressure to zero on the tubing. Monitor tubing for psi buildup for 30 minutes to ensure SCSSV holds pressure from below. Equalize pressure and open SCSSV. 3. Shut off lift gas and allow well to die. 4. RU to pump down tubing. PT surface lines to 2500 psi. Be Pump two wellbore volumes (tubing and casing below packer) of 8.5 PPG salt water. Inject KW-132 corrosion/scale inhibitor at 0.754 concentration during second wellbore volume. Monitor casing pressures during pumping. 6. RU to pump down the tubing-casing annulus. PT surface lines to 2500 psi. e Fill tubing-casing annulus with 8.5 PPG salt water (including 0.754 KW-132 corrosion/scale inhibitor) by alternately pumping salt water and bleeding gas pressure. Do not exceed 1500 psi casing pressure. Monitor tubing pressure while pumping. e Bleed any remaining pressure from pumping off of tubing and casing. Monitor pressures for buildup. 9. Bleed SCSSV control line pressure to zero to close the SCSSV. 10. RD pumping lines. Close all tree and casing valves. 11. Install pressure gauges on tubing and all casings. \oe60\62.doc RECEIVED DEO 1 ? Alaska Oil & Gas Cons. Commission Anchorage FI{G "UI~TC-XAEH" T~q. hgt., 4-1/2" BUtt. ~ x b ~-over 4-1/2" Butt. b x 2-7/8" EUE p ., . C~mco "TN)P-LA-SSA" TRSV0 2-7/8# EUE 0xd t : b, 2.313" ID Butt. Casing 055 ' 2,398' · 1'-1/2" "UR-etd" GLV'I & "R~" VR Latches, 2.31'3" lO 2-?/6" I~U- etd t x b .. 4;203. 2-7/8", 6.51H-80 £UE 8rd Tub£ng TOL 7,267' $,460' 6,371.' · o 7,052' t3 14 I$ 9-5/6"t.471Hr80 7,370, 7,598' 8,087' 16 '17 Baker "FB-I" Pkr. 10,426' DXL v/lO' SBa, BeXX Gu£de ~0,439' DxL (4.00" ZO) ._ ~elervoJ. r Datum; 11,085' liD · 9,915' 1%rD Tag .@ .10",83'9' VLH 6/889'800'-'Ss ~[u-Cubin{ B.~.'~ 10,032' DILl. ~C 8 10,822' DIL 7", 291 X-80 Butt. ll,]4l' __ d 9,012' 9,434t :.9,738' 1-0,045' 1'0,353' 1.0,430' 1.0,43L' J9 10,501.' . .PEI~ORATXOHS (OIL) .10,560' - ~0,618' 0-2 1'0,640' - 10,668' O-3 10,694' - 10,714' G-4 10,~30' - 10,762' 0-5 i0,790' - ~0,822'' 1'0,840' - 10,910' 10,933' - 10,965' ll-2 10,995' - 11,058' 11-3 21,070' - 11,098' 11-3 Baker #80-40" t~mcetor, 3.OO# ID B~er "4.00 x 3.00" Seal Aeey.. (10' long) TWO :J ti. tbq, w/ sp. c1'. cpigs., 2.44 l" ID . Baker hai£-cut mule shoe, 2.406" XE Dav. J. atXon- 36 ' .o 1.1.,300' PBTD { I) :~52.'. Tb .. · ' WEC 2/89 DEC.1 ? 1991. · Alaska Oil & Gas C~ns. commission ,' i~ STATE OF ALASKA ALAS. :OIL AND GAS CONSERVATION COM,,. 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 3 Cond. #4 Spark Platform 5. Datum elevation (DF or KB) 115' KB above MSL Feet 6. Unit or Property name North Trading Bay Unit 7. Well number 2,606' FSL, 2,492' FEL, Sec. 26-10N-13W-SM At top of productive interval 701' FNL, 91' FWL, Sec. 35-10N-13W-SM At effective depth 875' FSL, 185' FEL, Sec. 34-10N-13W-SM At total depth 1,057' FNL, 221' FEL, Sec. 34-10N-13W-SM S-2RD 8. Approval number 799 9. APl number 50-- 733-20172-1 10. Pool Hemlock & G-Zone 11. Present well condition summary Total depth: measured true vertical Effective depth: measu red true vertical Casing Structural Conductor Surface 2,055 ' Intermediate 7,370 ' Production Liner 4,174' Perforation depth: measured See Attachment #1 true vertical 11,352' feet 10,132 ' feet 11,300 ' feet 10,090' feet Length Size Plugs (measured) Junk (measured) 11,300' 11,188' Cemented Measured depth 13 3/8" 2,000 sx 2,055' 9 5/8" 1,000 sx 7,370' 7" 1,175 sx 11,341' - 11,352' CMT 11,300' Fill Rue Verticaldepth 1,926' 6,827' 10,123' Tubing (size, grade and measured depth) 2 7/8" N-80 10,501' Packers and SSSV (type and measured depth) FB-1 Packer @ 10,426', "TRDP - lA- SSA" TRSV @ 315' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Anchorage 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 98 60 1541 1140 80 Subsequent to operation No stabilized well tests are available yet. 14. Attachments~ ¢/2 Daily Report of Well Operations [] Copies of Logs and Surveys Run [] is true and correct to the best of my knowledge - ~~ ~---~2" 3 15. I hereby certify that the foregoing Signed /.~/~/2cq~/"~ Title District Operations Engineer Date~ Form 10-404 Rev. 12-1-85 Submit in Duplicate S-2RD PERFORATION RECORD Attachment #1 G-Zone G-2 G-3 G-4 G-5 i0,560' - 10,618' 10,640' - 10,668' 10,694' - 10,714' 10,730' - 10,762' TVD , , 9,498' - 9,545' 9,563' - 9,586' 9,608' - 9,626' 9,637' - 9,664' Hemlock H-1 H-2 H-2 H-3 H-3 H-4 10,790' - 10,822' 10,840' - 10,910' 10,933' - 10,965' 10,995' - 11,058' 11,078' - 11,098' 11,125' - 11,145' TVD 9,687' - 9,712' 9,728' - 9,738' 9,801' - 9,826' 9,850' - 9,899' 9,915' - 9,931' 9,952' - 9,968' Below BP MRO / em/29A/Sundr 2 Attachment #2 Well S-2RD Daily Operations Report 1/27/87 1. RU CTU and pump equipment. Pressure test to 3000 psi. 2. RIH w/coil tubing. Upweights increased dramatically near tubing tail (to 16,500#); decided that job could not be completed safely utilizing coil tubing due to 'corkscrewed' tubing (potential existed to part the coil tubing). 3. POH and RD CTU & pump equipment. 2/5/87 1. RU electric line. Pressure test to 400 psi. 2. RIH w/30' of 2" dump bailer for gauge ring--no obstructions--tag fill @ 11,201' DIL. POH. 3. RIH Set thru tubing B.P. @ 10,832' DIL. POH. 4. RIH Dumped 1.22 gal. of 20/40 sand on B.P. POH 5. RIH Dumped 7.4 gal. Class G cement on B.P. in 2 runs. POH. 2/6/87 1. WOC 24 hrs. 2/7/87 1. RIH and closed vent on B.P. POH. 2. RIH and dumped 7.4 gal Class G cement on B.P. in 2 runs. 3. POH and RD W.L. 218187 1. WOC 2/9/87 1. Begin to produce well at limited drawdown. PMS/em/29A/Sundr2 A~aska Oil & Gas Cons. STATE OF ALASKA ALASr,, ,'OIL AND GAS CONSERVATION COM~,,oSlON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [~ Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator 5. Datum elevation(DF or KB) Marathon Oil Company 115' KB above MSL feet 3. Address 6. Unit orProper~ name P.O. Box 102380 Anchorage, AK 99510 North Trading Bay Unit 7. Wellnumber S-2RD 8. Permitnumber 74-24 9. APInumber 50-- 733-20172-1 10. Pool 'Hemlock & G-Zone 4. Locationofwellatsurface Leg 3 Cond. #4 Spark Platform 2,606' FSL, 2,492' FEL, Sec. 26-10N-13W-SM Attop of productiveinterval 701' FNL, 91' FWL, Sec. 35-10N-13W-SM Ateffective depth 875' FSL, 185' FEL, Sec. 34-10N-13W-SM Attotaldepth 1,057' FNL, 221' FEL, Sec. 34-10N-13W-SM 11,352 ' feet Plugs (measured) 10,132 ' feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface 2,055 ' Intermediate 7,370 ' Production Liner 4,174' Perforation depth: measured 11,300' feet Junk (measured) 10,090 ' feet Size Cemented 11,300' - 11,352' CMT 11,188' - 11,300' Fill Measured depth ~ue Verticaldepth 13 3/8" 2,000 sx 2,055' 1,926' 9 5/8" 1,000 sx 7,370' 6,827' 7" 1,175 sx 11,341' 10,123' See Attachment #1 true vertical RECEIVED FEB 0 9 1987 ~aska 0il & Gas Cons. Oommission Anchorage ~bing(size, grade and measured depth) 2 7/8" N-80 10 501' Packers and SSSV(type and measured depth) FB-1 Packer @ 10,426', "TRDP - lA - SSA" TRSV @ 315' 12.Attachment~: #2 Description summary of proposal [] Detailed operations program [] BOP sketch [] February 4, 1987 13. Estimated date for commencing operation Date approved 1/29/87 14. If proposal was verbally approved Name of approver Russ Douglas Date 15. I hereby, certify that the foregoing is true and correct to the best of my knowledge Signed b/~ol ~/~--- Title District Operations Engineer Conditions of approval Commission Use Only Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI / .... ~~ .... by order of ~: ~:~.. ~ Commissioner the commission Date.. Approved by Form 10-403 Rev 12-1-85 Submit in triplicate S-2RD PERFORATION RECORD Attachment #1 G-Zone G-2 G-3 G-4 G-5 10,560' - 10,618' 10,640' - 10,668' 10,694' - 10,714' 10,730' - 10,762' TVD 9,498' - 9,545' 9,563' - 9,586' 9,608' - 9,626' 9,637' - 9,664' Hemlock H-1 H-2 H-2 H-3 H-3 H-4 10,790' - 10,822' 10,933' - 10,965' 10,995' - 11,058' 11,078' - 11,098' 11,125' - 11,145' 9,687' - 9,712' 9,728' - 9,738' 9,801' - 9,826' 9,850' - 9,899' 9,915' - 9,931' 9,952' - 9,968' MRO/em/29/Sundr2 Attachment #2 Well S-2RD Cement Plug Procedure 1. RU wireline. 2. Pressure test lubricator to 2,000 psi. 3. RIH w/cement dump bailer for gauge ring - tag bottom. POH. 4. RIH w/thru-tubing bridge plug. Set at 10,837' DIL. POH. 5. RIH w/cement bailer and dump sand to cover bridge plug. POH. 6. RIH w/cement bailer and dump bail of cement. 7. Repeat #6 until 10 linear feet (2.1ft3) of cement covers the bridge plug. POH. 8. RD wireline. 9. Wait 48 hours. 10. Unload and test well. MRO/em/29/Sundr2 STATE OF ALASKA ~-'" ALAS, OIL AND GAS CONSERVATION COM. ,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging i~ Stimulate [] Pull tubing [] Amend order [] Perforate E3 Other [] 2. Name of Operator 5. Datum elevation(DF or KB) Marathon Oil Company 115' KB above MSL feet 3. Address 6. UnitorProperty name P.O. Box 102380 Anchorage, AK 99510 North Trading Bay Unit ..