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174-005
• STATE OF ALASKA , ~~ ~~S'~~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETlON OR RECOMPLETION REPORl` AND LOG 1 a. Well Status: Oii ~ Gas ~ Plugged ~ Abandoned ~ Suspended ~ zonaczs.ios ' 2oAaczs.iio GINJ^ WINJ~ WDSPL^ WAG ^ Other^ No. of Completions: 1 b. Weil Ciass: Development ^~ ~ Exploratory^ 5ervice ^ Stratigraphic Test^ 2. Operator Name: Marathon Alaska Production, LLC 5. Date Comp., Susp., or Aband.; v" 8/18l2009 ~ f2. Permit to Drill Number: 174-005 ' ~~ ~ 3. Address: P.O. Box 196168, Anchorage, AK 99519-3043 6. Date Spudded: 5/03/1974 Redrill 13. API Number: 50-733-20158-01-00 . 4a. Location of Weil (Governmental Section): Surface: 2608' FSL, 2495' FEL, Sec. 26, T10N, R13W, SM • 7. Date TD Reached: 5/25/1974 Redrill 14. Well Name and Number: North Trading Bay Unit S-01 RD ~ Top of Productive Norizon: 8. KB (ft above MSL): 115 Ground (ft MSL): 15. Field/Pool(s): Total Depth: 1170' FSL, 377' FEL, Sec. 27, T10N, R13W, SM 9. Plug Back Depth(MD+TVD): 230 RKB, 55 BML G-NE/Hemlock-NE Oil • 4b. Location of Well (State Base Plan~e /,C~~rdinates, NAD 27): ~ ~~ Surface: V(~~ fi6~~:9Q845~~ ,11,1' "y- -1 Zone- H ~ 2 ? k ~ 10. Total Depth (MD + TVD): •11060 MD, 10168 TVD • 16. Property Designation: ADL0035431 ,/ TPi: /'91~'x- ' '~ j~~ / / Zone- ,~/! Total Depfh: x- ~+ y- - . Zone-T 11. SSSV Depth (MD + TVD): 17. Land Use Permit: 18. Directional Survey: Yes ~ No ~ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: 60 (ft MSL) 20. Thickness of Permafrost (TVD): 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. CASING, LWER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE AMOUNT FT T~P BOTTOM TOP BOTTOM CEMENTING RECORD pULLED 13-3/8 61 J-55 0 2802 0 2792 18 1900 sk G/10% Gel/Neat 9-5/8 47 N80/P110 0 7951 0 7592 12-1 /4 1000 sk G w/ 1% CFR-2 7 29 P110 7696 11060 6804 10168 8-1/2 1000 sk 23. Open to production or injection? Yes ~ No Q If Yes, list each 24. TUBING RECORD interval open (MD+TVD of Top & Bottom; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 950-10069 Baker FB -1 @ 9980 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. .. -7 ~ .~: - , ' r`` ., ,n~~~ , DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED . '°' '~~.~:~ 9570, 575 set CIBP's during plugging 230-575 41 bbls (124 sk 1.132 yd) 15.9 ppg G Neat 7132-7446 25 bbls (124 sk 1.132 yd) 15.9 ppg G Neat 9596-10069 17 bbls (84.32 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, co~t~,~~gr~ s ncll~pratory analytical results per 20 AAC 25.071. C ~ ~~ ~,~G.~~~114C_~/Li` S E P p ~ .,~.~._~.~ 2009 ~3A7 ~ Alaska Oil & Gas Cons. G'ommdssiQn ~~~~~ ~~~. ~ ~ ~ ~ ~j z00~ Anchor4~e ~ ~~ ~ Form 10-407 Revised 2/2007 CONTINUED ON REVERSE I~ ~~ v~~ 1•/~ ~~T G • i 28. GGOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ^ Yes y ^ No if es list intervals and formations tested , , Permafrost - Top briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base G-Zone 9,493 8,948 G-Zone production horizon 10,216 9,519 Hemiock 10,487 9,728 W. Forelands 10,940 10,083 Formation at total depth: W. Forelands 11060 10165 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tiffany Stebbins Printed Name: Tiffany Stebbins Title: Regulatory Compliance Representative Signature: Phone: 907-565-3043 Date: 9/2/2009 ~~ ~,D 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 weil 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 Disposai, Water Supply for /njection, Observation, or Other. Multiple comptetion 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 verticai thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. item 22: Attached suppiementai 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 intervai). 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 fitervals 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. Form 10-407 Pevised 212007 ,. ~'"'~~°"~~~~~~:.~ STATE OF ALASKA ALASKA~AND GAS CONSERVATION COMMISSI~ '~`~~%`•~ ~ ~ ~~~~ WELL COMPLETION OR RECOMPLETION REPOR~~~I~I~ ~~~, ~t.~~~~,=~E,.:; 1a. Well Status: Oil ~ Gas ~ Plugged ~ Abandoned ~ Suspended ~ 20AAC25.105 20AAC25.770 GINJ^ WINJ^ WDSPL^ WAG ^ Other^ No. of Compietions: ib. Well Class: ; ; I Development ^ Exploratory~ Service ^ StratigraphicTest^ 2. Operator Name: Marathon Alaska Production, LLC 5. Date Comp., Susp., or Aband.: 8/18/2009 12. Permit to Drill Number: 174-005 3. Address: P.O. Box 196168, Anchorage, AK 99519-3043 6. Date Spudded: 5/03/1974 Redrill 13. API Number: 50-733-20158-01-00 4a. Location of Well (Governmental Section): Surface: 2608' FSL, 2495' FEL, Sec. 26, T10N, R13W, SM 7. Date TD Reached: 5/25/1974 Redrill 14. Well Name and Number: North Trading Bay Unit S-01 RD Top of Productive Horizon: 8. KB (ft above MSL): 115 Ground (ft MSL): 15. Field/Pool(s): Total Depth: 1170' FSL, 377' FEL, Sec. 27, T10N, R13W, SM 9. Plug Back Depth(MD+TVD): 230 RKB, 55 BML G-NE/Hemiock-NE Oil 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- y- Zone- 10. Total Depth (MD + TVD): 11060 MD, 10168 TVD 16. Property Designation: ADL0035431 TPI: x- y- Zone- Total Depth: x- y- Zone- 11. SSSV Depth (MD + TVD}: 17. Land Use Permit: 18. Directional Survey: Yes ~ No ~ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: 60 (ft MSL) 20. Thickness of Permafrost (TVD): 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTIIVG DEPTH TVD HOLE SIZE CE ENTING RECQRD AMOUNT FT TOP BOTTOM TOP BOTTOM M pULLED 13-3/8 61 J-55 0 2802 0 2792 18 1900 sk G/10% Gel/Neat 9-5/8 47 N8o/P11o 0 7951 0 7592 12-1/4 1000 sk G w/ 1% CFR-2 7 29 P110 7696 11060 6804 10168 8-1/2 1000 sk 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) 3-1/2" 950-10069 Baker FB -1 C~ 9980 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 9570, 575 set GBP's during plugging 230-575 41 bbls (124 sk 1.132 yd) 15.9 ppg G Neat 7132-7446 25 bbls (124 sk 1.132 yd) 15.9 ppg G Neat 9596-10069 17 bbls (84.32 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: Nours Tested: Production for Test Period Oil-Bbl: Gas-MCF: Water-8b1: Choke Size: Gas-Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24-Hour Rate ~ Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity - API (corr): 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No ^ Sidewall Cores Acquired? Yes ^ No ^ If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. Form 10-407 Revised 2/2007 CONTINUED ON REVERSE l J C , J 28. GEOLL}GiC MARKERS (List all formations and markers encountered): 29. ! FORMATION TESTS NAME MD TVD Well tested? ^ Yes ^ No If yes list intervals and formations tested , , Permafrost - Top briefly summarizing test results. Attach separate sheets to this form, if 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 6 _~ Signature: ,lZ~~!'f,1(.g~ Phone:907-565-3043 Date: 8l27/2009 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log o~ all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, Water Injection, Water-Alternating-Gas fnjection, 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. {tem 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from rnore than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the intervai reported in item 26. (Submit a separate form for each 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 analyticai laboratory information required by 20 AAC 25.071. Item 29: Provide a Iisting ot intervals tested and the con~esponding formation, and a b"rief summary in this box Submit detailed test and analytical laboratory information required by 20 AAC ?_5.071. Form 10-407 Revised 2/200? • ~ l~~~ l~'t.F~ R ~1fiWQ~ RKB-MSL 115' WATER DEPTH 60' MASTP 550 psi MIT 5/13/09 TM D @ 11060' ND @ 10168' API# 50-733-20158-01 Surtace Casing- @ 2802' 13 3/a" 61 ppf J55 Cemented with 1900 sks CTOC @ Surface Gauge Hole Production Tubing @ 10069' 3 1h" 9.2 ppf N80 Buttress Marathon Oil Company North Trading Bay Unit Spark Platform Well S-1 RD "FINAL P&A CONFIGURATION" "Pollard Wireline Report" 3 1/~" GS "Hoid Open" Tool set across SCSSV Tool = 2.84" OD X 1.992" ID X 9 91' Lon HO Tool installed Mav 13 2009 @ 330' 1.75" OD Gauge Ring to 10441' on 5-13-09 TOL 7696' - Squeezed with 100 sks Intermediate Casing- 7951' 9 5/e" 47 ppf N80 Buttress CMT 1000 sks CTOC @ 4636' Gauge Hole Baker FB -1 @ 9980' Prior to sidetrack PRF'D and SQZ'D at 7900' and at 8125' cut window at 7950' - 8020' Baker half cut mule shoe @ 10069' Completion fluid 8.5 ppg Salt Water Fish Otis tool string 20' lost 12/88 Depth of fish "Unkown" Fill @ 10605' WLM 6/88 Fill @ 10441' WLM 5/13/2009 Production Liner @ 11060' 7" 29 ppf P110 Buttress Cemented w/ 1000 sks CTOC @ 1997' Gauge Hole Calculation TOC at 8600' CMT BOND LOG 8/27/2009 All Depths measured RKB to top of equipment All depths are RKB unless otherwise noted TAGGED TOC @ ~55' BML ~345' SurFace Cement P~ug ~575' RKB to ~230' RKB Mixed & Pumped 41 BBLS 15.9 ppg "G" RIH CIBP, set at 575' RKB RIH TOT @ ~590' RKB Jet Cut 31h" @~590' RKB Pulled OOH Camco MMG GLM 2.875" ID RK Latch 2449' 8217' 4064' 8881' 5422' 9405' 6545' 9860' 7459' ~668' Intermediate Piug Pumped 25 bbls 15.9 ppg "G" Tag TOC @ 7132' RKB 8/4/2009 AOGCC witnessed tag, chart for 15 min. I Pertorated 3 ~/2' @ 7/20/209 1000 si Test 3~/2" & 9 5/a" Casin 7/18/2009 CIBP with ~10" CMT Above Bailed Cement to 9520' RKB Set CIBP @ 9570' RKB 7/16/2009 Ta ed TOC Bottom Hole S ueeze Plu 7/15/2009 ~1009' Set Squeeze Plug Pumped 17 bbls 15.9 ppg "G" Dis laced TOC to 9596' RKB PBTD 10971' MARATHON SPARK S-1RD FINAL P&A CONFIGURATION Page 1 8/27/2009 TMD = 11060' 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 5et OMMENTS 10069'RKB 7/15/2009 7/21/2009 8/2/2009 8/4/2009 575'RKB 8/14/09 CIBP - Baiied cmt 7796' RKB 7128' RKB/ 25 bbl 600' RKB Perf at 575 RKB 300' FfNISHED S-1 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 300' FINISHED S 2 Tag @ 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 Existing Perf at 575 RKB Pre-existing Pre-existin N/A 300' FINISHED S- 3 575' to 275' RKB 7/20/2009 7/20/2009 7/20/2009 Tag TOC - 57' BML 1000 si 1000 si 400 si 8 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 9/3/2009 300' FINISHED S- 4 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 1000 si N 9 12 2009 ~R to 10776' RKB 9/13/2009 S-5 Ta @ 10440' RKB 2~0 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'- 9/11/09 Tag @ 9912' RKB 7900' RKB 7600' RKB/24 bbls 1010' RKB Perf at 1005' RKB Tested to 1000 psi - 9/12/09 7~24~2009 Ta - 7533' RKB TOC @ 744'RKB S 7 Tbg -1000 psi 9/2/2009 9/3/2009 CIBP-Perf @ 575' Circulate Ciean 7/24/2009 7/24/2009 2571' RKB 2271' RKB / 24 bbls 1009' 300'cmt - 9/12/09 Pmp 300' Top plu C~ 575-275' 9/12/09 45 bbt 0 si cs - Faifed 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 Pert at 574' RKB 350' Bal Plug Tag TOC @ 1797' 300' FINISHED S 8 Tag @ 9661' RKB 2nd 2nd - 8/20/2009 574' to 274' RKB Can not inject S/9/2009 8/9/2009 8/20/2009 1444' RKB / 24 bbl 595' Tag TOC- 51' BML at 3000 si 1500 si 1500 si 500 si 1794' 8 21 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 Pert at 574' RKB Tag @ 9555'RKB 300' FINISHED S 9 Tag @ 10418' RKB 574' to 274' RKB 1.5 bpm 8/9/2009 8/9/2009 8/24/2009 597' Tag TOG 51' BML _ 1800 r;~,~i ~~ ~GO psl 1500 si 500 si 1000 PSI N 9 2 2009 9/15/2009 ~ ~ Report Date: 8/18/2009 Well # S-1RD 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- 1RD PROJECT: Marathon Oil Co. - P&A Day 58 A ~ ~ Proserv ost & Activity Date: 8/18/2009 TIME 6:00 Travel to Spark platform. 6:30 Held safety meeting and JSA on crane operations. 7:00 Boat arrived. Offload 14 bags of cement and backload multible pallots of scrap. Offload 150 bbls of waste fluid into 3 separate tanks, lifted to the work deck one at a time, filled, then lifted back down to the boat. 14:00 R/U wireline unit. M/U 1-11/16 weight bar. 15:00 RIH and tag TOC at 55' BML. POOH 15:30 Move over to well S-8. CREW PaAAE HOURS CREW NAME ; HOURS 1eff Thompson 9.5 Randy Lafleur 9.5 Gene Hess 9.5 Mathew Boudreaux 9.5 Cyprian Ukudi 9.5 Page 1 of 2 i r~ Report Date: $/17/2009 Well # S- 1RD 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- 1RD PROJECT: Maratnon Oil Co. - P&A Day 57 A ~ ~IProserv ost & Activity Date: 8/17/2009 TIME 6:00 7ravei to Spark platform. 6:30 Held safety meeting and JSA on mixing/ pumping and crane operations. 7:00 Circulate 75 bbls for bottoms up. 8:00 M/P 41 bbls, 124 sks of 15.9 ppg, 1.132 yield, class "G" Neat cement for a 300' cmt balance plug in both the 9-5/8" and the 13-3/8"x 9-5/8" casings, from ± 575' RKB to t 275' RKB. 12:00 Clean all equipment and work deck. 13:30 Move over fo wetl S- 5 CREW NAME NOURS CREW', NAME H~UR~,S Jeff Thornpson 7.5 Randy Lafleur 7.5 Gene Hess 7.5 Mathew Boudreaux 7.5 Gyprian Ukudi 7.5 Page 1 of 2 ~ ~ Report Date: 8/15/2009 Well # S-1RD 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- 1RD PROJECT: Marathon Oil Co. - P&A Day 55 Proseru ost & Activity Date: 8/15/2009 TIME 6:00 Travei to Spark platForm. 6:30 Held safety meeting and JSA on running wireline and crane operations. 7:00 N/U tree on well. 9:00 R/U e-line and lubricator with pump hoses. 9:45 M/U 2 ft perforating gun @ 4 spf for 3-1/2" tbg. 10:00 RfH to 574' RKB and pressure up to 500 psi and perforate tubing. POOH 10:30 R/D e-line and move wireline unit out of way, 12:00 Clear enough room on deck to put tank when boat arrives. 13:30 Offload and backload supplies and pipe. Bring up 125 bbl tanks and dispose waste fluid, one at a time while taking on water. 17:30 5ecure wells and equipment. 18:00 Shut down for the day. Work Scope for 8-16-09 S-1 Circulate 9-5/8" csg and 13-3/8" x 9-5/8" until clean. Install top cement plug. CREW NAME HOURS CREW NAME NOURS Jeff Thompson 12 Randy Lafleur 12 Gene Hess 12 Mathew Boudreaux 12 Cyprian Ukudi 12 Page 1 of 2 • ~~ Report Date: 8/14/2009 Well # S- 1RD Day 54 PROSERV OFFSHORE ~ DAILY ACTIVITY REPORT & COSTS ~IRroseru Proj Team Leader: Jeff Thompson Field Sup.: PIC Site: Todd Paxton PLATFORM: Spark Cost & Activity Date: 8/14/2009 PROJECT NUMBER: 29052-21 WELL NUMBER: S-1RD PROJECT: Marathon Oil Co. - P&A TIME 6:00 Travel to Spark platform. 6:30 Held safety meeting and JSA on running wireline and crane operations. 7:00 R/U slickline and RIH & retrieve SCSSV Hold Open Sleeve. 8:30 R/D slickline and R/U e- line with 3-1/2" tbe cutter. 9:30 R/U jacking plate to tbg hanger and jack up 30,000 Ibs against tbg hanger. RIH to 590' RKB and cut tbg. Tubing jumped up slightly, proving cut. POOH w/ ~ line & R/D. 10:30 Rearrange deck, making room to lay down pipe. 11:30 POOH with 3-1/2" tubing and lay down on deck. Checked for NORM and was clean. 15:30 R/U e- line with gauge ring & junk basket anad RIH to 590' RKB and tag top of tbg. POOH. 16:30 M/U and RIH with 7.710" CIBP to 575' RKB and set in 9-5/8" csg. POOH. 17:30 Secure well and equipment. 18:00 Shut down for the day. Work Scope for &15-09 S- 1 Perforate for top cement plug. Circulate 9-5/8" csg and 13-3/8" x 9-5/8" until clean, provided we have necessary space to return fluids. Install top cement plug. CREW NAME HOURS CREW NAME ; Nf3URS Jeff Thompson 12 Randy Lafleur 12 Gene Hess 12 Mathew Boudreaux 12 Cyprian Ukudi 12 Page 1 of 2 i ~ Report Date: 8/8/2009 Well # S-1RD Day 48 C PROSERV OFFSHORE ~ DAILY ACTIVITY REPORT & COSTS ~Proseru Proj Team Leader: Jeff Thompson Field Sup.: PIC Site: Todd Pa~on PLATFORM: Spark Cost & Activity Date: 8/8/2009 PROJECT NUMBER: 29052-21 WELL NUMBER: S- 1RD PROJECT: Marathon Oil Co. - P&A TtME 15:Q0 R/U hanger pulling tools on top of hanger. 16:30 Attempt 3 times to pull up on tbg hanger without success. Appears that tbg is not fully cut. 17:30 Secure wells and equipment. 18:00 Shut down for the day. Work Scope for 8-9-09 S- 9 Test & tag bottom cmt plug in presence of AOGCC rep. Perforate, m/p cement for intermediate balance plug. S- 8 Test & tag bottom cmt ptug in presence of AOGCC rep. Perforate, m/p cement for intermediate balance plug. CREW NAME HOURS CREW' NA-ME HOURS Jeff Thompson 3 Randy l.afleur 3 Gene Hess 3 Mathew Boudreaux 3 (,yprian Ukudi 3 Page 1 of 2 i Report Date: 8/4/2009 Welt # S-1RD Day 44 A PROSERV OFFSHORE DAILY ACTIVITY REPORT & COSTS Prvseru Proj Team Leader: Jeff Thompson Field Sup.: PIC Site: Todd Paxton PLATFORM: Spark Cost & Activity Date: 8/4/2009 PROJECT NUMBER: 29052-21 WELL NUMBER: S-1RD PROJECT: Marathon Oil Co. - P&A tIME 6:00 Travel to Spark platform. 6:30 Meld safety meeting and JSA on pressure testing, running wireline and explosives and crane operations. 7:00 Prepare for testing and tagging TOC when AOGCC representative arrives at 8:00. 8:00 AOGCC representative arrived. Hold safety meeting and JSA. 8:45 Pressure up on tubing to 1000 psi with the 9-5/8" csg showing the same pressure, chart for 15 minutes. Good test. 9:30 M/U 1.5 G.R. and RIH to 7072' WLM (7132' RKB) and tag TOC. POOH. 10:00 Move over to well # S- 2RD (10:00 -11:30) 11:30 R/U slickline and RIH and pull out °Hold Open Sleeve" from SCSSV. 12:00 R/U e- line with 2.70" tbe cutter. 12:15 RIH to 600' RKB and cut 3-1/2" tbg. POOH 12:30 R/D e- line 12:45 Circulate well clean at 1.5 bpm. 13:15 N/D tree to tbg hanger and lay down in well bay. 14:45 M/U spear and 3-1/2" work joint with elevators and crane. 15:15 Engage spear into tbg and hanger. Attempt to pull up hanger, pulling up to 30,000 Ibs. Work up and down numerous times without any movement or success. 17:30 Secure wells and equipment. 18:00 Shut down for the day. ` CREW NAME HOURS ;GREW NAME MOUR,S Jeff Thompson 10.5 Randy Lafleur 10.5 Gene Hess 10.5 Mathew Boudreaux 10.5 (,yprian Ukudi 10.5 Page 1 of 2 ~~ • Report Date: 8/3/2009 Well # S-1RD Day 43 A PROSERV OFFSHORE ~ DAILY ACTIVITY REPORT & COSTS ~Proseru Proj Team Leader: 1eff Thompson Field Sup.: PIC Site: Todd Pa~on PLATFORM: Spark Cost & Activity Date: 8/3/2009 PROJECT NUMBER: 29052-21 WELL NUMBER: S-1RD PROJECT: Marathon Oil Co. - P&A TIME 6:00 Travel to Spark platform. 6:30 Held safety meeting and JSA on pressure testing and crane operations. 7:00 R/U pump hoses and pressure up on tbg to 1000 psi and 9-5/8" csg pressure came up the same as tbg pressure. Pressure fell to 800 psi. Pressured back up to 1000 psi and got the same results. Pressured up to 1100 and the pressure fell to 900 psi. Pressured up to 1200 psi and pressure fell to 1000 psi and stayed. Charted 15 min. 10:00 Bled off pressure and ~igged up slickline and RIH to 7128' RKB and tagged TOC. POOH. 11:30 R/D slickline. 12:00 Move over to well # S- 9 GREW NAME H~JRS ' CREW MMAE ` ; Ht~lRS". Jeff Thompson 6 Randy Lafleur 6 Gene Hess 6 Mathew Boudreaux 6 Gyprian Ukudi 6 Page 1 of 2 ~ • Report Date: 8/2/2009 Well # S-1RD Day 42 A PROSERV OFFSHORE ~ DAILY ACTIVITY REPORT & COSTS ~ Proserv Proj Team Leader: Jeff Thompson Field Sup.: PIC Site: Todd Pa~on PLATFORM: Spark Cost & Activity Date: 8/2J2009 PROJECT NUMBER: 29052-21 WELL NUMBER: S- 1RD PROJECT: Marathon Oil Co. - P&A fi1ME 6:00 Travel to Spark platform. 6:30 Held safety meeting and JSA on mixing & pumping cement and crane operations. 7:00 M/P 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 TOC to 7446" RKB, leaving a 350' intermediate cmt balance plug from 7796' RKB to 7446' RKB, in both the 3-1/2" tbg and the 9-5/8" x 3-1/2" annulus. WOC 11:00 Clean all cmt equipment and work deck. 12:00 Move over to well S- 9 CRE W NAME HtNJRS t~2EW (+tAME HQURS` Jeff Thompson 6 Randy Lafleur 6 Gene Hess 6 Mathew Boudreaux 6 Cyprian Ukudi 6 Page 1 of 2 l ~ - Report Date: 7/25/2009 Well # S-1RD Day 34 B PROSERV 4FFSHORE ~ DAILY ACTIVITY REPORT & COSTS ~ Proserv Proj Team Leader: Jeff Thompson Field Sup.: PIC Site: Todd Paxton PLATFORM: Spark Cost & Activity Date: 7/25/2009 PROJECT NUMBER: 29052-21 WELL NUMBER: S-1RD PROJECT: Marathon Oil Co. - P&A TIME ' pESCRIt~TfON OF ACTlltll"(ES 14:00 R/U pump lines and begin circulating down tbg, returning up the 9-5/8" csg at 1 bpm because of the tack of rate with injection pump on S-4. S-1RD returning pure oil. 17:00 Shut down pumping. Disposal pump gaining pressure - up to 1000 psi. Secure wells and equipment. 