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Home My WebLink About169-039C~ Marathon MAM ®Alaska Production LLC May 28, 201Q ~'~~=~ Jl.i;~! '~~ `~ ~1~P; b-~~.~ Daniel T. Seamount, Jr., Commission Chair Alaska Oil & Gas Conservation Commission Attn: Jim Regg 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Alaska Asset Team P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/565-3076 RE~ElVE~ au~i a ~ znla Alaska oa ~ ~~ cam. Commission Anchorage ~~~~~ ~ Reference: Report on Disposal Injection Operations Well S-5, Spark Platform, North Trading Bay Unit ~~ ~ ~ ~ Well S-5 on the Spark platform of the North Trading Bay Unit is governed by Disposal Injection Order (DIO) No. 15, approved August 31, 1998. This report covers the final disposal injection operations for S-5 from January 1, 2009 until September 20, 2009, when the well was plugged and abandoned. S-5 has been shut-in for most of the reporting period. The only injection during 2009 was in August and September for a total of 1433 barrels, injected at a maximum pressure of 2250 psi. Attached please find an injection monitoring report and charts showing volume injected, maximum tubing injection pressure, inner annulus injection pressure and outer annulus injection pressure. Please contact me with any questions at 907-565-3043. Sincerely, ,~.~~~~~ Tiffany Stebbins Compliance Representative cc: M. D. Dammeyer Well file Houston file O O N O N W O O W O O O 1 /1 /2009 1/11/2009: I 1/21/2009 ! ! i 1/31/2009 2/10/2009 ~ ~ 2/20/2009 ! 3/2/2009 3/12/2009 ~~ 3/22/2009 !~ 4/1 /2009 ~ 4/11/2009 4/21/2009 ~ 5/1/2009 5/11/2009 ~ n 5/21/2009 ~ 5/31/2009 o . 6/10/2009 I ~ ~ ! ~ ~ 6/20/2009 m' ' ' ~ I 6/30/2009 n ; I 7/10/2009 '! ~ ~ 7/20/2009 7/30/2009 ~ 8/9/2009 . 8/19/2009 8/29/2009 ~~ ' ~ i 9/8/2009 _ i 9/18/2009 __ ____ ~ ;~ j5D 6 ~O tD i ,t! e0 iQ ~ ~ ~ ~ ~~ i ~ ~ }~- ~ O Q d ~ i8S f~ O i t~~n O t~~jt1~ © O t~~f1j~ Q O (~ty~y~ O f~ Q r,1~ d t~f~ 67 Q Jtt.~~~1 9 ~ ~ ~ '9 0 ~ ~ Q 4 G ~y N N N ~i O ~ ~ D r N c~"i y N ~ ~ rj yy 'J t,~ N ~ C b Q~~+ 'e ~ ffi~ ~ , L' O O O Q O O Q 0 G7 S3 Q d ~.? C3 O C) ~] 4 N 3 N H _ ~.. ?~ d ° ° ° ° W a °° a ewe ° w w ta ~ '" ° a ~ ~ C C7 i .. r .w}. ~ e`^ ,ti ..R ~ ~. .. ~ a ~ ~ op ~ y~ a Fa -u N ~ ~ w ~ ~ ~ w ~ O ~ ~ ~1 Gn ~. 4 A N .. ~~ S11 ~ ~ ~ O o D ~ ~ _ ~ m ~ ~ O Q ~ ~ n-. ~ O r r n • cfl m N O w O O O O N O O ~~ N 1 /1 /2009 1/11/2009 I , !, i 1 /21 /2009 1/31/2009 ~ 2/10/2009 i 2/20/2009 !~, i 3/2/2009 I { I 3/12/2009 I 3/22/2009 ~ ~ ~ 4/1/2009 I 4/11/2009 m 4/21 /2009 ' ! D 5/1/2009 ' j ~ y 5/11/2009 i s 5/21/2009 ~ ~ ~ 5/31/2009 ' } 6/10/2009 ! ~ ~ ~ `~ s ~ 6/20/2009 6/30/2009 y 7/10/2009. 7/20/2009: o' I I 7/30/2009: ~ ~ 8/9/2009 ' 8/19/2009 ~ I. 8/29/2009 ' 9/8/2009 9/18!2009 _- _ I!'_ ! __ ----- U~ O O (1 O N ~ O O N CJ~ O O O 1 /1 /2009 i 1 / 11 /2009 ' i 1 /21 /2009 ~ i 1/31/2009 i I 2/10/2009 ~ ~~ 2/20/2009 ' i 3/2/2009 , i 3/12/2009 ~ ~ i 3/22/2009 'i 4/1 /2009 i ~ 4/11/2009 ', ! i ~ 4/21/2009 ~,I ~ ~ 5/ 1 /2009 ; o 5/11/2009 j I 5/21 /2009 I, - i ~ `~° 5/31/2009 + I I I m ~ 6/10/2009 6/20/2009 ~ I 6/30/2009 i ~ ~~ ! 7/10/2009 • ~ . ~ 7/20/2009 ~ ~ i ~ l N i 7/30/2009 '~ ~ j 8/9/2009 ~ J i I 8/19/2009 ~ i 8/29/2009 - I I i 9/8/2009 ~, ! ~ 9/18/2009 i ~~ ~ ~ ~ ~ T. .-f ~ S O A~ ~ o D ~ ~ ~ ~ m ~ ~ O Q ~~ ~ O~ r~ r C7 c~ m W O W ~ sT~~~~ or- RE_~~~cR ~ OCT 1~~009 P,! P;SK~ L AND GF,S C:ORlSERVpTiC~f~i COMMiSS, ~ ~ - -~ ~ - ~ 1 CoQS. COm~nission ~~~~~ ~~~~~~~~ ~~~ ~~ ~~~~~~~~~~~~ ~ ~~ ~~~~ ~ ~~~~ `1a. Well Status: Oii ~ Gas ~ Plugged ~~ Abandoned ~ Suspended ~ 2oaAC2s.ios zona.czs.iio GINJ~ WINJ^ VdDSPL~ WAG ^ Other^ No. of Completions: ib. Well Class: ~ Development ^ Exploratory[~ Service ~• Stratigraphic Test^ ', 2. Operator Name: Marathon Oil Company 5. Date Comp., Susp., or Aband.: 9/20(2009 12. Permit to Dril~ Number: 169-039-0 ° 3. Address: P.O. Box 196168, Anchorage, AK 99519-6168 6. Date Spudded: 4/22/1969 13. API Number: 50-733-20186-00-00 ` 4a. Location of Well (Governmental Section): Surface: 2608' FSL & 2488' FEL, Sec 26, T10N, R13W, SM 7. Date TD Reached: 5/26/1969 14. Well Name and Number: N. Trading Bay Unit S-05 a Top of Producfive Horizon: 1514' FSL & 786' FWL, Sec 35, T10N, R13W, SM 8. KB (ft above MSL): 115 , Ground (ft MSL): 15. Field/Pool(s): G-NE/Hemlock-NE Oil • Total Depth: 1839' FSL & 598' FWL, Sec 35, T10N, R13W, SM 9. Plug Back Depth(MD+TVD): 85' below mud line Undefined WDSP .. 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 227762.198 ' y- 2534473.610 ~ Zone- 4 t~. Total Depth (MD + TVD): .. 11562 MD, 10259 TVD-~ 16. Property Designation: ADL018776 ~ TPI: x- y- Zone- Total Depth: x- 225472.593 y- 2530079.615 Zone- 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: 18. Directionai 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 aIl logs here and submit electronic and printed information per 20 AAC 25.071): 22• CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 13-3/8 61 K-55 0 2245 0 2073 18 1090 sks "G"/10% gel 400 sks "G" Neat tail 9-5/8 47 P110lN8o 0 11527 0 10127 12-1/4 1000 sks "G"/1%CFR-2 23. Open to production or injection? Yes ~ No Q If Yes, list each 24. TUBING RECORD interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2 600-11337 10796,11069 Bkr"F"pkr 11429 Baker "D" pkr 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 9/20/09 tagged TOC @ 85' BML 275-575 22 bbls, 109 sks 1.132 yd, 15.9 ppg "G" Neat 575 set CIBP 9/16/09 tagged TOC C~3 1972' RKB 2045-2345 25 bbls, 124 sks 1.132 yd, 15.9 ppg "G" Neat 9/14/09 tagged TOC Q 10440' RKB 10826-11397 squeeze perfs 25 bbls, 124 sks 1.132 yd, 15.9 ppg "G" Neat 26• PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24-Hour Rate ~..~ Oil-Bbl: , Gas-MCF: Water-Bbl: Oil Gravity - API (corr): 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No ^ Sidewall Cores Acquired? Yes ^ No ^ If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. ; :#,;: G Form 10-407 Revised 2/2007 CONTINUED ON REVERSE ~~~~~~~ ~~~ ~ ~/~/~~ ~~.Ti~'~ ~ ~;~- % G~- 2Z9 ~J ~ • • 28. GEOLOGIC MARKERS (List a~l formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ^ Yes ^~ No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top 0 needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base 0 Top of perf targeting G-zone G-2 10,826 G-4 10,926 G-5 10,974 Top of perf targeting Hemlock zone H-1 11,026 H-2 11,064 H-3 11,210 H-4 11,329 Formation at total depth: Hemlock H-4 zone 11,562 30. List of Attachments: summary of abandonment, final P&A wellbore 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 t Signature: Phone: 907-565-3043 Date: 10/13/2009 vv ~/ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion repor[ and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item ia: Classification of Service wells: Gas injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for /njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one intervai (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 Marathon Oil Company • • Page 1 of 2 North Trading Bay Unit no. S-05 API 50-733-20186-00-00, Sundry Number: 309-142 Work Summary 7/19/09 R/U pump hoses and open well. Tbg and 9-5/8" csg both were on a vacuum. Pump 50 bbls down tbg and pressure came up to 2500 psi on tbg & csg. R/U slickline with 3" gauge ring. Open well and pressure was at 0 psi. RIH w/ slickline & tag up at "n" nipple at 10756'. POOH. M/U 2.25" impression block and RIH to 10756'. POOH. Impression block appeared unmarked like sand or fill. M/U junk bailer. RIH w/ 1.75" junk bailer to 10756' and work through bridge and go down 20 more ft. to 10776'. Slickline was getting sticky. POOH from fear of getting stuck underneath fill. R/off lubricator and inspect bailer. Substance came out sticky, oily, and almost hard. Secure wells and equipment. 8/13/09 Open well to 0 psi and pump 8 bbls with the disposal well pump and pressure came up to 500 psi. After pumping 85 bbls and pressure slowly climbing, disposal pump quit working and pressure was up to 1950 psi. R/U P&A pump to well and disposal tanks and finish pumping 115 bbls @ 2 bpm @ 2200 psi. Pressure slowly fell to 0 psi in 1 hour. Recorded on chart. R/U slickline and start temperature survey with Pollard Wireline's tools. Out of the hole with first temperature survey. R/D slickline and secure well and equipment. 8/17/09 R/U pump hoses and test 13-3/8" csg to 500 psi and chart for 15 minutes. Good test. Note: Opened tubing to check pressure and it was on a vacuum. Performed maintenance on equipment and straightened up work deck while waiting on approval to proceed forward on remaining wells. 8/19/09 Marathon Oil Company submits an Administrative approval request to AOGCC to begin disposal of class II fluids. The well is currently authorized for disposal under Disposal Injection Order No. 15, but the well failed an MIT on 6/25/09. The AOGCC requested that we establish casing integrity. The well had a static pressure-temperature survey on 5/12/09 and a second one on 8/13/09 after pumping 200 bbls of cold water down the tubing. Ken Walsh of Marathon interpreted both surveys and determined that they "track each other very well ... that all the injected water exited into the perforated intervals below the packer located at 10,796' MD." 8/21/09 AOGCC issues Administrative Approval No. DIO 15.001 allowing Marathon to use S-05 to dispose of fluids during abandonment operations as long as stipulated conditions are met. Spark S5lnjection Monitaring Sheet Date Maximum Tuding Pressurc (PSq Maximum trtner Annufus Pressure (PSI~ Maximum t?uie€ Annulus Pressure (PSI) Tota11lolume injected {BP~} Cumuiative Yalume ~68Lsj ~t12212009 22~~ 22Q0 0 328 325 8P23C2Q09 225~ 2250 Q t38 463 arzarzno~ Q c~ a a ass &12512009 2250 2250 0 t2 4FS 8C2612009 2250 225Q E3 22 897 8J2712009 225fl 225Q D 243 740 $12812QQ9 225U 2250 ~ 72 812 812992009 0 €1 ~ 0 812 8l34t2009 225U 22~a ~ 1&6 978 8131d2t309 0 !1 D 0 978 9(it2QQ9 22at1 225U 6 9 887 912CZ~dl9 225U 2254 0 2!S 1283 9t312409 225t1 225Q 0 132 9335 91dt2~9 225t3 2250 Q 98 1433 91592QQ9 tk 4 U 0 9433 sr~naas o o €~ a ~asa 9fI12~9 fl ~ tl 8 1433 Totallnjecfed: 1433 ~ s , Marathon Oil Company Page 2 of 2 North Trading Bay Unit no. S-05 API 50-733-20186-00-00, Sundry Number: 309-142 9/13/09 Finished pumping away disposal fluids in well S-5. R/U cement equipment and materials. M/P 25 bbls, 124 sks of 1.132 yield, 15.9 ppg, ciass "G" Neat cement down tbg, injecting into the perfs, and displace TOC to10696' RKB. Pump pressure never exceeded 2200 psi and never did pressure up after hitting the perfs. Clean all cement equipment. Consolidate waste oil drums out of well rooms while organizing and cleaning platform and equipment. Secure platform and equipment. 9/14/09 Test bottom plug down the tubing to 3000 psi and chart for 15 minutes. Good test. Witnessed by Bob Noble with AOGCC. Test 9-5/8" X 4-1/2" 1000 psi and chart 15 minutes. Good test. Witnessed by Bob Noble with AOGCC. R/U lubricator with e-line. Ensure SCSSV is pumped open and test lubricator to 1000 psi. RIH with 2 ft perf gun @ 4 spf and tagged TOC at 10440' RKB. Reported to Winton Aubert with AOGCC and was given verbal approval to continue according to procedure on well. Pulled up to 2345' RKB & pressured up tbg to 500 psi & attempted to fire gun. Gun shorted out and misfired. POOH to fix gun but got stuck at SCSSV. Checked pressure on SCSSV which still showed 5000 psi on it. Functioned valve several times and still could not pass tools thru it. Ordered a hold open tool to slide down the wireline and open the valve. Tool will be delivered in the morning. 