~ 4. Location of wellatsurface 2,606' FSL, 2,492' FEL, Sec. Attop ofproductiveinterval 701' FNL, 91' FWL, Sec. Ateffective depth 875' FSL, 185' FEL, Sec. Attotaldepth 1,057' FNL, 221' YEL, Sec. Leg 3 Cond. #4 Spark Platform 26-10N-13W-SM 35-10N-13W-SM 34-10N-13W-SM 34-10N-13W-SM 7. Well number $-2RD 8. Permitnumber 74-24 9. APInumber 50-- 733-20172-1 10. Pool Hemlock & G-Zone 11. Present well condition summary Total depth: measured true vertical 11,352' feet 10,132' feet Plugs (measured) 11,300' - 11,352' CMT Effective depth: measured 11,300 ' true vertical 10,090' feet feet Junk (measured) 11,188' - 11,300' Fill Casing Structural Conductor Surface 2,055 ' Intermediate 7,370 ' Production Liner 4,174' Perforation depth: measured See Attachment #1 true vertical Length Size Cemented Measured depth True Vertical depth 13 3/8" 2,000 sx 2,055' 1,926' 9 5/8" 1,000 sx 7,370' 6,827' 7" 1,175 sx 11,341' 10,123' RECEIVED Tubing (size, grade and measured depth) 2 7/8", N-80, 10,501' Packers and SSSV (type and measured depth) FB-1 Packer @ 10,426', "TRDP - lA - SSA" TRSV @ 315' JAN 2 1 Naska 0ii & Gas Cons. Commission Anchorage 12.Attachment~ #2 Description summary of proposal ~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation January, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the'best of my knowledge Signed ~/~c~A- Title DiStrict Operations Engineer Conditions of approval Approved by Commission Use Only Notify commission so representative may witness [] Plug integrity I Approval No. [] BOP Test [] Location clearance ')/,- ..-,.,, ~.t~ - ~ Form No. Dated __/_./.~ .......... -- ......- by order of Commissione, commissior, D,,te Form 10-403 Rev 12-1-85 Submit in triplicate S-2RD PERFORATION RECORD Attachment #1 G-Zone G-2 G-3 G-4 G-5 10,560' - 10,618' 10,640' - 10,668' 10,694' - 10,714' 10,730' - 10,762' TVD 9,498' - 9,545' 9,563' - 9,586' 9,608' - 9,626' 9,637' - 9,664' o Hemlock H-1 H-2 H-2 H-3 H-3 H-4 10,790' - 10,822' 10,840' - 10,910' 10,933' - 10,965' 10,995' - 11,058' 11,078' - 11,098' 11,125' - 11,145' 9,687' - 9,712' 9,728' - 9,738' 9,801' - 9,826' 9,850' - 9,899' 9,915' - 9,931' 9,952' - 9,968' MRO/em/29/Sundr2 RECEIVED Alaska 0il & Gas Cons, Commission Anchorage Attachment #2 Well S-2RD Sand Plug Back Procedure 1. Shut in well one day prior to rigging up CTU. 2. RU pump equipment and CTU over Well S-2RD. 3. Pressure test lines and equipment to 3,000 psi. 4. RIH w/coil tubing. Fill remaining tubing with 3% KCL fluid (excess fluid from Well S-8 workover). 5. Correct coil tubing measurements to DIL depth by use of a tubing tail indicator on the coil tubing. 6. Spot 15 bbl pills HEC polymer containing 1-2 lb/gal sand on bottom. Polymer to have one hour breaker. POH to 8,000'. 7. Allow sand to settle for 2-4 hours. RIH. Tag sand. Repeat Step #6 until the top of sand plug is at 10,830' DIL. 8. POH and RD equipment. 9. Return well to production and test. MRO/em/29/Sundr2 RECEIVED Alaska Oil & Gas Gons. Gommission Anchorage /---.. STATE OF ALASKA ,--. ~ ALASKAL AND GAS CONSERVATION CC ~:ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation [~z[ 2. Name of operator 7. Permit No. Marathon Oil Company 74-24 3. Address 8. APl Number P.O. Box 102380, Anchorage, AK 99510 so- 733-20172-01 Leg #3, Conductor #4, Spark Platform 4. Location of Well at surface 2606' FSL, 2492' FEL, Sec. 26, T10N, R13W, SM 5. Elevation in feet (indicat~KB.DF etc.) I 6. Lease Designation and Serial No. 115' RKB' I ADL-18776 9. Unit or Lease Name North Trading Bay Unit 10. Well No. $-2R9 11. Field and Pool Trading Bay Hemlock & "G" Zone For the Month of August ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks The 3-1/2" tubing and associated completion equipment was pulled. Cleaned out approximately 800' of fill to PBTD of 11,280'. Ran 2-7/8" tubing with a permanent packer set at 10,426' DIL. Perforate 160' of "G" Zone and Hemlock from 10,560'-11,032'. Well put on production. FINAL REPORT 13. Casing or liner run and quantities of cement, results of pressure tests 14. Coring resume and brief descriptio.n 15. Logs run and depth where run 16. DST data, perforating data, shows of H2S, miscellaneous data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--R~ort din th,s form ,s required l[or each calendar month, re§ardless of the status of operations, and must be filed in duplicate w}th the Alaska Oil and Gas ConserYation Commission by the 1 §th of the succeeding month, unless otherwise directed. Form 10404 Submit in duplicate Rev. 7-1-80 STATE OF ALASKA ALASKA: ~AND GAS CONSERVATION Ct MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ OTHER [] 2. Name of Operator 7. Permit No. Marathon Oil Company 74-24 3. Address 8. APl Number P.O. Box 102380 Anchorage, AK 99510 50- 733-20172-01 4. Location of Well Sur fac e: Leg 3, Cond. #4, Spark Platform 2606' FSL, 2492' FEL, Sec. 26-10N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 115' RKB I 6 . Lease Designation and Serial No. ADL-18776 12. 9. Unit or Lease Name North Trading Bay Unit 10. Well Number S-2RD 11. Field and Pool Trading Ba.v Hemlock and "G" Zone Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing ~ Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or ComPleted Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Well S-2RD Workover Workover operations should begin in March 1985, and be completed usin~ the attached procedure. RECEIVED FEB 0 ! ]985 /Uaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Conditions of APproval, if any: BY L(IH~IE C. SMITI~ Approved by COMM ISS ION ER ^pprovec~ Copy Returned By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate NTBU WELL S-2RD WORKOVER RECOMMENDED PROCEDURE 1. Skid rig over Well S-2RD. RU and pressure test lubricator to 2500 psi. 2. Perf tbg above packer at 10,429'. 3. Kill well. Set BPV. ND tree. NU and test BOPE. 4. POH and LD 3-1/2" tbg and packer. 5. PU DP. RIH w/ 8-1/2" bit to top of 7" liner at 7167'. POH. 6. RIH w/ 6" bit. CO to PBTD at 11,300'. POH. 7. RIH w/ 8-1/2" bit and 9-5/8" csg scraper to top of 7" liner. POH. 8. RIH w/ 6" bit and 7" cs§ scraper to PBTD. POH. 9. LD DP. 10. Complete well w/ packer at 10,400', 2-7/8" tubing, gas lift equipment and subsurface safety valve nipple. 11. Set BPV. ND BOPE. NU and test tree. Pull BPV. Obtain stable production test. 12. Perforate the folloWing intervals under drawdown' Bench Depth (DIL) H-3 H-2 H-2 H-2 H-I 11,000' - 11,032' 10,933' - 10,965' 10,878' - 10,910' 10,840' - 10,872' 10,790' - 10,822' 13. Obtain stable production test. 14. Release rig and turn well over to production. 15. Pump scale inhibition treatment. JAB 'cas 09-27 -84 RECEIVED F E B 0 1 1985 Alaska Oil & G~s Cons. Commission AnL',h::~re~ge · ,~--,-~ STATE OF ALASKA :-~-'-~ ALASKa-, -AND GAS CONSERVATION L .MISSION SUNDRY NOTICES AND REPORTS ON WELLS OTHER [] ~~, 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. Marathon Oil Company 74-24 3. Address P.O. Box 102380 Anchorage, AK 99510 4. Location of Well Surface: Leg #3, Cond. ~4, Spark Platform 2606' FSL, 2492' FEL, Sec. 26-10N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 115' KB above MSL 6. Lease Designation and Serial No. ADL 18776 8. APl Number 50- 733-20172-01 9. Unit or Lease Name North Tradinq Bay Unit 10. Well Number $-2RD 11. Field and Pool Trading Bay NE Unit Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 12. NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of startirlg any proposed work, for Abandonment see 20 AAC 25.105-170). On September 13, 1984, an atte~ was made to reperforate the well as approved in the Sundry intent of August 27, 1984. The well was not reperforated because hard fill was encountered at 10,642' 148' above the Bench H-1 perforations 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Conditions of APproval, if any: By Order of Approved by COMMISSIONER the Commission Date O~/ Date ! '[ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA "~". ALASKA-._ ,L AND GAS CONSERVATION C'_ .~IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator Marathon Oil Company 3. Address P.