18:00 Shut down for the day. Work Scope for 7-26-09 S-1RD Set intermediate cement balance plug depending on disposability of returned well fluid. S- 2RD POOH with 2-3/8" coiled tubing. CREW NAME MOURS CREW NAME HOURS; Jeff Thompson 4 Randy Lafleur 4 Gene Hess 4 Mathew Boudreaux 4 Cyprian Ukudi 4 Page 1 of 2 . ~ Report Date: 7/23/2009 Well # S-1RD PROSERV OFFSHORE DAILY ACTIVITY REPORT & COSTS Proj Team Leader: 1eff Thompson Field Sup.: PIC Site: Todd Paxton PLATFORM: Spark PROJECT NUMBER: 29052-21 WELL NUMBER: S-1RD PROJECT: Marathon Oil Co. - P&A Day 32 B Proseru ost & Activity Date: 7/23/2009 TlME DFSt;RfF~'IO1N OF ACTfYII'tES 13:00 R/U pump lines and started circulating contaminated fluid out of well. 16:00 Shut down in order to catch up on disposal of returned fluids. 17:30 Secure wells and equipment. 18:00 Shut down for the day. Work Scope for 7-24-09 S- 7RD Test bottom plug, tag TOC, pull up and pertorate for intermediate plug. S- 2RD Test intermediate plug, tag TOC, pull up and cut tubing. CREW NAMf HOURS CREW IV~AE MtIkEF'~5 Jeff Thompson 5 Randy Lafleur 5 Gene Hess 5 Mathew Boudreaux 5 Cyprian Ukudi 5 Page 1 of 2 r~ ~ Report Date: 7/21/2009 Weil # S-1RD PROSERV OFFSHORE DAILY ACTIVITY REPORT & COSTS Proj Team Leader: Jeff Thompson Field Sup.: PIC Site: Todd Pa~on PLATFORM: Spark PROIECT NUMBER: 29052-21 WELL NUMBER: S-1RD PROJECT: Marathon Oil Co. - P&A Day 30 B ~~ Proseru ost & Activity Date: 7/21/2009 TiME DESCf2tPTiON OF ACT1Y171E5 9:00 R/U e- line & RIH with 2 ft of perf guns Q 4 SPF to 7796' RKB. Misfired. POOH 10:00 Rebuild perforating guns. 11:00 RIH with perf gun again to 7796' RKB and fire guns. POOH 12:00 R/D e- line and R/U pump hoses to 13-3/8" csg and bleed off 400 PSI gas thru gas buster. Fitl w/ water. 13:30 Test 13-3/8" csg to 250 PSI and chart results for 15 minutes. Good fest 14:00 Move to well # 7RD CR~W NAhAE HOUR.S ` CREW NI4ME -H~' Jeff Thompson 5 Randy Lafleur 5 Gene Hess 5 Mathew Boudreaux 5 Cyprian Ukudi 5 Page 1 of 2 ~ ~ Report Date: 7/20/2009 Well # S- 1 RD Day 29 A PROSERV OFFSHORE ~ DAILY ACTNITY REPORT & COSTS ~ Proseru Proj Team Leader: Jeff Thompson Field Sup.: PIC Site: Todd Paxton PLATFORM: Spark Cost & Activity Date: 7/20/2009 PROIECT NUMBER: 29052-21 WELL NUMBER: S-1RD PROJECT: Marathon Oil Co. - P&A TIIuIE QESCRIPTION OF AGTtVITtES 6:00 Travel to Spark platform. 6:30 Held safety meeting and JSA on pressure testing and running e- line. 7:00 R/U pump hoses to tbg and 9-5/8" csg. 7:30 Unable to pressure up on tbg because it was pressuring up both tbg and csg at the same time. 8:00 Unable to pressure up on csg because it was pressuring up both tbg and csg at the same time. 8:15 Pressured up on tbg & csg at the same time to 1000 psi and charted for 15 minutes. 6ood test. 9:00 Moved over to well # 3. ; qiEW NAME HOURS CRE1A/ N~-ME ` Ht~1R5, Jeff Thompson 3 Randy Lafleur 3 Gene Hess 3 Mathew Boudreaux 3 Cyprian Ukudi 3 Page 1 of 2 - ~ Report Date: 7/19/2009 Well # S-1RD Day 28 A PROSERV OFFSHORE DAILY ACTIViTY REPORT & COSTS Proseru P~oj Team Leader: Jeff Thompson Field Sup.: PIC Site: Todd Paxton PLATFORM: Spark Cost & Activity Date: 7/19/2009 PROJECT NUMBER: 29052-21 WELL NUMBER: S-1RD PROJECT: Marathon Oil Co. - P&A TIME [?ESCRIPTION OF AC71Y{TIES 6:00 Travel to Spark platform. 6:30 Held safety meeting and JSA on running cmt dump baiters on E/L and pressure testing. 7:00 R/U ~ line w/ cmt dump bailers & RIH and dump remainder of cmt. TOC left at 9520' RKB (9460' WLM) 10:00 Out of hole with dump bailers. R/D e- line and WOC. 12:00 Move over to well # S- 5RD - CREW PfAME HOURS CREW ` NAME ` H(~t1RS' Jeff Thompson 6 Randy Lafleur 6 Gene Hess 6 Mathew Boudreaux 6 Gyprian Ukudi 6 Pagelof2 I~ ~ Report Date: 7/18/2009 Well # S- 1RD Day 27 ~~ PROSERV OFFSHORE ~ DAILY ACTIVITY REPORT & COSTS ~ Proseru Proj Team Leader: 1eff Thompson Field Sup.: PIC Site: Todd Paxton PLATFORM: Spark Cost & Activity Date: 7/18/2009 PROIECT NUMBER: 29052-21 WELL NUMBER: S-1RD PROJECT: Marathon Oil Co. - P&A TIME DES(:FtfFsllC~f`~F ACt"11flTIES 6:00 Travel to Spark platform. 6:30 Held safety meeting and JSA on running CIBP & cmt dump bailers on E/L. 7:00 RIH with CIBP to 9536' WLM & tag top of cmt. Pull up 25 ft and set CIBP at 9511' WLM (9571' RKBy 8:30 CIBP misfired and did not set. POOH. 9:30 Out of hole with no plug on W/L. M/U another plug and rehead e/line. 11:00 RIH with 2nd CIBP to 9510' WLM & set. CIBP set successfully. POOH & R/D e- line. 12:00 R/U sfickline and RIH to reset SCSSV Hold Open sleeve while e- line m/u cmt dump bailing tools. 14:30 Out of hole with slickline. R/U e- line. 15:00 RIH with cement dump bailers (30 ft of bailer barrels) and dump first load. POOH 16:00 RIH with dump bailers and dump 2nd load. POOH. 17:30 lay down lubricator and pick up tools. Secure well. 18:00 Shut down for the day. Work Scope for 7-18-09 5-1 RD Finish dump bailing remainder of cmt on top of CIBP. S-2 RD Attempt to circulate in preparation for cmt balance plug. S-7 RD Perform well diagnostics and get injection rate. CRE W NAME HCfUi2S ' CREW NAME F#~li~5: Jeff Thompson 12 Randy Lafleur 12 Gene Hess 12 Mathew Boudreaux 12 Gyprian Ukudi 12 Page 1 of 2 a • Report Date: 7/17/2009 Well # S-1RD Day 26 PROSERV OFFSHORE DAILY ACTIVITY REPORT & COSTS Proserv Proj Team Leader: Jeff Thompson Field Sup.: PIC Site: Todd Paxton PLA7FORM: Spark Cost & Activity Date: 7/17/2009 PROIECT NUMBER: 29052-21 WELL NUMBER: S-1RD PROIECT: Marathon Oil Co. - P&A TIME QESCRiPT10N UF ACTIVITIES 6:00 Travel to Spark platform. 630 Neld safety meeting and JSA on running slickline and E/L. 7:00 R/U slickline and test lubricator to 1500 psi. RIH with SCSSV Hold Open retrievat tool & tatch on. Tool is stuck. 9:30 Order out Go Devil cutting tool & Oil jars. 11:00 Tools arrive. 11:15 Drop Go Devil tool and POOH with wire. 11:45 M/U JDC pulling tool & RIH and retrieve Go Devil tool. POOH 13:00 Out of hole with Go Devil tool. M/U Fishing tools and RIH to retrieve fish. 13:30 Latch on to fish and work oil jars until Hold Open Sleeve pulled free. POOH with sleeve. 15:45 R/D slickline and rig up e- line with 2.28" CIBP. 17:30 Perform maintenance and clean up work deck while waiting on helicopter. 18:00 Shut down for the day. Work Scope for 7-1&09 S-1 RD 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 NA141E HQURS CR~At: tVAAAE ' t~ll~.,S Jeff Thompson 12 Randy Lafleur 12 Gene Hess 12 Mathew Boudreaux 12 Cyprian Ukudi 12 Page 1 of 2 ~ ~ Report Date: 7/16/2009 Well # S-1RD Day 25 A PROSERV OFFSHORE DAILY ACTIVITY REPORT & COSTS Proserv Proj Team Leader: Jeff Thompson Field Sup.: PIC Site: Todd Pa~on PLATFORM: 5park Cost & Activity Date: 7/16/2009 PROJECT NUMBER: 29052-21 WELL NUMBER: S-1RD PROJECT: Marathon Oil Co. - P&A 'f(ME [3ESCFtIlyTIUN QF ACfIVt'i'IES ` 6:00 Travel to Spark platform. 6:30 Held safety meeting and JSA on pressure testing and running E/L. 7:00 Open tbg and bled pressure down from 2500 psi to 250 psi where 18 bbls oil returned 8e pressure remained same. R/U flow iines on 9-5/8" csg. Open csg & pressure showed 275 psi. 9:00 Pump on tbg while monitoring csg. Both tbg & csg pressure came up together to 1050 psi. Shut down pmp. 9:15 Pressure holding. Bled down tbg slowly and csg pressure fell at same rate as tbg. Both bled to 175 psi , flowing back oil #rom tbg & would not drop. Opened csg & flowed back oil C~ .25 bpm until gas returned at surtace. After gas was gone, csg went to 0 psi but continued to flow slightly. 10:45 Shut in csg & pressure back up on tbg to 1050 psi. Csg remained at 0 psi. Tbg fell off to 0 psi. 11:15 Repeated the same process & got the same results. 11:45 Shut in well and tree valve failed to hold. Serviced tree valve. R/U E-line with wgt bar, CCL, & cbl head. 12:00 RIH & tagged cmt at 9596' RKB (9536' WLM) POOH correlating SCSSV with tbg hanger to verify RKB. SCSSV was located from 280' to 270' WLM (330' -340' RKB). 13:00 Out o# hole. Move to well S- 2RD. Work Scope for 7-17-09 CREW NAME HOURS t~2EW NAME 'HOUI~ Jeff Thompson 7 Randy Lafleur 7 Gene Hess 7 Mathew Boudreaux 7 Cyprian Ukudi 7 Page 1 of 2 ~ ~ Report Date: 7/15/2009 Well # S-1RD Day 24 PROSERV OFFSHORE DAILY ACTIVITY REPORT & COSTS Proserv Proj Team Leader: Jeff Thompson Field Sup.: PIC Site: Todd Pa~on PLATFORM: Spark Cast & Activity Date: 7/15/2009 PROJECT NUMBER: 29052-21 WEL~ NUMBER: S-1RD PROJECT: Marathon Oil Co. - P&A tIME DESt~ttP'Tf0AI:4F ACflViT1~S ' 6:00 Travel to Spark platForm. 6:30 Held safety meeting and JSA on mixing & pumping cement and testing csg and running S/L 7:00 Continued well diagnostics. Opened 3-1/2" tbg and pumped water at 2.25 bpm (s 2500 psi for 110 bbls and shut down. Tubing pressure dropped to 0 psi. 830 Opened 9-5/8" csg showing 1200 psi. Bled to 0 psi thru gas buster and csg continued to flow back oil at .25 bpm. 9:30 Shut in csg after showing no decrease in flow. Purge pump lines clean. 10:00 R/U slickline and tes# lubricator to 2500 psi. 10:45 RIH with 1.75" gauge ring to 10,069' RKB without any restrictions. POOH and R/D slickline. 12:30 R/U bender, pump lines, and cmt bags for mixing cement. 13:30 Mix & pump 17 bbls, 84.32 sks of 15.9 ppg, 1.132 yield, class G neat cement and displace to 766$' RKB with 66.5 bbls of displacement ffuid where pump pressure came up to 3000 psi and held solid without any drop in pressure. Shut in well after verifying that cmt could not be pushed down any further without exceeding pressure limitations. 15:00 Clean up all cement equipment. 16:30 Dispose of all contaminated fluids down S-4RD. Total fluid disposed of today was 150 bbls 18:00 Shut down and fly back to XTO platform. Work Scope for 7-16-09 S-1RD Test cmt plug in perfs. Test 9-5/8" csg. RIH and tag TOC and perforate for balance plug. Attempt to circulate around and pmp cmt balance plug. S-2RD Test cmt plug in perfs. Test 9-5/8" csg. RIH and tag TOC and perforate for balance plug. Attempt to circulate around and pmp cmt balance plug. CR~1AI NAME FIOi1R5 CREW' NA~+lE HOUt~' Jeff Thompson 12 Randy Lafleur 12 Gene Hess 12 Mathew Boudreaux 12 Gyprian Ukudi 12 Page 1 of 2 - ~ Report Date: 7/14/2009 Well # S-1RD Day 23 B PROSERV OFFSHORE DAILY ACTIVITY REPORT & COSTS ~ ~ Proseru Proj Team Leader: Jeff Thompson Field Sup.: PIC Site: Todd Paxton PLATFORM: Spark Cost & Activity Date: 7/14/2009 PROJECT NUMBER: 29052-21 WELL NUMBER: N/A PROJECT: Marathon Oil Co. - P&A TIIWE DESCRIPTtON OF ACT1Y1TiES < 15:00 Attempt to R/U on tree but tree valves would not hold pressure. Greased gate valves and then they quit leaking. 16:00 R/U pump in connections on 9-5/8" csg, while W/L personnel R/U lubricator and S/L tools on top deck. 18:00 Shut down and fly back to XTO platform. Work Scope for 7-15-09 S-1RD Complete csg diagnostics, run S/L, get injection test on perForations & pump cmt plug into perfs. S-2RD Test cmt plug in perfs. S-7RD Complete csg diagnostics, run S/L, get injection test on perforations & pump cmt plug into perfs. "CREW NAME HOURS CRE1N NAIIAE N~#lFtS Jeff Thompson 3 Randy Lafleur 3 Gene Hess 3 Mathew Boudreaux 3 Cyprian Ukudi 3 Page 1 of 2 . ~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~~~~ ~~~~~I ~~ DATE: August 18, 2009 P. I. Supervisor FROM: Lou Grimaldi SUBJECT: Wellbore plug integrity Verification Petroleum Inspector Surface Plug Marathon Oil Company Spark Platform, S-01 RD PTD #174-005, Sundry #309-138 Tuesdav, Auqust 18, 2009; I witnessed the tag of top of cement (T.O.C.) by wireline (W.L.) of the Surface cement plug in Marathon's Spark platform well # S- 01, North Trading Bay Unit. A 1 11/16-inch gauge ring was run into the well on W.L. to a depth of 185 feet wireline measurement (W.L.M.) where it set down solidly. The plug was tagged 3-4 times with out any signs of going deeper or sticking. There appears to be a competent surface cement plug at 245' R.K.B. (elevation 60 feet) / 185 feet W.L.M. (T.H.F.). Attachments: None ~ ~'~ ~Q:.~~ ~~~}I 1 1i P~ '~ 1- t i~''.~~ k ~ Wellbore Plug NTBU Spark S-1 Surface plug 08-18-09 LG.doc 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg j~~ r~17~~„~ 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-01 RD ~ Spark Platform ~ PTD #174-005, Sundry #309-138 ~ Tuesdav, Auqust 4, 2009; I witnessed the pressure test and tag of top of cement (T.O.C.) by wireline (W.L.) of the Intermediate cement plug in Marathon's Spark platform well # S-01 RD, North Trading Bay Unit. The pump was lined up to pump down the tubing when I arrived. Reportediy the I.A. was in communication with the tubing, this was proved out as the I.A. pressure rose and declined with the tubing during the test and bleed-off. The tubing/I.A. was ~ pressure tested to 1000 psi for 15 minutes. After an initial decline of 10 psi the chart recorder drew a straight line for the 15 minute test. A 1.5-inch gauge ring was run into the well on W.L. to a depth of 7072' 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 intermediate cement plug at 7132' R.K.B. ~' (elevation 60') / 7072' W.L.M. (T.H.F.). Attachments: None "~DO~ ~;-;~n~'~~~ ~~'~' ~` - Non-Confidential Wellbore Plug TBU Spark S-1 08-04-09 LG.doc 1 of 1 Q[�/, MaPat�l®i�J�y�c,Alaska Production LLC Alaska Asset Team \ -. 4- - C> d P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/565-3076 August 3, 2009 1 c Cathy Foerster ) C G Gi L U l State of Alaska Alaska Oil and Gas Conservation Commission 333 W. 7"' Avenue, Suite 100 SED Anchorage, AK 99501-3539 Re: 20 AAC 25.300 (Request for Information) – Status of Oil and Gas Wells Dear Ms. Foerster: In response to your June 22, 2009 letter requesting a plan of action and timing for such activities associated with the referenced list of inactive wells, please find attached a table with the requested information. As indicated in the table, Marathon anticipates a measured program of P&A activities, averaging three -to -five well abandonments per year. Marathon has already begun such a program with its offshore wells, beginning with the Spark Platform wells in 2009. All of the onshore wells on the list are within active oil and gas leases that are regularly visited and inspected. Marathon anticipates updating plans for its inactive wells in the appropriate annual Plan of Development for each property. Any and all forward activities are subject to funding approval. Please also note that your June 22 letter erroneously referenced "KU 41-08". We believe that your June 22 letter reference to well "KU 41-08" was a typo and is intended to refer to Well KU 41-18. This well matches the referenced drilling permit (171-010). Should you have any questions or wish to review the attached plans with us, please feel free to call Lyndon Ibele at (907) 565-3042. Sincerely, �d—'J- Carri Lockhart Alaska Asset Team Manager Attachment: Marathon plan for list of inactive wells cc: B. Schoffmann L. Ibele K. Skiba T. Stebbins Well Files Marathon Oil Company, Alaska Asset Team Anticipated schedule of well abandonment activities Confidential 8/3/2009 Timing lWell I Permit No. I Pad or location 2009-2011 S-1 RD 174-005 Spark S-2RD 174-024 Spark S-3 169-011 Spark S-4 169-034 Spark S-5 169-039 Spark S-7RD 169-096 Spark S-8 171-033 Spark S-9 174-027 Spark TS -1 168-048 Spurr TS -2 168-050 Spurr TS -3RD 168-065 Spurr TS -4 168-066 Spurr TS -6 168-090 Spurr TS-7RD 169-026 Spurr TS -8 169-027 Spurr TS -9 169-092 Spurr 2012-2015 BC 7 176-006 BCU Pad 7 CLU 3 181-058 CLU Pad 3 CLU 4 187-034 CLU Pad 3 KU 33-30 159-015 KGF pad 33-30 KU 42-30 181-091 KGF pad 33-30 KU 44-30 168-071 KGF pad 33-30 SU 23-15 161-014 Sterling Unit KU 41-18 171-010 KGF pad 41-18 KU 43-12 169-087 KGF pad 14-6 KU 11-6 165-017 KGF pad 34-31 KU 21-5 169-035 KGF pad 43-32 W F1-21 rd 193-183 West Fork WF2-21 192-010 West Fork . ~ MEMORANDUM State of Alaska Alaska Oii and Gas Conservation Commission TO: Jim Regg ~~ ~I~$~~~ DATE: July 16, 2009 P. I. Supervisor FROM: Bob Noble SUBJECT: Abandonment Plug Test Petroleum Inspector NTBU S-01 RD Marathon Oil Company PTD 174-005 , ~~~!~.~ `,~ ~' ,i ; ~ ~D~~ j~~~~~~ ~ 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-01 RD. Upon arrival I met with Marathon's rep. Dan Byrd. Julv 15, 2009 They set the plug consisting of 17 BBLs of Class G, 15.9ppg cement. The procedure called for the cement to be displaced with 85 BBLs of water. The well pressured up while displacing cement and they were only able to get 66.5 BBLs of the planned displacement pumped. 3000 psi was left on the tubing overnight. July 16, 2009 When I arrived i found 2500 psi left on the well. Marathon bled the tubing down. While bleeding the weii down 17 BBLs of crude oil back returned to their bleed tank. A 1500 psi test was then attempted on the tubing. The IA pressure tracked the tubing. This told me that there was some type of tubing-to-IA communication. Gas was bled from the IA during depressure operations. A second attempt to pressure test the tubing was performed, and this time tubing and IA failed to pressure up. My feeling is they did not pump enough fluid to fill the void left by bleeding the gas off of the IA. Marathons Dan Byrd asked me what I thought they should do. I told Dan that he needed to get with his engineers and have them contact AOGCC engineering staff for another plan forward, as I was not going to make that call from the field. An e-line tag was performed and good hard cement was found to be at TOC 9596' RKB. A new procedure came in from the AOGCC office. They were to set a retainer and bail cement on top of it. I told Dan to call me when he was ready for me to come out and witness another pressure test and tag on this well. Summarv: I witnessed 2 attempted pressure tests of the tubing in NTBU S-01 RD - both failed; also witnessed a successful tag of cement plug verifying the top at 9596 feet RKB. Attachments: none S-1RD Page 1 of 1 ~ ~ 1~4- oos Aubert, Winton G (DOAj From: Aubert, Winton G (DOA~ Sent: Thursday, July 16, 2009 3:08 PM To: 'Laughlin, Gary A.' Cc: DOA AOGCC Prudhoe Bay; Schwartz, Guy L(DOA) Subject: RE: S-1 RD AOGCC hereby approves changes to Sundry 3Q9-138, for well NTBU S-01 RD (PTD 174-005 described below. All other ac~oroved Sundrv stinulatinns ann~~ Winton Aub AOGCC From: Laughlin, Gary A. [mailto:galaughlin@marathonoil.com] Sent: Thursday, July 16, 2009 2:59 PM To: Aubert, Winton G (DOA) Subject: S-1RD Importance: High ~~~~~ JUL 1 ~ 2009 From: Laughlin, Gary A. Se~ Thursday, July 16, 2009 2:57 PM To: Aubert, Winton G (DOA) Cc: Laughlin, Gary A.; Berga, Pete; Keppers, Craig J. Subject: Draft Email to AOGCC on S-iRD Importance: High Winton, This is a follow up on ourdiscussion regarding complications on well S-1RD located on the Spark Platform (please reference Sundry # 309-138). After performing the operation lined out in the P8A procedures on Line #7 the cement plug failed to hold pressure. The TOC was tagged at 9536' MD. Marathon would like permission is set a bridge plug in the tubing at 9532' and dump bail between 25-50' of cement on top of the plug. Pressure test tubing. Continue on line #9 of the procedure. Thanks Gary Laughlin 7/ 16/2009 • Tiffany Stebbins Regulatory Compliance Rep. Marathon Oil Company P.O. Box 190168 Anchorage, Alaska 99519-6168 Re: G-NE/Hemlock-NE Oil North Trading Bay Unit S-O 1 RD Sundry Number: 309-138 Dear Ms. Stebbins: • ~ ~I ~ / ~ ~ ~~ ~ ~~~~~~ .,~'J;.. :~~ ~ ~.~D~ 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, ar such further time as the Commission grants for good cause shown, a person af~'ected 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 worlflng 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 h DATED this Z day of July, 2009 Encl. . / ~~ ~ i~ ~ ~ ^(~ ~ ~ ~ , U STATE OF ALASKA ~ ,~~Y: i~;; ~~, ~009 ~~~ ALAS~OIL AND GAS CONSERVATION COMMIS510N APPLICATION FOR SUNDRY APPROVAL~~ti~:~ ~~r ~~as i~~ras. Commissian ~n nnr ~~ ~Rn n.~.