9/15/09 R/U and install tool in hole to hold SCSSV open. POOH with e-line. Out of hole with gun. Repair bad section of e-line. M/U gun. RIH with gun to 2045' RKB and pressure up tbg to 500 psi and shoot gun. Pressure fell to 0 psi. POOH to SCSSV. Raise lubricator and drop hold open tool. POOH with e-line. Circulate 180 bbls around to clean up well. R/U cement equipment and materials. M/P 25 bbls, 124 sks of 1.132 yieid, 15.9 ppg, class "G" Neat cement down tbg, taking returns out of 9-5/8" csg, displacing TOC to 2045' RKB, leaving a 300' cmt balance plug from 2345' to 2045' RKB in both the 4- 1/2" and the 9-5/8" x 4-1/2" annulus. WOC 9/16/09 Test tbg and csg intermediate plug to 1000 psi, charting each for 15 minutes. Both were good test. Jim Regg with AOGCC waived witnessing tag and test at 16:00 yesterday by telephone. N/D tree. Clamp bolts on tree were frozen up with rust. With clamps removed, attempt to remove tree but would not move. R/U e-line and discover short in e-line. Rehead e-line. M/U 4.5" tbe cutter and hold open sleeve for SCSSV and RIH and tag TOC at 1971' RKB. Pull up to 600' RKB and cut tubing. Tree ~ came off when tbe cut. POOH with e-line and lay down tree. R/U landing joint and handling tools and screw into hanger. POOH and L/D tubing. R/U e-line and M/U CIBP for 9-5/8" csg. RIH and tag top of tbg. Pull up to 575' RKB and set CIBP. POOH. N/U tree while M/U 2 ft perforating gun @ 4 spf for 9- 5/8" csg. 9/17/09 R/U e-line and RIH with gun to CIBP. Pull up 1 ft and attempt to pressure up to 500 psi. Well circulated back up the 13-3/8" csg at 2 bpm at 0 psi. Did not fire gun. POOH with e-line. Pump 7 bbls of dye and got the dye back at the return tank. Communication in 9-5/8" calculated to be at 54 ft. Report and then order packer which was found locally along with work string. Will be delivered tomorrow moming. 9/18/09 Offload workboat of work string and backload S-5 tubing. Tally pipe and packer. RIH with packer and set at 275' RKB. Test against CIBP to 500 psi. Good test. Release packer and POOH with packer and work string. R/U e-line and M/U 2 ft gun @ 4spf and RIH to 575' RKB and perforate 9-5/8" csg. POOH. RIH with packer and set at 275' RKB. Test against CIBP to 500 psi. Good test. Attempt to circulate but pressured up. Bleed off and POOH with packer and work string. R/U e-line and M/U 2 ft gun @ 4spf and RIH to 565' RKB (10 ft above last shot) and perforate 9-5/8" csg. POOH. R/U tree on welL 9/19/09 N/D tree. RIH with packer and workstring to 275' RKB and set packer. Attempt to circulate but cannot. Bleed to 0 psi. POOH with packer and workstring. N/U tree, BOP and 1-1/4" workstring and handling tools. RIH with1-1/4" workstring and tag TOC. Pull up 10 ft and R/U pump lines. Empty poly tanks below deck. R/U cement equipment. M/P 22 bbls, 109 sks of 15.9 ppg, 1.132 yield, class G Neat cement, spotting on top of CIBP at 575' RKB and leaving TOC at 275' RKB (100' BML). Pull 10 joints of workstring out of hole and wash off TOC. POOH with remaining joints of workstring. Clean cement equipment. 9/20/09 R/U wireline and RIH with 1-11/16" weight bar and tag TOC at 85' BML in the presence of Bob Noble with AOGCC. POOH and R/D wireline. R/D P&A equipment. Shut down. ---- ~ ~f~ Marathon Oil Company North Trading Bay Unit ~~p~~~~y Spark Platform Well S-5 ~' "FINAL P&A CONFIGURATION" RKB-MSL 115' All Depths measured RKB to top of equipment WATER DEPTH 60' All Depths are RKB unless otherwise noted TMD @ 11562' 9/20/2009 ND @ 10259' AOGCC Witnessed Tag TOC @~85' BML PBTD @ 11437' ~ ~ ~ ~~ ~ ~ ~ ~ ~ MASTP 10 psi MIT 5/12/09 ~ ` ~ ~~ , 9/16/2009 API # 50-133-20186 ~315' Surface CMT Plug ~575' RKB to ~260' RKB Conductor Pipe @ 436'_ M& Pumped ~22 bbls 15.9 ppg "G" CMT 20" Removed After Cementing 13 ~~;~° Displaced TOC to ~85' BML 9/16/2009 Pertorated 9 5/8' Casing @~575' RKB Set CIBP @ ~575' RKB Cut & Pulled 4~/2" Tubin From ~600' RKB Surface Casin~- @ 2245' 9/16/2009 13 3/a" 61 ppf K55 Buttress AOGCC Witnessed Tag TOC @~1972' RKB 12.451" ID .1521 bbl/ft . CMT 1090 sks "G" 10 °/o gel Lead 9/15/2009 400 sks "G" Neat Tail Returns to Surface -373' Intermediate Cement Plug 2345' RKB to 1972' RKB ~100' Below SCS ~273' Above SCS M& Pum ed 25 bbl 15.9 "G" CMT Production Tubing - 11337' 41/z" 12.6 ppf N80 Buttress 9/15/2009 3.958" ID .01522 bbl/ft Pertorated Tubing C~ ~2345' RKB 9/14/2009 ~ Ta ed Zone Plu TOC @~10440' RKB Baker "F" Packer @ 10796' 9/13/2009 Bottom Hole Cement Squeeze Plug OTIS "XO" SLIDING SLEEVE @ 10999' SS - M& Pumped ~25 bbls 15.9 ppg "G" CMT Displaced TOC to ~10440' RKB Baker "F" Packer @ 11069' TOC ~629' Above Packer "G" Pertorations G-2 10826' 10876' OTIS "X" NIPPLE @ 11178' ``X" G-4 10926' 10946' G 5 109 i 4' 10998' OTIS "N" NIPPLE @ 11273' II'~~,I, "N" ` HI'~~ EOT @ 11337' Il,l~ljl~, "H" Hemlock Perforations H 1 11026' 11056' Production Casing -1152T H2 11064' 11180' 9 5/s" 47 ppf P110 & N80 Buttress H3 11210' 11305' 8.681" ID .0732 bbl/ft . H4 11329' 11397' CMT 1000 sks "G" Neat CTOC @ 8213' Gauge Hole Calculations ~ ~ Baker Model "D" Packer @ 11429' PBTD 11437' TM D = 11562' MARATHON SPARK S-5 FINAL P&A CONFIGURATION PAGE 1 9/30/2009 ~ • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~~~, ~ti~~,~ ~~~ DATE: Sept 14, 2009 P. I. Supervisor ~ ~ I ~ FROM: Bob Noble SUBJECT: Well Abandonment Petroleum Inspector NTBU S-5 Marathon Oil Corp q,,v/1~{t!1t PTD 169-039 y y,~ppp~ ppm`~~..., .~~i`~^1 ~i ~p, `U LVLl~ Y~i ~.?~ts~~'{."' V'..-e..+~t l 5~ f Sept '14, 2009 I traveled to the North Trading Bay Unit (NTBU) Spark platform and met with Marathon Oil rep Dan Byrd. Dan notified me that Proserv Offshore had mixed and pumped 24 barrels of Class G Neat cement, and had squeezed it into to the perfs at 10826' to 11397' RKB. (Not witnessed). I witnessed a 15 min, 3000 psi pressure test on the tubing and saw 0 psi loss in pressure. I witnessed a 15 min, 1000 psi pressure test on the IA and saw 0 psi loss in pressure. Proserv Offshore rigged up and ran in to well to tag the cement. TOC was found at 10440' RKB. TOC was 256' higher than expected. Dan Byrd was concerned with the height of the cement so he called AOGCC Sr. Petroleum Engineer Winton Aubert to get an approval to proceed with the procedure. Sept 20, 2009 I traveled back out to the Spark platform and met with Marathon's rep Dan Byrd. Dan notified me that Proserv Offshore had set a bridge plug at 575' RKB. They had then mixed and pumped 22 barrels of 15.9ppg Class G neat cement on 9-19- 09. (Not witnessed). I witnessed Proserv Offshore rig up and run into NTBU S-05. TOC was found to be at 195' wireline measurement, placing the plug 80' below mudline. Summary: I witnessed successful verifucations of abandonment plugs in NTBU (Spark platform) Well S-5. • MEMORANDUM TO: Jim Regg P. I. Supervisor j~ FROM: Bob Noble Petroleum Inspector Sept 14, 2009: State of Alaska Alaska Oil and Gas Conservation Commission DATE: Sept 14, 2009 SUBJECT: Well Abandonment NTBU S-5 Marathon Oil Corp PTD 1 fig-039 I traveled to the Spark platform and met with Marathon Oil Rep. Dan Byrd. Dan had notified me that Proserv Offshore had mixed and pumped 24 barrels of class G Neat cement, and had squeezed it into to the perfs at 10826' to 11397' RKB. (Not witnessed). I witnessed a 15 min, 3000 psi pressure test on the tubing and saw 0 psi loss in pressure. I witnessed a 15 min, 1000 psi, pressure test on the IA and saw 0 psi toss in ~ pressure. Proserv Offshore rigged up and ran in to well to tag the cement. TOC was found at 10440' RKB. TOC was 256' higher than expected. Dan Byrd was concerned '~ with the height of the cement so he called Winton Aubert to get an approval to proceed with the procedure. Summary: Attachments: none ~,~-~. Aband, Marathon, NTBU S-5, 9-14-09, BN.doc • • ~ ~ ~~s ~ ~.: ~~~.. ~~ ~ 4.~ ~ ~~~ r .:~ ,:~ ~ _ ~ ~~~~ ~ ~ ~~~ ~ ~ ~~ ~~~ 9 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~ ~ ~, ~ SEAN PARNELL, GOVERNOR ~g ~~ ~_~ ~ ~. ~ ~~ ~~~ ~ ~~ ~~ -~ ~-78~ ~~ olsa/ vt~--.7 333 W. 7th AVENUE, SUITE 100 COI~TSERQATIOI~T CO1~II~IISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Tiffany Stebbins Regulatory Compliance Representative Marathon Oil Company PO Box 190168 J b~ Anchorage, AK 99519 1 ~ ~ ~ Re: G-NE/Hemlock-NE Oil, Undefined WDSP, North Trading Bay Unit 5-05 Sundry Number: 309-142 ~~~ t . T~.~.J. ~ ~~' .. .. ' . .. . Dear Ms. Stebbins: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair c~~ DATED this < day of September, 2009 Encl. STATE OF ALASKA ,(~ ALAS IL AND GAS CONSERVATION COMMI~N ~ ~ p`• APPLICATION FOR SUNDRY APPROVALS 9(1 AA( 9~ 9A(1 ~ `~ ~ ~ ~~/Ei~ . ,. , . ~ 2009 . ... , . r"*,..... f wenmieeinn 1. Type of Request: Abandon Q' Suspend ^ Operational shutdown ^ Perforate ^ Waiv~r~~~~~e Other ^ Alter casing ~ Repair well ~ Plug Perforations ^ Stimulate ~ Time Extension Change approved program ~ Pull Tubing ~ Perforate New Pool ~ Re-enter Suspended Well ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Marathon Oil Company Development ~ Exploratory ~ 169-039-0 • 3. Address: Stratigraphic ~ Service ~. 6. API Number: P.O. Box 190168, Anchorage, AK 99519-6168 50-733-20186-00-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: N01"th TI'ldltlg Bay Ulllt S-05 . Spacing Exception Required? Yes ^ No ^ Spark platform 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL018776 • RKB-MSL 115' G-NE/HEMLOCK-NE OIL; UNDEFINED WDSP ~ 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): 11,562' 10,259' • 11,439' • 10,152' Baker "D" pkr 11,429' Casing Length Size MD ND Burst Collapse Structural Conductor Surface 2,245' 13 3/8" 2,245' 2,073' Intermediate Production 11,527' 95/8" 11,527' 10,127' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,826 - 11,397' 9,796 - 10,116' 4 1/2" 12.6#, N-80 Buttress 11,337' Packers and SSSV Type: Camco TRB-6 SCSSV Packers and SSSV MD (ft): 261' Two Baker model "D" permanent packers 10,796 & 11,069' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ~ Exploratory ^ Development ^ Service ^~ . 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: Oil ~ Gas ^ Plugged ^ Abandoned Q• 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ~ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tiffany Stebbins Printed Name Tiffany Stebbins Title Regulatory Compliance Rep. Signature Phone Date ` 907-565-3043 -~~ ~'0 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~~ "~~p~ Plug Integrity [I~ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other: / ~~ ~ ~ ~ ~~ ~t~-'^~, eern~..~- P.~~:t~ ~~`i[r~P' iS G,..^<!J`~a/e_~J.~S' . ,~~,~ ~ o .~I~C'" 2 J, ~~Z ~~J Subsequent Form Required: /~ - (,~ O ~ ~ ~ ~ ~ ~ ~ ~ APPROVED BY ~~~! ~~ ~ ~ Approved by: COMMISSIONER THE COMMISSION Date: ~ Form 10-403 Revised 06Y20d6 " ' ~~~='~~ ~~~ ~ ~~ ~. w~ Z~~~ ~2'~~ /~ ~ ~ ~ Submit in 'c~~~ • • MARATHON OIL COMPANY NORTH TRADING BAY UNIT SPARK PLATFORM WELL S-5 TEMPORARY ABANDONMENT PROCEDURE 03/31/09 WELL DATAAPI# 50-133-20186 Elevation: 115' RKB - MSL Nipple: OTIS "N" NIPPLE @ 10,756' Water Depth: 60' 3.725" ID Totai Depth: 11,562' Surtace Casing: 13 3/s" 61 ppf K55 Buttress @ 2,245' Packer: Baker "F" packer @ 10,796' 12.451" ID, .1521 bbl/ft Baker "F" packer @ 11,069' Production 9 5/a" 47 ppf N80 Buttress @ 11,527' Pertorations: G-2 @ 10,826' - 10,876' Casing: 8.681" ID, .0732 bbl/ft G-4 @ 10,926' - 10,946' G-5 C~ 10,974' - 10,998' Tubing: 4~/z" 12.6 ppf N80 Buttress @ 11,337' H-1 @ 11,026' - 11,056' 3. 958" ID, .01522 bbl/ft H-2 @ 11,064' - 11,180' H-3 C~ 11,210' - 11,305' SCSSV: Camco TRB-6 SCSSV C~ 261' H-4 C~ 11,329' - 11,397' PBTD: 11,429' CURRENT STATUS The well has no further utility and is to be temporarily abandoned 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 tree valves and flanges. Repair as needed. 2. Mobilize abandonment crew and equipment to location. Perform JSA and rig up equipment. 3. Check tubing and casings for pressure. Bleed off through gas buster. Fill and test casings with weighted fiuid. Record results. 4. Perform JSA for proper slick line operation. Pressure up on SCSSV control line and lock open. Rig up slick line lubricator and test to 1500 psi RIH with gauge ring to "X" Nipple at 11273' pull wire line plugs as needed. POOH. 5. PerForm JSA on pressure pumping. Rig up pump and pump lines on tubing. Test pump lines to 1500 psi. Establish an injection rate and record results. Monitor 9 5/s" casing pressure for possible communication. ~-d 3 6. Perform JSA on mixing cement. Mix and pump ~5 bbls of cement and squeeze perforations. Squeeze to 1000 psi over injection pressure or until cement is displaced to a depth of 10726' RKB. 7. WOC and test to 1000 psi. Record results on a continuous pressure chart recorder. Spark Well S-5 Page 1 4/17/2009 • • 8. 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 to top of bottom hole cement plug @ 10726' RKB and record results pick up to 2345' RKB and fire guns. POOH. 9. PerForm JSA for cement mixing and pressure pumping. Rig up cement pump and lines. Test lines to 1500 psi. Break circulation down the 4 1h" tubing taking returns up the 9 5/a" casing annulus. Mix and pump 21 bbl cement slurry for a 300' intermediate cement plug from 2345' RKB - 2045' RKB in the 4 1h" tubing and the 4 1h" X 9 5/a" casing annulus. Displace with weighted fluid. 