~. Box 102380 Anchorage, AK 4. Location of Well 99510 Surface: Leg ~3, Cond. #4, Spark Platform 2606' FSL, 2492' FEL, Sec. 26-10N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 115 ' KB above HSL 6. Lease Designation and Serial No. ADL 18776 12. Check Appropriate Box To Indicate Nature of Notice, Report, or NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon' [] Stimulation' Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing 7. Permit No. 74-24 8. APl Number 50- 733-20172-01 9. Unit or Lease Name North Tradinq Bay Unit 10. Well Number 11. Field and Pool Trading Bay NE Unit )ther Data SUBSEQUENT REPORT OF: (Submit in Duplicate) Altering Casing [] Abandonment [] Other (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 0 [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). on September 13, 1984, an attempt was made to reperforate the well as approved in the Sundry intent of August 27, 1984. The well was not reperforated because hard fill was encountered at 10,642' 148' above the Bench H-1 perforations Abska Oil & Gas s ig n ed~O.,-~ ,_~. ~--'~'~ The space below for Commission use 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date__ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate "-"~, STATE OF ALASKA "-"~. ALAS,.. OIL AND GAS CONSERVATION L, OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 7, Permit No. ~4-24 ~ 8. APl Number 50- 733-20172-01 2. Name of Operator Marathon Oil Company 3. Address P.O. Box 102380 Anchoraqe, 4. Location of Well AK 99510 Surface: Leg 3, Cond. #4, Spark Platform 2606' FSL and 2492' FEL, Sec. 26-10N-13W-SM 9. Unit or Lease Name North Trading Bay .Unit 10. Well Number S-2RD 11. Field and Pool Tradinq Bay NE Hemlock 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. · 115' RKB ! ADL-18776 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [~ Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon I-] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] q (Note: Report multiple completions on Form 10~407 with a submitted Form 10-407 for each completion,) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is Marathon's intention to reperforate the well with 2-1/8" guns, 4 HPF, 0O phasing, under drawdown: Bench H-1 10,790' - 10,822' DIL Bench H-2 10,840' - 10,872' DIL H-2 10,878' - 10,910' DIL H-2 10,933' - 10,965' DIL Bench H-3 11,000' - Bench H-2 10,840' - 2-1/8" guns, 4 HPF, 11,032' DIL 10,872' DIL will be reperforated with 90° phasing, under drawdown. Well test data Note: 1-11/16" 08-16-84: 82 BFPD, 62% WC, 31 BOPD, .-. ';ubsequent Work Reporte~ guns will be used if 2-1/8" 51 BWPD ~ ' ~l~s~ 0il & Gas Cons. 60m~tS~0~ Anchorage guns will not fit downhole. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Conditions of Approval, if any; Approved by Approved By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, In~ Post OfficE: .... 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 3uly 6, 1983 Mr. C. V. Chatterto~n' State of Alaska 0il and Cas Conservation Commission 3001 Porcupine Drive- Anchorage, AK 99501 .Subject: North Trading Bay Unit - Spark Platform Perforation of Wells S-aRD (11-35) and S-9 (44-34) Dear Mr. Chatterton: Attached are the Sundry Notices describing the remedial well work recently performed on Spark Platform in Cook Inlet. Our stated intentions to reperforate Well S-9 detailed in our June 1, 1983 "Sundry Notice" to you were changed during the work. Well S-9 was not reperforated. Very truly yours, M. D. Haas Area Engineer MDH:MCW:pg Attachment RECEIVED J U L '- 8 ]1983 Alaska 0il & Gas Cons. Commissior~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ,,-.,. STATE OF ALASKA .,... ALASKP'" AND GAS CONSERVATION C'- MISSION SUNDRY O' 'ICB$ AND OH 1. DRILLING WELL [] COMPLETED WELL:g3 OTHER 2. Name of Operator ARCO Alaska, ,Inc. 3. Address P. O. Box 100360 ; .Anchorage, 4. Location of Well Spark Platform Conductor #4, 2606' FSL and 2492 T10N, R13W, SM 5. Elevation in feet (indicate KB, DF, etc.) 115 RKB 12. Alaska~ 995]~ Leg ~3 FEL of Sec~26 i 6 . Lease Designation and Serial No. ADL 18776 7. Permit No. 8. APl Number 50- 133-20172-01 9. Unit or Lease Name . Nor~_h ~rading ~a.y Un~ 10. well Number S-2 RD (1]-35) 11. Fie~d and Poo~ Trading Bay Hemlock and 'G' Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data Zone NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations X~ Altering Casing [] Stimulate [] Abandon [] .Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state' all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following intervals were perforated with 4 spf in June of 1983: Zone Interval G-2 10560 - 10620 G-3 10640 - 10660 G-4 10690 - 10710 G-5 10740 - 10760 H-1 10800 - 10820 H-2 10870 - 10910 10945 - 10965 H-3 10995 - 11015 JLIL - 81,983 · 41aska Oil & Gas COns. '~nchorage C°mnTi~;$ion 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. '[he space below for Commission use Conditions of Approval, if any: Approved by COMMISSIONER By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office E,.,.. ~00360 Anchorage, Alaska 99510 Telephone 907 276 1215 June 1, 1983 State of Alaska Department of Natural Resources Oil & Gas Division 3001 Porcupine Drive Anchorage, AK 99504 Subject: North Trading Bay Unit Well~(ll-35) and S-9 (44-34) Gentlemen: Attached are the Sundry Notices of our intention to reperforate existing producing intervals in Wells S-2RD and S-9. We intend to open to production a non-perforated interval (H-2) in Well S-2RD. Very truly yours, M. D. Haas Area Engineer MDH:MCW:ml Attachment RECEIVED .Alaska Oil & ~as "" .... Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASK/'-""L AND GAS CONSERVATION ~-~FiMISSION 1. DRILLING WELL [] COMPLETED WELL I~ OTHER 2. Name of Operator 3. Address ANCO Alaska, Inc. P.O. Box 100360 AnchoraGe, Alaska 99510 4. Location of Well Spark Platform Conductor #4, Leg ~3 2606' FSLand 2492 FELof Sec. 26 T10N, R13W, SM 7. Permit No. 8. APl Number ,50-133-20122-01 9. Unit or Lease Name ~r~_h q~r~]ing f~y flnit-_ 10. Well Number · S-2 RD (1]-35) 1 1. Field and Pool Trading Bay 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. SerrLtock and 'G' zone 115 RKB I ADL 18776 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~:] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon E] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any' proposed work, for Abandonment see 20 AAC 25.105-170). We intend to reperforate the following intervals with 4 spf: 10560-10580 (G-2) 10590-10620 (G-2) 10640-10660 (G-3) 10690-10710 (G-4) 10730-10760 (G-5) 10800-10820 (H-i) 10995-11015 (H-3) 11060-11090 (H-3) We intend to perforate the following interval with 4 spf: 10875-10905 (H-2U) 10935-10965 (H-2L) RECEIVED JUN 0; !~fl~3 '$ubsequemt Wq~'k .Be?o~ccl D~ted Anchorage No. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title The space below for Commission use Date Conditions of Approval, if any: Approved by ORIGINAL SII NEll DY [OAI~E C. SMITH Approved Returned COMMISSIONER the Commission Form 10-403 ' Rev. 7-1-80 Submi! "Intentions" in Triplicate and "Subsequent Reports" in Duplicate orrn 10-4..03 ~EV. 1-10-.73 ,. ' ~-' ' * ' ' ' - " - .: ";/.' ' . submit"lntention~" in Triplicate · . ',; "' . - & "Subsequent Reports" in Duplicate · STATE OF ,SKA OIL AND GAS CONSERVATION COMMtTTEE SUNDRY NOTICES AND REPORTS ON WELLS {Do not u~e this form for pro~3osaSs to drill or to deepen U~e "APPLICATION FOR PERMIT-j- for ~ch proposals.) OIL ~ GAS F-1 WE~L~ WE~L-J oT.ER NAME OF OPERATOR .. . · ARCO Oil & Gas C .ompan_v ~"' ADDRESS o~ o~TO~ P. O. Box 360, Anchorage, ~- 99510' LOCATION OF WELL Spark Pht£ormr UpPer Cook Inlet Atsurfa~. Conductor 94, Leg:'#3 .... 2606' FSL arid '2492 '--'FCL 'of ' sec.. 26, TioN, m3W:,:'~m: ..... . EL~ATi~'~S [Sh&~ ~hether DF,' RT, Ga, etc,) -' ' 115 ..... - . · ..~ . - . . . - . . .. 5. ~UMER ICAL CODE 50-21.33-20172-0t 6. LEASE DESIGNATION AND SERIAL NO. ADL 18776 . ~ 7. IF INDIAN, ALLOTTEE OR TRIBE NAM'E' ii, UNIT, FARM OR LEASE NA~E North Trading Bay.'.Unit 9. %YELL. NO, 5-2 (11-35) Redrill 10. FIELD AND POOL, OR WILDCAT Trading Bay N.E. :Hemlock ..-. ' · . 11. SEC, T, R., M., [8OTTOM HOLE. OBJEC'~IVE)-- Sec. 34, T10N, R13W, SM .. I2. PERMIT ~.4.'.: - .- . - Check Appropriate. Box To Indicate Nature of Notice, Report, or..O~erData-~, s.oo* o..c,o,z~ ~ .aa. Do.- - ~ sHOoT,"~ oR AC,D,Z,.~ i_ I ABANDONMENT* ~ REPAIR %VELL ~.....CHANGE ~"S . ~ (o,.er) Remrforation 0f .pr~ucing, int~al~- I (Other) [ [' ' (NOTE: R epo~ r~.lts of multiple completion on Well _ -Compbt[pn pr,~ecompletion Reoo~ and L09 form,) 15. D~CRIBE PRO~SED OR COMP~ED OPERATIONS.(Clearly ~ate all petttn~t detalt~ and 9ire ~Unent.date% Including estimated ~ate of ~a~ln9 any propped wo~. We reperforated the following intervals 'in .S-2Rd. (4JSPF; using 2-1/8" thru tubing gun) Hemlock B=i G-5 Zone G-2' Zone -- DIL DEPTHS -- 10,8~4' - 10~798' 16' 10,743' - 10,733' 10' 10,588' - 10,572' 16' TOTAL 42' 16.. i hereby certify that the foregoing Is true and correct RECEIVED- DEC 1 8 1980 ' ., Alaska 0ii & ]3as:C0ns. C0mmjssi0n Anchorage ,. , [l'hls space for State office use) APPROVED BY CONDITIONS OF APPROVAl_, IF ANY.- ..... TITLE OAT E: See Instructions On Reverse Side ARCO Oil and Gas "~ ~any Alaska Distri,~ Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 265 6518 Christian Woessner District Engineer November 17, 1980 State of Alaska Department of Natural Resources Oil and Gas Division 3001 Porcupine Drive Anchorage, Alaska 99504 SUBJECT: North Trading Bay ~Unit Well S-2Rd (11-35) Gentlemen: Attached is a sundry notice of our intentions to re- perforate existing producing intervals in the above mentioned well. Very truly yours, C. Woessner CW:JGA:js Attachment RECEIVED NOV ! 