~},T.,.,..., 1. Type of Request: Abandon ~• Suspend ^ Operational shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ~ Repair we)I ^ Plug Perforations ^ Stimulate ^ Time E~ension ~ Change approved program ^ Pull Tubing ~ Perforate New Pool ~ Re-enter Suspended Well ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Marathon Oil Company Development ~ Exploratory ~ 174-005-0 . 3. Address: Stratigraphic ~ Service ~ 6. API Number: P.O. Box 190168, Anchorage, AK 99519-6168 50-733-20158-01-00 ' 7. If pertorating, 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'adlllg Bay Unlt S-01 RQ Spacing Exception Required? Yes ^ No ^ Spark platform 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL035431 ' RKB-MSL 115' ' G-NE/HEMLOCK-NE OIL • 12• PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,060' • 10,168' - 10,971' 10,098' 10,605' Fill 20' Otis tool string Casing Length Size MD ND Burst Coliapse Structural Conductor Surface 2,802' 13 3/8" 2,802' 2,792' Intermediate 7,951' 9 5/8" 7,951' 7,592' Production Liner 3,364' 7" 11,060' 10,168' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,215 - 10,801' 9,505 - 9,964' 3 1/2" N-80 Buttress 10,069' Packers and SSSV Type: Otis "FMX" TRSV w/'XXR' plug in SCSSV Packers and SSSV MD (ft): 330' Baker FB-1 9,980' 13. Attachments: Description Summary of Proposal Q 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 ate 907-565-3043 ~ ~Q ^ Q COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~~~' ~~ v Plug Integrity [~ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: p A~1 C 1 ~~ GLYh~..(- ~~q ~ ~C~.C~rr~tn.~ `~'~~: t~ii./~ 4-S ~ R~°7 ~.. ~.1,~ ~1~. ~ZJ '~ ~ ~~~Y'n .x J Subsequent Form Required: ~~`y~.~ APPROVED BY ~ Q ~ ~ Approved by: COMMISSIONER THE COMMISSION Date: 1 " G~X/'' .~,~'~ ~D Y • u. r-t7' Form 10-403 Rev}sqd ~2p0,8~ t ~ ! ~ ~ ~~~, ~~,, J'.~t~ ~t ~S 2009 (~'a s"bm~t ,__-~~7~~ , ~ • • MARATHON OIL COMPANY NORTH TRADING BAY UNIT SPARK PLATFORM WELL S-1RD TEMPORARYABANDONMENT PROCEDURE 03/31/09 WELL DATA API# 50-733-20158-01 Elevation: Water Depth Total Depth: Surface Casing: Intermediate Casing: Production Liner: CURRENT STATUS 115' RKB - MSL . Tubing: 31/z" 9.2 ppf N80 @ 10069' 60' • SCSSV: Otis Ser 10 FMX TRSV at 330' 11,060' ' Nipple: XXR plug at 330' 13 3/s" 61 ppf J55 @ 2802' Packer: Baker F&1 packer @ 9980' 9 5/a" 47 ppf N80 ~ 7951' PerForations: 10.215 - 10801' Fill to4~6G9r` 1~,~`~ ~ 7" 29 ppf P110 11,060' PBTD: 10,971' TOL C~4 7696' ~- c 1o~4~il ~ I,(z.c`; t ~ The well has no further utility and is to be temporarily abandoned by following the procedure below. 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 the operation of the tree valves, flanges. Repair as needed. 2. Mobilize abandonment crew and equipment to location. Perform JSA and rig up equipment. 3. Check tubing and casings for pressure. Bleed off through gas buster. Fill and test casings with water. Report results. 4. PerForm JSA for proper slick line operation. Rig up slick line lubricator and test to 1500 psi. Pressure up and lock SCSSV open. RIH with gauge ring to the end of tubing at 10069' pull wire line plugs as needed (XXR at 330'). 5. POOH with slick line and rig down. 6. PerForm JSA on pressure pumping. Rig up pump and lines on tubing, test lines to 1500 psi. Pertorm injection rate. Monitor 9 5/s" casing for possible communication. Record injection rate and pressure. 2~ ~- ~°~`~'~ t 7. PerForm JSA on mixing and pumping cement. Mix and pump,l~bbls of cement and squeeze the pertorations. Squeeze to 1000 psi over injection pressure or until cement is displaced to a depth of 9800'. 8. WOC and test to 1000 psi. Record results on a continuous pressure chart recorder. 9. Perform JSA on safe electric line operation and explosive handling. Rig up electric line lubricator and test to 1500 psi. RIH with perForating guns loaded with 2 ft of 4 SPF tubing punch and tag TOC for bottom hole cement plug @ 9800' RKB and record results. Pick up to 7796' RKB and fire tubing punch. 10. Perform JSA for cement mixing and pressure pumping. Rig up cement pump and lines, test lines to 1500 psi. Break circulation down the 3 1h" tubing taking returns up the 9 5/s" casing annulus. Mix and pump 18 bbl cement slurry for a 300' intermediate cement plug from 7796' RKB - 7496' RKB in the 3 1h" tubing and in the 7" Liner and the 9 5/a" casing to cover the "LAP" (100' below to 200' above). Displace with weighted fluid. 11. WOC and test to 1000 psi and record with a continuous pressure chart recorder. Spark Well 1 Page 1 ~ 4/17/2009 . . ' • ~ 12. PerForm JSA on electric line operation and explosive handling. Rig up electric line lubricator and test to 1000 psi. RIH with 3 1h" jet cutter and tag TOC @ 7496' RKB and record results. Pick up to 600' RKB and cut 3 1/z" tubing. POOH. 13. Rig down tree. 14. Perform JSA on proper pipe handing procedures. Pull 3 1/z" tubing and check for N.O.R.M. 15. Perform JSA on proper electric line operation and the handling of explosives. RIH with 9 5/s" gauge ring and tag top of tubing stub at ~ 600' RKB. POOH 16. RIH with 9 5/s" CIBP to 600' RKB, pick up to 575' RKB and set. 17. RIH with perforating gun armed with 2 ft of 4 SPF casing punch, tag CIBP @ 575' RKB and fire guns. POOH. RD electric line. 18. PerForm JSA on cement mixing and pressure pumping. RU pump and lines, test pump lines to 1500 psi. NOTE: IF POSSIBLE A)Circulate clean, down the 13 3/s" casing and up the 9 5/a" casing with weighted fluid. Mix and pump 41 bbl cement slurry for a 300' cement plug in the 9 5/s" casing and the 9 5/a" x 13 3/s" casing annulus from 575' RKB - 275' RKB. B)If unable to circulate the 9 5/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 surtace plug from 575' RKB - 275' RKB in the 9 5/s" casing only. 19. Pick up work-string 20' above TOC @ 275' RKB and circulate work string clean. POOH. 20. 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. 21. RD. Well is temporarily abandoned. Spark Well 1 Page 2 ~ 4/17/2009 ~AARAT#f~l~ ~~ RKB-MSL 115' WATER DEPTH 60' Maximum angle = 38 deg API# 50-733-2015&01 Surface Casing_- C~? 2802' 13 3/8" 61 ppf J55 Cemented with 1900 sks CTOC = surface Tubin 3 1/2" 92 ppf N80 Buttress Intermediate Casing - 7951' 9 5/8" 47 ppf N80 Buttress Cemented w/ 1000 sks Prior to sidetrack PRF'D and SQZ'D @ 7900' and 8125' Cut window @ 7950-8020' Marathon Oil Company North Trading Bay Unit Spark Platform Well S-1 RD "CURRENT" All Depths measured RKB to top of equipment All depths are RKB unless otherwise noted FMC UM-TC-IAEN Tbg Hgr X-over 4 1/2" butt box x 3 1/2" butt Pin Otis Series 10 "FMX" TRSV @ 330' 3 1/2" Butt txb 2.813" w/'XXR' plug in SCSSV (set in 1992) Camco MMG GLM 2.875" ID RK Latch 2449' 8217' 4064' 8881' 5422' 9405' 6545' 9860' 7459' TOL 7696' - Est TOC 7500' Baker FB -1 @ 9980' Baker half cut mule shoe @ 10069' Perforations Fish Otis tool string 20' lost 12/88 Depth of fish "Unkown" Fill @ 10605' WLM 6/88 Production Liner C~ 11060' 7" 29 ppf P110 Buttress Cemented w/ 1000 sks TOC at 8600' CBL G1 10215'-225' G2 10234'-306' G3 10334'-359' G4 10378'-423' G 5 10444'-454' H 1 10487'-527' H 2 10539'-604' H3 10705'-801' TD = 11060' ~ ~~~~~t~N ~, RKB-MSL 115' WATER DEPTH 60' API# 50-733-20158-01 Maximum angle = 38 deg Surtace Casing - @ 2802' 13 3/a" 61 ppf J55 12.515" ID, .1521 bbl/ft Cemented with 1900 sks CTOC = surface Tubin 3 1/z" 9.2 ppf N80 Buttress 2.992" ID, .00870 bbl/ft TOL 7696' - Squeezed with 100 sks Intermediate Casing- 7951' 9 5/a" 47 ppf N80 Buttress 8.681' ID, .0732 bbl/ft Cemented w/ 1000 sks Prior to sidetrack PRF'D and SQZ'D at 7900' and at 8125' cut window at 7950-8020' Est TOC 7500' Marathon Oil Company North Trading Bay Unit Spark Platform Well S-1 RD "PROPOSED" Baker half cut mule shoe @ 10069' Fish Otis tool string 20' lost 12/88 Depth of fish "Unkown" ~~ ~i,~~! Fill @ 10605' WLM 6/88 f~a~~~~~~; Production Liner C~ 11060' ' - 7" 29 ppf P110 Buttress ~ 6.184" ID, .0371 bbl/ft Cemented w/ 1000 sks TOC at 8600' CBL All Depths measured RKB to top of equipment All Depths are RKB unless otherwise noted 300' Surtace CMT Plug 95/a"and95/a"X133/s"=41bblSlurry 9 5/e" only = 22 bbl Slurry 575'RKB-275'RKB Pertorate 9 5/e" Casing @ 575' RKB CIBP @ 575' RKB Camco MMG GLM 2.875" ID RK Latch 2449' 8217' 4064' 8881' 5422' 9405' 6545' 9860' 7459' Perforate tubing @ 7796' RKB 300' Intermediate Cement Plug 18 bbl Cement Slurry 7496' RKB - 7796' RKB 100' Below and 200' Above liner lap Baker FB -1 @ 9980' Squeeze perts with 22 bbls Cement Leaving top of cement at 9800' (300' above pertorations) Perforations G 1 10215'-225' G2 10234'-306' G3 10334'-359' G4 10378'-423' G5 10444'-454' H 1 10487'-527' H2 10539'-604' H3 10705'-801' TD = 11060' • • Spark Platform Abandonment Review North Trading Bay Unit Marathon Oil Company ~---~ Well NTBU S-O1RD (PTD174-005) - Sundry Application 309-138 Well NTBU S-02RD (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 5-05 (PTD169-039) - Sundry Application 309-142 Well NTBU S-07RD (PTD169-096) - Sundry Application 309-143 Well NTBU 5-08 (PTD171-033) - Sundry Application 309-144 Well NTBU 5-09 (PTD174-027) - Sundry Application 309-145 Requested Action: Marathon Oil Company (Marathon) proposes to permanently abandon the above referenced wells on the Spark Platform in the Cook Inlet. Recommendation: I recommend approval of the above referenced Sundry Applications to a11ow Marathon to permanently abandon the wells. Discussion: Marathon proposes to permanently abandon the above wells on the Spark Platform by setting the required multiple cement plugs in the wellbore. (At a later date to be determined the Spark Platform structure will be removed; at this time the casing strings will be cut and pulled just below mudline to complete the total abandonment of the wells. ) The Spark Platform is one of two, the other being the Spurr Platform in the North trading Bay Unit (NTBU). Production began from the Spark Platform in January 1969 and peaked at nearly 12,000 bopd in November 1969 before beginning a rapid decline. By January 1992 production from the platform had fallen to less than 300 bopd and production was shut in. In November 1996 gas production, but not oil production, from the platform was reestablished but and peaked at over 5.2 mmcfpd in May 1998. The platform produced no water during the first year an a half of gas production but then quickly rose to over 200 bwpd. The initial attempt at gas production ceased in May 2000, a second attempt was made beginning in July 2003 but as soon as there was any significant gas production there was also significant water production, up to almost 40Q bwpd. By September 2005 significant gas production had ceased on the platform but intermittent, averaging about 1 mmcfpd but only producing, usually, one day per month, production continued until July 2007. There have been no further attempts to resume production from the platform. Cumulative production from the platform is about 17.5 mmbo and 6.8 bcfg, 4.6 bcfg of which was associated gas recovered during oil production. • ~ There have been a total of twelve wells drilled from the Spark Platform, of which four have already been P&A'd (NTBU S-O1, 5-02, S-02DPN, and 5-07). Of the eight "active" 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 lcnown oil accumulations accessible from the Spark Platform range from zero for an economic limit of 300 bopd for the platform to 1,096 mbo for an economic limit of 50 bapd for the platform. The following table shows the remaining reserves at various economic limits. Economic Limit (bo d) Remaining Reserves (mbo 50 1,096 100 869 200 410 300 0 Below is a graph of the decline curve analysis showing production extrapolated to a 50 bopd economic limit. Without specific economic information it is impossible to say what truly the economic limit is for the Spark Platform. However, in a May 23, 1992, letter from Marathon to the Department of Natural Resources (copy attached) Marathon stated that the platform had been uneconomic since 1990 and that at that time the break even oil price was in excess of $20/bbl. Although oil prices are substantially higher than that now operation costs have also increased dramatically since that time and the platform likely remains uneconomic today at any oil production rate that could be obtained from the existing facilities and wellbores. • ~ ~ ~ a 04TE Several attempts have been made at sustaining substantial gas production from the platform but none of them ha~e lasted more than a year of regular production, and you ha~e 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 ~~,.~j ~~~ Sr. Reservoir~iigineer April 23, 2009 - Revised July 2, 2009 C~ ,o __ - - . - ~~ ~~t ~~s ~ ~ ~ ~,.~ ~, b O ~ . . 13 : 0.0763624 A.e. ~ . . . . . .... . cp :288.35766Vtl ~ti :0137/1982 . . . . [e ; 0226/LOt4 Fnel I~te : 49.9199 hbVd , ~ , CLmFYOd. :17508.aNtt~ i: 10 . . CLm Cmte : 0131/t992 ~ f~serves : 1096.35 ~~UI . . . ~. - - . F~serves Oete : 02/28/2014 ~ . . B42 : 18BW21W~I f { . . . . Farecasl Enrlatl 9Y ~ F~te I ~ . ~ ~ ~ ~ OB Farecast dvte : nbt Save~i . ' - . Rasme Type : Nx~e ~ ~O' i ,a ~-,~-~-~--,~~T 19~`n 7~ J7T_i 7d7s 9t929394959697989400D102030405060708097071727374 Marathon MARATHON Oil Company 1—i&k-oc)S Alaska Asset Team North America Production Operations P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/565-3076 March 1, 2009 CEIIVEFED ._ ...__ . _ _..... MAR a 2 2009 Alrislug, nil & Ge's Eons. Cammis". t; Commissioner: Cathy Foerster Alaska 011 and Gas Conservation Commission Anchorage 333 W. 7th Avenue Suite 100 Anchorage, AK 99501-3539 "NED Re: Notice of Revised Suspended Wells Regulations and Request For Verification of Suspended and Shut-in Well Information Dear Cathy: Marathon received your letter dated January 28, 2009 (Cert # 7005 1820 00012499 5999) requesting Marathon to validate information contained within it. Marathon has reviewed the data and found it to be accurate. Marathon is in the processes of reviewing and addressing the new regulatory requirements in "20 AAC 25.110 Suspended wells". If you have any questions, please do not hesitate to contact Gary Laughlin at 907-565-3036 or email him at galaughlin@marathonoil.com. Sincerely, Ben Schoffmann Operations Manager MARATHON OIL COMPANY 1.3 SARAH PALIN, GOVERNOR r j lJ ALASKA OIL AND GALS 333 W. 7th AVENUE] SUITE 100 CONSERQAnOAI COMUSSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 January 28, 2009 FAX (907) 276-7542 CERTIFIED MAIL RETURN RECEIPT REQUESTED 7005 1820 0001 2499 5999 Ben Schoffman Marathon Oil Company PO Box 196168 Anchorage AK 99519-6168 7 r� �, 7�t'P Re: Notice of Revised Suspended Wells Regulations and Request for Verification of Suspended and Shut -In Well Information Dear Mr. Schoffinan: Enclosed are the Alaska Oil and Gas Conservation Commission's revised regulations regarding suspended wells (i.e., 20 AAC 25.110). Also enclosed are a list of suspended wells and a list of long term shut-in wells operated by Marathon Oil Company. For each list, please verify the information for each well, and provide any corrections by April 1, 2009. Location inspections required under 20 AAC 25.110 should be coordinated with Jim Regg at 907-793-1236 or jim.regg@alaska.gov. If you have any questions regarding this notice, please contact Tom Maunder at 907-793- 1250 or tom.maunder@alaska.gov. Sincerely, /�74 64-41 Cathy P. Foerster Commissioner Enclosures ri Complete items 1, 2, and 3. Also complete A. S+9�- item 4 if Restricted Delivery is desired. X If Print your name and address on the reverse qy?---� so that we can return the card to you. B. Received by (Pd Name) C. E Attach this card to the back of the mailpiece, or on the front if space permits. �� p D. Is deliv address different from item 1? 1. Article Addressed to: If YES, enter delivery address below: H Agent ❑ Addressee rte of Delivery ❑ Yes ❑ No Ben Schoffman postal Service - � 0— IT CERTIFIED mail only., RECEIPT • . No Insurance (Domestic corn Ln WWW -u5ps lT 10.59 P S P0,9 ru P~$ o CertlNed Fee 62.70 z � Retum Receipt Feen tFjdorsertierM Requlred9 $2.20 O ® ccrq D-WerY Fee (Ree mmerd RequlreM 10. N j 00 C 01 g95 T°�'P`s'�°e` 4 f5.f Ben Scho uran E3 ° Marathon Oil Company 4AW�•;' PO Box 196168 or PO box No. AK 99519-616 Anchorage ri Complete items 1, 2, and 3. Also complete A. S+9�- item 4 if Restricted Delivery is desired. X If Print your name and address on the reverse qy?---� so that we can return the card to you. B. Received by (Pd Name) C. E Attach this card to the back of the mailpiece, or on the front if space permits. �� p D. Is deliv address different from item 1? 1. Article Addressed to: If YES, enter delivery address below: H Agent ❑ Addressee rte of Delivery ❑ Yes ❑ No Ben Schoffman Marathon Oil Company PO Box 196168 Anchorage AK 99519-6168 rvice Type 1ACertified Mail Express Mail ❑ Registered Return Receipt for Merchandise ❑ Insured Mail ❑ C.O.D. 4. Restricted Delivery? (Extra Fee) ❑ Yes 2. Article Number (Transter from service label) 7005 1820 0001 2499 5999 PS Form 3811, February 2004 Domestic Return Receipt 02595-02-M-1540 Operator Suspended and Shut In Wells MARATHON OIL CO Field Current Date of Permit API Number Well Name Status Status Surface Location....................................................... Lease(s).................................. 'EXPLORATORY 202-129-0 50-133-20517-00-00 ABALONE 1 SUSP 3/9/2003 250 FSL 3000 FEL Sec 29 T 2 N R 12 W SM FEE-OSMAR KASILOF 202-257-0 50-133-20520-60-00 KASILOF SOUTH 11-1 SUSP 4/15/2004 520 FSL 1340 FWL Sec 28 T 3 N R 12 W SM ADL0384529 ADL0384534 KENAI C.L.U. 206-121-0 50-133-20563-00-00 CANNERY LOOP UNIT 12 SUSP 9/8/2006 2490 FSL 2365 FWL Sec 4 T 5 N R 11 W SM ADL0324602 ADL0359153 ADL0365454 FEE-TR119 NINILCHIK 208-023-0 50-133-20574-00-00 NINILCHIK UNIT G OSKOLKOFF 7 SUSP 6/12/2008 2969 FSL 3023 FEL Sec 23 T 1 N R 13 W SM ADL0389180 STERLING 161-014-0 50-133-10012-00-00 STERLING UNIT 23-15 SUSP 10/23/1966 2715 FNL 1520 FWL Sec 15 T 5N R 1 O W SM FEDA028135 TRADING BAY 174-005-0 50-733-20158-01-00 N TRADING BAY UNIT S-01 RD SI 1/25/1992 2608 FSL 2495 FEL Sec 26 T ION R 13W SM ADL0035431 169-011-0 50-733-20175-00-00 N TRADING BAY UNIT S-03 SI 2/25/1992 2613 FSL 2495 FEL Sec 26 T ION R 13W SM ADL0035431 169-096-0 50-733-20197-01-00 N TRADING BAY UNIT S-07RD SI 2/25/1992 2612 FSL 2488 FEL Sec 26 T ION R 13 W SM ADL0018776 171-033-0 50-733-20233-00-00 N TRADING BAY UNIT S-08 SI 1/25/1992 2577 FSL 2566 FEL Sec 26 T ION R 13W SM ADL0017597 174-027-0 50-733-20265-00-00 N TRADING BAY UNIT S-09 SI 1/25/1992 2570 FSL 2563 FEL Sec 26 T ION R 13 W SM ADL0017597 168-048-0 50-733-20120-00-00 N TRADING BAY UNIT SPR-01 SUSP 8/18/1992 615 FNL 2072 FEL Sec 34 T 1 O N R 13W SM ADLOO17597 168-050-0 50-733-20122-00-00 N TRADING BAY UNIT SPR-02 SUSP 8/19/1992 664 FNL 2007 FEL Sec 34 T ION R 13 W SM ADL0017597 168-065-0 50-733-20133-00-00 N TRADING BAY UNIT SPR-03 SUSP 8/18/1992 618 FNL 2068 FEL Sec 34 T ION R 13 W SM ADL0017597 168-066-0 50-733-20134-00-00 N TRADING BAY UNIT SPR-04 SUSP 8/13/1992 666 FNL 2003 FEL Sec 34 T ION R 13W SM ADL0017597 168-090-0 50-733-20153-00-00 N TRADING BAY UNIT SPR-06 SUSP 8/10/1992 642 FNL 2072 FEL Sec 34 T ION R 13W SM ADL0017597 169-026-0 50-733-20181-00-00 N TRADING BAY UNIT SPR-07 SI 8/26/1992 622 FNL 2068 FEL Sec 34 T ION R 13W SM ADL0017597 169-027-0 50-733-20182-00-00 N TRADING BAY UNIT SPR-08 SUSP 8/26/1992 664 FNL 2000 FEL Sec 34 T 1 O N R 13 W SM ADL0017597 169-092-0 50-733-20200-00-00 N TRADING BAY UNIT SPR-09 SUSP 8/18/1992 618 FNL 2076 FEL Sec 34 T ION R 13W SM ADL0017597 Wednesday, January 14, 2009 • W. Vl~n ProducUOn M anaaer Alaska Region J Domesuc ProducUOn Marathon M4RATNON Oil Company P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 March 23, 1992 Mr. Haroid Heinze, Commissioner Department of Naturai Resources 400 Willoughby Avenue, 5th Floor Juneau AK 99801-1796 Dear Commissioner: SUSPENSION OF PRODUCTION OR OPERATIONS Enclosed for processing is an appiication for suspension of production or operations and a fiiing fee of 550. Pursuant to 11 AAC 82.670 Suspension of Production or Operations, Marathon Oil Company, P. 0. Box 190168, Anchorage, Alaska 99519, hereby requests approval of suspension of production or operations for a two-year period commencing June 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: TlON, 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 inciuded in this amount is the g6.7 MM invested during that time. The break-even oil price for 1991 was over S20 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 ~20. The Unit does have economic gas reserves which could be developed from Spark. Gas reserves have been proved with a down structure fuei gas well on the Spurr Platform which has recovered 3.5 BCF. Current plans call for developing remaining gas reserves by recompleting Spark Platform Wells A subsidiary of USX Corooration ~ Mr. Harold 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 Unocai and Marathon con- tracts. Because both companies currently have sufficient deliverability to ,~ _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 developed. 