10. WOC and test to 1000 psi. Document results using a continuous pressure chart recorder. 11. Perform JSA on electric line operation and explosive handling. Rig up electric line lubricator and test to 1500 psi. RIH with 4 1h" jet cutter and tag Intermediate cement plug @ 2045' RKB and record results. Pick up to 600' RKB and cut the 41/2" tubing. POOH. 12. Rig down tree. 13. PerForm JSA for proper pipe handing procedures. Pull 4 1h" tubing and check for N.O.R.M. 14. Perform JSA for safe electric line operation and explosive handling. RIH with 9 5/s" gauge ring and tag top of tubing stub at ~ 600' RKB. POOH. 15. RIH with 9 5/s" CIBP to 600' RKB, pick up to 575' RKB and set. 16. RIH with perforating gun armed with 2 ft of 4 SPF casing punch, tag CIBP @ 575' RKB and fire guns. POOH. Rig down electric line. 17. 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/a" casing and up the 9 5/s" casing with weighted fluid. Mix and pump 41 bbl cement slurry for a 300' cement plug in the 9 5/s" casing and the 9 5/s" x 13 3/s" casing annulus from 575' - 275' RKB. B) If unable to circulate the 9 5/a" X 13 3/s" casing annulus, RIH with work-string to CIBP, Pick up work- string 10' and displace a 22 bbl slurry for a 300' cement surFace plug from 575' - 275' RKB in the 9 5/s" casing only. 18. Pick up work-string 20' above TOC @ 275' RKB and circulate work string clean. POOH. 19. WOC. PerForm JSA for wireline operations. RIH with Blind Box and tag TOC @ 275' RKB and record results. POOH. 20. RD. Well is temporarily abandoned. Spark Well S-5~ Page 2 4/17/2009 ~ 1MIARATH~M :-1 RKB-MSL 115' WATER DEPTH 60' TM D C~ 11562' TVD C~ 10259' PBTD @ 11437' MASTP 10 psi MIT 5/12/09 API # 50-133-20186 Conductor Pipe C~A 436' 20" Removed After Cementing 13 3/a" ~ • Marathon Oil Company North Trading Bay Unit Spark Platform Well S-5 "CURRENT" All Depths measured RKB to top of equipment All Depths are RKB unless otherwise noted Surtace Casing - C~ 2245' 13 3/a" 61 ppf K55 Buttress 12.451" ID .1521 bbl/ft CMT 1090 sks "G" 10 % gel Lead 400 sks "G" Neat Tail Returns to Surface Production Tubing- 11337' 4 lh" 12.6 ppf N80 Buttress 3.958" ID .01522 bbl/ft Baker "F" Packer @ 10796' OTIS "XO" SLIDING SLEEVE @ 10999' Baker "F" Packer @ 11069' OTIS "X" NIPPLE @ 11178' OTIS "N" NIPPLE @ 11273' Production Casing- 11527' 9 5/s" 47 ppf P110 & N80 Buttress 8.681" ID .0732 bbl/ft CMT 1000 sks "G" neat CTOC @ 8213' Gauge Hole Calculations Camco TRB-6 SCSSV @ 261' "G" Pertorations G-2 10826' 10876' G-4 10926' 10946' G-5 10974' 10998' "H" Hemlock Perforations H 1 11026' 11056' H2 11064' 11180' H3 11210' 11305' H4 11329' 11397' EOT @ 11337' Baker Model "D" Packer @ 11429' PBTD 11437' Marathon Spark S-5 Current Page 1 612/2009 TMD = 11562' ~ ~ ~ Marathon Oil Company North Trading Bay Unit MAR.A~T11€3M Spark Platform Well S-5 -. °PRCIPC1RF11° RKB-MSL 115' WATER DEPTH 60' TMD C~ 11562' ND C~ 10259' PBTD C~3 11437' MASTP 10 psi MIT 5/12/09 API # 50-133-20186 Conductor Pipe C~ 436' 20" Removed After Cementing 13 3/s" Surtace Casing - C~ 2245' 13 3/s" 61 ppf K55 Buttress 12.451" ID .1521 bbl/ft . CMT 1090 sks "G" 10 % gel Lead 400 sks "G" Neat Tail Returns to Surface All Depths measured RKB to top of equipment All Depths are RKB unless otherwise noted D' Surtace CMT Plug C~? No More Than 100' BML 9~/e"and95/8°X133/e°=-41bblSlurry 9 5/e" only =~22 bbl Slurry -575' RKB to ~275' RKB / 100' BML Max Perforate 9~/s" Casing C~ --575' RKB ~ ~575' RKB Cut & pull 4~/2° Tubin From ~600' RKB ~300' Intermediate Cement Plug 2045'RKB-2345'RKB --100' Below SCS -200' Above SCS 25 bbl 15.9 pp "G" CMT Production Tubing- 11337' 4 ~h" 12.6 ppf N80 Buttress 3.958" ID .01522 bbl/ft Baker "F" Packer @ 10796' OTIS "XO" SLIDING SLEEVE @ 10999' Baker "F" Packer @ 11069' OTIS "X" NIPPLE @ 11178' OTIS "N" NIPPLE @ 11273' EOT @ 11337' Production Casing - 11527' 9 5/8" 47 ppf P110 & N80 Buttress 8.681" ID .0732 bbl/ft CMT 1000 sks "G" Neat CTOC @ 8213' Gauge Hole Calculations Bottom Hole Cement Squeeze Plug TOC ~130' Above Top Perfs MIN Mix & Pump ~25 bbls 15.9 ppg "G" CMT Displace TOC to ~10696' RKB Pollard WL RIH w/ 3.30" OD Gauge Ring 6/23/2009 tagged fill ~ 10835' "G" Perforations G-2 10826' 10876' G-4 10926' 10946' G-5 10974' 10998' "H" Hemlock Perforations H 1 11026' 11056' H2 11064' 11180' H3 11210' 11305' H4 11329' 11397' Baker Model "D" Packer @ 11429' PBTD 11437' Marathon Spark S-5 Proposed Page 1 6/12/2009 TM D = 11562' ~ • Ataska Asset Team Marathon MUIRATAON ~ Alaska Production LLC Anchorage,~A 99519-6168 {~~ ~' ~ l ~ ~ ~ ~1 Telephate 907/561-5311 Fa~t 907l565-3076 August i 9, 2Q09 Mr. Guy Schwartz Alaska Uit and Gas Conservation Commission 333 West 7m Ave, Suite 1~0 Anchorage, AK 99501 Re: Disposal Injection Order No. 15 North Trading Bay Unit Spark Plat#arm Weil No. S-5 ~ k ~ ~ i ., _ . ~ ~) 4„~ `,' . r_v s Y.~ 4 v~' aJf w~r i. -. De~r Mr. Schwartz: Marathon Alaska Production, LLC (Marathon) would like administrative approvai to begin disposal of Class it fluids down Spark well no. S-5. S-5 is currentfy authorized for disposal under Disposal Injection Order No. 15, but the weli failed an M!T an 6/25/09. Diagnostics were run on S-5 June 25-26 and discussed with AOGCC. Summary is as follows: • On June 25, 2009 the well S-05 (DIO #15) had a WRP set at 10,800', weN was filled with fluid and both the tubing string and IA were pressured up to y 65Q psi. The OA gauge was at 0. During the pressuring up af the tubing and IA,the OA pressure remained static.~Throughout the entire process, 13-3/8" outer annulus pressure remained unaffected. • On June 26, 2009 personne( reported both the tubing and IA had bied down to 0 psi. After further diagnostics, it was determined there is commun~cation between the 3-1/2" tubing and 9-5/8~ casing and possibly a packer leak. • Shared results with AOGCC on June 26. It was our understanding that we could not use S-05 until further diagnostics have been performed. It was afso our understanding we were permitted to use the S-4 but after approximately 200 bbls had been injected; we were required to run a PT survey. Results of the survey were good and permission was granted to continue using S-4. After approximately 948 bbls injected into S-4 the perfs piugged up. We requested approvaf #o reperf G2 aone from 4594-4624' and 46544684'. We had na success with the reperf. The well would no longer take fluids. On 8111/09 we requested AOGCG approval #o use S-5. Approval was granted on 8/12/09 to run a PT survey on S-5 after pumping 200 bbls of cold fresh water down the tubing. A PT survey was completed 8/13/09. Ken Walsh, Sr. Production Engineer for 11Aarathon, has reviewed the data and piot overlay of the static pressure-temperature surveys recorded 5/12/09 and 8/13J09, and has interpreted them as foilows: ~ . `The survey on 5/12/09 was taken after a long shut in period. The survey taken on 8/13/09 was recorded shortly after pumping 200 bbls of cold wa#er down the tubing. The character and trend of the two pressure and temperature sun+eys track each other very well with the exception of the temperature signature that shows a sharp cooling trend fram about 10,500' • • Marathon Alaska Productfon, LLC Disposal Injection Order No. 15 North 7'rading Bay Unit no. S 5 to the tag depth of 10,776' MD. ft is in#eresting ta note that there is a gas iift mandrel placed at 10,502' MD. It wouid be incorrect to assert that the fiuid pumped on 8/13/09 exited this mandrel as there is no indica#ion o# the e~ected temperature profile bend back to normai gradient abave this mandrel. Therefore, it is my interpre#ation #hat alf of the injected water exited into the perForated intervals below the packer lacated at 10,796' MD. This is consistent with the cooling trend exhibited afi the bottom of the log." With casing integrity verified, +njection fluids entering into the perforated zones, and no upward migration of fluids behind cement, Marathon would tike administrative approval to begin drsposing of Class !! fluids under the follawing guidelines: f) We will follow the stipu(ations of DIO No. 15. 2) We have a documented pressure test on the 13-318" outer annulus of 53fl psi on August 17, 2009. 3) We will man the well i00% of the time during injection operations. If there is any evidence of communication with the 13-3/8u outer annulus, operations will be shut down immediately and notification will be made to the AOGCC. 4) We anticipate injecting approximatefy 2400 bbls of Class II fluid in suppart of ongoing P&A operatians on the Spark Platform. 5) Monitar operating parameters including tubing pressure, annular pressure and record fluid volume. 6~ We will plug and abandon S-5 at the end of our P&A effarts. ~) We anticipate abandonment operations to be complete by October 7, 2009, If you have any questions, p(ease contact me at 907-565-3043 or by emai! at tastebbi ns ~ marathonoil.com. Sincerely, Tiffany Stebbins Regulatory Compliance Representative cc: L.lbele G. Laughlin T. Paxton K. Walsh Page 2 of 2 DIO 15 - Marathon Spark S-5 . Schwartz, Guy L (DOA) From: Regg, James B (DOA) Sent: Wednesday, August 19, 2009 5:14 PM To; Schwartz, Guy L(DOA); Aubert, Winton G(DOA) Subject: RE: DIO 15 - Marathan Spark S-5 Approval conditions need to include: Page 1 of 2 ~ ~ ~~~~~~ 1) continuous manning during injection; pressures (injection; all annuli) recorded every 30 minutes (?) 2) statement about SI if any indication of pressure communication or leakage to OA; might even set a pressure threshold for OA (much less than 500psi test) 2) weekly summary of injection to include TIO plot, volume-pressure plot, total volume injected, and any anomalous conditions and pressure bleeds Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99507 907-793-1236 From: Schwartz, Guy L (DOA) Sent: Wednesday, August 19, 2009 3:44 PM To: Aubert, Winton G(AOA); Regg, 7ames B(DOA) Subject: FW: DIO 15 - Marathon Spark S-5 Any comments?? ... this would only be a temporary approval as the well will be P& A'd soon. I concur with Mr. Walsh that the temp profile overlay shows fluid exiting below the packer. I can write up the AA letter for them tomorrow unless you guys see something that needs changing. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 From: Stebbins, Tiffany A. [mailto:tastebbins@marathonoil.com] Sent: Wednesday, August 19, 2009 3:08 PM To: Schwartz, Guy L (DOA) Subject: DIO 15 - Marathon Spark S-5 Hi Guy, I've revised the administrative approval request to use Spark S-5 after MIT failure. Please let me know if I've captured all #he necessary information the AOGCC witl need for their discussions. If ok, I wiU drop ofF the ariginal today to you. «DIO 15 AOGCC Approval to dispose 8-19-09.ZIP» 8/20/2009 ~TD /(y`(-o3`~ 1000 2000 , 3000 4000 d 5000 ~ v Z ~ a o sooo , ~ooo, 8000, 9000 ' 10000 1100 ~ooo I, Pressure-Temaerature Profile 1 Going in hole OVERLAY 2. 8-13-09 vs 5-12-09 ; I ' I I - -- ~ ~i ~ ' - - - I - _ i - . = ~ -_ - ~ ~ ~ ~ ~ ~ - _ _ _ _ - _ - ---- -- - -- __ _ ___ _ - ~ - - - -- - _ , ~ --- t • i ' 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 Temperature (Deg. F) ~ Pressure - PerFs 6°x°° 13 3/8" ~ 9 5/8 TBG • GLM Psia 5-09 Temperature - -Temp 5-09 Pressure (psia) 1500 2000 2500 3000 3500 4000 4500 ~~ ~~ ~ - ~3 `~ Marathon Oil Well: S-5 Field: Spar 05-12-2009 1000 2000 3000 4000 ~ 5000 ~ d ~ ..~ t ~.+ ~ 6000 0 7000 ~ 8000 9000 10000 11000 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" TBG • GLM Temperature I 0 0 400 Pressure-Temperature Profile 1 Going in hole to 10725' MD ~ ~ 2. UVell Shut-In , F ~ ~ - ~ - - .__ - ~F C k - - ~ ~ Y - Pressure (psia) 800 1200 1600 2000 2400 2800 3200 3600 4000 i M MARATHON Marathon Oil Company Al~ska Asset Team Spark S-5 North Trading Bay Unit Pressure-Temperature Sarvey ~ ~-1~ 1~9-03~ Objective: Run PT (Pressure / Temperature) survey after pumping about 200 bbls of cald fresh water down the 4-1/2" production tubing to confirm integrity of the tubing and ensure injection is entirely into the open "G" Sand perforations. History: On 7/19/2009, tagged at 10,756' with a 3" OD gauge ring and a 2.25" OD impression block (unmarked). Ran a 1.75" OD junk basket 20' deeper on the same day to 10,776' recovering "sticky" fill. Procedure: 1. Hold safety meeting with Pollard slickline contractor, pump operator, and platform workers. 