9 ]980 Naska 011 & {3as Cons. Commission Anchorage ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form 10-403 EV. 1~10-73 · ' " ~ '- ' ' Submit"Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE 0[~ . ,LASKA 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.) WELL' --] WELL L--J OTHER 2. NAME OF OPERATOR ARCO Oil & Gas ComPanY 3. ADDRESS OF OPERATOR P. O. Box '36'0, Anchorage, AK 99510 4. LOCATION OFWELL Atsurface Spa.rk Platform Cond. '~4 Leg 2606' F. SL'an'd 2492' iF-EL, of Sec. 26 · T i'0-N'~ R. 1.3 W,.'SM .- . -. · . . IlL ELEVATIONS (Show whether DF, RT, GR, etc.) 115 RKB Check Appropriate Box To Indicate Nature of Notice, Re) : · · NOTICE OF INTENTION TO: · . ... . F.^CTURE~"~A~ ~ ' ~U~'"~ ~O~"~ET~ ~ . s.oo~o. ~c,o,z~ ~ ~.~.oo.* --' REPAIR WELL ' ' I ~_~ CHANGE P~N5 . ~ (Other) ~ou,.r)Reperforat~-~xist~ng producin~ 1 - ' 1 nr_a~va~ s- %. ,Pi NUMERICAL CODE . 50-133-201.72"01 6. LEASE DESIGNATION AND SERIAL NO. ADL 18776 7. IF INDIAN, ALLO~I I-EE OR TRIBE NAME 8. UNIT. FARM OR LEASE NAME North Trading Bay Unit 9. WELL NO. S--2 (11-35) Redrill 10. FIELD AND POOL, OR WILDCAT Tradinq.Bay NE Hemlock' SEC., T., R., M., {BOTTOM HOLE OBJECTIVE) Sec. 34, T 10 N, R 13 W, SM 12. PERMIT NO. 3ort, or Other Data SUBSEQUENT REPORT OF= WATER SHUT-OFF' ~ REPAi RING WELL FRACTURE TREATMENT ~ ALTER lNG CASING # SHOOTING OR ACIDIZING ABANDONMENT* (NOTE: Report results of multiple completion on Well Completion or Recomptetlon Report and Log form.) DESCRIBE PROPOSED OR COMPLETED'OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. We intend to reperfora%e the following, intervals'with 4 10733' - 1'0,743', 10798' spf. 10,572"':' 10,-588' . . r . · , (DIL depths) -: · .. ~.. . ~ · . . . - 10,814' RIEC. EIVED NOV 1 9 1980 Naska 0il & Gas Cons. Commission Anchorage . I hereby certify that the foregoing Is true and correct {This.space for State office~se) /-~ .~/? . .~ , '. c.... ..... . ~j .'. -..,~ COMMI$$sTOATEi:~ CONDITIONS OF R~OVAL, IF ~V: BY ORDER 0F THE- COM~ISSION . . . See Instructions On Reverse Side DATE. 11//').~ ~ DATE,, Approved Copy Returned Fo~m 1 R~V..1-! 0-? $ Submit "intontlo;v:' In '1 riplicate & "Subsequent Reports" In Duplicate STATE C _ASKA 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.) OiL l--fl CAS i--! WELL I -] WELLi I OTHER 2. NAME OF OPERATOR ARCO Oil & Gas 3, ADDRESS OF OPERATOR P. O. Box 360, 4. LOCATION OF WELL Company Anchorage, AK 99510 Atmdace Spa.rk Platform Cond. 04 Leg #3 2606' ESL and 2492' FEL of Sec. 26 - T t0'N, R 13 W, SM ELEVATIONS (Show whether DF, RT, GR, et~) 115 RKB Check Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO; ,. [mn~oReperforate existin9 producin~ I PI NUMERICAL CODE 50-133-201.72-01 6. LEASE DESIGNATION AND SERIAL NO. ADL 18776 ' 7. IF INDIAN, ALLOT'FEE OR TRIBE NAME 8. UNIT, FARM OR LEASE North Trading Bay Unit 9. WELL NO. S-2 (11-35) Redrill 10. FIELD AND POOL, OR WILDCAT Tradin~..BaY NE Hemlock' 11. SEC.,T., R.,M.,(BOTTOMHOLEO~JE~IVE) . Sec. 34, T 10 N, R 13 W, SM 12. PERMIT NO. ~ort, or Other Data SUBSEQUENT REPORT OF: WATER SHUT-OFF' ~]. REPAIRING WELL FRACTURE TREATMENT q ALTER lNG CAS lNG # SHOOTING OR ACIDIZll'~-, ABANDONMENT* (Other) (NOTE: Report result'~ ,:.t multiple completion on Well Completion or Recompletion Report and Log form.) DESCRIBE PROPOSED OR COMPLETED'OPERATIONS {Clearly state all pertinent details, and give pertinent dates, Including estimated date of M:artin9 any proposed work. We intend to reperfor~te the 4 spf 10,572' ' 10,588' (DIL depths) following-intervals with '10733' - 10,743', 10798' - 13,814' RECEIVED NOV 1 9 1980 Alaska 0il & Gas Cons.. Commission Anchorage I hereby certify that the foregoing Is true and correct (This space for State office, i::/. (//~~u ~/., ~/ CONmTIONS OF A~OVAL. ~F ~L~Y ORDER See Instructions On Reverse Side DATE - DATE /,,// ? Approved Returned AtlanticRichfieldCompany North Am~F"~ Producing Division South Al~'- jistrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 September 5, 1974 Mr. Homer Burrell State of Alaska Department of Natural Resources 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Burrell: Enclosed are cppies of the Completion Report, openhole logs and' direction survey for the NTBU S-2 (.11-35) redrill well recently completed on the Spark Platform. Very truly youFs, James_ D. reamer _ District Drilling Supervisor JDK/gld Attachment ["ol'~u P.- ? -' SUBMIT IN DI, .. !~ATE* STATE OF ALASKA ~seeoth~r m- st ructions on OIL AND GAS CONSERVATION COMMITTEE r~v~,.~ side; i. i i WELL COMPLETION OR RECOMPLETION' REPORT AND LOG* w ELL W ELL DR Y Other b. TYPE OF COMPLE~ON: NEW WELI, ~ WORK OVER ~ DEEP- EN ~ PLUG ~ DIFF. ~ACK ~S,',.~ Oth~ Redr!!l 2. NAME OF OPERATOR ' ~ Atlantic Richfield Compa.n.¥ , , 3. ADDRESS OF OPERATOR P.O. Box 360 Anchorag.e~ A~aska 99510 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* Atsu~ace Spark Platform cond #4,.L~g #3, 2606' FSL ~ 2492' FEL of Se¢'26...T10N, R13W, SM ' At top prod~tervai repor~eaoelow _ , 701' FNL & 91' FWL of Sec 35, T10N, R1SW, SM ~t total dep~ 1057' FNL & 221.''FEL of Sec 34, T10N, R13W, SM ORIGINAL 5. API NUI4E, RICAL CODE 50-133-20172-01 6. LEASE DESIGNATION AND SERIAL NO. ADL 18776 7. IF INDia. N, ALLOTTEE OR TRIBE NAiVIE 8. UNIT,FA/i.M OR LEASE NAME North Trading Bay Unit 9. WELL NO. S-2 (11-35~ Redrill 10. rm~b ~d~v rGon, OR WILDCAT ~adina Bay NE l-lamlnak 11. SEC., T.~R., M.~ (BOTTOM HO~ O~E~IVE) Sec 34, T10N, R13W, SM 12. PERMIT BrO. ~ . 74-24 6-13-74 J · 7-11~-74· [ 7-31-74 115' RKB ~ i%{TT~EPTH. MD & TVD[1O.iPiLUJ~C.'.I~_ MD & TVD[20. IF lVIULTI2PLIg COM. PL., ] 21. -';NTERYALS DRtI, LED BY ~,~,~ ~'a~-, [ 11~ ,.)UU '~D [ I{OWlVI. A.N¥* ~ ILqLTARI TQDLS ' '! CABLE TOOLS ~%7~0~ t~- t11X~sm, ~ "G" and Hemlock 10,563 - ll,145'MD ' · MADE 9,500' - 9,9'68'TVD o ' DIL, FDC-CNL, CBL -GR ~: Collar Locator ~v~.~ ~.~ .... , i~ ,., CAS~G RgCORD (Report all strings set in well) C~S~4G SIZE ~ -' ..... ' 15 ~/8" 9 5/8" 26. 7ti [ J-SS [ 2.000' 18" 2000 sx (m'ioin, l% , .47.' N aP 10,949.? LINER l~IgC O~D TOP (A'ID) 7167' 28. PEI~WORATIONS Op~._2N TO PRODU ON'' (interval, s'- e~ and number) 10,563' - 10,618' .5"' 4 SPF 10,643' - 10,668' .5" 4 SPF 10,694' - 10,714' '.5" ,' 4 SPF 10,733' - 10,758' .5" 4 SPF 11,008' - 11,058' .5" 4 SPF I 'A~O, UNT PULI,~.~" 12 1/4 .1COO .qx (m-iginn!i Il I I I II I III IIII 27. TUBING REC OP~D' 11.341.' 1.175 "C," _ -. - E ,--~~50!' !O,a. 55' Onen holm/TH~ g Hirec_tian~ 33. I here~ ee~if~ that the f~egot~g ~nd atf~h~d~nformation is complete and eorrec~ as determined from all-available records SIGNE - _ _ ~ ,. - . TLE ~~~__ DATE ~~ ........... / omnu~ u. ~eaSl~r So. District Bvillin~ a,,~-~,,isnr ' ~ *(See Instructions and S~ce, for Addi,ional Data on Reverse Side) so. II,U/5 - II,D~5' .b" 4 ~'DUCTIOAI ' ' ' ' ' DA~p~ 5~luL-in) · 7-28-74 . [ Gas Lift 8-2-74 . [ 24. ' J~en ' ] ~041 [ ~Xn [ 77~ i PLO?', ~BING }CAS~G PRESSUR~ ICA~C~'i'~ OI~BBL. GA~C~. W~BBL. -- ' - tOIL GRAVI~I (CO~.) 140 .J 1120. [ - > [ 2041 I 430 J 278 . 31. DISPosiTIoN OF GAS (~Old, u,ed ]or ~uei, vented, etc.)- 29. ACID. Si!OT, F;~AcTcrRE. CE2,IENT SQUE_~ZZ, ETC. DEP~Ii 1NTEllV.~L (MD) /AMOUN£ ;,ND I(iND OF MATE~....AL. USED SqueeZed. liner~lipl a7.167' w/!DO ~w "G" INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lands and leases in Alaska. item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- merits given in ether spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separate production from more than one interval zone (multiple completion), so state ~n item 20, and in iteq~ 22 show the prcJuc~,g interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. ,Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produced, show- ing the ac:fditional data. pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this welt should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 ~bove). WATV_.,R AND MUD NAM~ M~-AS., Beluga + 1450' + 1446 Tyonek 3709 ' 3492 MGS 5038 ' 4672 Top Hemlock 10790 ' 9686 Top W. Forelands 11233' 10037 AND I)~'I'lilCTEI) SlIOWS iii i · i il ii JOB No A-6-5-?L; .__ DATE 8-2-74 ........ REPORT and PLAN of SUB-SURFACE SURVEY 'COMPLETION REPORT JULY ATLANTIC RICHFIELD cO. NORTH TRADING BAY UNIT 5-2 REDRILL KELLY BUSHING ELEV, 115 FT "DECLINATION 24 DEGREES TANGENTIAL HETHOD OF COMPUTATION PREPARED FOR ADDCO BY F. H,'LINDSEY $ ASSO¢, RECORD OF SURVEY ............ ALL CALCULATIONS' PERFORMED BY I B H ELECTRONIC ........ COMPUTER--- - - TRUE MEAS. DRIFT VERTICAL SUB DEPTH ANGLE ...... DEPTH ...... ~EA ..... 7375 22 45 6832.52 ..... 6717.52 7395 23 15 6850.89 6735.89 7466 24 0 6915.75 6800.75 .... 