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 51.0 MM since that time as shown in Exhibit 4. Investments totaling 56.9 MM incurred since 1988 are not included in this caiculation. As with Spark, the break-even oil price for 1991 was over ~20 per barrel, not including OD&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 mechanical problems. :~ ~0~~ 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 ' inciude the substantial ~nonies required to stay in compliance with oil ~ spill and process hazard management regulations recently enacted. These losses are not acceptable and as a result Spurr Platform and the attendant onshore production facility at Granite Point must be shut in. Until recently, the non-unit area deveioped by Spurr was thought to contain significant undeveioped reserves. Evaluation of 3-D seismic and the performance of Monopod Platform Well A-28RD now indicates no further economic deveiopment potential exists. With once planned development potential eliminated, Spurr has no further utility for oil production under current economic conditions. Future gas production from Spurr is possible and will be evaluated as part of the overall development scheme. Marathon's Plans Durina 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 aiso 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. Haroid Hein! • ' March 23, i992 Page 3 A major undertaking during this suspension period will be the evaiuation of abandonment options for Spark, Spurr and Granite Point Production Facility. This evaluation will attempt to optimize method and timing of abandonment. As no platform has been abandoned in the Cook Inlet to date, much research needs to be done prior to abandoning the first structure. It is stressed that this work does not preciude the pianned 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. Sincereiy, . -- ~4-y '~~ ~ ~ ~. ~ ~ 1 ~ ~., y ~ . W. Watson cc: Mr. James Eason Department of Natural Resources Division of Oil and Gas P. 0. Box 107034 Anchorage AK 99510-7034 A:LAND2/MH07/6GP ~ , ~ t ~ • EXHIBIT 1 ATTACNED AND MADE A PART OF UNIT AGREL~~lENT FOR THE flEVEL~PMEJVT AND OPEAATiON OF THE NORTH TRAOING 8AY UNIT AREA -~.' NORTH TRADING BAY UNIT BOUNDARY PRIOR TO AUGUST 2. 1976 '~.. ~ 1 2T~ 26 T T 10 N R 13 1~i/ T9N R13W btARATHON ~~~\ ~ 40L~J5431 , ~ ~ ~ ~ NORTH TRADING BAY UNIT BOUND AND HEMLOCK b 'G' FORMATIdI PARTICJPATING AREA BOUNDAR I EFFECTIVE AUGUST 2~ 1978 ~ 34 ' 35 2 ARATHp ~ UNION MARATHON AOL•17597~ ~ qpt 187~6 \\ MapsouacE OIVISION OF LANOS PROTAACTION SHEE7, GRID NO. 5•13-5 STATE OIL ANO GAS LEASES AOL•17597, qp~.18776, aDL•]5431 LEGEtVD O ~~ TRACT NO. PAqTIC1PATING AAEA NORTH TRADING 8AY UNIT AAEA HEI~LOCK & `G' PARTICIPATING aREA ~ ~ COOK INLET, ALASKA PARTiC1PATiNG AREA LATEST CONTRACTION DATE: AUGUST 2, 1976 ' ~WNERSHIP AS OF:SEPT. 1, 1988 RAARA~'HO~ ~oL C~4i1PA~1iY i , 4 ~` 1r , ~ ~ ~ ; ' zae :.aea ~.aae z.aee .aee :.zea _.zae ;.aee "' ytARA?HON OfL C;,~p,Vy ' I s.aea ~orrrx rx,wu~rc anr ~~~t I " 5 ` :YHIBIT ? .aat ~s.s3~ " 'OYALTY P,EDUCTIOV sw _ ~ i ' m 9 ~ m . ~ T _ _ I i ~ ~ _ ° a~~e I ~ ' 9 _ m i . 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I ~ ai ~ ~ ' • `~ ~~ _ '' •~• m ~ -~_, ~ ! ,, td4 '~ i [ ~ .Y~~ ~ . ;~~1 ,~ ~ ~ ~ / , - , / I N 9~ ~ ' ~ ~ ~ . ~~ 'oL ~ f ~ • ~ ~ ~ ~ I ~~ •' .~ ' ,~_7~ , I Is ~i ' ~ • ~ -~~ ~ 84li ' I , r: ' • :9i~4 ~~~~ ;: ~ ~ N ~ ~ ~ ~ Z1 / ~ :qOIII ~ ry ' ~ ~5~ . ~'"3 . a I a, ~ I ~ / =-~7 i ~m 9 t 1~T85-! ~ ~ ~ :i~ ~ !~ 'Sji j_ ~ ~ I I ~, ~, dt l ~ i ~ :'a~~~ ~ i v~ " :ON-R13W 1:59~ ~ ~s .4DL 18~76 '.aea 3.aae :.aae ' ~ a.eo• ..aaa ' z:aee .~.aee .a.aeo .s.eo~ Laughlin, Gary A. From: Laughlin, Gary A. Sent: Monday, May 18, 2009 8:35 AM To: winton.aubert@alaska.gov Cc: Laughlin, Gary A. Subject: FW: Conversation Follow-up Importance: High Sensitivity: Confidential Attachments: Picture (Enhanced Metafile); Picture (Enhanced Metafile) • ?~~:_.,:_~~;. , 'K~ ~ . , i. -, . .~. ,., . ._. '~~2', ~.r„„. From: LaughUn, Gary A. Sent: Monday, May 18, 2009 8:21 AM To: (winton_aubert@~admin.state.ak.us) Cc: Laughlin, Gary A. Subject: Conversation Follow-up Importance: High Sensitivity; Confidential Winton, This is a follow up to our conversations May 13th and May 14th, 2009. All Wells • It is my understanding you will be checking to see if you can strike the phrase "temporarily abandoned" in each well abandonment procedure and ~eplace it with "permanently abandoned" for the Spark Platform sundries submitted in April 2009. • We are currently running a gauge ring and temperature surveys for all wells on the Spark Platform. I expect to see the results Tuesday or Wednesday next week. After reviewing, I will send you an email on the order we plan to abandon the wells. We plan to have simultaneous well abandonment operations. The only certainty at this time is we will abandon S-5 last. . Marathon will be added an additional 70' of cement to the top of the cement surface plug, thereby increasing it to 370' to adhere to the regulatory citation 25.112 section (d). (d) Plugging of the surface of a well must meet the following requirements: (1) by the displacement method, a cement plug at least 150 feet in length, with the top of the cement no more than five feet below original ground ~ level onshore, or between 10 and 30 feet below the mudline datum offshore, must be placed within the smallest diarneter casing string; . _ ; I~dtrc~t?tort UU i:~rn~€iry ~ #+~or?f* Trtt;~i~n~ Bciy Urt+C ~ ~, ~ ~ ~ ~~ra~k PMatfnrm ~~,fril S•~ , . . "F~Ft~f wC3Sk~3"____._ ( R~'{~-~e+'u~ i~r'~ ~ ~ ~-a~lt ~ .m9i ~°i 'w::l ~~ ~~e!' 1 ~ i i ~:'1' ~ 4~1~F1'~G' ~A.^{7`~~Y ~~.5~ n ~, s.i. 6 i~~ft.Sf. 1~'o't ~f~r~ t ,i.~ • ..r=i r ~'u~i ,~w~ ~: ~'s . ~ 3976 ~ 3329' A~f M 34•r 33-2p2€+5 ,~: ~;, ,~. "~ ,': -_... _ __ . _. . '.~1ft j i~}~iCR ~;q'1"~A~t: F'~t.p 9 7 i ~ F r,~;~ :~~;a"+iS b?5' ttKf3 I', ~ ~N~.~ k.~'~fY~ ~.FiJ.:JUf~i .:. „„„. ~~'~"~~ ~ .~. .~«. .r.,~... ~`~' Jf Iy - 21 bJI~ S-~~3~ct ?ix~ k~T3,,^1.. F ri.~ It~tk3 ~f5' faV~i3 ~ ~ ~ ;:, -,~ r ~.ti I I I ,r~x" ~.;= ~r sz~~ a~c~ ~~„~,; ~ ~~, 1~~a t~~,i, If Part B online line 17(example is from the S-09 Sundry), is unsuccessful the a"top job" will be performed. This step exists on all Sundries but line number may vary. .~ ~ . F'~ I'•.i-rr .I:., .~ r. : ~~?I 1 ~F. ~t~J ~.IF.:U'~,I~ ,. ., 1 ,:.•in~; ri; lT.I ~~~ ~r.., 'inRS. ,. -~~1FF ir_,~ l'~JC 'r;l. ~ ..~ .., ... ~,, . ,-„~ ~... } . ;t. r~ , .~.,,.,~-1-,; ;, ~~. "~~ ~ I r.~., .:Ir ~ ., .~ '; ~ ,; ,;t~, ~ ~.~ I~ i~. ~i _ • . ~,;~i,iM rr l i J~<re~ti :r: "uid. :ti . x . ~>~.n;c 1_l :. . :•, r~~n- ... . . ,._ ,..,~~.~al•[ L.I..I'I, f.'~. ,.' ;i,1i.. ,.~..~r,: , il;~l'; ,r . :~: :' •ir •.~::I,i' .r. ~„ y ,•.' ~ '_' ° [:~r;i I 1'. a't'tJ „~. f~'.',.'Y. :. :,.;~ ~ ~ . .... ~ . . F~'(P . ?~r' ~+<< ._ 1;1 I'' ~~i~::l.le, Ir~:, . i;l,-,°:~ r~ie;. ~.d =e 1`:~ ` ....,i~~~ :a.~.~i.a i~5; R - s~~,t5. ~rnt~,.=.t°~~~r, tt: ~':IF+P, ~~Gx. .,.., .~~.r°,.,>_~,i,l!. "I;. . r;w! tl :~i~ ,.,.. ~.. : .~ ?'.d . . ~' 4~ ~~v _ _.~'~'i:.~ I :.i.:f~':1.:'. ti~i,k'. IL. 1 .~. - .. ~ .ti/.;: +'~. f~lti' ~ , . . ~il?~ ar I•.. 2 S-9 We v~iill be attempting to remove a fish located approximately 4' below the tubing hanger stuck in the early 90's from S-9. Thanks Gary s 0 Marathon Oil Well: S-1 Field: Spark 05-13-2009 Pressure (psia) 400 800 1200 1600 2000 2400 2800 3200 3600 4000 0 Pressure-Temperature Profile 1000 __ 1. Going in hole to 10400' MD 2. Well Shut-In 2000 --- ---- 3000 4000 ~ 5000 ~ ~ .~ .C ~ y 6000 -- ~ 7000 8000 9000 -- 10000 --- - -- - - 11000 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 0 Mandrel Temperature ~ ~ Marathon Oil Company Alaska i in Domestic ,.-,-oduction RO. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 April 8, 1992 Mr. Lonnie Smith Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Smith: Enclosed are the AOGCC "Report of Sundry Well Operations" for the Spark Platform temporary shutdown. Should you have any questions regarding the report, please contact E. V. Oberts at (907) 564-6436. Sincerely, .L~~C~ Ibel(~%~e~ Operations Engineering Supervisor Attachment \docs\ml\6.doc RECEIVED APR 1 1 t992 Alaska .0il & Gas Cons. (;ommissio~ ~chorag8 A subsidiary of USX Corporation : 0 R i G IN A I. 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 I 5. Type of Well: 6. Datum elevation (DF or KB) I Development X Marathon Oil Company Exploratory__ 115' KB above MSL feet 3. Address I Stratigraphic 7. Unit or Property name P.O. Box 190168 Anchorage, AK 995191 Service__ North Trading Bay Unit 4. Location of well at surface Leg 3 Cond. #5 Spark Platform 8. Wellnumber 2,608' FSL, 2,495' FEL Sec. 26-10N-13W-SM S-1RD At top of productive interval ' 9. Permit nu_mbedapproval number 91-407/P'~,',,, :~-,~ 1,110' FSL, 162' FWL, Sec. 26-10N-13W-SM At effective depth 10. APl number 1,164' FSL, 368' FEL, Sec. 27-10N-13W-SM 5°-733-20158-01 . At total depth 11. Field/Pool 1,170' FSL, 377' FEL~ Sec. 27-10N-13W-SM Trading Bay Hemlock & G 12. Present well condition summary Total depth: measured 11,060 ' feet Plugs (measured) true vertical 10,168' feet None Effective depth: measured 10 9 71 ' feet Junk (measured) true vertical ' feet 10,098' None Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2,802' 13 3/8" 1,900 sx 2,802' 2,792' Intermediate 7,951' 9 5/8" 1,000 sx 7,951' 7,592' Production Liner 3,364' 7" 1,000 sx 11,060' 10,168' Perforation depth: measured See Attachment #1 true vertical Tubing (size, grade, and measured depth) 3-1/2", N-80, 10,069' Packers and SSSV (type and measured depth) FR-1 Packer fa q:qRD': "FMX" 13. Stimulation or cement squeeze summary Intervals treated (measured) TR~V 0 330' RECEIVED APR 1 1 199~ Alaska Oil & Gas Cons. 60mmiSsi0t~ Anchorage Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 104 0 648 1095 o o o o Tubing Pressure 45O 0 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ._X 16. Status of well classification as: Oil x___ Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~-----~ _/~' /c-~p_ ~,., ~, ;i::~:~ Title Operations Form 10-404 Rev 06/15/88 Engineering Supv. Date SUBMIT IN DUPLICATE SPARK PLATFORM WELL S-1RD Daily Summary of Operations 1/15/92 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 tubing pressure to production. 1/27/92 RU to pump down tubing. Casing pressure equals zero psi and tubing pressure equals 100 psi. PT lines to 2000 psi. Pump 108 bbls. filtered inlet water (FIW) down tubing at 3 BPM, 300 psi. Pump 108 bbls FIW treated with corrosion inhibitor down tubing at 3 BPM, 200 psi. RD off tubing and RU to pump down 9-5/8" casing/tubing annulus. Fill annulus to surface with 307 bbls. treated FIW. Monitor TP and CP. TP : 10 psi, CP = 0 psi. Pressures stable. 1/29/92 RU w/reline. PT lubricator to 1500 psi - OK. Run 2.80" gauge ring to 400' (through SCSSV at 330'). Set 'XXR' plug in SCSSV profile at 330'. Bleed TP from 10 psi to atmosphere. RU to pump down 9-5/8" casing/tubing annulus. Fill casing w/ 251 bbls treated FIW. Pump additional 17 bbls at 2 BPM and 470 psi while monitoring TP. No increase in tubing pressure id/caring that plug is holding. CP to 0 psi when stopped pumping. RD pump and w/reline. 1/30/92 through 2/5/92 Monitor TP and CP. Both stable at 0 psi. No pressure buildup. Disconnect gas lift line and flow line. Install blind flanges. 2/22/92 TP = 0 psi. CP = 0 psi. Close all tree valves. FINAL REPORT. \Spark\SIRD.doc RECEIVED APR 1 7 1992 ~Jl & Gas Cons. t~om~'tssio~ ~nchorags FMC "UH-~ ~AEN" Tbg. hgt., 4-[/2" Butt. ~ x b 'X-over 4-1/2" Butt. b x 3-1/2" Butt. p 13-3/8" , 61# J-55 Butt. Casing 2,802' 3-I/2", 9.2# N-80 Butt..Tubing TOL 7,696' 9-5/8", 47# N-80 Butt. Casing 7,951' Baker "FB-I" Pkr. w/ 10' SBE, Bell Guide, 4.00" ID · 9,980' 9,993' Reservoir Datum: 10,739' MD 9,915' TVD 9,800' SS Fill ~7", 29# P-Il0 11,060' utc. Casing N'rBU Well S-iR0 Wellbore Diagram Completed 9/~0/85 330' 2,449 4,064' Otis Series i0 "FMX" TRSV, 3-1/2" Butt. : x b, 2.813" ' Se~: 'Y.>',R' Pi!:c in SCSSV Camco "~G" GLMs w/ 1-1/2" 2.875" ID, 3-1/2" But~. t x #2 5,422' 6,545' #3 ~4 7,459' 8,217' 8,881' - 9,405' 9,860' Camco "KBUG" GLMs w/l" "JR-Std." GLVs & "BK-2" Latches, 2.875" ID, 3-1/2" Butt. ~ x b ~8 #9 9,996' 9,997' Baker "80-40" Loca~or, 3.00" Baker 4.00" x 3.00" Seal Assy. (10' long) Two its. tbg. w/ sp.cl, cplgs 2.99" ID IO,069' Baker Half-cut Mule Shoe 3 0" Perforations {DIL) i0,215' - 10,225' G-I i0,234' - i0,306' 10,334' - 10,359' G-3 ' Deviation ~ 38° 10,378' - 10,423' G-4 lO,4~&' - 10,454' G-5 ' ..', iO,487' - 10,527" H-! 10,539' - 10,579' H-2 10,587' - 10,604' H-2 10,705' - 10,735' H-3 10,751' - 10,801' H-3 i0,971 ' PBT~ < / i,/S2 Attachment #1 S-1RD PERFORATIONS G-Zone G-1 G-2 G-3 G-4 G-5 10,215' _ 10,225' 10,234' _ 10,306' 10,334' - 10,359' 10,378' _ 10,423' 10,444' _ 10,454' 9,505' - 9,513' 9,520' - 9,576' 9,600' - 9,617' 9,633' - 9,667' 9,683' - 9,691' Hemlock H-1 H-2 H-3 10,487' - 10,527' 10,539' - 10,579' 10,587' _ 10,604' 10,705' - 10,735' 10,751' - 10,801' 9,717' - 9,748' 9,757' - 9,790' 9,795' - 9,809' 9,888' - 9,912' 9,924' - 9,964' ~docs~SlRD\spark' doc RECEIVED APR 1 1 1992 Oil & Gas Cons. ~ommissio~ ;Anchorage Marathon Oil Company W, Wats¢~'''''' Productir., .anager Alaska Region Domestic Production P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 December 17, 1991 Mr. D. W. Johnston Head Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: RE: SPARK PLATFORM This letter requests the Alaska Oil and Gas Conservation Commission (AOGCC) to approve Marathon Oil Company's plan to temporarily shutdown production from the Spark Platform beginning January 1, 1992. Production from the Spark Platform has been uneconomic over the past few years and we do not expect this to change in the foreseeable future given the trends in oil prices. Marathon forecasts that production from Spark Platform will recommence in 1994-1996 from gas bearing intervals above the current oil productive reservoirs. The timing and whether we recommence oil production will be dependent on the economics at that time. Attached are "Application for Sundry Approvals" for all wells on the Spark Platform along with the well schematics and well securing procedures. One mechanical barrier will be the SCSSV. We will notify you when we plan to test them so a representative of the AOGCC can witness the test. All facility topsides equipment will be shutdown, drained, and mothballed with the exception of power generation for lighting, navigational aids and cathodic protection. Fire and gas detection and suppression systems will also remain operational. Marathon plans to periodically visit the platform to inspect the status of all operational systems and the wells. Your expeditious action on this request is appreciated. Sincerely, W. Watson Alaska Region Production Manager ROM/it/OS15/506 RECEIVED DEC 1 ? 1991 Alaska Oil & Gas Cons. Commission Anchorage A subsidiary of USX Corporation * '~ STATE OF ALASKA ~ ALAo,,A OIL AND GAS CONSERVATION COMMIS~,,JN - APPLICATION FOR SUNDRY APPROVALS : ~ 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well -- Change approved program __ Operation shutdown __ Re-enter suspended well __ Plugging __ Time extens,on __ Stimulate __ Pull tubing ~ Variance __ Pedorate __ Other 2. Name of Operator 3. Address P.O. Box 190168 4. Location of well at surface 2,608' FSL 2.495' At top of productive in{erval 1,110' FSL, 162' At effective depth 1,164' FSL, 368' At total depth 1,170' FNL, 377' 12. Present well condition summary Total depth: measured true vertical 5. Type of Well: Development X__ Exploratory __ Stratigraphic __ Anchorage. AK 9951 ~ Service~ Leg 3 Cond. #5 Spark Platform FEL, Sec. 26-10N-13W-SM FWL, Sec. 26-10N-13W-SM FEL, Sec. 27-10N-13W-SM FEL, Sec. 27-10N.-lSW-$M 11,060' feet 10,168' feet Plugs (measured) 6. Datum elevation (DF or KB) 1 11:;' ER ~k~,"- M~I North Tradinn Ray Ilni'l' 8. Well number S-1RD 9. Permit number 74-5 10. APl number 50-- , 733-201_58-01 11. Field/Pool Trading B~y Hemlock & G None feet Effective depth: measured true vertical Casing Length Structural Conductor Surface 2,802' Intermediate 7,951' Production Liner 3,364' Perforation depth: measured See Attachment #1 true vertical 10,971' feet 10,098' feet Size Junk (measured) Cemented None Measured depth True vertical depth 13 3/8" 1,900 sx 2,802' 2,792' 9 5/8" 1,000 sx 7,951' 7,592' 7" 1,000 sx 11,060' 10,168' RECEIVED Tubing (size, grade, and measured depth) 3-1/2", N-80, 10,069' Packers and SSSV (type and measured depth) DEC 1 ? 1991 Alaska 0il & Gas Cons. 60mm%s¢Ot~ Anchorage 13. Attachments 1, 2, Description summary of proposal x Detailed operations program __ &3 14. Estimated date for commencing operation ~ 15. Status of well classification as: January 2, 1992 16. If proposal was verbally approved Oil S..]I Gas __ Suspended __ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed --~'~ TitleOperations Engineering Superv. Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness i Approval No. Plug integrity __ BOP Test __ Location clearance __ Appro,~ed Oo~¥ I Mechanical Integrity Test __ Subsequent form required 10- ~¢',~..- F,,eturned ~ BOP sketch Approved by order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner F°rmlO'403RevO~/~8C. ~'.'][? "~ ~, SUBMIT IN TRIPLICATE Attachment #1 S-1RD PERFORATIONS G-Zone G-1 G-2 G-3 G-4 G-5 M_go 10,215' - 10,225' 10,234' - 10,306' 10,334'- 10,359' 10,378' - 10,423' 10,444'- 10,454' TV__~O 9,505' - 9,513' 9,520' - 9,576' 9,600' - 9,61Z' 9,633' - 9,667' 9,683' - 9,691' Hemlock H-1 H-2 H-2 H-3 H-3 10,487' . 10,527' 10,539' - 10,579' 10,587' . 10,604' 10,705' . 10,735' 10,751, - 10,801, Tv__~o 9,717' - 9,748' 9,757' - 9,790' 9,795' - 9,809' 9,888' - 9,912' 9,924' - 9,964' \docs\S1RD\spark. doc RECEIVED DEC 1 ? lggl Alaska Oil & Gas Cons. Commissior~ Anchorage Attachment #2 \ SPARK PLATFORM WELL S-1RD WELL SECURING PROCEDURE 1. Hold safety/operational meeting. 2. 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. 5. 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. 7. 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. 8. 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 DEC 1 ? 1991 Alaska Oil & Gas Cons. ~ommiss'mt~ Anchorage FMC "UH-TC-IAEN" Tbg. hgt., 4-1/2" Butt. t x b -X-over 4-I/2" Butt. b x 3-1/2" Butt. p 13-3/8" , 61# J-55 Butt. Casing 2,802' 3-1/2", 9.2f! N-80 · Butt..Tubing TOL 7,696' 9-5/8", 47# N-80 Butt. Casing 7,951' Baker "FB-I" Pkr. 9,98Q' w/ 10' SBE, Bell 9,993' DI]__ Guide, 4.00" ID - Attachment~:"'~o · , , 330' 2,449 4,064' 5,422' 6,545' 7,459' 8,217' 8,881' 9,405' 9,860' 9,996' 9,997' 5park rla~torm NTBU Well S-IRD Wellbore Diagram Co~p£eted 9/10/85 Otis Series 10 "FMX" TRSV, 3-l/2" Butt. t x b, Z.813" I." Camco "MHG" GLMs w/ I-1/2" ~:/:,~.