2. Note and record static surface tubing pressure on production tubing. 3. MIRU pump lines to pump fresh water down production tubing. Pressure test pump discharge lines to 3000 psi m~imum. Set maximum injection ~ressure limit to 2600 psig. 4. Open well and pump about 200 bbls of fresh water below 64 degrees F tempera.ture down the wellbore at no more than 2 bpm rate. Shut down and monitor pressure falloff for 3 hours. This will also a11ow a better differentiation in the temperature profile to determine where the fluid is exiting the tubing and wellbore. 5. While waiting for the falloff, MIRU Pollard slickline unit with depth encoder. 6. Pick up and make up memory 1-1 /4" Tandem Pressure-Temperaiure gauge, 5' of 1- i I2" stem, 1-1/2" oil jars, and 10' of 1/1!2" stem to rope socket. Pull tool string into lubricator. Take lubricator to tree and make up to top of swab valve. 7. Pressure test lubrica.tor with fresh water fluid to 2500 psig. Bleed off pressure and open well again noting surface pressure. 8. RIH to 0' RKB (Tubing Hanger). 9. Record surface pressure / temperature bench for 5 min. 10. RIH logging at 60'/min to Iast ta.g depth of 10,756'. 11. Stop 10 min and record P/T bench. 12. Log up at 60'/min to surface. Record another 5 minute bench at surface. 13. Shut in well and wait for one hour. Repeat Steps 9 thru 12. 14. POOH and lay down tools and lubricator. 15. Rig down unit. Note and record final surface pressure with gauge. Close permit and release crew. 16. Send in gauge data immediately to John Butler at Pollard with instructions for quick processing and distribution af the data.. Data, to be emailed to Ken Walsh and Todd Paxton at kdwalsh(a~marathonoil.com and tpaxton(a~marathonoil.com . Ken Wa1sh 907-283-1311 (office) 907-394-3060 (cell) Todd Paxton 907-394-1322 (cell) . ~ Report Date: 7/19/2009 Well # S- 5 RD Day 28 B ~~ PROSERV OFFSHORE ~ DAILY ACTIVITY REPORT & COSTS ~ Proseru Proj Team Leader: Jeff Thompson Field Sup.: PIC Site: Todd Paxton PLATFORM: Spark Cost & Activity Date: 7/19/2009 PROJECT NUMBER: 29052-21 WELL NUMBER: S- 5RD PROJECT: Marathon Oil Co. - P&A TlME LIESCRIPTION OF AG?IYIT'IES ` 12:00 R/U pump hoses and open well. Tbg and 9-5/8" csg both were on a vacuum. Pump 50 bbls down tbg and pressure came up to 2500 psi on tbg & csg. 12:30 R/U slickline with 3" gauge ring. 13:30 Open well and pressure was at 0 psi. RIH w/ slickline & tag up at "n" nipple at 10756'. POOFI 14:30 M/U 2.25" impression block and RIH to 10756'. POOH 15:00 Impression block appeared unmarked like sand or fill. M/U junk bailer . 15:30 RIH w/ 1.75" junk bailer to 10756' and work thru bridge and go down 20 more ft. to 10776'. 16:30 Slickline was getting sticky. POOH from fear of getting stuck underneath fill. 17:00 R/off lubricator and inspect bailer. Substance came out sticky, oily, almost hard. 17:30 Secure wells and equipment. 18:00 Shut down for the day. Work Scope for 7-20-09 S- 5 Progress forvvard depending on orders from office. S-2RD Test cmt on top of CIBP, Test both tbg and csg. S-3 Perform well diagnostics. N/D tree and RIH with CIBP in 9-5/8" csg. CREW NAME HOUR5 CREW NAAAAE HtWRS Jeff Thompson 6 Randy Lafleur 6 Gene Hess 6 Mathew Boudreaux 6 Cyprian Ukudi 6 Page 1 of 2 LaughFin, 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 ~ Attaahments: Picture (Enhanced Metafile}; Picture (Enhanced Metafile) ~;~ ~.~~. '{~.? _.s, . ..a, , ._. t.YSi~•~: r~'..~•i_:f `.:i` From: LauqhAn, Gary A. Sent: Monday, May 18, 2009 8:21 AM Ta: (winton aubert@admin.state.ak.us) Cc: Lauqhlin, Gary A. Subiect: Conv~rsatlon Follow-up Importance: Hiqh Sena~itivity: Confidentiai i Wihtoll, This is a fallow up to ou~ conversations May 13th and May 14th, 2009. All Weils • It is my understanding you will be checking to see if you can strike the phrase "temporarily abandoned" in each well abandonment procedure and replace it We are currently running a gauge ring and temperatu~e 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 ta have simultaneous well abandonment operations. The only cer#ainty 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). with "permanently abandoned" for the Spark Platform sundries submitted in April 2009. ~ (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 diameter casing string; f~dt«rc~t~~vrr UII Cc~rn~~ny i~oK?I± 7r~;iFltr~ 8ny L1ttRE ",~„' •, ~ ,~ ` i 5~~rk Pi~Mf~rm 1"leii ~-~ _ ; ~~ Pfi~1 pOSki~~~ Rk6-NISL 11a' M'ut4* tJ~:{~1~r GL' "~!ux ruw~fs - ~~ . ~ 3576 ~ 3329' i.'i li;?~lti 5~"7'+#I~. °i ~+'W.:t i!_~, .,~ I~.bili. ~~;'1 ~,'t~~~.~:f.'1 ~~r~p,11~~PxR~i.lhC~r..:.riy . .,~.i r~ L A~! +i ~0• i 33-2D2~5 S ri~ir~; ?i;x: ~t?T?:}- ':,~ ~ , ~,~' P.~.(i w' ,~! < ::.w..:>+' i i'~~, 1' C-s~ k~'~I~'' __.. __ _ . . _._. , . .~i~~ ~ ~1'ar.h C;eT~Hn: N!i:F H~r.• n: ~;r;~ ~ '~fr`" ~e b I6' (~~.C! ~,; ~.h~.x 1;s ~~• ~;~ ~a,~ = '~e" ar~ Ip' - I,e ~';r13 •.'~'~ 1tkL! ~l5'?aKii ~i:'= F~t'37'~, RK7 If Part B online line 17(example is from the 5-09 Sundry), is unsuccessful the a"top job" will be performed. This step exists on all Sundries but line number may vary. .~i . Nl:l'•.r~~f- .I.:.- .~ . 1.-~~ . ~'I ~ I~I_Y, t+~'i':I ~.I~.:~'~.I , ..1, ::.~f~c;. C!~ S'~.~ ~.r.~ i~..,~ ~r YS. .-s~t ~I(1W51fi ( .~Jf.~ , ~~:d. F~`R?~ 7 ,.:?~;"_=~~5.,. .. ,. ~1 I 1 -.. :tl(.~ ~ .i-::'~rl I ll= l.ti ~~ . . ;.9Y~~, uH3~~~ ,L L Il. St' . , c.-:fl,+~ Y7~1 t ~tx:ii~t1"..:4 .~ !.'~?.1. ~~_, ~~;,.1 ~51:I1~f ~a ~ '!'.~. . . . , "~•'}r~11 ' I I'Ir 1'c. ,; ~ 11 .". 7t: ;);~i; f . : :''tM ' . h .~..` ~4~ f,'„'1' . ::~ , ,. . ~.,. .. :t~:>C~;~ :r .. ~ ~ e:it:h ~ ~~ ~i'~'t,l ~ F!:,;P. 2,r.,• ft^...,. 1;3 I` ~_I s1.le~ In ., i,l~'<~ rne,.';7 ,a '. 1~ '. , .~..ci~; ~i'i'i.l~ia5,-':':. ti~if~fs~ .vr,r~~,:41-i,~ t.; ~.~dErF, ::°r,... .,,. n~.r..~;,.~~iFi! "I:_ .,t ,.} :~ ;tF , n ,.. :°.~ t t! .;':ta , . ' 1i .S ~ ~ __ 'I..t t ..I:I'U..' << I.L! ht? l a. - 1: .. .i'e~ . ~ th~* ~ , .c~ii'4 ~:~rl•r. • 2 S-9 We wil! be attempting to remove a fish located approximately 4' below the tubing hanger stuck in the early 90's from S-9. Thanks Gary ~ ~ U ~ ~ Page 1 of 3 ~~"~ ~~ ~ ° c~ 3 ~' Schwartz, Guy L (DOA) From: Stebbins, Tiffany A. [tastebbins@marathonoil.com] Sent: Thursday, July 02, 2009 1:32 PM To: Schwartz, Guy L (DOA) Subject: RE: S-05 bottom Cement plug Shouldn't be a problem to hold off and talk with Gary and Proserv in detail. For ali our welis, the condition when we actually enter the well to begin abandonment could change so any one of these procedures could change again before the work is done. Hoping to hear soon that some of the 403's have been approved. Thanks, ~~~~,~. ~xe~.~,~ Regulatory Compliance Representative Marathon Oil Corporation Phone 907-565-3043 Ce11907-529-0522 Fax 907-565-3076 _ _ _ __ _ _ From: Schwartz, Guy L (DQA) [mailto:guy.schwar~@alaska.gov] Sent: Thursday, .luly 02, 2009 1:19 PM To: Stebbins, Tiffany A. Cc: winton.aubert@alaska.gov; Regg, James B(DOA) Subject: RE: 5-05 bottom Cement plug Tiffany, OK ... that makes a bit more sense if tag is at 10835'md. . But raises the question of whether the fill is just enough low side to inhibit the tools but not plug off the tubing. Looks like you are assuming just the upper set of perfs is going to take any injection thru the Sliding Sleeve at 10999'. The pressure test (CMtT ) failed so fluid is going somewhere for sure. i may be prudent to do a bit more pressure testing to verify how bad the tubing is leaking to the IA (If the plug is still installed - think it was a WRP). I think we need to think about this one a little more.... I would rather hold off till Gary gets back to finalize the P& A on this one. We should have plenty of time. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 _ _ _ .__ From: Stebbins, Tiffany A. [mailto:tastebbins@marathonoil.com} Sent: Wednesday, July 01, 2009 2:54 PM To: Schwartz, Guy L (DOA) Subject: RE: S-05 bottom Cement plug 9/8/2009 ~ ~ Page 2 of 3 Wednesday Proserv received and reviewed wire line reports from 6l23/09 and 6/27/09 for S-5. Fill inside tubing is up to 10,835'. It is unknown if fili is also in the annulus between and below the two packer. A new proposed cement bottom hole plug is as follows: 4.5 x 9 5/8" annulus b/w packers - 273' x.0535 bbl/ft = 14.6 bbl From Sliding steeve of 10,999 + 100' above top packer (10,696) inside 4.5" tubing (10 999 -10 696) x 01522 = 4 6 bbl Total 19.2 bbls. Prosenr will actually be preparing 26.1 bbls cement slurry using 3 super sacks cement so there wiit be 6.9 bbis extra slurry during job. if the fill moves downward and we are abie to estabiish injection rate, then more slurry will be prepared to squeeze off the perForations. This part is unknown but we will talk with AQGCC inspector prior to changing quantities. 8.7 bbls of 95.9 ppg "G" cmt slurry per 2-ton super sack of cement 2 super sacks = 17.43 bbls To get 19.2 bbls, have to mix 26.1 bbls in 3 super sacks. 26.1 bbls (3 sacks) -19.2 bbls = 6,9 bbls extra bbl slurry Extra 6.9 bbl/capacity of 4.5° tbg (.Q1522 bbls) = 453' 10,696' - 453' = 10,243' TOC @ 26.1 bbls 10,999 -10,243' = 756' long bottom plug It is unknown if it is possible to fill the annulus so this part of your calculation was omitted. 4.5 x 9 5/8" annulus -(11,337- 10826') x.0535 bbl/ft = 27.3 bbl Thanks, C'Jti~~a,ri,t~, ~J~e~ Regulatory Compliance Representative Marathon Oil Corporation Phone 907-565-3043 Cell 907-529-0522 Fax 907-565-3076 From: Schwar~, Guy L (DOA) [mailto:guy.schwar~@alaska.gov] Sent: Tuesday, June 30, 2009 2:10 PM To: Stebbins, Tiffany A. Subject: RE: S-05 bottom Cement plug Tiffany, Here are my calcs... I know we won't fill in all the space in packers. Can you show me where you guys got the 25 bbls voiume??? . Did I miss something? I am assuming no cement below the bottom perf or above the top perf in the 9 5/8" annulus. 4%" tubing- (11337-10726' ) x.01522 bbi/ft = 10 bbl 4.5 x 9 5/8" annulus -(11,337- 10826') x.0535 bbUft = 27.3 bbl 9_5/8" ca_sing .__(11397_- 11337') x,0732 bbl/ft =_4.3 bbl Total = 41.6 bbls Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 9/8/2009 ~ ~ Page 3 of 3 From: Stebbins, Tiffany A. [maiito:tastebbins@marathonoil.com] Sent: Tuesday, June 30, 2009 1:14 PM To: Schwartz, Guy L (DOA) Subject: RE: 5-05 bottom Cement plug Guy, Attached, please find a revised wellbore diagram after the PT survey. Please let me know if this helps. Thanks, Uti~~a~, U~e~~utind Regulatory Compliance Representative Mazathon Oil Corporation Phone 907-565-3043 Cell 907-529-0522 Fax 907-565-3076 __ _ _ From: Schwartz, Guy L (DOA) [mailto:guy.schwariz@alaska.gov] Sent: Tuesday, June 30, 2009 11:33 AM To: Stebbins, Tiffany A. Subject: S-OS bottom Cement plug Tiffany, Can you confirm the bottom cement plug for S-05? The procedure states 33 bbls but I get closer to 43 bbls. I don't know if there is a recent tag but I used the bottom perf at 11397' as the bottom of the cement plug. 1 could be missing some information........ Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 9/8/2009 L �l Marathon J MARATHON ,,Alaska Production LLC Alaska Asset Team P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/565-3076 August 3, 2009 P A"r��G 0 Cathy Foersterf`�� u� State of Alaska Alaska Oil and Gas Conservation Commission 333 W. 7`1' Avenue, Suite 100 Anchorage, AK 99501-3539 Re: 20 AAC 25.300 (Request for Information) — Status of Oil and Gas Wells Dear Ms. Foerster: `�cL.o3�t In response to your June 22, 2009 letter requesting a plan of action and timing for such activities associated with the referenced list of inactive wells, please find attached a table with the requested information. As indicated in the table, Marathon anticipates a measured program of P&A activities, averaging three -to -five well abandonments per year. Marathon has already begun such a program with its offshore wells, beginning with the Spark Platform wells in 2009. All of the onshore wells on the list are within active oil and gas leases that are regularly visited and inspected. Marathon anticipates updating plans for its inactive wells in the appropriate annual Plan of Development for each property. Any and all forward activities are subject to funding approval. Please also note that your June 22 letter erroneously referenced "KU 41-08". We believe that your June 22 letter reference to well "KU 41-08" was a typo and is intended to refer to Well KU 41-18. This well matches the referenced drilling permit (171-010). Should you have any questions or wish to review the attached plans with us, please feel free to call Lyndon Ibele at (907) 565-3042. Sincerely, �a Carri Lockhart Alaska Asset Team Manager Attachment: Marathon plan for list of inactive wells cc: B. Schoffmann L. Ibele K. Skiba T. Stebbins Well Files e 11-1 Marathon Oil Company, Alaska Asset Team LU i �V � I i.1 L� ` Y L 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 , . Alaska A. Team (. M, ') Marathon MARATHON Oil Company RECEIVED PO BOX 196168 Anchorage, AK 99519-6168 JUL 0 2 2007 Telephone 907/561-5311 . Fax 907/565-3076 Alaska Oil & Gas Cons. COO1missioß Anchorage June 28, 2007 Tom Maunder AOGCC 333 West 7th Ave, Suite 100 Anchorage, AK 99501 S~NED JUL 1 '7 2007 Reference: 2006 Annual Report of Disposal Injection Operations Well S-4 and S-5, Spark Platform, North Trading Bay Unit Dear Mr. Maunder: This annual report of disposal operations covers the period of January 1 , 2006 through December 31, 2006 for wells S-4 and S-5 on the Spark platform of the North Trading Bay Unit. Disposal via well S-4 is governed by Disposal Injection Order (010) No. 13 for the North Trading Bay Unit (approved September 17, 1997), and disposal well S-5 is governed by DlO No. 15 approved August 31 , 1998. During the report period, there were no production activities on the Spark platform. The only producing gas well, S-2rd, was shut-in for the entire period due to liquid loading. Therefore, there were no fluids produced or injected during the report period. All rates and pressures for the two Spark injection disposal wells were "zero" as indicated on the attached plots for calendar year 2006. The last mechanical integrity test for S-5 was conducted on July 13th 2004 and the next such test is due by July 13th 2008. Well S-4 is not equipped with a serviceable tubing or packer, and therefore mechanical integrity is established by alternative means as set forth in 010-13. Sincerely, ¥.5 ..("B. Schoffmann Operations Superintendent Marathon Oil Company Enclosures J "9-o3~ . . Disposal Well S-4 Casing Pressure Spark Platform - North Trading Bay Unit I- Spark #4 Casing Pressure I 1 BOO 600 2000 1600 1400 '" ;200 I! " f ~1000 II. '" i BOO to o j;3 o o 0> ~ j;3 ~ Dale Disposal Well S-5 Casing Pressure Spark Platform - North Trading Bay Unit I- Spark #5 Casing Pressure I 2000 1 BOO i5 ~ ~ j;3 0 j;3 0 5: ~ :;¡ Dale 1600 1400 '" ;200 I! " 11000 II. '" ¡ BOO o . . Disposal Well S-4 Injection Volume Spark Platform - North Trading Bay Unit I_ Spark #4 Injection Volume I BOO C II. ~500 ID ,; E =400 ~ c: .2 g300 :š 700 600 - ~ ~ ~ i5 ~ j;3 j;3 0 0 0 0 0 :;¡ g 0> 0> 0> ¡;j ~ o o 0> Date Disposal Well S-S Injection Volume Spark Platform - North Trading Bay Unit I_ Spark #5 Injection Volume I BOO 200 700 600 C II. ~500 ID ,; E =400 ~ fš 1300 oS i5 ~ ~ j;3 0 j;3 0 5: 8 0 0> 0> Date . . Disposal Well S-4 Injection Pressure Spark Platform - North Trading Bay Unit I_ Spark #4 Injection Pressure 1 2000 600 ¡;¡ ~ 5: ~ o o 0> ~ j;3 o o 0> 1 BOO 1600 1400 '" I ei1200 " f ~1ooo II. c: o 11 BOO II :š 400 200 j;3 ~ Dale Disposal Well S-S Injection Pressure Spark Platform - North Trading Bay Unit I_ Spark #5 Injection Pressure I 2000 1 BOO 600 1600 1400 .. ii ~1200 I! " i1000 II. c: o I BOO :š ~ ~ ~ i5 i5 0 j;3 ~ 8 5: 0 0> 5: Dale e e I~CJ-031 Alaska Asset T earn Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/565-3076 June 13, 2006 ,~ (-j .L t Z 006 Winton Aubert AOGCC 333 West 7th Ave Suite 100 Anchorage, AK 99501 "K'" b. NÏ'.\r::; ..')¡'\¿<¡f"!,& ........ -,,-V . . ~:::. ïnnç, ic~_'w "'¡',J .~ ,:~" :..,;... Reference: Report on Disposal Injection Operations Well S-4 and S-5, Spark Platform, North Trading Bay Unit Dear Mr. Aubert: This annual report of disposal operations covers the period of January 1, 2005 through December 31, 2005 for wells S-4 and 8-5 on the Spark platform of the North Trading Bay Unit. Disposal via well 8-4 is governed by Disposal Injection Order (010) No. 13 for the North Trading Bay Unit (approved September 17, 1997), and disposal via well S-5 is governed by 010 No. 15 approved August 31, 1998. Attached are two plots showing injection volume and injection pressure for wells S-4 and S- 5. Injection into well 8-5 began on September 3, 1998. Because well 8-4 is designated as a backup disposal well for S-5, injection into S-4 ceased when injection began in S-5. The S-2RD gas producer was flowed from mid-November 2004 until it was shut in mid- September 2005 due to liquid loading problems. Injection of the produced fluid from the S- 2RD well was injected solely into the 8-5 well. All injection into S-5 was below the 010 operating limits of 1 000 bbls/day and 3000 psi surface disposal pressure. A workover of S- 2RD is currently under evaluation. If this workover is implemented and is successful, injection operations will recommence in S-5 with S-4 as the backup. Sincerely, 0tckl~ A.' B. Schoffmann Operations Manager L:\Spark\Wells\Regulatory\Spark 4 and 5 Annuallnj Rept - 06-2006.doc Enclosures ----...--. -~ 2,000 1,800 .,¡¡j 1,600 iiïI "...~ 1,400 "fj g) ëii a.. 1,200 III :1 en en 1,000 CÞ ... a.. c 0 ~ 800 CÞ ...... .5 600 400 200 b ~~ r.,:)'6 o ~~ ,'tJ.~ ~~ 0) b ~~ ,,/+'6 ---'-"--.---- ------ _._---~ Disposal Wells 5-4 and 5-5 Injection Pressure Spark Platform· North Trading Bay Unit [ ~s~ +S·4 e '.' . "'" ~....JU bI2 wi.,.... IìiI .- r. ".. !WJ iiiI Wlit!j IIii ïIJj~ ~ IJ¡íj tJ!j,. 1!!\\!L".ì.J I!!!I\I;;;j~W ~¡¡¡j E:1J iiíI ÍIiIi ¡¡,¡¡ . .... IìiI~ÍÎiiJrJjj ~ f¡¡¡J iiiJ¡¡¡j ~ ~~ !illJ ¡¡,¡¡ !Jj¡j iî¡j 1M! IJiIjj f!fJ! ~ !ill ¡,;¡ [¡¡¡¡ ¡,.¡ w !!,i ií.J ¡¡,j iIÍiI ~ w ~ w bi; LJ kill ¡¡,¡¡ b;¡ IMI kIJ \r!.j ~~ iiiI ¡¡¡J btI Mil I¡¡j !.s\I iiI:J e lid ¡i¡j ~ \r!.j b ~ ~~ ~~ b ~~ ~ ~r::Þ b ~ ~~ ~~ ~~~ ~~ ~~~ t}:)e<i ~r;;s rJ~ tt.:~~ ~+'fj tX~'fj ~'\:{ ~r:::¡).::$ ~ RI RlOv (\.*0 (\. 5)flJ I\;) '\J '\J 'V 'V 800 700 600 o a.. ¡¡: In o.ï E :1 ~ C o ti Q) .-. ..5 500 400 300 200 100 ---. --.-.. ._. '._~ iii. ~å &. .. &..&f-. . Ià.~ . J1 &. J1 ft~ ¿¡,. & o ' £;. _. ----- ._---, ----" --.-- .~._--~--- Disposal Wells S-4 and S-5 Injection Volume Spark Platform · North Trading Bay Unit /}}, d1 /}}, lit:. £ AA¡;¡¡./k &11 , f& ¡J.. &¡,¡. /:3, :\ l4../ì,i A f'iJPA. /ì,~ /ì, r~ (~&.~!' I /ì,~ \. 4¡¡¡. Alii. &, iii. iii. ,. .&£ 1& ¡¡¡, &, ,,/J:, 1iI./A ¡j, Ih "" ~ iii. Ià Ii> A 1& Ii. iii. Æ:, Ii t1 Æ:, At¡"., /i:,. ¡¿ Ii::, &. 8;, ~~ ~~~ ~~ t..:')~ ~t..:')~ rv.~ ~ ~~ t..:~ ~~~ ~~~ ~~~ ~~~ t..:.~ ~r.,:.~ ~i~ ~~')~ ~~ ~<:ð PIt rç ¿~ b ~ L --- ._. ----' ~ - .8·4 iii. S·5 J e e . '''1''~';-;' .,.~,,~ ,-':j"~'~':'~'-~'''''~.,~~. ,., ""^'-~'~-"." ,;r.,' ,'.....,,~"':'f::"''':,y' ....,..--~,_.,.-.",.. '. ;.;. ~~ 'l';)e~ ~ 'V ~ ~(;S ~oc; 'V ~ ~(;S (\. *,0 ~ ~~ ~ (\. ~q; ~ ) ;: ~ Marathon t ~ARATHO~ J Oil Company ) Alaska Asset Team Northern Business Unit P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907-561-6311 Fax 907-565-3076 '.:!.\:::.."..:J .......""..;.,. "~~" 'tj (~'''c.; t: October 10, 2005 CJ ; 9 -- ,. Mr. Mark Myers, Director State of Alaska, Dept. Natural Resources Division of Oil and Gas 550 West ¡th Avenue, Suite 800 Anchorage, AK 99501-3560 Re: North Trading Bay Unit ~ \-\ Cc.. \ 0 .\:' \ \e: Thirty-third Plan of Development and Operations VIA COURIER Dear Mr. Myers: Marathon Oil Company, as the Operator of the North Trading Bay Unit (NTBU), submits the Thirty- third Plan of Development and Operations in compliance with Article 10 of the North Trading Bay Unit Agreement. This plan is for the period January 1, 2006 through December 31, 2006, and includes both the Basal-F/Upper-G gas sands and the G-Zone/Hemlock oil reservoir. Marathon Oil Company is Operator of the facilities used to develop the NTBU oil and gas reserves. . The facilities include the Spark Platform, Spurr Platform (formerly Texaco "A") and the Granite Point Production Facility (GPPF). Spark Platform oil production was shut-in on Janüary 26, 1992. Spurr Platform oil production was shut-in on July 16, 1992. The Granite Point Production Facility has been inactive since the shut-in of all oil production (July 16, 1992). The NTBU was operating under a Suspension of Production approved through December 31 , 2003. Gas production from well S-2rd resumed in July 2003 as Marathon advised in a letter dated September 12, 2003. L..... \ ~ '-\ ~ 0 ð- '-\ S" 0- \ ~ -.s -- d- () t ~ d-' - 0 \ OPERATIONS COMPLETED UNDER PRIOR PLAN (32nd PLAN) 1. The surface facilities on Spark platform were modified to accommodate remote operations and the installation of dehydration facilities. Dehydration facilities were installed by November 2004 and production was re-established. 2. The S-2rd wellbore was returned to production in November 2004. After a few shut downs for facility adjustments, the well produced continually from February to September 2005. The average rate during that time was approximately 1.9 MMSCFD with a FTP of 1,000 psig and 353 BWPD. Production ceased in September due to water loading problems. Attempts will be made to re-establish production during the remainder of Year 2005. Produced gas is sold into the CIGGS system and produced water is re-injected into Well #S-5 (010 #15). 4 \(o~-()~~ .50-~s~- ~CJ\~<o"-où 5t;ANNED OCT 3 1 2005 North Trading Bay Unit ) 33rd Plan of Development and Operations October 1 , 2005 Page 2 ) THIRTY-THIRD PLAN OF PRODUCTION AND OPERATIONS ANTICIPATED ACTIVITIES 1. The Plan shall be effective from January 1, 2006 through December 31, 2006. 2. Upon evaluation of the recent production data, a workover of the S-2rd to set a bride plug will be considered. The purpose of the workover will be to shut off zones that are believed to be high water producing intervals. 3. No developmental drilling is planned. 4. No platform abandonments or permanent well abandonments are planned. 5. Reservoir engineering studies will be furthered. The purpose of these studies are to understand the source of water production from Well #S-2rd, determine possible remedies, review remaining recoverable hydrocarbon volumes, and evaluate economic impact of the work proposed. NTBU S-02RD MCF 8-051 BW Injected 73,830 Production Period 1/1/05 thru 08/31/05 395,979 Marathon and its working interest partner, Unocal, are committed to finding the most economic means to maximize recovery of NTBU gas reserves in a timely manner. Marathon Oil Company, as Unit Operator, reserves the right to modify or supplement this Plan of Development and Operations. No changes will be made without the ADNR's approval. Marathon's contact is Clyde Scott, 713-296-2336. Sincere~ ~. Barnes pvr' Alaska Asset Team Leader n :\callups\NTBU _33POD .DOC Via Courier cc: C. M. Scott, Marathon John Zager. Unocal Winton Aubert, AOGCC, CEF 811.1 b MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supen'isor Î¥f"1 7kidt DA TE: Thursday, July 2~. 200-t SliBJECT: t\lechanicallmegnry Tests I\to\R.ATHON OIL CO 5-05 FROI\I : John Crisp Petroleum Inspector N TRADTNG SA Y UNIT 5-(15 Src: Inspector Reviewed By: Pol. Supn' '5S.C--- Comm NON-CONFIDENTIAL \Vell Name: N TRADrNG SA Y UNIT S-05 Insp Num: mIlJCrO-t07210713-t2 Rei Insp Num: API \Vell Number: 50-733-20186-00-00 Permit Number: 169-039-0 Inspector Name: John Crisp Inspection Date: 7/13/2004 Packer Depth Pretest I nitia I 15 Min. 30 Min. 45 Min. 60 Min. \Vell I 5-05 ¡Type ~nj. P TVD 10::!59 IA 0 ::!3ÜÜ ::!300 2300 2300 2:101) P.T. 11690390 TypeTest SPI Test psi ~ 390 75 OA 1500 975 1000 1000 \000 Inten'al OTHER P/F Tubing 0 (J 0 0 û Notes: The TVD of packer could not be verified from Platform when I arrived. f\,larathon Rep. Todd Pa.xton had previous !\lit test form w/2300 test pressure. The OA had no gauge installed while Operator pressured up Lo\.. I requested OA gauge be installed & mOnitored. The equipment used for PT was vel) !>mall volume pump. The IA pressure was anained previous to my arrival on Platform. I informed Todd he should contact AOGCC Anch, Office before using injection well. I told Operator a totally wi messed I\'\IT may be requested for AOGCC before well could be used for disposal. ,lA{tr{J-4.') l li,~,', t \ k (( ') Ice(;..l .f-û re eLL) f..A]:;==\" LoJ' f\-o(~ C'e: ~ 4\~~ ~\.r w ¡-h\c-' So 5; -"'"' "7) <] ~(?11' 7(Z'l/Ò4- Thursda). Jul) 22. 