7546' 26 30 6987.35 6872,35 7609 27 30 7043.23 -6928,23 7670 29 1:'5 7096,45"-6981.45 ....... 7765 31 0 7177,88 7062,88 7859 33 15 7256,49 7141.49 7943 34 15 '7325.93 7210.93 ..... 80A2'35 15 7406,77-72'91.77 ........ 8( 33 30 ...... 7489,33 7374,33 ..... 8259 33 - 0 '7559,78 ......... 83~9 32 30 ..... 7639,06 ~"'?~2~,06 8413 32 15 7718.55 ..... 7603.55 ' 8506 31 45 7797,64~' 768Z.64 ..... 8589 3! 45 ...... 7868.22 :" 8683 33 15 -7946,8~ ....... 7831.8~ 8809'36 0 80~8,76 793~,76' ~' 8914 37 ~0 ..... 81~2.07 8017.07 ..... 9007 37 .29102,.36 9227 ..... DRIFT' TOTAL DIRE¢ S 37 W 2046,67. ~$ ~3 W 2052,~ $ 34 W 2076,38 $ 38 W 2~04,51' $ 4~ W 2126,46 '$' 39 W 21~9,63 S 40 W 2187,11 $ 41 W 2226,01 $ 42 W 2261,14 $ 42-W 230~,60 · 46 W 2374,69 -46 W ........ 2409,77 44 W 2~45,85 44 W 2481,06 46 W 2511,4'0 44 W 2548~47 42 W 2603.51 ~1W 2651,75 2693.58 3.75 7,69 15 8206,09 8091.09 $ 42 W 0 8282.95 8167,95 $ 44'W 273 · -'30 .... 838~.7! ........ 8269,71- $-42-'"-W .......... 278 COORDINATES' " C L 0 ....... DISTANCE ... S 501,98'WL~ 2538,'66 5 1507,36 W 2546,50 5' 1523,51W 2575.35 DOG L'E6 ............................ S .U R E $ SEVERITY ..... SECTION..- ...... ANISLE ......... DEG/IOOFT .............. DISTANCE- ~ 36 ~6 25 ~ OEO00 .......... 2536,85 S 1545,48 W 2611,03-S 36-17 32 S 1564,57 W ....... 2640,03 $ 36 20 39 S 1583,33 W .2669,80 S 36-.22 25 5. 161~.78 W ...... 2718,63"-S-36 26 20 S 16~+8,59 W 2770,01 $ 36 31 25 5 1680.22 W 2817,07 S 36 36 56 $ 1718.46 W.' W 3,782 ........... 2607,17 .... W 2,682 ..... 2636,2'5 ..... W 3,264 ...... 2666",05 W ............. 1,9 16 .................... 2'7 W .... 2,459 .............. 2766,50 ....... W .... 1o362 .............. 2813.',73 .... 2873,97" $' 36" 4'3' 20'"W .......... 1',0~0 ................... 2870,80 1756,/~! W 2928',17 $"'36 51 .... 28 ..... W .................. 2,1-04 ......................... 292'5,,27 1789,32'W ..... 297'3,35 '5'36---'59 ..... 52' W ..... 1~435 .................. 2'970',7-2 1825,65 W ...... 3023';25 ..... $' 37 ......... 8 ...... 5-1'-'-'W ....... 0,532 ....................... 3020,-8.~ 1860.50 'W 3073.05 '$ '37" 15 33 W ......... 1',1"70 ..... :: ........... 3070.89 ......... 1896e49 W "/3'~21.66 5 37 21 53 ~ ....... 0.538 ............... 3119,67 5~925.91 W ~".3~64.85 $ "37"29 ....... 0 W .............. 1-268 .......................... 3t63~'06' 1961.71 W 3216,0'6 '5'37 35 ........ 15 W ................ 1,963 ................ 3214".'43 ......... ' 2011.27 ~ 3289.90 S ~7"~1 12 W 2.361 ..... ~288'.~2 2053.21 W--' 3353,72 S-37 ~5 O'W ................ 1.538 .................. 3352i~t- 2'090,87' W 3409.86 S 37 ~9 12 W 0.706 ...... 34.08.55 " S- 2129~66 W ...... 3~65.38 S"-37-55 'IO""W' ..... 1.819 .................... ~66~".2t 2178,23 W: ........ ~537,'79 ....$"-'38 ........ 0 11-.-~..: ................ 1'.017 ................. :3536,-72~- 8556.33-8441,33 $' 46 w 28-68,10"S 22.61,50 W 3652',45"S'"38' 15-20 W ........... 1,3.i8 .................. 3651'i'"7'1 .... . · TRUE ...... · -, . - DO'~ LB.B .... -. NE'AS, D.R[FT VERTICAl.. __.iSuB'"...'~'' DELFT.:'".-. .... TOTAL.COO-ED.[NATEs.-'~/...;i~..'C' L o $ U R E. S .... SEVERITY SECT[ON ...... .:DEPTH ANGLE.'..DEPTH ............... SEA .............. D']REC. ' ' ' D[$T'ANCE -'ANGLE -..DEG/[OOFT ' D'['$TANCE _.;:-.' D H ................................ ' .... DEG, '.:'.i.' ........ ' ............. ·i'. .......... .~. ......... ' ............... L ............ ~ .... D.- '~' $ .......... ' . ....................... . ........... ............... .: . : ..................... ................. . ........... 9535 33 45 .86.40,30 852.5,30 S 45 W : .2907,78.5 2301o[8 W .... .370'8,18' $'$8 21 27 W 0,605 3"707,56 969~ ~4 15 8770,91 8655,9[. $ 46 W-' .2969,'55 .$~2365,14 W..~/~796,33 S'~8 ~2 9 W 0,475 3795,89 9869 34 0 8916,82 ' 880X'82 .... S. 46.~ 3.03'7,92 $ ~35e9~ W ....... ~'8'93.,94 $ ~8 ~' 27 W 0,142 ~89~,66 100'6.8 33 30 9'082,76.. 8967,76 .... $ 44. W ...... 3116,93 S. 2512,24:.~ ..... ~003,.32-.$ 3'8 52 7 W ........... 0,612 ~0.03,14 ..... 10301 32 O. 9280,35 9165,35 S ~5 W '3204,23 $ 2599',~4 W ..... 4126,1!' & 39 ~ 6 W 0,684 4.126~03 10612 33 .~5. 9373,18 9258,18.. $ ~5 -W .......3247,27 $. 2&~.2,~8. W ....... ~186,64 $ 39 8 17 W 1,12~ 4186,60 .105~6 35 0 95~5,71 9400,71 $ 43 W .... -3320,26 $ 2710,64. W 4.286,23 $ 39 ~3 .40 W 1,195 ~286,20 10707 34 45 9615,13 9500,13 S 45 W .336'9,03 S 2759,.41. W 43D4,85 $ 39:19 9 W 0,967 .10879 36 45 .... 9752,95 963'7,95 $.4~ W 3~5'5~"GV/282'8"27'"H'~'~7'6~"$2 ~'9 2.2' 5'2 W ~,54~6 .4.~57,&5.~ ~097~. 38 15 .9826,77 9711,77 ...... $...~.I W ........ 348.9,~3 S.....2866,~ ~ ............ 4.§~5,8. $ 39 24 7 W 1,722 ~51~,82 ]1150 38 15 9965,77 9850,77 $ 40 W 3573',37 $. 2936,89..W ~625,~0 S 39-2~ 58 W 0,350 ~625,~0 .. '.o~to~ ~,o.~.'Cco'sU,~ ' ~?"~""~..~AF'S" S~ i',='Z"' Z~', .~' ...... . i-ii',ii.!.../' ii..!i ...... i ..... i.' ..... ._' .............. .. '_ ',~' .i," 'r_-,".'' ....... ....... / '" : · .................................... .................. .............. .......... 3 : 'L ' ........................ OUTED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, TRUE -.MEASURE-D -- VERTICAL SUB -- ND-TVD ....... VERTICAL ---DEPTH ............ DEPTH SEA DIFFERENCE- -- CORRECTION- TOTAL COORDINATES 7465 ........... 6915. 6800,- 550 ............ 550 ............. 2076,10 S - 1523.32 -- 757-.7 ............... 7015, .... 6900, - 562 ........... 12 .............. 2115,37 S i55z~,9~ -7692 .......... 7115,- 7000, 57-7 ............... 15 ........... 2158,16 S t590,49-W '" --2809 ........ 7215, 7100, 594 ............. 17 -- - 2205.z+7 S 1630,7~ (. ?930 ............. 7315. --7200, 615 ............... 21 ................ 2255,6t-S-- 1675.2~ ...... 3052 .............. 7~15. 7300.- - 637 ............. 22 ......... 2307,51 S 1722,2~-W .... 8172 ............ 7515. 7~00, 657 ........ 20 ....... 235A.~8 S 1768.~0 -- 8290 ........... 7615, 7500, 675 ............. 18 .......... 2399,12 S 18!~,63 ....... 8~09 ............ 7715, 7600. 69~-- 19 2~C, 2~ S- 1858.9~ ...... 8526 --7815.- 7700, 711 ............. 17 ....... 2~88.52 S 1902,22'W .......... 86~.5 .............. 7915, - 7800, .... 730 ................ 19 - 2533.~6 S 19~7,22 ..... 8767- 801-5.---7900,-- 752 ................. 22 2585.28 S 199~.85- 8892 ........... 8115.-- 8000, 777 .................. 25 .... 26~1.86 S 20~+,~1 ........... 9018 ............ 8215, ......8100, ...... 803 ........................... 26 .......... 2698,23 S 2095 · 36:--W ............ 91~-1 8315, 8200, ..... 826 ........................ 23 ............ 2750,74 S 21z+~, 96 ..... ........ 9264 8415.-- 8300. ..... 849 ............................ 23 ....................... 2801,88 S 2192,92' ...... 9~8¢ ................ 8515. 8~00, ........ 869 ..................... 20 ....................... 28~8~7~ S--~ ..... 950~ ..................... 8615~- 8500~-- 890 ................... 21 ...................2895,82 S . 2289~22 .... ............ 9.62-~ ............ 87-t5,-- 8600, .... 9t0 ................. 20 ............ 29¢3~1!- S ...... ..... 97¢6 88t~---8700~ ..... 9~1 ..................... 21 ............................ 2990~21 S ' -986-7 89t-.5,-- 8800, .... 952 ...................... 3037.06 2~35,05 .: ...... 9987 90~5, ..... 8900, 972 ........................... 20 ...................3086,66 S ....... 10106 91-15. 9000, 99~ ........................... 19 ..................... 3131,17 S ...... 2526.¢8 .... .... ~022-~ '-92~5,- 9100, 1009 ............................... t8 ......................... 3t75,35 S - 2570,66-'-W ..... t0'3 ~2 9315,' 9200, 102~ ................ 18 ................ 3220,29 'S ...... 2615,60-' W ~.10n6¢ 9~15, ..... 9300, ---1048 ................................... 21. 3268,68-S ....... 2662,55-'~ ..... t-0.58-5. --9515, 9~00, ..... 10-70 .......................... 22 ..................... 331-9,89 -S ...... 27t0,30-W t~-70-7- 96.15,-- 9500~ ...... t-092 ....................22 ............. ~368,9.6-S ......... ~--t0 8-32. 97--1-5 · ....... 9600 ,-~t-'1-'t-7 2~ ........................ 3424,44 S ..... .... 109-58 .... 9815,- 9700, .... ~3 ........................ 26 .......... 3~82,~2- $ 2860,36- ~ ........ !t085-- 9915,-- 9800, ....... 1170 ....................27-': ............. 35~2,'7~ S 29t1,16 /RP'"')LATED-VALUES' FOR EVEN 1000 FEET OF '.",'tEASURED DEPTH, TRUE ............................................ ME A 5URE'-D ..... VERTICAL- ......... SUB DEPTH DEPTH ...... SEA ........ TOTAL- COORDINATES ................ ...... 8000' 7372,'" 9000 ......... 8200. ----&O008 9026. ........ 1t000 98~7.- 7257. ........ 2295.59 S 8085. ..... 2690.43 S 8911. ..... 3089.93 S 9732~ ........ 3502.23 S- 1702.24 2088,04 2486.16"W 2877.20 , ~ ; · ~ ~ , .' : :_ ~ ', ~ .; ..... ~ ..... i~' L t ' _ ~ .' ~ .......... ~ ..... ~ .L-~ ..... L_; . ,, ~" ~ ..... .,. E ~ ....... : ....... ;..