~."VR-Std." GLVs & "RK" latches 2,875" ID, 3-1/2" Butt. t x ~ #2 #3 #4 #5 Camco "KBUG" GLMs w/l" "JR-Std." GLVs & "BK-2" Latches, 2.875" ID, 3-1/2" Butt. t x b .. #8 #9 Baker "80-40" Locator, 3.00" Baker 4.00" x 3.00" Seal Assy. (10' long) Two its. tbg. w/ sp.ci, cplgs 2.99" ID · . Reservoir Datum: 10,739' MD 9,915' TVD 9,800' SS RECEIVED DEC 1 ? 1991 Alaska Oil & ~as Cons. t, ommissm~" ~7", 29# P~'IIO Anchorage o,,~t. Casing 11,76o' / 10,069' Baker Half-cut Mule Shoe 3.0" Perforations (DIL) 10,215' - 10,225' G-1 10,234' - i0,306' G-2 10,334' - 10,359' G-3 10,378' - 10,423' G-4 Deviation = 38° 10,444' -. 10,454' G-5 ' 10,487' - 10,527" H-I 10,539' - 10,579' H-2 10,587' - 10,604' H-2 10,705' - 10,735' H-3 10,751' - 10,801' H-3 10,971' PBTD HRO/NEF Revised 7/88 [ ~THON OIL C0~ N0~ ~G BAY EXHIBIT 2 ~ , - ROY~ R~UCTION ] , , , ~~t'19~~ .... ~-~5 ~ma /~ / RECEIVtU - ' I I' DEC 1 ? 1991 Alaska Oil & Gas Cons. Comm'tss~'ov~ Anchorage Marathon Oil Company Ala~,~.~., ,on Domestic Production RO. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 October 3, 1989 Alaska Oil & Gas Conservation 3001 Porcupine Dr. Anchorage, AK 99501 Commission Dear Mr. Chatterton: Attached for your approval is an "Application for Sundry Approvals" appropriate attachments for Spark Platform Well~IRD. Should you have any questions regarding any application or report, please contact me at (907) 561-5311. Sincerely, D. K. Corlett District Operations Engineer Attachment em\docs\m1\6 with Rrc.o OCt o 9 l~jp~cj Alasi<a 0il & Gas Cons. Commissio~ AnChorage A subsidiary of USX Corporation ~' STATE OF ALASKA ~LASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS IG IN AL 1. Type of Request: Abandon i Suspend __ Alter casing __ Repair well Change approved program __ Operation shutdown __ Re-enter suspended well ~ Plugging ~ Time extension ~ Stimulate __ Pull tubing ~ Variance __ Perforate ~ Other 5. Type of Well: Development X_~ Exploratory __ Stratigraphic Service 2. Name of Operator / Marathon 0i ! 3. Address ..... r .... ., P.O. Box lg0168 Anchorage; AK 9951 4. Location of well at surface Leg 3 Cond. ' 2 ' 2.608 FSL, ,495 At top df proi:lucbve mterva~ #5 Spark Platform 1,110' FSL 162' At effective depth 1,164' FSL, 368' At total depth 1,170' FNL, 377' 12. Present well condition summary Total depth: measured true vertical FEL, Sec. 26-10N-13W-SM FWL, Sec. 26-10N-13W-SM FEL, Sec. 27-10N-13W-SM 6. Datum elevation (DF or KB) 1!51 KB abnv~ MSL 7. Unit or Property name North Trading Bay 8. Well number S-1RD 9. Permit number 74-5 10. APl number 5o-733-20158-01 11. Field/Pool FEL, Sec. 27-10N-13W-SM 11,060' feet 10,168' feet Plugs (measured) feet Unit Trading Bay Hemlock & G None Effective depth: measured true vertical Casing Length Structural Conductor Surface 2,802' Intermediate 7,951 ' Production Liner 3,664' Perforation depth: measured See Attachment #1 true vertical 10,971' feet 10,098' feet Size 13 3/8" 9 5/8" 11 Junk (measured) Cemented 1,900 sx 1,000 sx 1,000 sx None Measured depth 2,802' 7,951' 11,060' True vertical depth 2,792' 7,592' 10,168' RECEIVED Tubing (size, grade, and measured depth) 3-1/2", N-80, 10,069' Packers and SSSV (type and measured depth) FB-1 Packer 0 9,980', "FMX" TRSV 0 330' 13. Attachments 2 & 3 Description summary of proposal _X_ OCT o 9 ]989 Alaska 0ii & Gas Cons. C0mmissi0r~ Anchorage Detailed operations program ~ BOP sketch x 14. Estimated date for commencing_operation 15. Status of well classification as: October 15, 1989 16. If proposal was verbally approved Oil ~ Gas __ Suspended Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of m,~ knowledge. Signed /.~) ~C0'7/.L ~ Title Di strict Operations Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Date J Approval No. ?_.. 9~.~ Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- /~ ~'" ORIGINAL SIGNED BY LONNIE C. SMITH Approved by order of the Commission ¢~,pp~oveC~ CoPY Retur~ed,~ Commissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment #1 S-1RD PERFORATIONS G-Zone G-1 G-2 G-3 G-4 G-5 MD 10,215' - 10,225' 10,234' - 10,306' 10,334' - 10,359' 10,378' - 10,423' 10,444' - 10,454' TVD 9,505' - 9,513' 9,520' - 9,576' 9,600' - 9,617' 9,633' - 9,667' 9,683' - 9,691' Hem 1 oc k H-1 H-2 H-2 H-3 H-3 MD 10,486' - 10,527' 10,539' - 10,579' 10,587' - 10,604' 10,705' - 10,735' 10,751' - 10,801' TVD 9,717' - 9,748' 9,757' - 9,790' 9,795' - 9,809' 9,888' - 9,912' 9,924' - 9,964' docs\SlRD\spark, doc Attachment #2 Well S-1RD Reperforation Procedure · 2. 3. 4. 5. 6. · · 9. Note: RU wireline unit. PT to 2500 psi. RIH w/ 2.7" scale cutter, cut scale, and tag fill. POH. RD. If heavy scale was cut, flow well for one hour to clean up. RU E-line. PT to 2500 psi. R~H w/ CCL, sinker bar, magnetic decentralizer, and 2-1/8" strip guns 0 0v phasing (30 off low end), 4 SPF. Perforate underbalanced by flowing well: G-2 10,246' - 10,306' DIL 60' POH. RD E-line. ~docs\Spark\SlRD Return well to production and test. Anticipated SBHP is 3000 psig. Wireline Attachment #3 SPARK PLATFL, n.~i' Lubricator w/Associated BOPE ~GREASE HEAD (Hydraulically Activated) LUBRICATOR MANUALLY OPERATED BOP ., PUMP IN SUB. SINGLE. COMPLETION GATE VALVE Marathon Oil Company Alaska I on Domestic Production P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 December 5, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed is the AOGCC "Report of Sundry Well Operations" with attachments for Spark Platform Well S-1 and S-9. Should you have any questions regarding the report, please contact me at (907) 561-5311. Sincerely, D. K. Corlett District Operations Engineer Attachment DKC/em/6/ml A subsidiary of USX Corporation STATE OF ALASKA ALA~ , OIL AND GAS CONSERVATION COMMIS~,~,q REPORT OF SUNDRY WELL OPERATIONS 1. OpeCations performed: Operation shutdown __ Stimulate x_._ Plugging __ Pull tubing __ Alter casing __ Repair well __ 2. Name of Operator : I 5. Type of Well: ' Marathon Oil Company i Development x ~ Exploratory __ 3. Address / Stratigraphic_ P. O. Box 190168 Anchorage, AK 9~.519~ Service__ 4. Location of well at surface ' Leg 3, Cond. ~;5, ~park ~iatfu~u, 2,608' FSL, 2,495' FEL, Sec. 26 10N-13W-SM At top of productive interval 1,110' FSL, 162' FWL, Sec. 26, 10N-13W-SM At effective depth 1,164' FSL, 368' FEL, Sec. 27, 10N-13W-SM At total depth 1,170' FSL, 377' FEL, Sec. 27, 10N-13W-SM perf°rate __ Pull tubing __ Other 6. Datum elevation (DF or KB) 115 KB above MSL feet 7. Unit or Property name North Trading Bay Unit 8s_W~l~)um her 9. Permit number/approval number 8-525 10. APl number 50~33-20158-01 11. Field/Pool Trading Bay Hemlock & "G" 12. Present well condition summary Total depth: measured true vertical 11,060' feet 10,168' feet Plugs (measured) None Effective depth: measured true vertical 10,971' feet 10,098 ' feet Junk (measured) None Casing Structural Length Size Conductor Surface Intermediate 2,802' 13 3/8" Production Liner Perforation depth: 9,751' 9 5/8" 3,664' 7" measured See Attachment #1 truevertical Cemented Measured depth True vertical depth 1,900 sx 2,802' 2,792' 1,000 sx 9,751' 9,142' 1,000 sx 11,060' 10,168' RECEIVED ~bing(size, grade, andmeasumdde~h) 3 1/2", N-80, @ 10,069' Pac~mandSSSV~ypeandmeasumddepth) FB-1 Packer @ 9,980' "FMX" TRSV @ 330' Oil & Gas Cons. Commission '~i'. ~mh0rago 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment ~2 "Daily Summary of Operations" 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 9/27/88 84 1336 1020 100 Subsequent to operation 11/01/88 64 1931 1080 15. Attachment~ ¢/2 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations ~ Oil _._.x Gas __ Suspended ~ 17. I hereby certify that the foregoing is true and correct t° the best of my knowledge. i Signed ~/~g~z~ ~~ TitleDistrict Service Operations Engineer 105 Date Form 10-404 Rev 06/15188 SUBMIT IN DUPLICATE G-Zone G-1 G-2 G-3 G-4 G-5 Hemlock H-1 H-2 H-2 H-3 H-3 Attachment #1 S-1RD Perforations 10,215' - 10,225' 10,234' - 10,306' 10,334' - 10,359' 10,378' - 10,423' 10,444' - 10,454' TVD 9,505' - 9,513' 9,520' - 9,576' 9,600' - 9,617' 9,633' - 9,667' 9,683' - 9,691' 10,486' - 10,527' 10,539' - 10,579' 10,587' - 10,604' 10,705' - 10,735' 10,751' - 10,801' 9,717' - 9,748' 9,757' - 9,790' 9,795' - 9,809' 9,888' - 9,912' 9,924' - 9,964' MDC/em/44A/Spark Attachment #2 NTBU Well S-1RD Daily Summary of Operations 10121188 RU CTU, PT equip. OK. Fill CT w/ FIW and RIH w/ 2-3/8" Navidrill w/ 2.70" diamond bit injecting 1/4 B?M @ 1700 psi to 8000' CTM. No sign of scale and no problems getting through SSSV or mandrels. 10/22/88 Tag fill w/ 2.70" bit and Navidrill. Increase pump rate to 3/4 BPM @ 3800 psi. Mill scale to 9000'. Circulate 1BPM @ 3800 psi for 45 min. Mill scale to 9800'. POOH to inspect Navidrill. RIH w/ new 2-3/8" Navidrill w/ same 2.70" diamond bit. 10/23/88 RIH pumping 1BPM @ 3600 psi and tag @ 9583'. Mill scale to 9741' and tag restriction. Mill through restriction and down to 10,100' CTM. Circulate out scale and POOH. Displace CT w/ diesel. RD CTU and put well in test. lO/28/88 RU pumping unit, lines, and PT, OK. Pump 50 bbl FIW and establish injection rate of 1BPM @ 1300 psi. Pressure dropped to 280 psi @ 2 BPM, well taking fluid. Csg press. = 1130 psi. Mix 1 bbl 194/4 w/ 49 bbl FIW. Pump 50 bbls of mix @ 2 BPM, injection press. = 270 psi, casing press. = 980 psi. Mix 13 bbls ESL 19P and 237 bbls FIW. Pump 25 bbls FIW as spacer, 2 BPM @ 270 psi. Pumped ESL mix @ 3 BPM, 80 psi injection press., casing press. = 960 psi. Final injection pressure = 300 psi, casing press. = 950 psi. Displaced ESL treatment 5' into formation w/ FIW. Pumped 550 bbls FIW @ 2.5-3 BPM, injection press, increasing from 300 to 400 psi, casing press, increasing from 940 to 1020 psi. RD. Leave well S.I. for 24 hours then bring well on slowly. 44A/Spark Marathon Oil Company July 1, 1988 Alaska R 1 Domestic ~-,oduction P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: Attached for your approval is the Application for Sundry Approval for Spark Platform Wells S-1RD and S-9. Should you have any questions regarding any application or report, please contact me at (907) 561-5311. Sincerely, D. K. Corlett District Operations Engineer Attachment DKC/em/6/M1 RECEIVED Alaska .Oil & ~as Cons. Commission 'Anchorage A subsidiary of USX Corporation STATE Of ALASKA ALASKa, ,.)IL AND GAS CONSERVATION COMM~oSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [~ Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator Marathon Oil Company 3. Address P. O. Box 190168 Anchorage, AK 99519 4. Location of well at surface Leg 3, Cond. #b, :spark ~.l. atform 2,608' FSL, 2,495' FEL, Sec. 26 10N-13W-SM 5. Datum elevation (DF or KB) 115 [C~ above MSL feet 6. Unit or Property name North Trading Bay Unit 7. Well number S- 1RD 8. Permit number 74-5 9. APl number 50-- 733-20158-01 At top of productive interval 1,110' FSL, 162' FWL, Sec. 26, At effective depth 1,164' FSL, 368' FEL, Sec. 27, At total depth 1,170' FSL, 377' FEL, Sec. 27, 10N-13W-SM 10N-13W-SM 10N-13W-SM 10. Pool 'Trading Bay Hemlock & "G"! 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11,060' 10,168' 10,971' 10,098' feet feet feet feet Plugs (measured) Junk (measured) None None Casing Length Size Structural Conductor Surface 2,802' 13 3/8" Intermediate Production 9,751' 9 5/8" Liner 3,664' 7" Perforation depth: measured See Attachment #1 true vertical Cemented Measured depth True Vertical depth 1,900 sx 2,802' 2,792' 1,000 sx 9,751' 9,142' 1,000 sx 11,060' 10,168' ~bing(size, grade and measured depth) 3 1/2", N-80, @ 10,069' Packers and SSSV(type and measured depth) FB-1 Packer @ 9,980' "FMX" TRSV @ 330' 12.Attachments 2 & 3 R .CEIVED Description summary of proposal Alaska Oit & Gas Cons. Commission , Anch0ra~,e Detailed operations program [] BOP sketch 13. Estimated date for commencing operation July 1988 14. If proposal was verbally approved Name of approver Subsequent Wor]~ Reported on /' Form No. ~Q.~ Dated a/--.~/~J'~ Date approved 15. I hereb~ certify that,the foregoing is true and correct to the best of my knowledge Title District Operations Engineer Commission Use Only Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test Approved by .,ItGINAL SIGNED 6Y LONNIE C. SMITH Form 10-403 Rev 12-1-85 Date [] Location clearance Approved Copy Returned ! Commissioner IApproval No. F" ~"m .%"-- by order of the commission Date Submit in triplicate G-Zone G-1 G-2 G-3 G-4 G-5 Hemlock H-1 H-2 H-3 H-3 Attachment #1 S-1RD Perforations 10,215' - 10,225' 10,234' - 10,306' 10,330' - 10,359' 10,378' - 10,423' 10,444' - 10,454' TVD 9,505' - 9,513' 9,520' - 9,576' 9,598' - 9,617' 9,632' - 9,667' 9,683' - 9,691' 10,486' - 10,527' 10,539' - 10,604' 10,705' - 10,735' 10,751' - 10,801' 9,717' - 9,748' 9,757' - 9,809' 9,888' - 9,912' 9,924' - 9,964' R[CEiVED Alaska Oil & Gas Cons. Commission Anc,horaQe MDC/em/44/Sundry , Attachment #1 · Well S-1RD Scale Cleanout and Inhibitor Treatment Procedure 1. SI de-emulsifier & scale inhibitor to gas lift five days prior to work. Notify GPPF 24 hours prior to shipping polymer. 2. RU Otis CTU, filter pumping units, and tanks. 3. PT CT to 5000 psi. 4. Lock open safety valve by closing needle valve. Connect two pen recorder and monitor pressure throughout job. Do not allow pressure to get lower than the valve's closing pressure. 5. RIH with 2.7" bit with 2-3/8" Navidrill. 6. Establish circulation with FIW. Continue producing well with gas lift. If unable to inject at a rate greater than 1BBL/MIN or unable to get returns to surface, add 10-20# of polymer/1000 gal FIW. 7. Work 2.7" bit down through tubing tail. 8. POH. RIH with 2.7" gauge on wireline. Tag bottom. 9. Rework any tight spots w/2.7" bit followed by 2.7" gauge. 10. POH. RD Otis. 11. SI well for 24 hours. 12. RU Dowell pumping equipment to S-1RD tree. 13. PT surface equipment to 5000 psi. 14. Pump treatment as follows: Alzska 0~, & (~as Cons. Oommiss[or~ Ar~choraga Stage 1. 50 BBL FIW (establish injection rate) Stage 2. 52 BBL FIW with 2.5% phosphonate preflush (55 gal. Scaletreat 194/4) Stage 3. 25 BBL FIW (Spacer) Stage 4. 370 BBL FIW with 5% inhibitor (770 gal. Scaletreat ESL 19P) Stage 5. 550 BBL FIW overflush Treatment to be pumped at 2 BPM, if possible. Surface pressures to be kept below 3000 psi to avoid fracturing the reservoir. 15. RD Dowell and shut in S-1RD for 24 hours. 16. Bring well on slowly to test. Start lift gas at lowest rate necessary to lift well. Then work up to a full lift gas rate of 3.1MMSCFD over a 24 hour period. After 24 hours adjust rate accordingly. 17. A Western Wellchems engineer will take fluid samples hourly for the first 24 hours to monitor inhibitor residuals. Two to four samples will be taken for the remainder of the week. After one week, samples will be taken once a month and sent to Wayne Cissell. 18. Gauge ring's will be run every 2-3 months to monitor inhibitor effectiveness. MRO/44/Spark Attachment #3 SPARK PLATFOR.., Coiled Tubing Lubricator w/Associated BOPE TO INJECTION HEAD DOUBLE BOP w/1 1/4' Rams 5000 psi WP HYDRAULIC RAMS LUBRICATOR SINGLE COMPLETION GATE VALVE ' RECEIVED j tj L - 5 1988 ^]S$k~t 0it & Gas Cons, Commission Anchorage Marathon Oil Company Alaska R ~ Domestic , .oduction P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 Apri] 1.1, .1988 Alaska Oil & Gas Conservation. Commission 3001 Porcup:i.ne Dr. A..p. chorage, AK 99501 Dear Mr. Chatterton: Attached is the AOGCC Report of Sundry W~ll Operations for Beaver Creek Well BC-5RD and Should you have any questions regarding any application or report, please contact me at (907) 561-5311. Sincerely, D. K. Cor]_ett District Operations Engineer At t achment DKC/em/6/M1 A subsidiary of USX Corporation ~-"'" STATE OF ALASKA ALAS~r,., JIL AND GAS CONSERVATION COMN,.o,51ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing [] Alter Casing [] Other [] 2. Name of Operator Marathon Oil Company 3. Address P. O. Box 190168 Anchorage, AK 99519 4. Location of well at surface Leg 3, Cond. #5, Spark Flat~-orm 2,608' FSL, 2,495' FEL, Sec. 26 iON-13W-SM 5. Datum elevation (DF or KB) 115 KB above MSL Feet 6. Unit or Property name North Trading Bay Unit 7. Well number S-1RD 8. Approval number 8-160 9. APl number 50-- 733-20158-01 At top of productive interval 1,110' FSL, 162' FWL, Sec. 26, At effective depth 1,164' FSL, 368' FEL, Sec. 27, At total depth 1,170' FSL, 377' FEL, Sec. 27, 10N-13W-SM 10N-13W-SM 10N-13W-SM 10. Pool Trading Bay Hemlock & "G" 11. Present well condition summary Total depth: measured true vertical 11,060' 10,168' Effective depth: measured 10,971 ' true vertical 10,098' Casing Length Size Structural Conductor Surface 2,802' 13 3/8" Intermediate Production Liner 9,751' 9 5/8" 3,664' 7" Perforation depth: measured See Attachment #1 true vertical feet feet feet feet Plugs (measured) None Junk (measured) None Cemented Measured depth True Vertical depth 1,900 sx 2,802' 1,000 sx 9,751' 1,000 sx 11,060' 2,792' 9,142' 10,168' Tubing(size, grade and measured depth) 3 1/2", N-80, @ 10,069' Packers and SSSV(type and measured depth) FB-1 Packer @ 9,980' "FMX" TRSV @ 330' RECEIVED 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Alaska Oil & 6as Cons. Commissior Anchorage 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 3/15/88 60 0 435 970 psi Subsequent to operation 4/05/88 131 0 1193 980 psi ~bing Pressure 70 psi 120 psi 14. Attachment~ #2 Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed District Operations Engineer Title Form 10-404 Rev. 124-85 Submit in Duplicate G-4 }{-2 }{-3 H-3 10,215 ' 10,234' 10,330' 10,374' 10,444 ' 10,486' 10,539' 10,705' 10,751 ' Attachment #1 - 10,225, - 10,306, - 10,359, - 10,423, - 10,454, TVD 9,505' _ 9,513' 9,520' _ 9,576' 9,$98' - 9,617' 9,631' - 9,667' 9,683' _ 9,69I' - 10,527' - 10,604' - 10,735' I0,801 ' 9,717' - 9,748' 9,757' _ 9,809' 9,888' - 9,912' 9,924 ' - 9,964 ' MDC lem144A/ Sundry RECEIVED Alaska Oil & Gas Cons, Commissior, Anchorage Attachment #2 Daily Report of Operations Spark Well S-1RD 3/16/88 RU E-line and PT to 2250 psi. OK. RIH w/CCL, sinker bar, 2-1/8" Silver Jet, 4 SPF, 45° phasing, 16 gm charge perf guns to 10,607' DIL. Correlate and with well flowing perforate Bench 2 from 10,538' - 10,552'. POOH, RD and put well in test. 3/17/88 RU E-line and PT to 2250 psi. OK. RIH w/CCL, sinker bar, 2-1/8" Silver Jet, 4 SPF, 25° phasing, 16 gm charge perf guns. With well flowing, correlate and perforate Bench 2 from 10,538' - 10,552' DIL. POOH, RD, and bring well on slowly and put in test. 3/18/88 RU E-line, PT to 2500 psi. OK. RIH w/CCL, sinker bar, 2-1/8" Silver Jet, 4 SPF, 45° phasing perf guns. Correlate and perforate H-1 from 10,490' - 10,504' and G-4 from I0,374' to 10,384'. POOH. MU new perfs guns as above, RIH and perforate G-3 from 10,330' - 10,340' and G-2 from 10,244' - 10,262'. POOH, RD, place well on production. 44A/Sundry ~ STATE OF ALASKA ALA OIL AND GAS CONSERVATION CO~~' .