200-t Page I of I UIC File Review Date: June 23, 2003 Subject: Unocal N. Trading Bay Unit (NTBU) Spark Platform Well S-05 (Waste Disposal) PTD #: 169-039 Orders: Reviewers: Initiating Action: CO 69, 74, 108 (pressure maintenance- 11 / 18/71) and 225 DIO 15 Tom Maunder, P.E. Intent to perform MIT Review Summary--Well File 1. This well was drilled in May 1969. 13-3/8" ~ 2245', w/1090 sx Class G w/10% gel followed by 400 sx Class G tail 9-5/8" ~ 11527', 1000 sx Class G. Ran CBL with determined TOC at 8400' 2. Rig was released 6/1/69 with the well completed as an oil producer.. 3. ARCO converted the well to an injector in December 1974. Injection into the well ceased in March 1981 according to RBDMS. 4. Conversion of the well from producer to injector was according to CO 108, issued 11/18/71, which authorized a pressure maintenance project. It appears that no Area Injection Order was issued to compliment CO 108. It is uncertain if issuing an AIO to compliment the CO was the practice in 1971. 5. The platform was "sold" to Marathon prior to the end of 1991 when Marathon proposed to SI the well. The well was SI long term effective February 25, 1992. 6. On June 9, 1998, Marathon submitted an application for underground disposal into S-05. Disposal was planned into the original production/injection perforations and a statement is made in the application (from the application for NTBU Suspension of Operations) that "This high recovery factor (>40% OOIP) and the high watercut of wells when they were shut in indicates that NTBU (Hemlock and G) has been swept and has no economic potential." 7. The well was converted to disposal service in September 1998. 8. Marathon submitted an operations report for S-05 in early October 2001. Due to an internal oversight error, this was the first report submitted for the disposal project. Review Summary--DIO 15 1. On June 9, 1998, Marathon submitted an application for a Disposal Injection Order (DIO) to allow disposal of the produced water from S-02 into S-05. Marathon erroneously applied for a Class II authorization. 2. On July 17, 1998, a hearing notice was published. 3. DIO 15 was issued August 31, 1998. The ordered specified in Rule 4 that the average daily disposal rate could not exceed 1000 bbl/day with the maximum disposal pressure not to exceed 3000. . M:\UIC File Reviews\030623-ntbuS-5-file-review.do¢ . In the course of their application, Marathon demonstrated mechanical integrity in June 1998. According to the available records, it does not appear that there has been an MIT since the original test in June 1998. Since the Marathon has not injected any fluids since June 2000, this is not a serious deficiency. Conclusion 1. NTBU S-05 appears to be in compliance with the applicable conservation orders and disposal injection order 15. Recommendation 1. A standard MIT should be conducted to demonstrate mechanical integrity, as proposed by Marathon. 2. Pending successful passing of the MIT, no further action is recommended or needed at this time. Tom Maunder, PE Sr. Petroleum Engineer M:\UIC File Reviews\030623-ntbuS-5-file-review.doc Company Alaska Re Domestic P.O !-?,c:,: '{ 76! ~513 Telephone 907/561-5311 October 12, 2001 Ms. Wendy Mahan Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501-3192 Reference: Report on Disposal Injection Operations Well S-4 and S-5, Spark Platform, North Trading Bay Unit Dear Ms. Uahan: ~ ~ (,oC..~ -~), '~_~L.~ ~J \ (~) -_. ~" This annual report of disposal operations covers the period of June 1,1999 through June 30, 2001 for wells S-4 and S-5 on the Spark platform of the North Trading Bay Unit. Disposal via well S-4 is governed by Disposal Injection Order (DIe) No. 13 for the North Trading Bay Unit (approved September 17, 1997), and disposal via well S-5 is governed by DIe No. 15 approved August 31, 1998. Due to an oversight the report due on or about July 1,2000 was not submitted, therefore this report covers a two year period. Attached are four plots showing injection volume and injection pressure for wells S-4 and S-5. Injection into well S-5 began on September 3, 1998. Since well S-4 is designated as a backup disposal well for S-5, injection into S-4 largely ceased when injection began in S-5. As shown from the attached graphs, injection into S-5 from June 1999 through June 2000 was. within the conditions of the disposal injection order. Little injection has taken place since July 2000 due to problems with the sole producing well, S-2RD. A workover of S-2RD is currently under evaluation. If this workover is implemented and is successful, injection operations will recommence in S-5 with S-4 as the backup. Sincerely, .-~-...., W. C. Barton Operations Superintendent N:\DRLG\SPARK~S-4\Spark 4 and 5 Annual Inj Rept - 10-2001 .doc Enclosures A subsidiary of USX Corporation Disposal Wells S-4 and S-5 Injection VolUme Spark Platform- North Trading Bay Unit 900 ......................................................... 300 ............................................ ~ ............ : .... · ......... .--~-- ........................................................................................................... 200 ................................ ~- ............................ ................................ ~ ..... --------- ......................................................................... 100 .................... * ..................................................... : .............................................................................................................. 0 I I $~ I I- I I I II, II IIIII III IIIII I I1~ . , , II1_1 [I I I, , I I ,I I IIII II Ill ~ H Disposal Wells S-4 and S-5 Injection Volume Spark Platform- North Trading Bay Unit 0.9 . ~, 1~.4"I ...... ............................................................................................. .S.51 0.6 0,5 ' 0,3 ~ 0 Disposal Wells S-4 and S-5 Injection Rates Spark Platform - North Trading Bay Unit 1600 1400 2oo ~ooo 800 600 400 ................................................................................................................................................................ ~- ...................... 200 120 100 Disposal Wells s-4 and S.5 Injection Rates Spark Platform. North Trading Bay Unit 0 ~F_2~I Dl-~laF~IllOll t/Il DUI ~.ID IO~rZ,~ Ot '~ ..... ._ :1 ilill i Operations performed:. ~ompany ;IZ-lO-UO ; Z:L101"'~ ; AllCl~OFage~ .., STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNBRY WELL OPERATIONS Operation Shutdown Stimulate ~ Plugging ~ Pull Tubing.. _ Altel' Ga~lng ~ Repair Wellm MARATHON OIL COMPANY P. O. Box 198168, Anchora~, AK gg519-6168 4. ~ of Well at Surface 2668' FSI., 2488' FEL, See 26.10N-13W, S,M. At top of Productlw Inlmval '1614' FSL, 786' FWL, Sec 35-10N-13W, S,M, A~ Efrec~ O~3th $, Type of Well: Stmtlgrapl~ Sa.~lm X Perforate .,..,,.,. Other X e, ~:Jlitum Elevation (DF m' KB) 11~' KB above MSL feet Unit m Pmm~ Name No~h Trading Bay Unit Wall Number 8-5 g. Perml{Nu~be~/.Ap~ Numbs' 10, APl N~ .... ' H~ & 0~ .... ~1111 i EffaelNe Depth: meaeured t 1439 feet Junk (measured) 11429' Baker"O' pe~ker true v~tlcat 10152 feel C~ Conductor Surface Liner Perfomlkm Depth: Lenffih Size Cemenlad IVl~mured Deplh True Veffi~al Depln 2245 13-3/8" 1090 ex 2245 2073 11627 95/8" 1000 ~x 11527 1012'7 memr, m'ed 10820' - 870', 10926'-946', 10974'-,998' tI02~. 066',, t t064'- 074', 11082~. 136' 11150'. 18(7,1t210'-2,10', 112~5'. 306', 1132g'-34g', 1t35"/'- 397" true vem~ 962~ · 668', 971 I' - 728', 9752' - 77Z, 9706' - 837, 9829' - 837', 9844' - 8,g1', g903' - 928', g954' - 980', ~ - 10038', 10057' - 074', 10081' - 116' Tubing (aiza, grade, and maalured depth) ,I-t/2", 12.1~, N-e0, butlr~ 0 11337' Pad<em and SSSV (type and meaeured de,h) Baker 'F" ~rm. packara ~ 10796' & 1106g' C, amco TRB.8 SOSSV {~ 261' Treated (maeaxe~) N/A Treatment Deserlptlen Ineludlr~ Volume~ Used md Final Pressure N/A 14. , .i,,.~ j Re!:w~tlve Daily Aver _a~le P~._ ~luatian ar Iniecfien Data OiI-Bbl Gas-MM Water-Bbl Casing Pressure ___ Tubing P~re Prior ~ Well Opel'etlon Sublequer, to Opera~ 0 0 377 16, Atfll~lrflen~ 1 t6. SlaKI~, of W~I Cl~~ C~ ~f ~ ~d 5u~ mn I 11. I ~~ t~ the fo~ ia t~ and ~o~ to the ~ ~ ~ kn~ge. F~I~ 10~ ~. ~~ '-- ..~ ~~AR~~I~ Su~encl~ ~ ~12]~ql t~I'~]ara~non L~II uompany ~ut z[~ to~/.,~ ~/ · Created ll¥/Oate: 04-SEP-98 $CHE#ANSKI Updated By/Dele: O4-~EP-g8 SCHEMANSK! Approved t1¥-. SCHEHANgK] MARATHON 0[£ spark PLatform Production & Facility Report for 03-$EP-98 ~__.#onthty. GAS ACTIVITY ERcititv ~rodu~f~n Executive Reg1~rks WaYne &$hannon out to spark today, S-& fnjectt~ ~ii via the a~ritor. Th~ insta{l~ ti~ fr~s~retor to S-~ t~. A~ of 1600 bra 9-~-98 ~e ~t a-5 in)ectim~e~ in service. semite. As of 2~00 hfs 9-3-~press~e= z6n.5 abLs aster p~uc~ t~y, T~- 1559~f O 3.2 ~fd ro:e. T~ 71,1F FLUID Total FLUid 0 Meter Factor O,OOO0 Corrected Fiutd 0 Water Cut: ,00 g Water cut TBPF: , tO0 ~ Corrected O~L~ 0 WATER INJECTION.~BBL} Toast: 04-SEP-98 15:27 PAGE 1 0 Dst Lv i Gao Test Do~ Gas Productim well Total Hfs Tim voiu~e Rate J~IRLMOn~h bmmcade ~CF MCF~ ~2RD .: 5.SO 31 _ 2,030 ,,, a,677 To:els: 2,030 Z,6~ Teat Gas Gas ~oter Nm. No~ Hrs,. HCFp .,, BPp ...CPSO Excess S~Prod Pressures in Pal Oe~iver Volant Rate Gas Csg Csg CSg Csg HCFD CPS CPSD $.G___.~.TR~.G 7' 9" 13" 16" Pressures in PSt Csg CeO Csg Csg ZBG._ 7- 9" 13" 16'_._.~~ __ Gas ~elL Teat ~ATER ~ISPOSA~ PROBLEM8 of t Test ~pVn Deferred _J~.L~ Total .... Hrs Tim 0i! Na,~ a~th ~ Co~ .... BBL - - -- i .... iiiii TOtalS: Teat Oil Fluid Ual I Tat Tes~ Rate Lfft NenTe~t . Prass~r;~.in ps~ ~ ~ AVq.~ APl TOG_ ~ ~,!.._ ~ "~,~ JJ!.,eLL Rear Ayg Oil Lift Sep Ga~ Csghead GOR Pressures ~n PS] water Rate Rate Rate Gas Rate SCF! HZS Csg Csg Csg Cuts ,, ape ~~ M¢FD eel PPH TaG ?" 9'._..~_1~'.~.~ ~&~n CUr S~PLES ~ ~-~ ~ FacitfT¥ ]nj DoNa Water ]nj ~al( Hfs TtM Vo&tme Rate Name .Do,r1 COda BBL ..npp S_~-~ .... 10.00 31 1&3 2&5 ~. 16,00..._.~6 ,. 126 377 Total s; Z69 Rate Pressures in Receflmmn= Delta Csg Csg Csg Csg _.. BPD gPO TB,..~G ~.._.~, 9,..~L., 13" 16" · Ac 100 100 . , 3~ ?06 ,.. Hater ln]ectfanR.emqrk~ ~ATER DZSF~AL. PRO~[EH~ A~AItZNG GOVERN~HTAPPROVAL~I iVl::D 1998 Alaslm Oil & Gas Cons, Commisdon ~l~atl ~-~araT, Floa gl l uompany A~C~OFag~~ Alaska Rec Domestic I5, ~ .,uotion _M. arathon Oil Company P,O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 November 3, 1998 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Reference: Sterling Well S-5 Conversion to Water Injection Well Dear Mr. Wondzelh Enclosed is the Report of Sundry Well Operations and Marathon Oil Company's Daily Report of Well Operations for Sterling Well S-5. As indicated in the reports, Well S-5 was converted to a water injection well on September 3, 1998. Sincerely, Produclion Engineer N :~FILG~ARK~.6~ARFTCL TR Enclosure A subsidiary of USX Corporation D£C 16 ~as~a 0il a ~as Cons. Commission Environmentally aware for the long runjlin~~, ~r',l~l BI lviaral;floll Ull ~ompany AI1C flOF age~ Alaska F ,1 Domestic r,oduction Marathon Oil Company P.O, Box 196166 Anohorage, AK 99519.6168 Telephone 907/561-5311 FAX COVER LETTER PLEASE DELIVER THE FOLLOWING TO: Name: Company: Fax No.: -~-: ' . Number of Pages (including coverpage): ~_. ,, -"" ',,, ....... FROM: . l[ IllI ii II i il[llll ,_Name: ........ ~'~,.,.",~ Location/Extension: ....... Fax. NO.: 907/564-6489 NOTE: ff transmission is not complete, please call 907/561-5311. A subsiciiary of USX Corporation Environmerttally aw, re for the lon~. '~ 6 1998 Alaska jon Domest,,., r~roduction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 November 3, 1998 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Reference: Sterling Well S-5 Conversion to Water Injection Well Dear Mr. Wondzell: Enclosed is the Report of Sundry Well Operations and Marathon Oil Company's Daily Report of Well Operations for Sterling Well S-5. As indicated in the reports, Well S-5 was converted to a water injection well on September 3, 1998. Sincerely, J. ~.