~ ..... : d.. '. :..J_: '. ,.SCALE I =500 ........ ._~ ;..: ~.'.~ ... ~ .... ~_~l..t.~.~.~ .... : ...... ,._~._:...t.~ i-ATLANTIC RICHFIELD CO.* .'.: ....... ~'-'-' l-t-l"t'/'-, ........ ' = ..... ................................... ' . , , , ..... ~. . .L :_ ~ .L .... L.:.." _J .... : .... ' ' t ' ....... 7-I .... ,'-; ......" i ' , ~ ; : I: ; ..... ~' '-~ ~ '-i'x-: .... ; i'~-~'-':' 7'-;- '," <'",: ' ', : ' - : :'-, ' ';-:-:"': ~ "h-:'t': ,': ~ ,'1': '"-,-; .... :,-"?' ': ' i~/ / ' · ~ ~ .~ .. ....... ,, ..... ~ ..... ~._.~ ........ ~.~ ...... ',_j.~ ~ .',.~_ ~.. , . ~ , ~ .... ~ ~ ..... ~ ~ I ...... t' ..~ --; .... ~*- :-.-.--t ...... . ' ....... . , ' 0 · , ' I : ~ : ' [ , ] ~ ~2.~I.~_ ~ , ' '/~ :-'.; '.1.~.; ' ..~ ; _ . .~ ................................. : . 200 .......... ~ ~-;"; i , ;"~_Z'l-7; ~_ ..~ .... ' I. ~~__~.~ ~.. . . - ..... ,; . ~ . ,'7i ..... 7"/"'~~" ................... r ............ / ~ '" ~ .' : I '' '~ ~' ' ' I I ~ ' , ~ ' _L ~__. ,.. .' ~., I : , . .... , .... ,.. ~ ~ ~%~; ;- ..... ~-'~' , ~'; ~:~,.f-'j.'l-'-?.-~-.Jt~.~ .... 1-'.-;.~-,-.~ -~ ~-~.~- ---~,-.-~.- .~-r ......... ~ <7-i~-i-~ ~ ~U~/-Ti-TF-i- ~?c"FT~ ' C"?i ....~ ' 7- i . . I COMPLETION REPORT- JULY 18~197t+- ATLANTIC-RICHFIELD CO, NORTH TRADING BAY UNIT S-2 REDRILL KELLY BUSHING ELEV,- 115 FT DECLINATION 24 DEGREES ~ADIUS-OF .CURVATURE METHOD OF COMPUTATION' PREPAY, ED FOR ADDCO BY F, M, LINDSEY $ ASSOCo ................................. RE~ORD OF SURVEY ALL CALCULATIONS PERFORMED BY ! 0 M ELECTRONIC CONPUTER ...... TRUE ........................ . ................... DOG LEG HEAS, DRIFT VERTICAL- SUB DRIFT TOTAL COORDINATES C L 0 S U R E S SEVERITY '- SECTION DEPTH ANGLE DEPTH SEA' DIREC ..... DISTANCE' ANGLE DEG/IOOFT DISTANC ............ D M DEG, D M $ -- '7~75 22'45 6832e52-'6717,52' S37eOOW 2046e67 S 1501,98 W 2538,66 S 36 16 25 W 0,000 -' 2534,85 .... 7395-"23 15 6850,93 6735,93 S$3,00W 2052e65 S 1507,00 W 2546,45 S 36 17 6 W 12,222 2542,66 7466 2~ O' 6915197 ' 6800,97 S34,00W 2074,89 S 1524,69 W 257&,85 S 36 18 ~4 W 5.338 2571,08 .... 7546~ 26-'30- 6988e32 6879e~2 S38,00W 2102,49 S 154~,74 W 2608,97 $ 3'$ 18 19 W 3,900 2605,14 7609 27-30 70~4e46 6929e46 S41,OOW 2124,56 S 1562,93 W 2637,52 S 36 20 24 W'- 2,742 7670 ....... 29~ 1'5 7098,13 6983,13 S39,00W 2146,77 S 1581,57 W 2666,~5 S 36 22 ~7 W 3,308 2662,72 --7765~3r---0-' 7180,29" 7065,19 S40,OOW ~183,55 S 1611,89 W 271~,06 S 36 26 ~ W 1,92~' 2710,40 -7659-33-15- 7259,89 ' 714b,89 S41,00W 2221,55 S 1644,35 W 2763,92 S 36 30 29 W ..... 2,~68 .... 2760,~7 7943 3~'-1~"-7329,7~'- 7214,7~ S~,OOW 2256,5I S 1675,28 W 2810,41S 36 35 27 W 1,370 ........... 2807.0% 804~ 35- 1.5 7411,08 7296,08 S4~,OOW 2298,~5 S 1713,03 W 2866,59 S 36-41 ~9"~W .... 1,010--- 2863,38 81-~I-'33" ~0 7492e79 7377e79 S4~,OOW 2339,32 S 1751,15 W 2922,15 S 36 49' 3-'-W - 2,077 2919e16 8225-'33 0 7563,0~ 7446e03 S46,00W 2971e89 S 178~,72' W 2967,75 S 36 56 3~-W leal9 .......... 2965,0¢ .... 8319 32 30~'' 76~2,09 7527e09 S46eOOW 2407e21 $ 1820,30 W 3017,97 S 37 5 45 W 0,532 .... 3015,5I' 8413 32' 15 7721e46 7606e46 S~4eOOW 2~42e80 S 1855e88 W 3067e83 S 37 13 30 W ..... 1,162 ...... .... 8506-31 .... $5' 7600,35 7685e35 S44,00W 2476e25 S 1890,12 W ~116e78 S 37 19 55 W 0,538 ..... ~114.7[ .... $589-~-45 ..... 7870,93' 7755e93'- S$6,00W 2509e13 S 1921,00 W 3160,07 S 37 2~ 16'~'W 1,26~ ..... ' ....... 3158,1~ --8683-"33-15 7950e20 '7835,20 S~4,OOW 2544,85 $ 1956,71W 3210.14 S 37 33 23' W .... le99I ..... ~208~ '-8509 96-- U'--805~eS$ 7938e88 S42,00W 2597e20 S 2005e5~ W 3281e40 S 37 40' 29 W 2,38'~ ...... 3279,9¢ --'89~"~'3730- 8138e01" 8023e01 S41eOOW 26~a,25 S 2047,1~ W 334ae09 S 37 ~ 48 W ....... 1,54~ ........ 9007~37'~15 - 8211,91 8096e91 S42eOOW 2686,53 S 208~,56 W 3400,42 S 37 48 32 W- 0,702 3399,05 9102'"35 0 .... 8288,15 8173e15 S~4,OOW 2727,98 S 2123,21W 3456,86 $ 37 53 38 W 1,79~' .."9227-35"-30 8389,60~ 827~,60 S42,00W 2781,38 S 2173,02 W 3529,61S 37 59 58 W 1,006 ..... 3528,54 "943~"3~ 0 8559,68 8444e68 S~6,00W 2866,2~ S 2254,96 W 3646,94 S 38 11 3~ W 1,28~ 3646,1~ 9535 33 ~5 .... 86~3,53 8528,53 S~5,00W 2905,70 S 2295,11W 3702,79 S 38 18 14 W 0,602 - 3702,1C 9693-'3'~~ ~5 877&,52' 8659,5Z S~6,00W 2967,62 S 2358,~3 W 3790,46 S 38 28 ~6 W 0,478 3789,95 . _ .................... ......... RECORD OF °SURVEY CALCULATIONS PERFORHED BY I B M ELECTRONIC COMPUTER TRUE ~EAS. DRIFT-VERTICAL---- SUB .... DEPTH-ANGLE .... DEPTM-] .... SEA-- D .... M ...... 9869 3~ O- 8920.22- 10068 33 30' 9085,68 10301 32 0 9281.63 10~I2 33 I5 .... 9375,I2- 1058~35--0--9519.15 10707-34"45--9618.42 8805,22- 8970.68 9166.63 9260,12 9404,15 9503,42 DEG,. DRIFT .... TOTAL COORDXNATE$ ....' C L 0 S U"R E-$ 7 DIREC ...................... DXSTANCE- · S46.00W 3036.21S 2429,16 W 3888,37 S44,00W' 3114,38 S 2507,33 W 3998.26 S45,00W 3204.28 S 2595,67 W 4123,71 S45.00W 3246,60 S 2637.99 W 4183.23 S43.OOW 3316.81 S 2705.79 W 4280.48 S45,00W 3366e57 S 2753.85 W 4349e43 S42.00W 3439,46 S 2823.01W 4449.64 S41,00W 3482,31S 2860.93 W 4506.82 $40,00W 3565,64 S 2932,09 W 4616,38 S37.OOW 3662.61S 3009,23 W ~740e27 10879 36'-~5'--9758.00-9643.00 10973 38-15-- 9832.58' 9717.58 11150 38 15-" 9971,58' 9856.58 1'1353 37 0 10132,36 10017.36 BOTTOH'-HOLE-CLOSURE ....... 4740,27 FEET AT S 39 24 2¢ W ............ DOG LEG ..... SEVERITY .... ANGLE ...... DEG/IOOFT ' D M $ .............. 'SECTION-- DISTANCE ___ S 38 39 43 W' 0,142-- 3888'03- S 38 50 12 'W-' ' 0.606 3998.06 S 39 0 34 W -'- 0,681 '~' 4123,61-' S 39 , 5 42 W - 1.126 -'~ 4183'16 S 39 12 24 W 1,211' 4280,46 $ 39 16 59'W .... 0,962 ......' 4349'"4Z' $ 39 22 41 W ...... 1.579 ....... z+449';64- S 39 2~ 18 W 1.731 '- ~506.82" S 39 25 52 W 0.350' ~616',38 S 39 2~ 2~ W 1,071'-- ~7~0,27 MEASURED' DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. .... TRUE . -*- MEASURED .... VERTICAL SUB' MD-TVD VERTICAL DEPTH ............. DEPTH SEA DIFFERENCE CORRECTION 7576 -7689 7806 7925 ....... 8047 ...... 8168 .......... 8287 ........ 8~05 ........... 8523 6915-. 6800 549 ......... 549 7015. .... 6900 560 11 "7115, - 7000 574 "14' 7215. 7100 590 ......... 16 7315. 7200 610-- 20 7415. - 7300' 632 .............. 22 7515. 7400 653 .... 2I ........ 7615. 7500 672 ......m ...... 19 7715. 7600 690 18' 7815.- 7700 708 ........ 18 7915,- 7800"- 726 ...................... 18 8761-- 8885' -- 901I~ 9135 9258 -- 9380 9501 9621 ' 9742 986'3 9983-- -'10103 10222 103'4'0 -- 10~6'0 10581 10703 10826 10951 1 t-078-- I133'1 8015, ........ 7900- 746 8115." 8000 770 ......... 8215. ..... 8100" 796' 26 8315.- 8200-- 820 ............. 8415~ - 8300-- 843 ............ 23 ....... 8515' .... 8~00 865 ...................22 8615~ ..... 8500' 886 ........................ 21 8715. -' 8600- 906 ............ 20 .......... 8815.-*' 8700-~ 927 ....... 21 8915. ...... 8800" 948' 2t 9015.- 9115. 9215. 9315. 9415'~- 9515. -- 9615~ 9715-' 9815. 9915e 8900 968 ........................ 20 ................ 9000 988 .................. 20 9100 1007 .......................... 19 9200 1025 ................ 18 9300'' 104~ 19 9400- 1065 9500' 1088 9600 1110 ............... 22 9700 1135 9800' 1I'63 ..................... 28 0015. ..... 9900 1190 27 0115',- 10000 1215- ....................... 26 TOTAL COORDINATES" 2074,53 S 2112,985' 2154.01 2199.79 S 2248.99 $ 2300,50 S 2349,81S 2439.74 S 2484.67 S 2528.56 S 2576.64 S 2631,02 $ 2688,27 S 27~1.97 S 2794.73 $ 28~.97 S 2892.23 2939,4~ $ 2986,74 3033,76 $ 3080.83 $ 3128,26 $ 317~,46 3218.99 3265.42 S 331~.69 S 3364,89 3~16.2~ 3471.94 S 3531.57-$ 3591.85 1524,45 1553.15".W 1587,~5 1625.62W 1668.53 1761.39 1807.8~ 185.2.91 1896.36 1940.73'W 1986,75W 2035.60 2086,13 2136.60 2185.16 2233.30 2281.57'--W 2329.18"-~ 2377,93-W 2~26,62--W 247~,45-W 2520.77'W 2566,02'-W 2610.38'-W 2656.63-W 2703,81' W:-- 2752,17""W S ..... 2801,7.5-W 2851,87 'W 2903,30 W- 2953,77 W 3652.0~ $ 3001,22 -INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH,* -- TR~E ....................................... MEASURED .... VERTICAL ..... SUB DEPTH DEPTH SEA ..... : TOTAL COORDINATES ................................ . 8OO0-- 9O00 1O0O0 11000-- 7376. .... 726[. 2280.53 8206. 8091~ .......... 2683.38 9029. 891~4 ....... 3087.k8 9853, 9738. ........ 3~9~.9~ 1696,90 'W 2081,73-~W- 2~81.0~ W 2871.88 W :~..¥ERTICAL_,_~!'SECT/ON i SCALE=I",vvv ~r~a"r~c .ic.