~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~3 Pull tubing [] Alter Casing [] Other [] 2. Name of Operator M~rathon Oil Company 3. Address P. O. Box 190168 Anchorage, AK 99519 4. Location of well at surface Leg 3, Cond. ~5, Spark. t-'latt'orm 2,608' FSL, 2,495' FEL, Sec. 26 10N-13W-SM At top of productive interval 1,110' FSL, 162' FWL, Sec. 26, 10N-13W-SM At effective depth 1,164' FSL, 368' FEL, Sec. 27, 10N-13W-SM At total depth 1,170' FSL, 377' FEL, Sec. 27, 10N-13W-SM- 5. Datum elevation (DF or KB) 115 KB above MSL Feet 6. Unit or Property name North Trading Bay Unit 7. Well number S- ll:~D 8. Approval number 8-160 9. APl number 50-- 733-20158-01 10. Pool Trading Bay Hemlock & "G" 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface 2,802' Intermediate Production 9,751' Liner 3,664' Perforation depth: measured See Attachment #1 true vertical 11,060' feet Plugs (measured) None 10,168' feet 10,971 ' feet Junk (measured) None 10,098 ' feet Size Cemented Measured depth 13 3/8" 1,900 sx 2,802' 9 5/8" 1,000 sx 9,751' 7" 1,000 sx 11,060' True Vertical depth 2,792' 9,142' 10,168' Tubing(size, grade and measured depth) 3 1/2", N-80, @ 10,069' Packers and SSSV(type and measured depth) FB-1 Packer @ 9,980' "FMX" TRSV @ 330' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 3/15/88 60 0 435 970 psi 70 psi Subsequent to operation 4/05/88 131 0 1193 980 psi 120 psi 14. Attachments #2 Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed District Operations Engineer Title Date. 5~'/~/~ Form 10-404 Rev. 12-1-85 Submit in Duplicate G-Zone G-1 G-2 G-3 G-4 G-5 Hemlock H-1 H-2 H-3 H-3 Attachment #1 S-1RD Perforations 10,215' - 10,225' 10,234' - 10,306' 10,330' - 10,359' 10,374' - 10,423' 10,444' - 10,454' 10'486' - 10,527' 10,539' - 10,604' 10,705' - 10,735' 10,751' - 10,801' TVD 9,505' - 9,513' 9,520' - 9,576' 9,598' - 9,617' 9,631' - 9,667' 9,683' - 9,691' 9,717' - 9,748' 9,757' - 9,809' 9,888' - 9,912' 9,924' - 9,964' MDC/em/44A/Sundry Attachment #2 Daily Report of Operations Spark Well S-1RD 3/16/88 RU E-line and PT to 2250 psi. OK. RIH w/CCL, sinker bar, 2-1/8" Silver Jet, 4 SPF, 45° phasing, 16 gm charge perf guns to 10,607' DIL. Correlate and with well flowing perforate Bench 2 from 10,538' - 10,552'. POOH, RD and put well in test. 3/17/88 RU E-line and PT to 2250 psi. OK. RIH w/CCL, sinker bar, 2-1/8" Silver Jet, 4 SPF, 25° phasing, 16 gm charge perf guns. With well flowing, correlate and perforate Bench 2 from 10,538' - 10,552' DIL. POOH, RD, and bring well on slowly and put in test. 3/18/88 RU E-line, PT to 2500 psi. OK. RIH w/CCL, sinker bar, 2-1/8" Silver Jet, 4 SPF, 45~ phasing perf guns. Correlate and perforate H-1 from 10,490' - 10,504' and G-4 from 10,374' to 10,384'. POOH. MU new perfs guns as above, RIH and perforate G-3 from 10,330' - 10,340' and G-2 from 10,244' - 10,262'. POOH, RD, place well on production. 44A/Sundry ~--. ~ ' STATE Of ALASKA ~ ALASKk ..~IL AND GAS CONSERVATION COMN.._dlON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate ~ Other [] 2. Name of Operator Marathon Oil Company 3. Address P. O. Box 190168 Anchorage, AK 99519 4. Location of well at surface Leg 3, Cond. #5, Spark Platform 2,608' FSL, 2,495' FEL, Sec. 26 10N-13W-SM At top of productive interval 1,110' FSL, 162' FWL, Sec. 26, 10N-13W-SM At effective depth 1,164' FSL, 368' FEL, Sec. 27, 10N-13W-SM At total depth 1,170' FSL, 377' FEL, Sec. 27, 10N-13W-SM 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 5, Datum elevation (DF or KB) 115 KB above MSL feet 6. Unit or Property name North Trading Bay Unit 7. Well number S- 1RD 8. Permit number 74-5 9. APl number 50-- 733-20158-01 Casing Length Structural 10. Pool Trading Bay Hemlock & "G" Conductor Surface 2,802' Intermediate Production Liner 9,751' 3,664' Perforation depth: measured See Attachment #1 true vertical 11,060' feet Plugs (measured) None 10,168' feet 10,971 ' feet Junk (measured) None 10,098' feet Size Cemented Measured depth 13 3/8" 1,900 sx 2,802' 9 5/8" 1,000 sx 9,751' 7" 1,000 sx 11,060' ~bing(size, grade and measured depth) 3 1/2", N-80, @ 10,069' Packers and SSSV(type and measured depth) FB-1 Packer @ 9,980' "FMX" TRS¥ @ 330' True Vertical depth 2,792' 9,142' 10,168' RECEIVE.I) Alaska 0il & Gas Cons. /~chorago 12.Attachmentg #2 Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation March 1988 14. If proposal was verbally approved Name of approver Date approved 15. I hereby, certify that t~e foregoing is true and correct to the best of my knowledge /I--.,. ,, ,/ Signed ~1<C¢,¢~~ Title District Operations Engineer Conditions of approval ORIGINAL SIGNED BY ' LONNIE C. SMITH Approved by Date Commission Use Only Form 10-403 Rev 12-1-85 Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved Copy Returned~ ., Commissioner J Approval No. C<:;;~ ._/ ~ by order of the commission Date Submit in triplicatV ATTACI{MENT #1 G-! TV1) G-2 10,215, _ 10,225, G-3 10,234, _ 10,306, 9,505' _ 9,513' 0-4 10,330, _ 10,359, 9,520' _ 9,576, G-5 10,378, _ 10,423, 9,598, _ 9,617, 10,444, _ 10,454, 9,632' _ 9,667' ~ 9,683' _ 9,691' //-1 //-2 //-3 10,486, _ 10,527, 10,539, _ 10,604, 9,717, 10,705' - 10,735, 9,757' 9,888 ' 10,751, _ 10,801' //-3 9,924 ' - 9,748' - 9,809' - 9,912' - 9,964' ~DC /em/44 /Sunary RECEIYEO 0il & G~s Corts. Commiss[c:, Anchorage Attachment # 2 Spark Platform Well S-1RD Reperforation 1. RU wireline unit. PT to 2,500 psi. 2. RIH w/2.5" GR, chip scale through tubing tail and tag bottom. 3. Work up to a 2.7" GR, if possible. 4. POH. RD. 5. RU E-line. PT to 2,500 psi. 6. RIH w/ 2-1/8" strip guns @ 45° phasing. 7. Perforate the following intervals underbalance: G-2 10,244' - 10,262' 18' G-3 10,332' - 10,336' 4' G-4 10,374' - 10,384' 10' H-1 10,490' - 10,504' 14' H-2 Test Well for 24 hrs. 10,535' - 10,552' 14' 8. RD E-line. 9. Turn well over to operator. em/MRO/44/Sundry .,~--"- STATE Of ALASKA -~'"~ ALAS Oil AND GAS CONSERVATION CON, .~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 ofwellatsurface Leg 3, Cond. #), 5park vlatfofm 2,608' FSL, 2,495' FEL, Sec. 26 10N-13W-SM 5. Datum elevation (DF or KB) 115 KB above MSL Feet 6. Unit or Property name North Trading Bay Unit 7. Well number S- 1RD 8. Approval number 523 9. APl number 50-- 733-20158-01 At top of productive interval 1,110' FSL, 162' FWL, Sec. 26, At effective depth 1,164' FSL, 368' FEL, Sec. 27, At total depth 1,170' FSL, 377' FEL, Sec. 27, 10N-13W-SM 10N-13W-SM 10N-13W-SM 10. Pool Trading Bay Hemlock & "G" 11. Present well condition summary Total depth: measured true vertical 11,060' 10,168' Effective depth: measured 10,971~ true vertical 10,098' Casing Length Size Structural Conductor Surface 2,802' 13 3/8" Intermediate Production 9,751' 9 5/8" Liner 3,664' 7" Perforation depth: measured See Attachment #1 true vertical feet feet feet feet Plugs (measured) None Junk (measured) None Cemented Measured depth ~ue Verticaldepth 1,900 sx 2,802' 2,792' 1,000 sx 9,751' 9,142' 1,000 sx 11,060' 10,168' ~bing(size, grade and measured depth) 3 1/2", N-80, @ 10,069' Packers and SSSV(type and measured depth) FB-1 Packer @ 9,980' "FMX" TRSV @ 330' RECEIVED DEC - 5 1986 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Alaska Oil & Gas Cons. Commission Anchorage 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 10/27/86 264 47 835 Subsequent to operation 11/5/86 331 82 1046 940 psig 950 psig Tubing Pressure 70 psig 110 psig 14. Attachments: #2 Daily Report of Well Operations ~ Copies of Logs and Surveys.,') ~Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge .~~ Signed District Operations Engineer Title Date 1?../~/8~ Form 10-404 Rev. 12-1-85 Submit in Duplicate G-Zone G-1 G-2 G-3 G-4 G-5 Hemlock H-1 H-2 H-3 H-3 ATTACHMENT #1 S-1RD PerfOration Record 10,215' - 10,225' 10,2'34' - 10,306' 10,330' - 10,359' 10,378' - 10,423' 10,444' - 10,454' TVD 9,505' - 9,513' 9,520' - 9,576' 9,598' - 9,617' 9,632' - 9,667' 9,683' - 9,691' 10,,486' - 10,527' 10,539' - 10,604' 10,705'- 10,735' 10,751' - 10,801' 9,717' - 9,748' 9,757' - 9,809' 9,888' - 9,912' 9,924' - 9,964' MDC/em/44A/Sundry RECEIVE'D DEC- 6 A~aska Oii& (~as Cons. Anchorage ' - ' Attachment #2 - '.' '. DailY~ Report-iof Operations Spark Well. S-IRD · .3. RIH and perforate w/4 SPF w/2 1'/8" expendable guns with 0° phasing @ the -following: ~' ~. . .-'-.'_ "- ' · ~ ~i'i0,238"i.'--.-~I0,268'-' ' ' ':"- ~' ' ' ' 0-3 i!Z"1'0',330".' ~=~' i'0,340'' -'..":..': · . H'i '".10., 486' ~'. 10,514' ..-. ' 4. ~ bo~om ~. 10,734~ ~:d . · ~ '. . . - · . -. . . .- · MDC/em/44A/Sundry . . . .. Anchorage t /---,. ?-" STATE OF ALASKA ,-~' '-"~ . AL. ,x,.~ OIL AND' GAS CONSERVATION C(. ,~,.,.,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 [] Stimulate [] Pull tubing [] Amend order [] Perforate~l~] Other [] 2. Name of Operator Harathon Oil Company 3. Address P. O. Box 102380 Anchorage, At( 99510 4. Location of well at surface Leg if, Cond. #.5, 8part~ t'±attorm 2,608' FSL, 2,495' FEL, Sec. 26 10N-13W-SM At top of productive interval 1,110' FSL, 162' FWL, Sec. 26, 10N-13W-SM At effective depth 1,164' FSL, 368' FEL, Sec. 27, 10N-13W-SM At total depth 1,170' FSL, 377' FEL, Sec. 27, 10N-13W-SM 5. Datum elevation (DF or KB) 115 KB above MSL feet 6. Unit or Property name North Trading Bay Unit 7. Well number S-1RD 8. Permit number 74-5 9. APl number 50-- 733-20158-01 10. Pool 'Trading Bay Hemlock & "G" 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface 2,802' Intermediate Production 9,751' Liner 3,664' Perforation depth: measured See Attachment #1 true vertical 11,060' feet Plugs (measured) None 10,168' feet 10,971 ' feet Junk (measured) None 10,098' feet Size Cemented Measured depth 13 3/8" 1,900 sx 2,802' 9 5/8" 1,000 sx 9,751' 7" 1,000 sx 11,060' Tubing(size, grade and measured depth) 3 i/2", N-80, @ 10,069' Packers and SSSV(type and measured depth) FB-1 Packer @ 9,980' "FTC(" TRSV @ 330' True Vertical depth 2,792' 9,142' 9,384' 1986 'Alaska 0il & Ar~c~:.c;ra!ie 12.Attachments~ /f2 Description summary of proposal E~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation October 28, 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~,J/("//,w~/f~''-- Title District Operations Engineer Date Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No..~.--~ [] Plug integrity [] BOP Test [] Location clearance I the commission Date Sub/mit ~ triplicate G-Zone G-1 G-2 G-3 G-4 G-5 Hemlock H-1 H-2 H-3 H-3 ATTACHMENT #1 S-1RD Perforation Record 10,215' - 10,225' 10,234' - 10,306' 10,334' - 10,359' 10,378' - 10,423' 10,444' - 10,454' TVD 9,505' - 9,513' 9,520' - 9,576' 9,598' - 9,617' 9,632' - 9,667' 9,683' - 9,691' 10,487' - 10,527' 10,539' - 10,604' 10,705' - 10,735' 10,751' - 10,801' 9,717' - 9,748' 9,757' - 9,809' 9,888' - 9,912' 9,924' - 9,964' MDC/em/44/Sundry ATTACHMENT #2 Spark Well S-1RD Perforation Procedure 1. Skid rig over Well S-1RD. Obtain 24 hr well test. 2. R/U W.L. Pressure test lubricator to 2,000 psi. 3. RIH Perforate the following zones 4 SPF, 0° phasing, under balanced w/2 1/8" expendable charge. 10,486' - 10,514' 10,330' - 10,340' 10,238' - 10,268' DIL (H-l) (28') DIL (G-3) (10') DIL (G-2) (30') 4. R/D W.L. Test well periodically for 1 1/2 - 2 weeks. 5. R/U W.L. Pressure test lubricator to 2,000 psi. 6. RIH. Perforate Hemlock Bench 2, 4 SPF, 0° phasing, underbalanced w/2 1/8" expendable charges. 10,538' - 10,554' DIL (16') 7. R/D W.L. Return well to production and test. PMS/em/44/Sundry STATE OF ALASKA ALASK,., JIL AND GAS CONSERVATION COMM,.._olON 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',~q Other [] 2. Name of Operator Marathon Oil Company 3. Address P.O. Box 102380, Anchorage, AK 99510 4. Locationofwellatsurface Leg 3, Cond. #5, Spark Platform 2,608' FSL, 2,495' FEL, Sec. 26 10N-13W-SM Attop of productiveinterval 1,110' FSL, 162' FWL, Sec. 26, 10N-13W-SM Ateffective depth 1,164' FSL, 368' FEL, Sec. 27, 10N-13W-SM Attotaldepth 1,i70' FSL, 377' FEL, Sec. 27, 10N-13W-SM 11. Present well condition summary Total depth: measured true vertical 11,060 feet 10,168 feet Plugs (measured) 5. Datum elevation (DF or KB) 115'KB above MSL 6. Unit or Property name North Trading Bay Unit 7. Well number S-1RD 8. Permit number 74-5 9. APl number 50-- 733-20158-01 10. Pool Trading Bay Hemlock & "G" feet Effective depth: measured 10,971 feet true vertical 10,098 feet Junk (measured) Casing Length Size Cemented Structural Conductor Surface 2,802' 13 3/8" 1900 SX Intermediate 9,751' 9 5/8" 1000 SX Production 3,664' 7" 1000 SX Liner Perforation depth: measured Attachment #1 Measured depth 2,802' 9,751' 10,060' true vertical Tubing (size, grade and measured depth) 3 1/2", N-80, @ 10,069' Packers and SSSV (type and measured depth) FB-1 Packer at 9,980' "FID{" TRSV at 330' Zone ~ue Verticaldepth 2,792' 9,142' 9,384' RECEIVED 12.Attachments APR 1 8 1986 Altmlm 011 & 0mm 0OHS, Description summary of proposal [] Detailed operations program [] BOP sketch [] At tachment #2 13. Estimated date for commencing operation 4/24/86 Date approved 14. If proposal was verbally approved Name of approver Date 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ned ~.)f OPe7 ~. ~/'-' ' Sig Title District Operations Engineer Commission Use Only Notify commissior~ so representative may witness I Approval No. [] Plug integrity '[] BOP Test 9' Lo.cation clearanceI Conditions of approval Commissioner the commission Date Approved by Form 10-403 Rev 12-1-85 Submit in triplicate G-Zone G-1 G-2 G-3 G-4 G-5 Hemlock H-1 H-2 H-3 ATTACHMENT #1 S-1RD Perforation Record 10,215' - 10,225' 10,234' - 10,306' 10,334' - 10,359' 10,378' - 10,423' 10,444' - 10,450' TVD 9,505' - 9,513' 9,520' - 9,576' 9,598' - 9,617' 9,632' - 9,667' 9,683' - 9,688' 10,487' - 10,527' 10,539' - 10,604' 10,705' - 10,801' 9,717' - 9,748' 9,757' - 9,809' 9,888' - 9,964' WJL/mcm/191 RECEIVED S-lPg) REPERFORATING PROCEDURE ATTACHmeNT #2 1. Rig up Dresser. Pressure test lubricator to 2,000 psi. me Perforate the following intervals 4 SPF, 0° phasing, underbalanced, with 2 1/8" expendable charges. Run Bench Interval Footage. 1 H-3 10,705' - 10,735' 30' 2 H-2 10,571' - 10,601' 30' 3 H-2 10,541' - 10,571' 30' 4 H-1 10,495' - 10,525' 30' 'i20" 3. Obtain stabilized production test. Perforate G-Zone under drawdown as outlined above: Run Ben ch Interval Fcc ta se e 5 G-4 10,398' - 10,423' 25' 6 G-4 10,378' - 10,398' 20' 7 G-3 10,332' - 10,360' 28' 8 G-2 10,273' - 10,303' 30' 9 G-2 10,243' - 10,273' 30' 133' R/D Dresser, return well to production. PMS/mcm/184/P4 APR 1 8 1988 Alas~ Oil & Gas Cons. Com~ Anchorage ~. - '-',, STATE OF ALASKA ""~, ~ ALASKA(' .AND GAS CONSERVATION CO ~IlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [] Workover operation ~ 2. Name of operator 7. Permit No. Marathon Oil Company 74-5 3. Address 8. APl Number P.O. Box 102380, Anchorage, AK 99510 50- 733-20158-01 4. Location of Well atsurface Log #3, Conductor #5, Spark Platform 2608' FSL, 2495' FEL, Sec. 26, TION, R13W, SM 5. Elevation in feet (indicate KB, DF, etc.) .[ 6. Lease Designation and Serial No. 115' KB I ADL-35431 For the Month of September 85 9. Unit or Lease Name North Trading Ba7 Unit 10. Well No. S-1RD 11. Field and Pool Trading Bay Hemlock & "G" Zone 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Tagged fill in 7" liner at 10,135' and cleaned out to 10,958'. A permanent packer was set at 9980' DIL. A total of 10,069' of 3-1/2", 9.2#, N-80 buttress tubing was run with associated gas lift equipment. The well was put on production, final report. 13. Casing or liner run and quantities of cement, results of pressure tests 14. Coring resume and brief descriptmon 15. Logs run and depth where run 1 §. DST data, perforating data, shows of H2S, miscellaneous data °cr o oil ~/ChOrage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED TITLE DATE _ NOTE--Re~t o~this form is required for each calendar month, regardless of the status of operations, and must be flied in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10A04 Submit in duplicate STATE OF ALASKA ~ ALASKA(~ AND GAS CONSERVATION CC ~/IISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation [~ 2. Name of operator 7. Permit No. ~ Marathon Oil Company 74-5 3. Address 8. APl Nurriber P.O. Box 102380, Anchorage, AK 99510 50- 733-20158-01 4. Location of Well at surface Leg #3, Conductor #5, Spark Platform 2608' FSL, 2495' FEL, Sec. 6, T10N, R13W, SM 5. Elevation in feet (indicate115, Ki~F' etc.) I 6. Lease DesiqnationADL_35431and Serial No. 9. Unit or Lease Name North Trading Bay Unit 10. Well No. $-iRD 11. Field and Pool Trading Bay Hemlock & "G" Zone For the Month of Auc~ust ,19 85 ... ,12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Retrievable packer would not pull free. The 3-1/2" tubing was cut at 9562' and the remaining 600' of 3-1/2" tubing and packer were recovered using an overshot fishing assembly. Cleaned out approximately 700'of fill to PBTD of 10,971. 3-1/2" tubing was run with a permanent packer set at 9980' DIL. 13. Casing or liner run and quantities of cement, results of pressure tests 14. Coring resume and brief description 15. Logs run and depth where run 16. DST data, perforating data, shows of H2S, miscellaneous data I\L%..L I V [U sEP z 985 Alaska Oil & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Rop~fon tills form is required for ea/calendar month, regardless of the status of operations,and must be filed in duplicate with the Alaska Oil and Gas~:onservation Commission by the l~Sth of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate ~ STATE OF ALASKA ALASKA _AND GAS CONSERVATION C(- .MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 7. Permit No. 2. Name of Operator ~ Marathon Oil Company 74-5 3. Address 8. APl Number P.O. Box 102380 Anchorage, AK 99510 50- 733-20158-01 OTHER [] 4. Location of Well Sur fac e: Leg 3, Cond. #5, Spark Platform 2608' FSL, 2495' FEL, Sec. 26-10N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 115' RKB 12. I 6 . Lease Designation and Serial No. ADL-35431 9. Unit or Lease Name North Trading Bay Unit 10. Well Number S-1RD 11. Field and Pool Trading ~Ba~ ttGt! Hemlock Zone Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate ~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing ~ Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Well S- 1RD Workover Workover operations should begin in March 1985, and be completed using the attached procedure. Rrr..C£1V ED FEB 0 1 1.985 Oil & Gas Cons. commission AnchoraP, e 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed-~ ~ ~-~J'~,'"~- T tle ~-~_'_~_~" The space below for Commission use Conditions of APproval, if any: OItlG'N/',L BY LOItltl£ C. SkilTil Approved by COMMISSIONER Approved 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-1RD WORKOVER RECOMMENDED PROCEDURE 1. Skid rig over Well S-1RD. RU and pressure test lubricator to 2500 psi. 2. Perf tbg above packer at 10,130'. 3. Kill well. Set BPV. ND tree. NU and test BOPE. 4. POH and LD 3-1/2" tubing and packer. 5. PU DP. RIH w/8-1/2" bit to top of liner at 7696'. POH. 6. RIH w/6" bit and boot basket. CO to top of production logging fish (approx. 10,710') lost 2-23-75. CO to PBTD at 10,971'. POH. (If unable to drill up or push fish to PBTD, recover fish w/junk basket). 7. RIH w/8-1/2" bit and 9-5/8" csg scraper to top of liner. POH. 8. RIH w/6" bit and 7" csg scraper to PBTD. POH. 9. LD DP. 10. Complete well w/packer at 10,100', inspected 3-1/2" tubing, gas lift equipment and subsurface safety valve nipple. 11. Set BPV. ND BOPE. NU and test tree. Pull BPV. 12. Perforate the following intervals under drawdown: Bench Depth (DIL) H-3 H-2 H-1 G-4 G-3 G-2 10,705'-10,737' 10,539'-10,603' 10,495'-10,527' 10,378'-10,423' 10,332'-10,360' 10,241'-10,305' 13. Obtain stable production test. RECEIVED 14. Release rig and turn well over to production. B o ! 1 185 15. Pump scale inhibition treatment. Alaska 0il & Gas Cons. Commission JAB/j w Anchorage 10-4-84 - 1 - May 29, 1980 Mr. Jim Shaginoff Spar k- Platform Box 1400 Kenai,. Alaska 9.9611 Re: ARCO Spark Well S-3 }~. Shaginoff: On May 22, 1980 you talked with Hoyle Hamilton concerning the S-3 well. You wanted to know if another no-flow test would be required]-'on!.~th~is' well since the well had been reperforated. We have lo~ked at -the production history prior to reperforation and compared that to your present well production. On the basis of these data we have determined that 'the well is still incapable of unassisted flow and therefore the subsurface safety valve requirement for this .well remains waived without an additional no-flow test. ~e~.~lRD~has also been recently reperforated. After reviewing the 10-403 form of May 14, 1980 and the previous production history this well also retains its no-flow status. Yours truly, petroleum Engineer ARCO Oil and Gas! :~pany · Alaska District~ Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 14, 1980 Mr. Hoyle Hamilton, Chairman Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99501 Re- Spark Platform, S-1 well Dear Mr. Hamilton' Enclosed are two copies of the Sundry Notice of the clean-out and reperforation work and two copies of the Monthly Report of Drilling and Workover Operations on the S-1 well. Sincerely, C. R. Knowles District Drilling Superintendent CRK/LAE/dac Enclosures (4) RECEIVED Anoh~ra~e ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Submit "I ntentions" in Triplicate "Subsequent Reports" in Duplicate Form 10-403 REV. 1-10~73 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE i. O,L ~ GAS r-! WELL'S' WEL~' ' OTHER 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.) 