~ry EIleT~ Production Engineer N :\DRLG\S PARK~S-5~RPTCLTR Enclosure A subsidiary of USX Corporation Environmentally aware for the long run. ~"'"' STATE OF ALASKA -'--'~ / ALASKA ,.. ,. AND GAS CONSERVATION CO, ..!ISSION 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 5. Type of Well: MARATHON OIL COMPANY Development ~ 3. Address Exploratory P. O. Box 196168, Anchorage, AK 99519-6168 Stratigraphic __ 4. Location of Well at Surface Service X 2608' FSL, 2488' FEL, Sec 26-10N-13W, S.M. At top of Productive Interval 1514' FSL, 786' FWL, Sec 35-10N-13W, S.M. At Effective Depth ~ i ' A ICONVERT TO WATER DIS,POS g At Total Depth 1839' FSL, 598' FWL, Sec 35-10N-13W, S,M. 6. Datum Elevation (DF or KB) 115' KB above MSL feet 7. Unit or Property Name North Tradinl~ Bay Unit 8. Well Number S-5 9. Permit Number/Ap~pro~al Nu__ml~r 91-411 10. APl Numbs[ ' ' Hemlock & G-zone 12. Present Well Condition Summery Total Depth: measured true vertical 11562 feet Plugs (measured) 10259 feet Effective Depth: measured true vertical 11439 feet Junk (measured) 11429' Baker "D" packer 10152 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: Length Size Cemented Measured Depth True Vertical Depth 2245 13-3/8" 1090 sx 2245 2073 11527 9-5/8" 1000 sx 11527 10127 measured 10826' - 876', 10826' - 946', 10974' - 998' 11026'-056', 11064' - 074', 11082' - 136' 11150' - 180', 11210' - 240', 11255'- 305', 11329' - 349', 11357'-397. true vertical 9626' - 668', 9711' - 728', 9752' - 772', 9796' - 837', 9829' - 837., 9844' - 891', 9903' - 928', 9954' - 980', 9993' - 10036', 10057. - 074', 10081' - 116' Tubing (size, grade, and measured depth) 4-1/2", 12.6~, N-80, buttress {~ 11337. Packers and SSSV (type and measured depth) Baker "F" perm. packers {~ 10796' & 11069' Camco TRB-6 SCSSV {~ 261' ORIGINAL RECEIVED 13. StimulatiOn or Cement Squeeze Summary Intervals Treated (measured) N/A Treatment Description Including Volumes Used and Final Pressure N/A NOV 1998 Alaska 011 & Gas Cons. Commission Anchorage 14. Reoresentative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Pdor to Well Operation 0 0 0 0 236 Subsequent to Operation 0 0 377 15. Attachments ~16. Status of Well Classification as: I Copies of Logs and Surveys run Daily Report of Well Operations X Oil__ Gas 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev. 06/(~88~ -- '~._~_~ ' N:\DRLG~SPARK~S-5~OGCC01A.XLS 706 Suspended.. Service Water Injection Well Submit in Duplicate R_14_DPFR Created By/Date: 04-SEP-98 SCHEMANSK! Updated By/Date: 04-SEP-98 SCHEMANSKI Approved By: SCHEMANSK! MARATHON OIL - Spark Platform Daily Production & Facility Report for 03-SEP-98 GAS SALES (MCF) Daily Monthly GAS ACTIVITY (MCF) Facility Production Executive Remarks Wayne & Shannon out to spark today. Blew down the casing on S-4 injection we[[ via the separator. Then instal[ed dump line from separator to S-5 tbg. As of 1600 hfs 9-3-98 we put S-5 injection we[[ in service. S-5 injection well pressure was 236 psi when placed in service. As of 2400 hfs 9-3-98 pressure= 706 psi. 268.5 Bb[s water produced today. Tbg= 1559 psi ~ 3.2 mmcfd rate. Temp= 71.1F Gas Test Down Gas Production Well Total Hfs Time Volume Rate Name Month Down Code MCF MCFD Excess Sand Prod Pressures in PSI Deliver Volume Rate Gas Csg Csg Csg Csg MCFD CPS CPSD S.G. TBG 7" 9" 13" 16" 04-SEP-98 15:27 PAGE 1 FLUID PRODUCTION (BBL) Daily Total Fluid 0 Meter Factor 0.0000 Corrected FLuid 0 Water Cut: .00 % Water Cut TBPF: .00 % Corrected Oil: 0 Honthly WATER INJECTION (BBL) Total: Daily Gas We[ S-2RD 5.80 31 2,030 2,677 Totals: 2,030 2,677 Test Gas Gas Water Sand We[[ Tst Test Rate Rate Rate Name No.__:. Hrs. MCFD BPD CPSD TBG WATER DISPOSAL PROBLEMS Pressures in PS[ Csg Csg Csg Csg 7" 9" 13" 16" Gas Well Test Remarks Oil Test Down Deferred Lift NonTest Pressures in PSI We[[ Total Hrs Time Oil Volume Rate Wtr. Cut Oil Cs9 Csg Csg Csg Name Month Down Code BBL MCF MCFD Avg % API TBG 7" 9" 13" 16" Oil Well Remar Totals: Test Oil Fluid Avg Oil Lift Sep Gas Csghead GOR We[[ Tst Test Rate Water Rate Rate Rate Gas Rate SCF/ H2S Name No. Hrs. BPD Cut% BPD MCFD MCFD MCFD BBL PPM TBG Pressures in PSI Csg Csg Csg Csg 7" 9" 13" 1 WATER CUT SAMPLES % Well Name Teqt Well Name Non-Test Facility Inj Down Water Inj Rate Pressures in PSI Well Hrs Time Volume Rate Recommend Delta Csg Csg Csg Csg Name Down ~ode BBL BPD BPD BPD TBG 7" 9" 13" 16" Water Injection Remarks S-4 10.00 31 143 245 245 100 100 WATER DISPOSAL PROBLEMS S-5 16.00 36 126 377 377 706 AWAITING GOVERNMENT APPROVALS Totals: 269 622 OCT 28 '98 14:59 MARATHOM KGF Marathon Oil Company October 28, 1998 P,2 Alaska Region Domestic Production Kenai Gas Field P.O. Box 1949 Kenai, AK 99611-1949 Telephone (907) 283-6205 Fax (907) 283-8175 Alaska Oil and Gas Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Attention: Mr. Blair Wondzell VIA FACSIMILE Re: Spark MIT- Well Dear Mr. Wondzell' We are planning on conducting a MIT test on injection well S-5, Spark Platform, on 10/30/98 or 11/2/98. When the permit was issued, permission was given to start injection and a witnessed MIT was to be conducted by 11/3/98. A MIT test, complete with circular chart recording time and pressure, was submitted before the issuance of the permit. However, it was conducted solely by Marathon Oil Company personnel and had not been witnessed by your department, thus the need for a witnessed MIT at a later date. If you would indicate your preference for a test day, we will set up transportation and conduct the test on the preferred date. Best regards, Don Erwin Production Supervisor DRE:slp [s Ip]h :\docs\spark\aog¢cm it .doc OCT 28 '98 14:58 MARATHON KGF Marathon Oil Company P.1 P.O. Box 1949 ~r'~ ~-,O~ _c) _ Kenai,.AK 99611-1949 Telephone (907) 283-6205 Fax (907) 283-6175 DATE: TIME: Fax Cover Sheet TO: FROM: NAME: COMPANY: PHONE: PHONE: FAX: PAGES SENT (Including Cover Sheet) .-'-~ ....... [ ] Response Requested [ ]Immediate [ ]Information Only REMARKS: r~c:~i v c:L~ Alast On Domestic Production Marathon Oil Company June 9, 1998 P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 ORIGINAL. Attn: Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE: Application for Underground Injection, Spark Platform Well S-5 Cook Inlet, Alaska Dear Mr. Wondzell: Marathon Oil Company, as Operator of the Spark Platform and gas production from the North Trading Bay Unit (NTBU), respectfully requests approval for an Underground Injection Permit for Spark Platform Well S-5. The injection permit is required for disposal of produced liquids associated with natural gas production from the North Trading Bay Unit. A reliable, high capacity disposal well is necessary in order to assure continued recovery of gas reserves from NTBU. Well S-5, the proposed disposal well, is a shut-in waterflood injection well completed in the Hemlock and G formation of the North Trading Bay Unit. Injection into Well S-5 was discontinued in 1981 when the NTBU waterflood was terminated due to poor economics. The NTBU Hemlock and G oil production was terminated in 1992. Well S-5 was originally drilled and completed by ARCO as a Hemlock and G oil producer in 1969. In 1974, ARCO recompleted the well as a waterflood injector into the Hemlock and G formations with 356 feet of perforations in the gross interval from 10,826-11,397 feet MD, 9,626-10,116 feet TVD (see wellbore diagram in attachments). Cumulative injection in Well S-5 was 13.7 MMSTBW. Marathon received permission from the State of Alaska Department of Natural Resources to suspend Hemlock and G oil production from the North Trading Bay Unit in 1992. Cumulative oil recovery at NTBU exceeded 40% of original oil in place (OOIP) at the time of shut-in. Marathon's May 22, 1992 application for NTBU Suspension of OperatiOns states: "This high recovery factor and the high watercut of wells when they were shut-in indicates that NTBU (Hemlock and G) has been swept and has no economic potential." A subsidiary of USX Corporation Environmentally aware for the long run. Application for Underground Injection, Spark Platform Well S-5 June 9, 1998 Page 2 Spark Well S-2rd was recompleted to develop NTBU gas reserves and continuous gas production was established in December 1996 upon installation of gas handling facilities on the Spark Platform. NTBU gas production is from the Basal F and Upper G formations at depths of 9,580-10,090 feet MD (8,722-9,087 feet TVD). Recent gas production has been accompanied by increased volumes of produced water. Remedial activities to shut-off the source of water production exhibit poor economics and have high risk of failure. Meanwhile, the injection pressure into the existing permitted disposal well (S-4) is climbing and approaching the limit of the available injection pressure. Thus, an injection permit is requested for Well S-5 to provide a second wellbore for water disposal and allow for continued recovery of NTBU gas reserves. Attached are a Request for Underground Disposal (Sundry Application, Form 10-403), and required information per 20 AAC 25.252(c). It is understood that approval of Well S-5 for injection service is contingent upon passage of a mechanical integrity test (MIT) per requirements of 20 AAC 25.412. Sincerely, MARATHON OIL COMPANY Gary Eller Production Engineer JG E/LCI/kz:O:~ELLER~SPAR K~DIS POSAL.WPD Attachments cc: W.C. Barron L. C. Ibele CEF Spark Well S-5 MARATHON OIL COMPANY NORTH TRADING BAY UNIT SPARK PLATFORM, WELL S-5 Request for Underground Disposal Applicant: Marathon Oil Company Attn: Gary Eller P.O. Box 196168 Anchorage, AK 99519-6168 Telephone: (907)581-5311 Facsimile: (907)564-6489 Date: June 9, 1998 Required Information as per 20 AAC 25.252(c): (1) Well Vicinity Plat - There are five wellbores within a one-quarter mile radius of Well S-5 at the depth of the proposed injection interval: S-2, S-2rd, S-7, S-7rd, and TS-8 (see attached map). The S-2 wellbore was plugged back with cement and replaced by S-2rd. The S2rd wellbore was plugged back with cement across the Hemlock and G and is presently an active gas producer in the Upper G and Basal F sands. The S-7 wellbore was plugged back with cement and replaced by S-7rd. The S-7rd wellbore was shut-in and secured in 1976 by filling the wellbore with kill-weight mud. Well TS-8 (Spurr Platform, operated by Marathon) was plugged back with cement to a depth above the Hemlock and G formations when the Spurr Platform was shut in 1992. (2) List of Operators & Surface Owners - Marathon Oil Company is the only operator in the vicinity of well S-5. There are no other operators within one-quarter mile of the Spark platform or the bottomhole location of the S-5 well injection interval. Marathon's mailing address is given above. The Spark platform is located within waters of the Cook Inlet owned by the State of Alaska (surface owner). There are no other surface owners within a one-quarter mile radius. (3) Affidavit - No affidavit is necessary since them are no adjacent operators or surface owners within one-quarter mile of the Spark Platform or the bottomhole location of Well S-5. (4) Geologic Data - The North Trading Bay Field was discovered in 1967 as a result of drilling the ARCO Trading Bay State #1. The trap for the hydrocarbons in the field is a slightly, westerly asymmetric anticline. Oil was produced from Hemlock and lower "G" formation (S-5: 10,800-11,425' MD). Gas is produced from upper "G" sandstones above the oil (S-5: 9,800-10,400' MD) in the S-2rd wellbore. The oil interval and the gas interval are separated by 400 feet of sandstone, shale and coal (S-5: 10,400-10,800' MD). Communication between the oil and gas intervals -1- NORTH TRADING BAY UNIT SPARK PLATFORM, WELL S-5 Request for Underground Disposal does not occur and is not expected to occur as a result of water injection (see cement bond log and fracture propagation analysis). Beneath the Hemlock lie coals, shales and sandstones of the West Foreland formation (S-5: 1,425'-TD MD). The oil interval is characterized by Hemlock sandstones that have few interbedded shale and coal beds. The Hemlock is in excess of 350 feet thick. The Hemlock sandstones are most likely in communication across the field, based on the common original oil / water contact. The lower "G," oil bearing sandstones are each separated by shale and coal layers. Their communication is probably more complicated, however, the water flood of these reservoirs effectively swept the individual sandstones. The "G" oil interval is 200 feet thick in total. These sandstones may each have a different oil / water contact. In both cases, the Hemlock and G oil recovery using water flood was sufficient to recover over 40% (20.5 MMBO) of the original oil in place. The Hemlock and G formation is sufficiently depleted to accept large water volumes for disposal purposes. The proposed injection interval is the existing perforated interval in the Hemlock and G formation between the depths of 10,826-11,397' MD (9,626-10,116' TVD) in the S-5 wellbore. (5) Logs - A copy of the cement bond log for well S-5 dated 5/30~69 is attached. Also attached is a spinner/temperature injection profile dated 12/16/74. (6) Casing Program - The following casing is set in well S-5: a) 13-3/8", 61 ppf, K-55 from 0' to 2,245', cemented wi.th 1,090 sacks b) 9-5/8, 47 ppf, BTC, N-80 & P-110 from 0' to 11,527', cemented with 1,000 sacks. The 9-5/8", N-80 casing is rated to a burst of 6,870 psi. (7) Fluid Description - The fluids to be injected in well S-5 are primarily produced water and associated natural gas condensates from well S-2rd, which is currently producing less than 200 BPD total liquids. The requested maximum permitted injection rate into Well S-5 is 1,000 BPD. Condensate production is not economic to recover at any time in the foreseeable future. The facility is unmanned, and is equipped only with two-phase separation, and has no active liquids pipeline to shore. (8) Injection Pressure - The last recorded injection test on well S-5 was in April 1976, when 10,380 BWPD was injected down the tubing with 1800 psig injection pressure. The average anticipated injection pressure is less than 1,000 psig. The requested maximum permitted injection pressure is 3,00.