~L° o~£ · NT B.U- RADIUS CURVATURE · r ' " 5'00' , SCALE, I -' · . ',_ATLAN:TI¢ RICHFIELD OIL i NTBU $'~.i(REDRIL ) I0,0 O! AtlanticRichfieldCompany North Ame~.,~9 Producing Division South Alas ~istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 5, 1974 Mr. Homer Burrell State of Alaska Department of Natural Resources 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Burrell: FILEt _'_,- Enclosed are copies of the Monthly Report of Drilling Operations for July for the NTBU S-2 (11-35) well recently completed on the Spark Platform. Very truly'~ '~easler District Drilling Supervisor JDK/gld Attachment AU6 9 I974 DiVISiON OF (}IL ANi) {];AS No. P---4 $- I-?0 STATE OF ALASKA OIL AND GAS CONSERVATION COMMI'rrEE SUBMIT IN DUPLICATE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Wl~LL NAME OF OP~TOR Atlantic Richfield Company ADf~hESS OF O~n~ATOR P.O. BOX 360 Anchorage, Alaska 99510 4. LOCATION OF W~J~L At surface Spark Platform cond #4, Leg #3 2606' FSL & 2492' FEL of Sec 26, T10N, R13W, SM ; AP1 NI3~E~CAL CODE 50-133-20172-01 6 L~._ASE DESIGNA~ON A~D $~IAL NO. ADL 18776 T IF INDIAN, ALOT lkl~ OR TRIBE NAME 8. L~,'IT FARAi OR LEASE NAME North Trading Bay Unit 9 W~!.L NO S-2 (11-35) Redrill 10 FIF..T,D AND POOL. OR WILDCAT Trading Bay NE Hemlock Lii SEC, T.. R.. M. (BOTTOM HO~ o~ Sec 34, T10N, R13~, SM 12. PERMIT NO 74-24 13. REPORT TOTAL DKPTH AT END OF MONTH, CHA~NGF_~ IN HOLE SIZE, CASING AND C]~N[ENTING JOBS INCLUDING DEPT~ SET AND VOL~ USED, PERFORATIONS. 'rESTS A_ND RESULTS FISHING JOB~ JU~'~rK IAI HOLE AND SIDE-TR~CKED HOLE AND ANY OTHER SIGNIFICANT CHA_~GES IN HOLE CONDITIONS NTBU S-2 (11-35) Redrill for July 1974 11,352'TD, 11,300' PBD = Testing well on 8-1-74. Drilled 8 1/2" directional hole f/8945 - 11,352' TD. Rn Schl D1L f/11,340.- 7363'; FDC-CNL f/11,312 - 7363'. Rn 102 jts 7" liner f/11,341 - 7167' w/float collar @11,300'. Cmt'd w/1175 sx "G" cmt. CO to 11,300' PBD. Tested lap w/2500 psi (did not hold). Rn Schl CBL w/GR f/PBD - Liner Top. Squeezed liner lap w/100 sx "G" cmt. Tested lap & csg w/2500 psi (held for 15 min). Rn WSO test on liner lap. (Rec 30' rathole mud). Perf 4 SPF f/10,509 - 10,510' CBLM (could not break down perfs). Reperf 4 SPF f/10,509 - 10,510' (could not break down perfs w/4000 psi). Rn WSO test on perfs. Had 100' of rise (10' of oil & 90'~ rathole mud). Rn 3 1/2" completion assembly w/btm tbg @10,501', BOT pkr @10,435', 12 Camco GL mandrels & ¥1vs and Camco 3 1/2" TRB-6 Safety Valve @298'. Landed'tbg & tested'tbg hanger'w/3000 psi. NU & tested tree w/3000 psi. Displaced mud w/water & water w/diesel, Set pkr @10,435'. Schl perf 4 SPF f/10,563 - 10,618'; 10,643 - 10,668'; 10,694 - 10,714'; 10,733 - 10,758'; 11,008 - 11,058'; 11,078 - 11,098' & 11,125' - 11,145'. Tested pipe & blind rams w/3000 psi & Hydrill w/1800 psi on 7-2, 7-9, 7-19, & 7-25-74. RR @7 AM 7-31-74. Test 7-31-74. 1922 BOPD 422 BWPD 224 GOR. FINAL REPORT AU8 9 I974 DIVISION OF OIL AND GAS sm~ ~%/~/--~---~f~-'z'°C'~ r,T~ S, Alaska Drlg Superviso_r~.~, 8/S/74 ,, oil and 9os conservotbn commtflee bythe 15~ of the suoc~din9 ~n~,~le~ Otherwise dirocted. AtlanticRichfieldCompany ,~'"~"~ North A~ Producing Division South Ala= ,strict ~.~. Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Ju:'~iy 2, 1974 . Mr. Homer Burrell State of Alaska Department of Natural Resources Oil & Gas Division 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Burrell: EncloSed are copies of the Monthly Report of Drilling ~perations for June for the NTBU S-2 (11-35) well now drilling from the Spark Platform. ~_~/District Drilling SuperVisor JDK/DLS/gld Attachment 97:4 l~n,a No. P*.-4 REV, STATE OF ALASKA SUBMrT IN DU~LICA'I~ OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WgLL W~LL OTHER 2 NAME OF OPEI%ATOR ATLANTIC RICHFIRLD COMPANY 3. ADDRESS OF' 0PEI{ATOR " P.O. Box 360, Anchqrage,.iA!aska 99510 4 LOCA~O~ O~ WEU. At Surface: 2606' FSL & 2492' FEL of Sec. 26., T10N, Ri~W', SM SPARK PLATFORM API NUA{ERICAL ~ODE 50-133-20172-01 LEASE DESIGNATION A%'D SERIAl. NO. ADL 18776 ? IF INDIAJff. ALOTTEE OR TRIBE NAME 8. L.~IT FARM OR ][,EASE NAME North Trading Bay Unit g %YELL NO S-2 .(11-$5) Redrill 10 F~ tND P~L. OR WILDCAT =_ Trad~n~ Bay NE Hemloc~ n sec. T.. ar~{~ (~oM ~O~ o~ Sec 34, TiON~ R15W, SM 12. P~VIIT NO 74-24 13. REPORT TOTAL DElmTH AT END OF MONTH. CI'IA~NGES IN HO~E SIZE. CASI~ A~ 'C~EN~ JOBS INCLU'DING DEPTH SET ~ VOL~ USED. P~O~TIONS. ~TS ~ ~SULTS FISHING JO~ J~K ~ HO~ AND SIDE-~CKED HOLE ~D ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~ITIONS NTBU S-2 (1!-55] for J~e,'. ~974 . MI ~ RU 6-14-74.. Pulled GLV ~10,806. Killed'.well w/9,3 PPg.mud. NU 50P. Tested R~s to' 5000 psi and Hydril to' 1800 psi, P0H w/5. i/2'.~', completion assembly. Clewed out to PBD ~11,'385'. Plug back W. Forel~ds perfs f/11,266-11,35~' w/100 sx "G" cmt f/11,375-10,854". Perf 9 5/8" csg':~7550' w/4 JS. ~ Set retainer .87495' ~ squeezed perfs w/200 sx Class "G" cmt , Perf 9 5/8" csg 87520' w/4 JS. Set RTTS .87249' ~ squeezed perfs w/200 sx' Class'"G" cement.' Drilled' out cmt to 7482' PBD. Tested squeeze w/2100 psi~ Cut 70' window in 9 5/8" csg.: f/7370'.-7440,. Spotted 150 sx cmt plug f/7153-7457'. 6/21/74 tested" 'BOP w/5000 psi'~ Hydril w/1500 psi. D0 ~t to 7375' KOP. Tested' kick off plug 2000psi ~d 20.,000~ wt.' Drilled 8 1/2'.' Directional Hole f/7375",8945,. Drilling 8 1/2'thole '88945.' on.July 1, 1974 This constitutes notice of abandonment of original well-bore, prior to redrilling the well . under another designation. Atl~cRichfieldCompany North Am"--~ Producing Division South Al, ~ Oistrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 June 17, 1974 Mr. Homer Burrell State of Alaska Department of Natural Resources Oil & Gas Division 3001 Porcupine Drive Anchorage, AK 99504 Dear Mr. Burrell- Attached is a copy of the Monthly RepOrt of Drilling and Workover Operations notifying you that work has commenced on the NTBU S-2 (11-35) Redrill. ~~ D. Keasler Dist. Drilling Supervisor JDK/DLS/kb Attachment CONFER= FILE: JUN 2 0 'i974 Form No, P-.-4 I~EV. ~,- 1-70 1, OIL WELL STATE OF ALASKA OIL AND OAS CONSERVATION COMMI'i'i'EE MONTHLY RE!PORT OF DRILLING AND WORKOVER OPERATIONS WlgLL OTHER "~i. ~A.~a~:'or opmtkroa Atlantic Richfield C. pmpany ~. ~b~ss or"6F~~'' P, O, Box ~60, ~chorage,, AK ,,pg,s lO At Surface: 2606' FSL & 2492' FEL of SEC 26, T10N, R13W, SM SUBMIT IN DLrPLICATE 50-153-20172-01 LEASE DESIGI~A'i~ION AND SERIAL ADL 18776 IF INDIA~ ALAgTYEL OR TR1BE ~: ].~."iT' F~d~ OR LEAsE 'NA.ME North Trading Bay Unit 9 WI/:LL NO ; S-2 (11-$5] Redrill ~o F~r.r,O A~WD ~OOL. OR WfL~d~' _ Tradin~ Bay NE Hemlock o~ Sec 34, T10N, R13W, SM I~ P~IT NO 74-24 13. RF~RT' TOTAL DEi~TM AT FoND OF MONqZH, CI-I~NGF~ IN HOLE SIZE, CASING A~ C~TING JOBS INCLL'DING DEPTH SET ~ VOL~ US~. P~O~TIONS, ~TS ~ ~SUL~ F~HING JO~ JL~K ~ HO~ AND SIDE-~ACKED HOLE ~D ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~ITIONS Operations to Redrill Well S-2 (11-35) commenced on 6-14-74. JUN 2, 0 ~9~4 DIVISION 0?,' OIL AND GAS / ............... . I~y 31, 1974 North Trading Bay Unit, S-2 (11-35) Atlantic Richfield Company ~74-24 Mr. James D. Keasler District Drilling Supervisor Atlantic Richfield Company Post Office Box 360 Anchorage, Alaska 99510 Dear St r: Enclosed is the approved application for permit to dri'll the above referenced well, on. or about June l, lg74 to a location in Section 34, Township Range 13bi, S.H. fr~n the 'Spark Platform.. Well samples, Core chips, and a mud. log are not required. A directional survey i s requl red. Pollution of any waters of the State is. prohibited, by.AS 46, Chapter 03, Article 7 and the 'regUlations promulgate~ thereunder {Title. 18, Alas.ka Administrative Code, Chapter 70)and by""the Federal t~a. ter Pollution Control Act' as amended. PriOr to conmmn'cing operations you may be contacted by a representative of the ~partment of Environmental Conservation. Pursuan.t 'to AS 38.40, Local tltre Under state Leases, the Alaska Department of Labor is being nottfieci of the .issuance of this permit to drill. Very truly yours, Tho~.as R. Marshall, Jr'.. Executive Secretary Alaska Oil and Gas C.onservation Committee 'TRM:Jh Enclosure CC: Department of Fish and .Game, Habitat SectiOn. w/o encl. Department of Environmental Conservation w/o encl. Department of Labor, Supervisor, Labor Law Compliance Division w/o encl.. AtlanticRichfieldC. ompar~y North Amerjf~l Producing Division Alaska Disti ' Post Office BOX 360 Anchorage, Alaska 99501 Telephone 907 277 5637 May 29, 1974 Mr. Homer Burrell, Director Division of Oil & Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, AK 99504 Subject- Redrill of'NTBU S-2 Well Gentlemen' The Atlantic Richfield Company requests your approval of the attached Application for Permit to Plug Back and Redrill the North Trading Bay Unit S-2 (11-35) well. We propose to abandon the West Forelands Zone and redrill to an upstructure location within the NTBU reservoir for recompletion in the "G" and Hemlock Zones. This well is now shut in and has not produced significant amounts of oil from the West Forelands Zone. Our proposal to redrill S-2 is part of the pressure maintenance project approved by Conservation Order No. 108 and will increase recovery from the "G" and Hemlock NE oil pools of the North Trading Bay Unit. The redrilled S-2 well will encounter the top of the Hemlock Zone 1000' south of producing well S-8 and 650' southeast of producing well TS-3 Redrill. We are presently completing the S-1 Redrill and wish to be- gin work on S-2 about June 1 as soon as the work on the S-1 Redrill is finished. Your early approval would be appreciated. James D. Keasler Dist, Drilling Supervisor JDK/kb Attachment o ;. oas' SUBMIT IN~ '~IACAT~ Form P~! (O~ mst~, ,~ o~ - STATE OF ALASKA OIL AND GAS CONSERVATION __ APPLICATION FOR ~RMtT TO DRILL, DE,EeEN, OR PLUG-B~CK ' ~DRILL ~ DEEPEN ~ PLUG BACK W~L~ WiLL O~l~ ZON~ ZON~ 2 NAME OF OpERAToR. Atlantic Richfield Company 3. ADDRE.S$ O~ P. 0. Box 56.0~ Anchorage, AK.. 99510 4 LOCATION OF ~ At surface MAY 0 U 2606' FSL & 2492' FEL of Sec 26, T10Ni)lt~,,~J~qS~F OIL AND GAS At proposed prod. zone 1100' FNL,,,~ 20.0' FEL of Sec 34,..TlON. 13~ DISTANCE IN MIL~ AND DIRECTION F.