2.NAME OF OPERATOR ARCO Oil and Gas Company 3.ADDRESS OF OPERATOR. P. 0. Box 360, Anchorage, Alaska 99510 4.LOCATION OF WELL Atsurface Spark Platform: 2608" N & 2495' W from SE Corner, Sec 26, T10N, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) ll5' RKB i4. CheCk Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20158 6. LEASE DESIGNATION AND SERIAL NO. ADL 35431 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME North Tradin§ Bay Unit 9. WELL NO. S-1 (14-26) 10. FIELD AND POOL, OR WILDCAT Trading Bay NE "G" Hemlock 'il. SEC., T., R., M., (BOTTOM HOL~ OBJECTIVE) Sec 27, T1ON, R13W, SM 12. PERMIT NO. 68-0103 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF [~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) Clean-out & reperforation (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. On May 5, 1980, RU Otis snubbing equipment and tested BOPE. Displaced tubing w/Drill-S WO fluid. Washed and rotated to 10,207' Spotted Dril-S Pill from tubing tail (10,203') to 10,117' Washe~ & rotated to 10,286' and hit hard sand bri.dge. Perforated 10,~44' - 10,234' DIL and 10,225' - 10,215' DIL. Releasedwell to production department @ 2400 hrs May 8, 1980. 24 hour test; May 13, 1980: 830 bbl gross, 158 bbl net w/81% cut. 16. I hereby certify that th~2Zng is true and correct TITLE Dist Drl§ Supt DATE May 14. 1980 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side ARCO Oil and Ga~"".L,,mpany South ^las ~Mr{ct Post Olfice Box 3(-;0 Anchorage. Alaska 99510 Telephone 907 277 5637 April 22, 1980 Mr. Hoyle Hamilton Chairman Alaska Oil & Gas Conservation Commission State of Alaska 3001 Porcupine Drive Anchorage, Ak 99501 Re' Sundry Notice, Spark Platform S-9, S-1 & S-3 Dear Mr. Hamilton' Transmitted herewith are three (3) separate Sundry Notices (in triplicate) filed by ARCO Oil & Gas Company, requesting an approval for the subject workovers. In the event your office should need additional infor- mation in conjunction with this matter, please do not hesitate to contact us. Very truly your/s, C. R. Knowles Dist. Drlg. Supt. CRK/KUP/dac Enclosures ARCO Oil and Gas Company is a Division of AllanlicRichfieldCompany ~ No. P~ STATE O~ .,a, kJ~ SUBMIT IN DUPLICA'r'~ _ ~*v. ~- ,-?o ~'~ A., N~EmC,U. CODE OIL AND GAS CONSERVATION COMMI'rI'EE 50-1 33-201 58 MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS LEASE DES:G~AT'ION AND SEI~IA.1.. NO, ADL 35431 '/IF INDIAI~.ALOT'FEE OR TRIBE NA~E OIL ~ O&e [] W~LL WELL OTHER NAME OF OPERATOR 8. L,~IT FARM OR LEASE NAME ARCO Oil and Gas Company North Trading Bay Unit 3. ADDREss ~F OPERATOR 9 P. O. Box 360, Anchorage, Alaska 99510 '4. LOCATION OF WELL 10 Spark Platform' 2608' N & 2495' W from SE Cr, Sec 26, TION, R13W, SM n WELL NO S-1 (14-26) FIFJ..D AND POOL, OR WI1.DCAT Trading Bay NE "G", Hemlock SE, C, T., R.. M. (BO'I'TOM HOLE Sec 27, TION, R13W, SM PEP. MIT NO 68-0103 13. REPORT TOTAL DEPTH AT END OF MONTH. CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AATD VOLUlVlI~S USED. PEP,~OP,.ATIONS, TESTS A.N'D RESULTS FISHING JOB~ JL~"NK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS On May 5, 1980, RU Otis snubbing equipment and tested BOPE. Displaced tUbing w/Drill-S WO fluid. Washed and rotated to 10,207' Spotted Dril-S pill from tubing tail (10,203') to 10,117' Washe~ & rotated to 10,286' and hit hard sand bridge. Perforated 10,~_44' - 10,234' DIL and 10,225' - 10,215' DIL. Released well to production department @ 2400 hrs May 8, 1980. 24 hour test; May 13, 1980: 830 bbl gross, 158 bbl net w/81% cut. 14. I hereby certify rrect - s~r~ ':~ Dist Drlq Supt , r~,.~ May 14, 1980 I ~ II I i Ill I ...... NOT[-- sport on this fo~ il required for .IQ~ GolendQr ~nth~ regQrdless of the Status of operatiofls~ and must ~ fil~d in duplicate wit~ oil and gas co~ervatbn commi~ee bythe IS~ of the suoe~ding mn~, ~le~ Qtherwiss directed. Form 10-403 RE~V. 1-10~?~ Subml t "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTIC. ES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) o,L i-~ GAs I'--1 WELLI-~J WELL L-J OTHER 2. NAME OF OPERATOR ARCO Oil & Gas Company ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Ak 99510 4. LOCATION OF WELL Atsur~ace Spark Platform, 2608' N & 2495' W from SE Cr. 'Section 26, T10N, R13W, SM. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 115' RKB 14, Check Appropriate Box To Indicate Nature of Notice, Re 15. APl NUMERICAL CODE 50-133-20158 6. LEASE DESIGNATION AND SERIAL NO. ' ADL 35431 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME North Trading Bay Unit 9. WELL NO. S-1 (14-26) 10. FIELD AND POOL, OR WILDCAT .Trading B.a¥ NE "G" Hemlock Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 27, TION, R13W, SM 12. PERMIT NO. )ort, or Other Data NOTICE OF INTENTION TO.' TEST WATER SHUT-OFF ~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR AClDIZE REPAIR WELL (Other) Clean out fill ABANDON* CHANGE PLANS & reperforate SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING, CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estlmatect date of starting any proposed work. This well was completed in June 1974 as a "G"--Hemlock Producer, and the production is restricted by barium sulfate scales in the tubing string along with fills in production casing. AOGC intends to clean-out the tubing scales and fills using Otis 4-1/16" hydraulic workover unit and Dril-S workover fluid with full returns to mud pit. This hydraulic workover unit contains 10,000# BOP stack with' shear rams, safety rams, stripper rams and equalizing rams. Upon completion of clean-out operation, H-2 & H-3 zones will be reperforated. - The operation will commence on or about April 30, 1980, upon completion of S-9. · 16. I hereby certify that the foregoing is true anti.correct C. R. KnnwiP.5 ,~'~ APPROVED BY [' CONDITIONS OF APPR~I~VAL, IF AN~'~y ORDER OF COMMI§SIONER DATE ,. April 22~ 1980 See Instructions On Reverse Side AttanticRiChfietdC°mpan¥ North Ame ~. ~rr~cdtucing south Atas~ post Office ~ox 360 Anchorage, Alaska 99510 Telephone 90'/2'/7 563-/ OWisiOn July 2, 1974 Idr. Homer Burrell State of AlaSka Department of Natural t~es°urces Oil ~ Gas Division porcupine Drive 5001 Alaska 99504 Anchorage, rrel 1: Dear ~lr. Bu . ,,~nthlY Repor. t~f, Drilling Opera}~.°~ ~om¢letea on th P recen%xY ~ '~ Very trulY yourS, james D. Keasl ~ jDK/DLS/gld Attachment ,it!! .... 8 'i974 ? It" [~" l"orm ~o. P--4 REV. STATE Ok ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUP. LICAT'~ MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS 1. WKLL WgLL OTHER NAME OF OPIIRATOR ATLANTIC RI,[IHF,IELD' COMPANY 3. ADDRESS OF' P.O. Box 360, ,,,Anchori~ge, Alaska 99S10 4 tX)CAT~ON OF At surface: Conductor for 5, Leg' 3, Spark Platt@m, 2608'N & 2495'W fr SE cr Sec 26, T10N, R13W, SM [~-APl NU~IERICAL CODE 50-133-20158-01 6 LEASE DESIGNATION AND SERIAL NO. ADL 35341 IF INDIA14', AI_XDTT'EE Ol~ TRIBE NAME S. L~,'IT FAI'~M OR LEASE qorth'Trading Bay Unit 9 WEI,L NO .q-1 10 FIFJ~ A_ND P(~L. OR WILDCAT i=Trading Bay - NE Hemlock I1 SEC, T.--. R. M' (BO~'I'OM HOl.,~ tl70N ~ 577W fr SE cr Sec 27, T10N~ R!3W~ SM 12: PmlT N'O 74-5, 13. REPORT TOTAL DKPTH AT END OF MONTH. CHANG~ IN HOLE SIZE, CASING AND CEMgNTING JOBS INCLUDING DEPTH SET AND VOLUMES USED. PEH~ORATIONS, 'rF_.STS AND RESULTS FISHING JOB~ $I~"NK ~ HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS NTBU S-1 (14-26) for June '. Ran WS0 test;' Ran 325:',jts' 5 1/2'". 9,2#. N-80 tbg w/12 GLV's and TRB-6 safety valve @'284.. Set'packer'@l'0,150,. .Pert 4 SPF @10,216-10,221,; 10,241.10,506'; 10,354'10,559'; 10,:578-10,425,'; 10,444-10,454'; 10,'487-10,527,; 10,539-10,579'; 10,'589-10,604'; 10 , 705-10, 735" ; 10,751-10,791'; 10,751-10,791'; 6 SPF 10,971-10,801'. Turned'iwell over' to"production ~'RR'@12 MN"6-13-'74. FINAL REPORT. Tested BOP rams w/2500', psi'~ Hydril ~/1500' psi'on 6-10-74. Replaced'seals in Hydril 6-11-74. JUL 8 i974 DIVISION 0F OIL ANi) C, gS AN£:t ORAC,£ /~2'.~¢~.-%-~ ._~ Dist:"Drilling.Super_yiso~ :7/2174. . ( NOT~'E ~7~eport on thie form is required for .eaCh calendar monthT regardless of the status of operations, end must I~ flied In dupllr, ote with the oil and (gas conservation committee by the Igth of the succeeding month, u~le~ otherwise d~rected. AtlanticRichfieldCompany North An~''''''''~ Producing Division South Alas.., oistrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 2'/7 5637 June 26, 1974 Mr. Homer Burrell State of Alaska Department of Natural Resources Oil ~ Gas Division 5001 Porcupine Drive Anchorage, Alaska 99S04 Dear Mr. Burrell: Enclosed are copies of the Well Completion Report (form P-7), open hole logs and directional survey, for the NTBU S-1Redrill (14-26) well recently recompleted on the Spark Platform. Very truly y~ District Drilling Supervisor JDK/gld Attachment D %!;MtON OIL ANO GAS Form P.- 7 ! '. .SUBMIT IN DI~., .... CATE* STATE OF ALASKA (See other m- st ructions on reverse sbic; OIL AND GAS CONSERVATION, COMMITTEE Anchorage, Alaska 99510 i i WELL cOMPLETION OR RECOMPLETiON REPORT AND LOG* i '11 i- i i i ii i i i la. TYPE OF WELL: o1I, ~ GAS [] ~--~ W ELI, X¥ ELL DR ¥ Other b. TYPE OF COMPLETION: NEW [----] WORK ~1 DEEP- ~ PLUG F~' WELt, OVER EN BACK RESVR. Other __ , 2. NAM E OF OP~rRATOR ATLANTIC RICHFIELD COMPANY 3. ADDRESS OF OPERATOR P.O. Box 360 4. L0C^TION o¥ WELL'-(Report location clearly and in accordance with any State requirements)* At surface Conductor 5 leg 3 At top prod. l~'re~rt~ ~ 'W f~ SE er Sec 26,T10N,R13W, Sm lll0N ~ 162E, fr SW cr Sec 26,T10NjRlSW',SM At total depth 5. API NUS/IF_JIlCAL CODE 50-155-20158-01 6. LEASE DESIGNATION AND SERIAL NO. ADL 35431 i~. IF INDIAN, A.LLOTTEE OR TRIBE NA1VLE 8. UNIT,FA.I1.M OR LEASE NAME North' Trading Bay Unit 9. WIlL NO.. S~l [14-26) Hemlock NE 0il Pool , 11. SEC., T., R., M,, (BOTTOM HOLE OBJECTIVE) Se c' .27, T10N, RISS, SM 12. P~'R3/iIT N'O. tl70'N [ 577W fr SE cr Sec '27.,T10N,R13W,SM 5-3-74 . ] 5-25~74 i. 6-13-74 . ! ]].~, 18, TOTAL DE.H, N~ & TVD~9. ;PLUG. ~CK MD & ~. ~ ~LT~LE CO~L., { ~ .... INTERVALS DRiLl, ED BY [ ~ [ HOW~Y* ROTARX TOOLS [ CABI,E TOOLS 11,060 MD(10.168]: 10'.,971MDf10.098~.[ SSnola i v~°=~ ann, ' =: PaObUC~NG zN~V~L(S).-OF ~S COmP~TiON--TO~ Bo~oM~dME (~ AND ~*- .... ' laS. WAS DmfCT~ONAL ~ SURVEY MADE ~ "G" zone'~ 10,216 C9519) - 10,454.. ~ Hemlock 10,487- 10',801 ~ (9974). . i Yes 24~. TYPE E~CTRIC AND OTH~ LOGS ~UN .Schl~berger~ DILl G~a Ray Density; G~a Ray/Cement Bond Log, CAS~G RECORD (Re~rt all strings set in well) C~S~4G SIZE ] ~I,GHT, LB/~T.~ G~D,~ ,~ DEP~ ~E~ (~) HOLE SIZE [ C~%ILNTING RECO~ ,~ ~OUNT PULLED l~ s/s', [61 ~ j-ss I 2s02,, is" ~ l~OOax 9 5'/S" ~. . . 47g: ..... ~s0gpll0 '10-5~o_ .. '~ '/4'[. . lnnn~ ...... . t ,, ",' ' 26. LIN.~w R~CO~ ] ,7. ~ TUBING -~q~z~a. t~=. ~ w~oo ~ ~gmd~_ · ' 1- ' I ,-~' 28. P T O" I~P ' O O ~ O val i um ) 20 -ACID Si'o :' C .. ~o,~4-~o,s, ~o.~os-~o,~,s~ .. .-~ .... _ . .. ~.3J8-10,423. 10,751-10,7~i , JUN 2 8 : :,.~;-44,i0,-454 . 10,751-10791 . , '} .... .. ~. PRODUCTION ~ ...... DATE P~RST Pi%ODUCTION [ ~ODUCTION ME'i[{OD (Plowh~g, g~$ li{~, ~m~Mg--size and ty~e o~ pum~ ......... ~LL ~nuL-in) 6-3-74 . Gas Lift ,,~ o~ ~,s~. ~ou~s TSST~ '[c~-~ox~ s~z~ ~P.O~'N ~o.~ O~B~. O~cr. w/:~~r--]'~s-om ~.~o ~5~ ~ i~ 1 ~/2". [*~'~? [ 2547. ] s~0 l.:: 206 [ 200 6-15-74 cx~m . FLOW, ~*BIHG , '7" SS ~ [ AL~T~ OI~BB~. GA~MC~. ~ss. 200 1090~ : [~-~ua ~ [ _ 2547. ] 510 31. DISPOSITION O~ ~*S (Sold} ~ed ~o~ I~el, v6~ted, etc.) Used for :fuel. ,: WATER--BBL, l OiL GRAVITY-AP1 (CORi:L) I20,6 IT~..81T WITN~8~;D BY i K.R. Keys LIST OF ATTACHMENTS ~s~ !: ~irectional .survey SS.._ s~~~:~~: :n ~~~_th.al t~Or~'''-~0~en . ho le 1 °t.~ ~a, ...... a ~[~:d;. [.: inf :rmationTiTLEiS complete~l~. ~_ '.'"and'--c°rrect7-~ :aS,,;,. determined~./~,from a.l~aVallableDATEreEor'ds__.~._~.__, -~- ~ -__ ,, ~ ' (See Instructions and Spaces [or Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete arld correct well completion report end log on all types of tanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not oti~erwise sho'wr~.) for depth n'~easure- merits given in ether spaces on this forn~ and in any attac!~;nents. Items 20, and )):: tf this well is completed for separate prcduction from r-~ore than one interval zone (multiple completion), so state ~n item 20, and in iteq~ 22 show the prcz]ucir~.g interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the intervc~l reported in iter'r~ 30. Submit a separate report (page) on this form, adequately identified, for each additional inte~vat to be seperately produced, show- ing the additional data pertinent to such interval. Item)6: "S~cks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Ittm )8: Submit a separate completion report on this form for each interval to be separately produced, (See instruction for items 20 and 22 above). SUMMARY OF ~O~MATION 'TESTS 1NCLUDIN(; IN~r~VAL TESTED, t'tRE~SURE DATA AI~D'~COVERIES OF OI~'. ~AS. 35. G~GIC MARK~ WAT~ AND MUD , , ,,, ,,, G Mkr 949~ 8948 G Prod Horiz 10216 9519 Hemlock 10487 972 8 Vest Foreland 10940 1008~ BHL 11060 10168 36. COHE DATA. AI'I'ACII BRIEF D~.C~I~]~ONS OF :LITIIOLOGY. POROSITY, FHACWR~. APP~fiT ~IPS AN9 I)B~I'ECT~I) SIIOWS OF OIL, G~ OR WAT~. _ .~.Y"' .... -mUS~.~ I r,l o... ~ E'L~''''.. b~,IO,'' '~ ,', 1'15"f'T' i ........... ' ............................... , ................................................................................. . ~A~D-'FO~' A'DDCO BY F~"-~' '~'I'NDSEY""A~X'~'A~SO~', ........... BB~ ............................................... ~ ............................................................. .................................... ' ...................................... RECORD" OP 'SURVEY ....................... 6 ..................................................................................................................... " ........... A~L CALCULATIONS PE~ffOR~'4ED"[~.Y,, I G :,," ..................................................................... ELECTRONIC COMPUTER ....................................... .................. TRL[E ...................... ..................... DOG -LEG ................... · ..... ,~.' D~IFT-'-VS;:tT. IC~L- ......... 5UB ....... DRIFT ....... TOTAL~ C'OORDINATE'S, ........ C-~-' 0-"5" U'R' E ''~o .................. ~T~.""A~'~GL~Z'--D[.~.I~TH-' S~A D'IREC - DISTANCE ....... A~GLE ....... DEC;/lUOFT' ....... .... ,.~ '.) ...... ~'~ ..................................................... DEG~ ......................................................................... D ..... M .... 5 ........................................................................... ......................................... ~:,-2 "2~ .... k5 ..... '?~bO.b'9 7'~6~-.5-9 5 ~'7'"W ....... :~0'2'~"'5 t452.18'w ...... ~0'~:~.~.6.-~ .... 5' z~.6- ' O"-~-2'-W ......... 0..~ ~¥,~i?'1 ....... ~:)~Z ...... 2Z 15 -'7~qi'.4~ Ta-75.~ ..... 5"~T W ........~z~25'.58 5 .... ~B8'.~5 w ..........205t',00 ....S-'~5 ..... ~ ...... ~-'5--W .............. O'-iO00 ............. l~z~-~-~-~ ......... ...... ' . ' Z'l~"2t ...... ~ 7"tz~4.,'79''~ 75'27. T9 ....... S .... 6'3 'W .... ~-4. F2,'29' S 'Z 5~,'0',18 W .... ~l16.g~ -5 ,z~i ......~+0' . , .~ ....... .~ ...... ~, ~ 2~? 2.~. 0 78t0;0© ?~lS"Og ...... S '6~ W ...... 1'~.~5:~.~0 5 ~512'i'13' W .......... 21'~:i.05''5 ~? .......0 ....... 5'8 ..... W .......... 2i"2'5:] ............... 20'~J'?-i'U'9 ....... 3'26 .....~ ....."' 5"~9S'~,~5 .........V~.o ....................... . . ~'f,l' '2a '~ ~050.~7 7935".2T 'S 6zi"'W ........... 1508.10 S 165~.01' W 22z,,~.70' S"~7 ~2 .... ~6"'W .......... a"~c 26--30 .....~0~,,(,.'3~ .... 705~-.'3n' S' 67-'W'' 1~11.2~ 5 1575.a'~ W 2256.29 '5 4'7'5'6'""5& .... ~%" 7.5~2 .. ~ ,,. , . ¥ ~. 5(,~.,2~:,'-'z+F, ~,i~,~:.~F.,., , ~OaO.~jD., , .... S" ?2-w-', 152~:.97. S !716.16 W, 22o5.S~, 'S 48 .... 22 ..... '77't~ ....... 29 0 .......~338'.z~: ........ 8221"~'4'5 ..... S"7'5 ...... W .......... 155'0'.~,7 S 18I'1.'3'1' W" 2384"28' 5 '[~9"'26 ...... 1"1 ..... e~,-~' 20' 0 ~z+l~.05 ..... 830.1','05 ...... S 77 W ..... 1550.39 5 185~.30 W 2~.23.t+8 .... 5 ""~ ..... - ..... ~,9 .... 5'5. ...... 95'I' 2t3'1'5 ..... 8z, 9'Ii'09 ....... 8"375",'09-N"S'-a"W ....... 155~3~'93 5 1896.29 W' 2~5a.83 'S O'~!',..(' ~ ~ .... 4'~ ........ ,~ 5 ?'l'"i"O 1 .......... [?'~:5'6'"~" 0 i ..... ~""' 8 ~-i~'''' W ................ t 55'~ i"96 ..... ~ ........... 19'! ?i"58 .... W ........... 2'~i 8' ~f, ~ 3 .... S ..... 5? ..... 21-" , ~..~ ~ ~ '~ ~ 0 ~..'~ 7 ..... ~'68 ~-i'~i'7 ..... N ..... ~'z+"-~'W ....... ~ 53-7~'8'Z'--5 "20~ ~. 87 -W ......... 2'601' i'8 ~ ....... 5 .... D'~ ~ 6"-2 5'1~, B~ o, . .- -""2 ...... .,0 q037. 67 ....... 8~iS.'6T" N. a6 'W lB2z~'~09 S 22T~.~1 W ....... 27~'7"i'85 .... 5'"56'"10' ~'2"5'W ...... ..... RECORD OF' SURV,i£Y ............................................................................ .~LL-C',.'~I CLJL~TIONc PE ""'~' [? .":i .- , ..., ,qFOR?ir.:D Y' I' B ELECTRO/'.IIC CO!"~PUTER ............................................................................ . . ........... TRL!E ....................................................... ...................................................................... DOG -b:EG ...................... EAe..,, D'ZlFT VERTICAL SUB ......... DR, I'FT' '" TOTAL CO0tRDINATES "- C L- 0 $'"U"R E'S ............SEVERITY .............. SECTI'Orq'--- ZPI'H ',,:,,~GLE "- D~':PTH ......... SEA ..... DIREC ......................... : .... DISTANCE "- A'IqGLE ........... DEG/'i'C"OFT .........DISTAC,~C'E-' ............ 9" "'.~ ........................................... :DEG. ........................................................ - .............. D ..... N "S ................. '~ ............................ ' .................... .. C221 B8 15 9.~!0,05 9595,05- N 85 .V.!" 1.~92,~09 S '2649,20 W.' .... 3060..69 'S 60,"~6"BB'"W "' 0.650- "3029;'2'0 045~ "3cJ-~ 0 '969z',.23 "-9579.,':.°3 ....../',! 86 Vl ..... 148'1','69 S .... 2797.98"'l~' .......J~].66.09 S '62 ' 5" 4'6'W .............'0,412 31 05.3'~'"g~ '~5 .....9752,50 "963S".['0 '- N'"8~ W ....... I~76~72 S ' '28,¢5,29 "W ....... g205,68 'S '62'.'"g'~ .....l~-'W ......... 1,6¢'~ .............. *"~'~' 07(..2'38 '0 ...... 9933,"17 .... 9818'i!7 ........ Fi 84' W ....... lz~6'2~06 S 298~,90'"W .........33'2'3,73 '$ ....6'3 ~54-1~'"g ................ 0';3'2'9' .................... OTTO~,~ HOLE'CLOSUR[2 ..... 3~:'75,-87" FEET "AT S '65'g[~' [~ W ............................................ ~ .............................................. ' ..................................... . ......... .. ...... ~.~ '-',.-'"-": .-~ ..... :. .... ..: ........ :. ............. : ................. ...... . ................... .......................................................... ~,~ . ,~ .... ... ........................ ., .............................. .......................................... . ........... . ........................ , ................ , ........................................... . .,. ~-, ~ ',.t!) u rH~'q OAtA' FOl<, EV(P,Y EV["N lOC, F'~=:,T UF ! ......................................... T,~OE ' . ......................... f¥!EA.%URED VERTICAL SUB '--MD-,TVD-" VERTICAL' - . -- OEnTH DEPTH- SEA DIFFERENC-E ........ £ORRECTION ............ 7869 .................. 751 7976 761 ...... 8093 .... 771 ......... 819].' ................ 781 8300 791 841-2 .... · -8523 ............. 8.11 8635 -- 821 8749 .... 831 . ......... 8979 ................ 851 ......... 9096 ..............861 ............. 921'6 ............................ 