~:NEAR~T TOWN O~ ~S~ O~F~ 28 Miles ~ from Kenai~ Alaska Tvp~State~ide s~,,,~,,a/o, ~. Federal Insurance Co. 8011-38-40 1). DISTANCE fRO~ PROPOSED' '-'~18. nOCATm~ TO N~.~ST P~OPERTY Oa LEASE ~I~Z, ~. 200 ! 960 ~Also ~o nearest drig. umit, if any) 1 ~[ D1STA~'~OM PROPOSED ~CA~ON" -- 115. PRO~S~ n~ o. A~m~ ~OR, ~. 650~ , J llS00~ MD 2L ELEVATIO~S (Show whethc~ DF, RT,-GR, ii5~ KB above .... 23.' ....... P~ED CASING AND CEMEN~G PROG~ 50-155-20172 - 0l S. L.EASE DmlGNATIO~"P~brO ~'~R~L NO'; ADL 18776 ?. IF INDIAN. A.LJ~ OR TFLLB~ NA2~i~ 8.UNIT~FARM OR LEASE NAJ~IE North Trading Bay Unit jg. WELL NO. il0. FIELD AND POOL. OR ~/II.DCAT J Trading Bay NE Hemlock Itl'- sec.. T,. I~ M.. {'RO'l~rOM .... J H OLE OBJECTIVE) JSec. 34, T10N, R13W, SM. il2. A~o.--, $100,000 l?. NO. ACRF-~ ASSIG.'N'EI~ TO THiS WELL 8O ~. RoYA~tY'oli'c^~/t.¢. TO~' ' Rotary 2~. APPROX, DATE WORK WILL START* June 1, 1974 SIZE OF HOL? SIZE OF CASING} V/EIGHT PER FOOT GRADE~ S~T'I'ING DEFVl'H Ot'ANTiTZ OF C[~[Ni 18 -~ 13-3/8 61~ .... J .. 2,055' Cement circ to Surface _~. .. iSxl./~. ' '9~S/8 ~ " 47~. NgP 10.949.. ,Ceme~[ed w/lOOOsx ."G" .......... 8rl/2 7 29~. N 10' 02a To~ Cam~nt, w/_~0 sx "G" ...... ; .' . , . , . _ · ..... Liner. 11~a70.'.Rt~C~.a edt ~ero~s tan. oF liner3 ...... ..... I -: ........ · ' '- ' - " · ~ ' ~ - · ~' -..; ~ - ' ~ m~ ~ ~ . ~ . ~ . ~ ] t ,,, , ...= .. History This well was originally drilled to 10972' & completed in the "G" and Hemlock zones thru perfs 10315-10750'. The perfs were later squeezed and the 'well deepened to llS00' & completed in the West Forelands thru perfs 11266-11556'. Present casing program is shown above. Only the West Foreland perfs are now open w/the "G" & Hemlock perfs cased & cemented off behind the 7t' liner. Proposed Program - See Attachment IN ABOVlg SPAC"~ D1~-~ItI~J-J[~ROPOS~D lwRO~ItAM: If ~I ~ to dee~n or plug ~, give ~m on ~ent p~u~lve zo~ ~d pro~ new p~du~lve ~e. ~f propel ~ ~ drill or ~n d~.o~ty,. ~lve ~nt ~ on ~bsu~a~ ~t~ ~d m~as~ ~d ~~r~e~ p~ram. . ~ Dist..Drlg. Supe 7 ' "' "'" ~' ~ ~ ' .... z -" ' ~'~ ' ' "' .- j a j SEE T ,S n'TAL LETTER ~ , .~ . ~ , , ,, J ,, ,.~, . · . L m ~ ~o 50_133_20172[71 .......... 1 74-24 5/33/74 '/ - *~, In--on, ~ R,~ Sid, SUBMIT IN T, ~ICAT~ l~orm P--I (Other instructions on reverse side) l~r. STATE O,F ALASKA OIL AND GAS CONSERVATION CO'MMITTEE _. 50-133-20172-O! APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR Plug 'B,~CK ],. ~..~'.SE'D'~ION^.O~"',~O S"~.~.NO, " ' I ADL 18776 DEEPEN {-'{ PLUG BACK [] I; Ir ,N'DI-~, ,u~'z'r~ OR 'raz'~E ~ 2 NAME OF OPEI~ATOR Atlantic Richfield company 3. ADDRESS C~ OPERATOR P. O. Box 360, Anchorage, AK..99510 4. LOCATION OF WELL At surface ~-ON'e-.-..~l"~ ~ZOIt~ I! ~{1[.--~ .~NIT, FARM OR LEASE NAME DlmfI U ["[lN°rthrradingBayUnit ...... IIUIELL'N°. ,, , u u 3 0 1974 c ,-as) lin. rmu~ .~ m,ob, ok W~L~C.~ DIVISION OF OIL AND · 2606' FSL & 2492' FEL of Sec 26, T10N, R13W, SM ANCHORAGE At proposed prod. zone 1100' FNL & 20.0' FEL.. of Sec 34, T10N, R13W. S~ '~3. DISTANCE IN MILES AND DIRECT:ON Fl(OM NEAREST TOWN OR POST O~'FICE 28 Miles NW from Kenai~ Ala,s, ka, ,,, 14. BOND INFORMATION: TYeiStatewide Surety and/or,No. Fe...deFal Insurance Co. 8011-38-40 15. DISTANCE FROM PROPOSED* i16. NO. OF ACRF-~ IN LEASE LOCATION TO NEAHEST 1 PROPERTY OR LEASE LINE, rt. 200 960 (Also to nearest drig. unit. ii any) 18. DISTANCE FROM PROPOSED LOCATION* ] 19. PROPOSED DgPTH TO NEAREST WELL DRILLING, COMPLEYrgo, OR APPLIED FOR, l~r. 650' 11500' MD ~$ding BaY NE Hemlock !1. SEC., T,, R., M., (BO'I'rOM HOLE OELIECTIVE) Sec. 34, T10N, R13W, SM 12. _ ~no--.~ $100,000 il?, NO. ACRES ASSIGNED TO THiS WELL 80 20. ROTARY OR CABLE TOOLS Rotary 21, ELEVATIONS (Show whether DF, RT, (IR, etc.) 22. APPROX, DATE WORK WILL START* 115' KB above MLLW ....... June It 1974 23. P~OPOSED CASING AND CEMENTING PROGKA. M SIZE OF HOLE SIZE OF CASING WEIGHT PER FOO~' GRAI~ [ SL'PTING DEPTH qL'ANTIT! or C{~MIIN'I ,,. , 18 13-3~8' 61# J 2,055' Cement circ to Surface , ~ ' ' 18-1~4' 9.-5/8 ·47# N§P .... i0.949 Cemented w/100Osx "G" .. , 8-.1./2 ~ 7 . 29# N 1C}_ 024 Tn? C. amant ,,,W/,3-qD ,,SI "G", ...... ~ ,,,,.. .... ; 1" 7 ............ 11 i 11 1,, , , , History This well was originally drilled to 10972' & completed in the '"G" and Hemlock zones thru perfs 10315-10750'. The perfs were later squeezed and the 'well deepened to 11500' & completed in the West Forelands thru perfs 11266 '11356'. Present casing program is shown above. Only the West Foreland perfs are now open w/the."G" & Hemlock perfs cased & cemented off behind the 7'.' liner. Proposed Program - See Attachment IN ABOV~ SPAC'E D~SCRIBE~OPOSE'D PROGRAM: If ~I is.to dee~n or plug ~, give ~ ~n present p~ive zo~ ~d pro~ ~w produ~ive ~e. ~f propel ~ W drill or ~n d~e~.o~lly,, give pe~ent ~ on ~osu~a~ ~t~ ~a meas~a ~d ~ue re,leal dep~Glye ~o~ut preventer program, DIRECTIONAL SURVEY '~Y~ El ~o *See In~on, On Revere Side A.e.,. m~nUCA~ coo~ - API~ROVAL DAT~ ................ Application for Permit To Plug Back ~ Redrill North Tradning Bay Unit Well S-2 Proposed Program for Redrill 1. Plug ~ abandon West Forelands perforations @ 11266-11556'/~ w/100 sx [550') cement plug f/PBD 11'584' + to 1'0850'+. 2.. Perforate @' 7520' +, set'cement retainer ~nd squeeze--9-5/8" casing belOw kick o--fl point @ 7400'_+'" $. Perforate @ 7520'+ ~ squeeze 9-5/8" casing above KOP.~'' 4. Cut S0' window in--9-S/8" casing f/7590-7440'+. '~ 5. Sidetrack well @ 7400'+-& redrill 8-1/2",hole llS00'+~ 6., Log ~ cement 7" 29# N-8--0 (or equivalent) liner @ TD w~00 sx cement. 7. Perforate & complete "G" and Hemlock zones. MAY 3 0 1974 DIVISION OF OIL AND GAS ANCHORAGE 'T-TI0 N - R 1:3 W -T SUPERIOR- TEXA~ 0 8 t~ TS-'6 ~1t ,1 r- , ,, SPARK ' i · ~s-~ ~ ! .//,',,"' I I /" !S-I RD ///"' / / ~ I / _ - -~,/ ! I I . / e-+--..-.... ! /~ I o,,.. '1 /....i ~<y;,' ', .,,' I ' · ' ' ; /ARCO . ''," I' '" '/TS'~I..,~' I // · ' .,/~T.B. ST! '-'~, ,,,' ,' ."' "~ -;' 7', I ' 1'-. /." __®' t // / / .' · '-r[~<~c°,~. ..... -e I." .'s'-~' / I I :',. T.S-~RD e,'~ ~' / I \ \ ! I /~.//' x,, "'.. PROPOSED ,. ,' . ' m ~../ / x x.. S'2 RD --/,. ,~ / m , ,lz / \ x,,. ·~-o/ · / , ./ \ '~ / ./ ' ~" !1 I '" /I , ~' // I ,, I, ~ ,, :,_-_ '/ '~ ~' S-7 RD I ARCO 24 'i /1! I /// I Q ~NOItTtt Tt~ADING BAY UNIT '-- "l;c-o- - -t /~.RCO LIN ION - MARATHON I T'TiON-R 12W I AR CO - SOCAL I I i I I I i t 19 25 30 AtlanticRichfieldCompany '0 SOUTH ALASKA DISTRICT 36 ' WELL LOCATION MAP NORTH TRADING BAY UNIT PROPOSED S-2 REDRILL MAY: 197,4 Company .... Lease & Well ~o. CHECK LIST FOR NEW WELL PERMITS Yes No Remarks I. Is well to be located in a defined pool ................. Y/~oK 2. Do statewide rules apply ......................... · 3. Is a registered survey plat attached .... / 4. Is well located proper"distance from property line ........... 5. ~i~ well located proper distance from other wells ............ ~ !6. Is sufficient Undedicated acreage available in this pool ........ ~t.~ 7. Is well to be deviated ...... ' .................. ~ 8. Is operator the only affected party ................... x~ __~ 9' Can permit be approved before ten-day wait ............... ~. _ lO. Does operator have a bond in force .................. · ll. Is conductor string provided ..................... ' 12. Is enough cement used to circulate on conductor and surface ...... //~]. 13.~l~' ~'11 cement tie in surface and intermediate or production strings . . . 14. Will cement cover all possible productive horizons .......... 15. Will surface casing cover all fresh water zones ........... ~16. Will surface csg. internal burst equal .5 psi/ft, to next string .... ~Cd~ ~ 17. Will all casing give adequate safety in collapse and tension ...... ~C~¢~? 18. Does BOPE have sufficient pressure rating ............... j~<~?~t '~ditional. Requirements: . ~z~;/~ ~/o~ '\