8'7 ............... 93'38 ..................... 88 1 ............. 9~5'2 ........................ 891 ............. 959 0 ....................... 90'1 971-7 ..... 911 9844 ..... 92'1 99'72 ..... 9'3-1 0100 ...................... 9,'.I. 1 0227 ............ : ..... 95:1, 035'5 ' 9 6'1 O-Z~S 5 ............... 971 SUB'C< .¢,..A DI:: :"TH. 5,- . 7~00, ........35~ ........................ 35~ TOTAL -- COORD tN.A~FE 5 ...................... 5, "' 7'700," '376 ............... 8 .... .5, 7800, 385 9 5. '-7900.' "397 ........ 12 5, ...... 80.00, .... 408 ......................... 1'1 ............ .5. 8'100. ..... 420 12' 1409.47. 5 .........146-3,~0 ....g.~.~ ................................................ 1429,69 ,5~/-.14.95.90.W.~ ..................................... -~?e~O -$ ...... 1529,99-W .................................................. ....... ~62'o'9~ 5-'/' 1565o48-'W'~ ............................................................ -'~79.86 5 1608.~2 Vi ........ 'lSO0.~a S-/ 1652,38 W ....... ..................... ..... ....... ................... 5, .... 8200, .... z+34 .......... lz+ -1-5~+'7', 39 5 .....1799,,82--W ................... 5, ...... 8300. .......... ~.~,9 .............................. 1.5' I' I ....... 1560,26'"'-5 .......... 1'853.73-'W ................. 5-. .... 8400, ......... 46a .............. 15 ................ 1'557'.'4~'-'5 ........... 19 I0,4'4" W .................. ~;~":~::~ ................................. 5 '~ 500 ' ~81.... 17 ' ' 1551,03 S ~1971,45 W~ - · ~:;-':-:"~: ............................. 1'5', .......... 86 00', ............. 501 ...................................... 20 .................................. t544 ,"t'3-' -5 .......... 2037 ,"0'7 "' W ............... : ..... .~- .... '!.~ ................................ 5', .......... 87'00"~ ........ 523 ............................ 22 .............. ' ............ ~'536 ,'97-'-'5 ............ 2'1'0'6 ,-~ 9" w .......... . .... :~.::-::-Q~ ........................................... , 5-'[ ........... 8800'~ ....... 5~7 ............................. 2~ .................................... ~ 5-~0','67'--~'~'2'18'0", 2~"' W'~ ..................... ~ ..... ~ ............................. 5"'~"-":-'"" 89 0-0 ',' ............. 5-7-5 .......................................... Z 8 ................................... 1 '52'5 '~-'1 '2'---~ .......... ":2259'~"5'~"W ........... L....~.: ............. .:zQ .................. --__ 5,- 9000", ....... 602 ......... ~7 ......... 1519,66'S ---2~37~79'-w ....... ~ ..... <:':' ............ - ....... 5, ..... 9100, .......629 ............ ' ' ',.' 1 09 W q- - ~-J':~. - ........................ 5-, ........ 9200'~ ............ 65'7 .................................. 2~t .... ' ...... ' 1 ~ 50'6 '8 6'-""5 ............. 2-~F95'-~ ~'3 .... w ................... 5, ........... 9 ~ 00"'~ ............... 685 ................................. 28 ................................. 1498','83 '~ ..... 25'7.~, ,'¢7 w ............................. ' ......... ~:.~ .............. 5. "'9~00. ........ 712 ....................27 .......... 149'1',81 5"/:265'3,19 'W~ '~::F~" C--u ...... ~:~. 5'~ ..... 9500.', ............. :74'1 29 ........................................... 1~86['1'(~'"""S'~ .... 2733.98 .... W 5", ........ 9600'i ............. 770 .................................. 29 ..................... 1479 ,"95"S ........28'1z+~56 W .................... :~ ' '~ .... ~'" , ' TRUE '/'. -':£ A .S U It E D V ~':' I',: T ! C A L DFP TM D F'.' P TH SUB SEA TOTAL' C,., 0~-, D I NATE' ~ ?~"'O 7637 -.~. , 7522. 1433.5S S '.THO0 g533. D4i8, i~;56.31S ...... l'O'O O0 ....... 9936, .... 9221" ........... 1505'i'35-' '$ .. ,. 1503,46 192t,2]. ~5~2,A2 'W ' ' ....... i ......... : ............. : ................ ~-~ .......... : ..... :- .......................... .~CALE_._L= lO00 : ........ : ......... , ...... :- ~ ~ . . · . .. _. ...................................... ~ ............ ............. ~ ................. :...: ........ : .......... <~__~_~ ...... ~_}_..~_~ ~ .: ~ . . .-,?---.~---:~ -: .... ~._~:_ , .~ ~ . . -~ ....... ~..?.: .... : .... ..... ~ '_ ................. :. ' : L : t~ · ' F ' ' ' t ' , ' . , ' ' .... ~F'-s-~ ..... ~ ............................ ~ ....... ~--'~'--~-~ .... ~-~ ..... ~--: .....+-~-'~-~-:~--~ .................... i- ":: ' ~-:- ~- ....... ' --'-~- .................. ~ ...... s ................................. ~--'~"'~-~ .... ~ .......~.--?--~-~-~-S-~-'-~-~ ........... ~--~- ............ ~ ............ ~- ~ : ......~ ..... ~ ......... ~ ........ :--:- .... ~__-~ ......... -: .... ~ .... ~.._~ ................. ~ ....... ~. ...... ?--. ...... :.-~-~ .... _=..~.~ ...... ~.~__~__~:_~__~_.~____~_.~ ......... ~__:_.~_._~_.~ ........ . ........... ~_~ ....... ~ .... ~_~.. ........ -.: .... ~ ........ _.~ -~~~-~.. _ ~ .... ~_ ~, ~ - ~. _~ _~ .:__ _ ~ ... .................... :. .................................... } ................ ~ ........... ~-~. --:---> ........... ~_.~ ........ ~ ............... ~ .... : ..... ~.__~ ........... ~ ................. · ..... i~ ........................ .... ~._~ ............ -. .__. ....... _.._ ............ ~ ...... ~ ........ ~_..-._~ ....... ~ ....... ~ ........ ~. ................ ~ ............. ~ ............ : ............... : ............. ~ ............... ~...~ ....... ~.-~ .......... _ ====================== ....... ~:_:':_ ::.:::__:-::::_.::::__::_..-~:.~::~-':-~:~--~:::.~_~:~-:::_::~:~'~ .... :::::~"-::::~:~--~.'~:~:~:.'.:::~:~:_-:~:-,-:: .... -'}--~-' .............. ' ..... l ............... ~--:- ...... ~ .............. :-~~:~"~/' ........... ~-'--" .... :'": ......... ~'~'- ....... ~ ........ ~ ....... ~ ................ .......... ~ ........... : ......... . --7~-~'TT_L~_". ~ ~_-/."~ _~.'. _ / - ~.-' .~: L.~'. ~' ~_~ ~.~._'_-.~-~'~. ~"-'~'--~S~Z._~L.. ___ ..._.. _:_~__..'-i~7~'~'~.7~-L~: ~' ~'. ~_/L.'_ ~-L~S~'_.-. ~_ ~-~:/... _'.~-~.' ~'~.~'--~' -. -.'_. ~. ~ ...... ~C'Z~L~/. ~".'/L -~ ~'~ l ~ ........ ~' ' I .......................... " ....................................... ~ :--~ ........... ~ ......................................... ~ .................. ~ ............................. ............... - ........ : ..... .......... ~ ......~ .... ~ ....... ~ ....... > ......... ~ - -'t ..................... , ............... . ............ ~ ............. . ................ ~. .............................. :.:'-~ :-.-::'--:.'-:~--_-....-:-:~-.-:- ':'_L' ':: ...... :_-:.:':~' :-__:_:---_:_-:-'-_-~'.~-:-: :.:~:: -.:.:':': '-'::'::_} ~'--'-: .... ~. .... .._ :---~:.':-'-".' '~."..'.-::-.':-L.- .... ..: -::-.-'.-.._: .... - ............ J ........ ~ ................ ~ .............. ~ ~'~TF__~ . .T. D = !0, GS, . ..... ~ ..................': .......... ........ ' '.L : ...... ~ - ' ........: ......:-~ ................. ~-~ ....... ' ...... ~ ....... :.-~.'-- TMD=-II~O .......... ' .............. : ............... ........... . .............. AtlanticRichfieldCompany North Americ~-"'%oducing Division Alaska Distrk_ Post Office Box 360 Anchorage, Alaska 99501 Telephone 907 277 5637 June 14, 1974 Mr. Homer Burrell State of Alaska Department of Natural Resources Oil & Gas Division 3001 Porcupine Drive Anchorage~ AK 99504 ----.;, CONFER: FILE: . Dear Mr. Burrell- Enclosed are copies of the required Monthly Report of Drilling Operations for May for the NTBU S-1 (14-26) well now drilling from the Spark Platform. Very truly yours, JDK/kb Enclosure JUN 1 7 t974 STATE OF ALASKA OIL AND OAS CONSERVATION COMMII~EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WW-LL NAME OF OP~tATOR Atlantic Richfield Company AD~RZSS OF OPk~TOR P. O. Box 360, Anchorage, AK lOCATiON OF WELL 99510 Conductor 5, Leg 3, Spark Platform 2608~N & 2495'W fr SE cr Sec 26 T10N,~R13W, SM SUBMIT 1~ Dt~LICA~ APl NUD/IEPACAL CODE 50-133-20158-01 6 LF~SE DESIGNA~ON AND SERIAL NO. ADL 35341 ? IF INDIA)~ ALOTiEE OR TRIBE NAME 8. I.,.~IT F.~RM Ott LEASE NAME North Trading Bay Unit WELL NO S-1 (14-26) F~LD AND POOL. OH WILDCAT Trad%ngBay Fiel~ ~-Hem~ock 9xl Poo~ sec. T.. ~.. OmmCTIV~ 250'W & ll00'N fr SE cr g~ ~7_ T1DM ~l~g_ ~M 12P~R.MIT~O ' ' 74-5 REPORT TOTAL DEPTH AT F~ID OF MONTH. CHANGES IN HOLE SIZE. CASING AND C~VIENTI_NG JOBS INCLUDING DEPTH SET AND VOLUMI~ USED, PERFORATIONS. TESTS A_NUD RESULTS FISHING JOBS JL~K IN HOLE AND SIDE-'I'RACKED HOLE AND A~Y OTHER SIGNIFICANT CI-IA~G~ IN HOI~ CONDITIONS NTBU S-1 (14-26) for May, 1974 Spotted 170 sx class G cement (kick off plug) @ 8016'. W0C 24 hr. Drilled cement f/7753-7951'. Sidetracked hole @ KOP 7951' & drilled 8-1/2" directional hole f/ 7951-11060' TD. Ran Schlumberger DIL & Gamma Ray/DenSity f/11043-7950'. Ran & cement- ed 3364' of 7" 29# Pll0 buttress liner w/BOT hydraulic MC liner hanger f/7687-11051' w/1000 sx class G cement. Cleaned out liner'to 10971' PBD. Ran Gamma Ray/Cement Bond Log f/10971-7587'. Top of cement @ 8600' w/good bondink below~ 8600'. Squeezed top of liner w/100 sx class .a cement. Cleaned out liner to 10971' PBD. Tested BOP to 3000 psi & Hydril~. to 2000 psi on 5-1-74, 5-8-74, 5-16-74 & 5-22-74. Running WS0 on 6-1-74. JUN 14. I he.~ ~i~ the for~o~g * ~ ~ ~ --Rl~o~t on t~i~ fo~ i~ rl~irl~ fo~ t~~ ~lln~r ~nt~ rlj~r~ltlI of t~1 Itotul of o~t~otio~ ~ mull Atl~nticRichfieldCompany North Ame,""~producing Division South Alas ...... ~trict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 2'/7 5637 May 14,1974 Mr. Homer.Burrell State'Of Alaska' Department of Natural.Resources'.' Oil & Gas Division 3001 Porcupine Drive Anchorage, AK 99504 . Dear Mr..Burrell' Enclosed'.are Copies'of the'reqUired'.MonthlY.Report of Drilling Operatios for April for the'NTBU. S-1 (14-26) well now'drillingfrom the'Spark PlatfOrm. Very truly yours, ~s ler'. . . Dist"Drilling Superv!sor JDK/kb Enclosure J REV '1 D~. 1--' I s~c _1'- CONFER: FILE: t,~AY !. 6 I974 ~ ~°' P~ STATE OF AJ.ASKA suBM~ ~ ~uC~ ~. ~-1-7o .~~ CODE OIL AND GAS CONSERVATION CO~I~EE ! ;, 50- ~ 35; 20 iS 8-0 ~ ....... ' L ].~ '~s~ n~f~X~o~ ~so s~ ~o. MON~LY RE~RT OF DRIL lNG i/ AND WORKOVER OPERA--NS. , [~ ~ ADL 35341 -. .~. ~ ....... ~. N~E OF OPhiR ,f Atlent~c E~chf~elE ~o~. -~ . .. North'Trading Bay Unit 'P. 0. ~ox 350, ~ora[e,'_Al~[a. 99510[ S-i ~14-25) · . '.r di a i ld !, ~-. s~... T.. ~.. ~.. (~o~t ~o~ 2608'N ~ 2495,~'fr.'SE"cr.SeCi26 . 1. . o~ . "T10N,'. R15W, SM · ' ' [ .250~W ~ ll00'N fr SE cr _.- .. . , ,. ' ,, , - ,, , .., [:. sec'..27,, T'tON, R13S,. $~ NTBU S-1 C14-26) For April, 1974:. RU 4-12-74. Tested' BOPE w/S000 psi; Killedlwel.1 w/filtered, inlet water' POH' and LD 4-1/2"' completion assembly. Cleaned'..out to PBD @ 10525".' Plugged' back f/10525-9788' w/250 sx G cement.- Tested hydril w/1800 psi fi rams w/3000 psi; Perforatedig-5/8'.: casing @ 8125.' w/4 JS. Set'. retainer~ 8-8075" ~ squeeZed'..p.erfs w/lBS sx cement. Perforated'@ 7900' w/4 JS. Set' retainer @-7804". ~'squeezed'..perfs w/200 sx' class G cement. Drilled.out cement ~..retainer tO'. 8061'. Cut- 70' window in 9-5'/8" casing f/7950- 8020'. Spotted':lTO sx cement kick off plug f/8060-7745'. Drilled'. out soft cement to 7990' after' waiting on cement 25' hours.' Plug unsuitable for kick off. Dril ling out cement on 5-1- 74. MAY ~ 6 I9'74 -...0,, 0. ~,. ,~ ,.....,... ,o, .~ .o,.......,.,,..o,,,.. 0, ,...,.,.. o, ....o,,......, oil and gas con=ervat{on commiffee by the 15~ of the succ~ding mon~, uflle~ otherwise directed. l~rm 1~'o, P--.4 ]%EV. a- I-?0 STATE OF .,.ASKA OIL AND GAS CONSERVATION CONU~ITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIOHS °,,* °" r-, W&LL wELL OT~! ~ N,a_X/E OF OP~TOI~ Atlantic Richfield Company ~ ADDP.~$'5 oF OPi:P. ATO~ SUBIV~TT ~ DUPLICATE %~ %~ ~muc~ CODE · 50-133-20158-01 6 LF~.SE DF-~:GNAI'[O.~ A.~D S~IAL NO. ADL '35341 . .~ ~.~ ~bbi,~ A~T~ o~ TRIBE ~AME ' "8. ~IT.F.~ O~ :'" ~orth ' Trading, B~7 'P. 0. Box 360,,,~c~,ora~e,' Al_aska. g9510 Conductor 5, Leg' 3,' Sp~E Platfom - 2608'N ~ 2495'fi'ir SE;'cr SeCl 26 'T10N~ '. Ri-3W,. SM : . . , ,, . . . . ~& LD 4-1/2" co~letion =sse~bly. Cie~ed. ou~ ~o' f/iO'523-9788' ~/250 sx G ce=en~. Tested hydril w/1800 psi i rams ~/3000 psi; Perforatedi9-5/8'.! casing @ 8125.'. -. w/4 JS. Set' retainer'. @' 8073" ~ squeezed'..perfs w/18S sx cement.- Perforated'@ 7900' w/4. JS. Set' retainer' @-'7804' ~ 'squeei~d~.perfs w/200 sx' class G cement. Drilled' out cement ~..retainer'. t0' 8051'. Cut 70' window in 9-518!' casing f/7950- 8020'. Spotted*:lT0 sx' cement kick off plug f/8050-7745'. Drilled*.out soft cement t°. 7990' after' waiting on cement 23' hours.' Plug unsuitable for kick off. Drilling out cement on 5-1-74. This constitutes notice of abandonment o£ original well.bore, prior to redrilling the well under another designation. UAY !, 6 I974 ~r~ry 4, 1974 74--5 Hr. B, T. Lo, Metal {k ~¢hor~, Alaska ~DIO Dear Sir-: E~'!.osed Is the approve~;..~H~lon for permit to drill the above refenmced welt oa ar abe~ t4areh t, t~974, at a location from the Spark Platform, Well sampl~ and are chips are not required. A directional survey Is required. Pollution of .a~¥ ~afers at tt~ State Is prohibited by AS 46, Chapter 03, ~lcle 7 ~-d ~ ~tafl~ p~t~ted ~.~~r (Title 18, Alaska ~ta~ed by e ~~f~l~ of t~ ~~nt of Envl~tal In fha ev~.t of suspeasl~ or aba~doa=t please glve this office adeq~ advaace notification so that we may have a wltness present. Very tr~ty yams, .? Homer L. Burrell Chelrean Alaska O! t and ~ Conser~ation ~t~tee Enclosure .cC' ~a-rtment of F~$h aad ~, Habitat Section v/o encl. AtlanticRichfieldCompany North Am¢~'~n Producing Division South Ala~ Jistrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 24, 1974 State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Attention Mr. Homer Burrell Gentlemen' Subject: Redrill North Trading Bay Unit Well S-1 Atlantic Richfield Company, as operator of the North Trading Bay Unit, requests administrative approval pursuant to Conservation Order No. 108, Rule No. 2, to redrill well S- 1 to a new upstructure location for recompletion in the "G" and Hemlock zones of the NTBU reservoir. Attached are the Application for Permit to Redrill the S-1 well, the $100 filing fee, and a plat showing the proposed redrill location. Well S-1 is presently producing about 70 BOPD and 1100 BWPD from the "G" and Hemlock formations and has been producing in this manner for several months. Our proposed plan to redrill S-1 to a new upstructure location will increase the ultimate recovery of oil from the "G" and Hemlock NE Oil Pools at North Trading Bay Unit. With respect to adjacent "G" and Hemlock completed wells, the S-1 redrill will encounter the Hemlock formation approximately 900' from producer TS-i, 1000' from producer S-8, and 780' from injector TS-9. Production will be from Alaska leases ADL 17597 and ADL 35431. We plan to commence operations to redrill NTBU well S-1 about March 1, 1974. We respectfully request your approval of this application at your earliest possible convenience. Very trqly yours, . B. T. Loudermilk District Drilling Supervisor BTL/LDS/sr kttachmen~s Porto P,~V. 9-~0-~/ STATE OF ALASKA SUBMIT IN TRIP~ .~T~ (Other instructions on reverse side) OIL AND GAS CONSERVATION ,COMMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK 1~. TYP~ OF WOrK DRILL [-1 DEEPEN [] PLUG BACK I~ b. Typm Or WiLL WELL WELL OTHER ZONE ZONE 2. NAME OF OPEI:~ATOR Atlantic Richfield Company 3. ADDRESS etv OPERATOR P. 0. Box 360, Anchorage, Alaska 99510 4. LOCATIONAt surface OF WELL Conductor 5, Leg 3 2608'N & 2495'W fr SE cr Sec 26, T10N, RiBW, SM At proposed prod. zone 250'W & ll00'N fr SE er Sec 27~ T10N~ R13W, SM 13. DISTANCE IN MILES AND DIRECTION FZCOM NEAREST TOWN OR'POST OFFICE* 28 miles NW from Kenai, Alaska APl, ,50-133-20 158-01 50-133-20158 6.I~E~SE DI~IGNATION AND S~J~L NO. ADL 35431 I. IF INDIAN, ALLO'z-r~:~: OR TRIBE NAME 8. UNIT~FARM OR LEASE NAME North Trading Bay Unit 9. WELL NO. s-1 (14-26) 10. FIELD AND POOL, OR WILDCAT Hemlock Prading Bay Field ~E 0il Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 27, T10N, R13S, SM 12. 68-103 14. BOND INFORMATION: Statewide Federal Insurance TYPE Surety and/or No. Co* 250 ' 18. DISTANCE FROM PROPOSED LOCATION' 19. PROPOSD D~PTH TO NEAREST WELL DRILLING, COMPLETEq), OR APPLIED FOR. ~. 780 ' 10,0~0~ ' + 15. DISTANCE FROM PROPOSED* LOCATION TO NEAREST PROPERTY OR LEASE LINI~., l~r. (Also to nearest drig, unit, if any) 16. NO. OF ACRES IN LEASE 320 21. ELEVATIONS (Show whether DF, RT, C-R, etc.) llS'RKB ~o~t $100,000 17. NO. ACRES ASSIGNED TO THiS WELL 80 20. ROTARY OR CABLE TOOLS Rotary 2~. APPROX, DATE WORK WILL START* March 1, 1974 23. P~OPOSED CASING AND CEMENTING PROGRAM , , SIZE OF HOLE SIZE OF CASING WEIGHT PER FOO~ GRAI3E SETTING DEPTH QUANTIT! OF CEMEN= , 8-1/2" 7" " 29# N-80 10,900' 400 sx Class G ~, / ~/' ~ e~ , , , , , Present Casing Program: 13-3/8" 61# J-55 set at 2802' 9-5/8" 47# N&P set at 10,580' TD 10,615' PRO 10~,198'(IvlD) See attachment for proposed operations.. rN ABOVE SPACE DI!ISCI~BE I~ROI~OSED PROGRAM: If proposal is to deePen or plug back, give data on present productive zone and proposed new productive zof~e. If Proposal is to drill or d~ePen direct Lonally,, give Pertinent data on s~bsurface locations and meastired and true vertical depths. Give blowout preventer program. 24. I hereb~q~y~e F~go~g i$ ~ .. ~rr~ ;. DATE, 1-24-74 rrr~i.st. Drlg. Supervisor (This space tor State office use) CONDITIONS OF APPI~3VA,L, IF ANY: SAMPLES AND CORE CHIPS R.EQ~ OTHER I~U~: [] YES ]~NO L DIZCTIONAL SURVEY YES [] NO A.P.I. NUMERICAL COD~ ,~'o - 1.55- Feb rua rv 4, DA~ 1974_ Feb ruary 4 ~ 1974 Attachment Redrill S-i, Spark Platform We plan to rig up over Conductor 5, Leg 3 Spark Platform on about March 1, 1974 and do the following work: le 3. 4. 5. 6. 7. 8. 9. Kill well w/filtered inlet water. Install BOPE, 3000 psi double rams and Hydril. Pull completion assembly. Clean out to PBD at 10,532'(MD). Spot cement plug 10532-9850~'. Perforate below K0P at 7975'+,~ Squeeze cement. Perforate 100' above KOP. Squeeze cement. Clean out below KOP at 7975'. Cut window in 9-5/8" casing. 10. Spot cement plug. 11. Drill cement to KOP at 7975'+. Test plug. 12. Directionally drill to a new upstructure location approximately 300'N and 700'W from the curren~ well bore Hemlock top. 13. Run DIL, FDL w/GR-Caliper. 14. Run and cement 7" 29# N-80 l£~er to TD at 10,900'+ (MD). Liner cemented w/400 sx Class G cement.~ 15. Clean out 7" liner to PBD. 16. Run CBL w/GR and collar 10cator. 17. Run single completion assembly. 18. Run production test and release rig. ~R'13w S UPBR IOR- TEXA CO 23 ARCO ' T ARCO 24 TRA DING BA¥ UN/T UN ION - MARATHON RK PLATFORM" I I I I I i ! , I 25 36 TTiO Nz.R:i2w': ARCO- S~)CAL 19 3O ATL ANTIC RICH FIE LDCOMPANY ALASKA DISTRICT WELL LOCATION MAP NORTH TRADING ..BAY · PROPOSED REDRILL S- I · SCALE I" = 2000' O~ JAN. 1974 ':~: Company /~, Z~-,' ~, ~ ._ Lease & Well No. CHECK LIST FOR NEW WELL PERMITS Yes No Remarks I. Is well to be located in a defined pool ................. ~ Do statewide rules apply ........................ Is a registered survey plat attached .................. I. Is well located proper distance from property line ........... 1. Is well located proper distance from other wells ............ i. Is sufficient undedicated acreage available in this pool ........ 4/~a~ Y. Is well to be deviated ......................... l~a~ Is operator the only affected party ................... Can permit be approved before ten-day wait ............... lO. Does operator have a bond in force ................... 1. Is conductor string provided .............. . ........ ~2. Is enough cement used to circulate on conductor and surface ...... 3. Will cement tie in surface and intermediate or production strings '.4. 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 17. Will all casing give adequate safety in collapse and tension ...... ~ · 18. Does BOPE have sufficient pressure rating ............... Additional Requirements-