____~0_~ig. The current shut-in tubing pressure is "zero." -2- r NORTH TRADING BAY UNIT SPARK PLATFORM, WELL S-5 Request for Underground Disposal (9) Fracture Propagation - A fracture propagation analysis was performed at the conditions of 1000 BPD at 1000 psi surface injection pressure. Results indicate that though a fracture may be initiated under these conditions, there would be little or no growth due to fluid leakoff. A similar analysis performed in support of the injection permit application for Well S-4 indicates that with injection rates as high as 28,000 BPD at 1000 psi, upward growth of the fracture would be limited to about 300'. Under the planned injection conditions, fracture growth would be impossible to achieve. (See attached letters.) (10) Water Analysis - The most recent available analysis for the produced water from well S-2rd is attached. Our lab is currently analyzing a water sample from well S-2rd that was gathered on June 2, 1998, and Marathon will provide this analysis to AOGCC immediately upon availability. (11) Freshwater Exemption - Freshwater aquifers in the Trading Bay Field have been exempted by the EPA as per 40 CFR 147.102(b)(2)(iv). -3- , ~ /,_.,~\ ....--.... O:\EXCEL\SUNDRY~OGCC~AOGCC01 .XLS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend__ Operation Shutdown Alter Casing Repair Well Plugging Change Approved Program Pull Tubing __ Variance Re-enter Suspended Well Time Extension Stimulate Perforate Other X 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 2608' FSL, 2488' FEL, Sec 26-10N-13W, S.M. At top of Productive Interval 1514' FSL, 786' FWL, Sec 35-10N-13W, S.M At Effective Depth I Request for Underground Disposal At Tota~ Depth 1839' FSL, 598' FWL, Sec 35-10N-13W, S.M. 5. Type of Well: Development Exploratory Stratigraphic Service X Datum Elevation (DF or KB) 115' KB above MSL feet 7. Unit or Property Name North Trading Bay Unit 8. Well Number S-5 9. Permit Number lO. APl Number 50- 133-20186 11. Field/Pool Hemlock & G-zone 12. Present Well Condition Summary Total Depth: measured true vertical 11562 feet Plugs (measured) 10259 feet Effective Depth: measured true vertical 11439 feet Junk (measured) 10152 feet 11429' Baker "D" packer Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: Length Size Cemented Measured Depth True Vertical Depth 2245 13-3/8" 1090 sx 2245 2073 11527 9-5/8" 1000sx 11527 10127 measured 10826'-876',10926'-946',1097~-998', 11026'-056',1106~ -07~,11082'-136',11150'-180',11210'-240',11255'-305',11329'-349',11357'-397' true vertical 9626'-668',9711'-728',975Z-772', 9796'-837,9829'-837',9844'-891',9903'-928',995~ -980',9993'-10036',10057'-074',10081'-116' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, N-80, buttress @.1t337' Packers and SSSV (type and measured depth) Baker "F" perm. packers @ 10796' & 11069' Camco TRB-6 SCSSV @ 261' 13. Attachments Description Summary of Proposal Detailed Operations Program BOP Sketch 15. Status of Well Classification as: 14. Estimated Date for Commencing Operation 6/21/98 16. If Proposal was Verbally Approved Name of Approver Date Approved Oil Service Gas Suspended .~X Suspended water injection well 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Production Engineer Date 2-Jun-98 FOR COMMISSION USE ONLY Conditions of Approval: Notify Commission so representative may witness Plug Integrity__ BOP Test__ Location Clearance Mechanical Integrity Test__ Subsequent Form Required ~_.~__ ~ IApproval No. Approved by Order of the Commission Commissioner Date Form 10-403 Rev. 06/15/88 Submit in Triplicate i \ ' . ~ - iii ii o~ffleta ., 500 W, International Airport Road Anohorage, Alaaka g9518-I Phone: (g07)-5{~1-1324 Fax: (~07)-5~-3~ Marathon Oil Company 3201 "C" Street Anchorage AK 99,519-6168 4 June, 1998 Attention: Mr. Gary Eller, Advanced Production Engineer Mr. Lyndon Ibate, Reservoir Engineer Re: Spa~ Platform, Well 8-5; Fracture Propagation Data Dear Sim, The results from our evaluation on Well $-5 are disGussed below. Well Information: BHSP Mid-Parr Depth Anticipated Maximum Injection Rate Anticipated Maximum Injeotion Pressure Casing 3000 psi 10,g12 It 11,212 It 1000 bpd (0.69 bpm) 1000 psi 4 %", 12.6 lb/fi, N-80 With the ciata given, worst case, even though a fracture may be initiated at a surfac~ injection pressure above 856 psi, the iow injeGtion rate would cause the fluid to be almost imme(tiately lost to leakoff through the fracture face, and any fracture created would close with little or no growth. Attached, please find a copy of a letter regarding a similar situation concerning Well S-4 that was prepared for Mr. Mike Olson last year. Unfortunately, we do not have a copy of the referenced 13lot in our files. This well was also deemed to create no hazard of fracture propagation or growth upward to the surface. Should you require any further information, or have any questions or ~omm®nts, please do not hesitate to contact the undersigned at 263-7800. OFS Sales Engineer, Alaska July 10, 1997 To: MIKe OISOn MARATHON O11 Company FrOm: Frect Peters Schlumberger Doweil Ref: Potential of Hy~lraullc Fracturing via Brine Disposal Operations in Well $.4, North Trading Bay Field Doweit's hydraulic fracturing simulation software, FracCADE~"~, was used to evaluate the potential of fracturing to surface via disposal operations in well S-4 of North Trading Bay Field. To assume worst-case conclitions, stresses were consiclerect to be normal from surface to ti~a bottom of the 13 3/8" surface casing, I.e. the si~allowest possible point of injection into the open hole formations if the surface casing ts adequately cemented. Coals and shale above the surface casing were included, since both types of formation are good fracture barriers. Actual stresses used can be seen on the attached plot. Under anticipated Injection condltlons of 300 barrels of bdne per day and 1000 psi surface tnJe~on pressure, FracCADE~" Indicates no hydraulic fraGture tan be established. While adequate downhole pressure may be reached to Initiate a fracture, the Iow injection rate would almost immediately be lost to ieekoff through the fre~ure faces, and tl~e fracture would close wtth little or no areal growth. Given t~e long interval of formation open behind production casing and below surface casing, it is impossible to determine with any accuracy how much brine could be Injected before any hydraulic fracture created would be sustained anti experience even minimal growth. TO further evaluate the worst-case scenario, a conventional fracturing procedure was simutatecl using the normal stresses discussed above. The results are defined on the attached plot. Even at an injeGtion rate nearly 100 times greater than that planned for disposal (20 BI=M, or 28,800 barrels per clay), the upwarct growtl~ of the fracture Is limited to about 300 feet above the sudace casing shoe by the first Wick shale found them. Under planned injection conditions, even this moderate upward growth woulcl be impossible to acl~ieva. Based on these studies, it is conflrmeci that tl~e planned disposal operations create no hazard of fracturing upward to the surface, assuming the sudaca casing st~oe ts property cementecl. Fred Peters Area Engineer, Alaska CT&E Environmental Services inc. CT&E Ref.# Client Name Project Name/# Client Sample ID Matrix Ordered By PWS1D · 970500001 Marathon Oil Co AK Region Routine Oilfield H20 Analysis S-2rd Produced Water Sample Other Liquids Client PO# Printed Date/Time 02/12/97 15:17 Collected Date/Time 02/03/97 00:00 Received Date/Time 02/05/97 16:30 Technical Director: Stephen C. Ede Sample Remarks: Sample was analyzed undigested tbr potassium. Parameter Results Potassium Barium Calcium Iron Magnesium Sodium Strontium Aluminum Manganese pH Alkalinity as CaC03 Bicarbonate Alkalinity Carbonate Alkalinity Conductivity Chloride Sutfate 294 1.59 5.27 5.45 3.35 108 1.09 1.00 U O. 200 U 8.38 124 105 19.0 702 14.2 ohm-meters 240 2.8 PQL 50.0 O.2OO 2.00 0.500 2.00 5.00 0.300 1.00 0.200 1.00 1.00 1.00 0.100 2.00 0.200 Units mg/L mg/L mg/L mg/L mg/L mg/L mg/L mg/L mg/L pH units mg/L mg/L mg/L mmhos/cm mg/L mg/L Allowable Prep Analysis Method Limits Date Date Init SW846-7610 02/12/97 02/12/97 BJS EPA 200.7 02/11/97 EMM EPA 200.7 02/11/97 EMM EPA 200.7 02/11/97 EMM EPA 200.7 02/11/97 EMM EPA 200.7 02/11/97 EMM EPA 200.7 02/11/97 EMM EPA 200.7 02/11/97 EMM EPA 200.7 02/11/97 EMM EPA 150.1 02/06/97 EMB SM18 2320B 02/07/97 EMB SM18 2320B 02/07/97 EMB SM18 2320B 02/07/97 EMB SM 2510B 02/06/97 EMB EPA 300.0 02/11/97 SPM EPA 300.0 02/11/97 SPM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISblON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Pull tubing __ Alter casing 2. Name of Operator Mar~thQn Address P.O. Box Oi 1 Company. 102380 Anchoragew AK 4. Location of well at surface Stimulate __ Plugging Repair well __ I5. Type of Well: Development __ Exploratory ~ Stratigraphic 9951 ' Service .x- 2,608' FSL, 2,488' FEL, Sec. At top of productive interval 1,514' FSL, 786' FWL, Sec. At effective depth 26-10N- 13W-SM 35-10N-13W-SM Perforate At total depth 1,839' FSL, 598' FWL, Sec. 35-10N-13W-SM 12. Present well condition sUmmary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface 2,245' Intermediate 11,527' Production Liner Perforation depth: measured 11,562' feet 10,259' feet 11,439' feet feet 10,152' Size true vertical Plugs (measured) RIG INA Other .Z... 6. Datum elevation (DF or KB) 11E' KB above M~L 7. Unit or Property name North Tradinq Bay Unit 8. Well number 13. S-5 L 14. 9. Permit number/approval number q1-411 //~.,,,.,,' ~ 10. APl numbe'r q§ 20186 11. Field/Pool Hemlock & G-Zone Junk(measured) 11,429' Baker Mod. "D" Pkr Cemented Measured depth True vertical depth 13 3/8" 1,090 sx 2,245' 2,073' 9 5/8" 1,000 sx 11,527' 10,127' Tubing (size, grade, and measured depth) 4-1/2", 12.6# N-80 Butt 0 11,337' Packers and SSSv (type and measured depth) 10-7q6' Baker "F" Perm Pkr...' Camco TRB-6 Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Gas 6o~S. See Attachment Prior to well operation Su bseq uent to operation 15. Attachments Copies of Logs and Surveys run ~ Daily Report of Well Operations _~_ - SSSV [a 26]'. 11.069' Baker "F" Perm Pkr. RepreSentative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure 0 Service 16. Status of well classification as: Oil ~ Gas ~ Suspendeo __ my knowledge. 17. I hereby certify that the fo/~~rue and correct to the best of ~';nf;0.40 e~v 06/~15,88~~' ~'~--~/ Title Engineering Supv. Tubing Pressure 0 0 SUBMIT IN DuPEICATE Operations feet Attachaent ~1 SPARK WELL S-5 G-2 G-4 G-5 H-1 H-2 H-2 H-2 H-3 H-4 MD 10,826' - 10,876' 10,926'- 10,946' 10,974' - 10,998' 11,026 11,064 11,082 11,150 11,210 11,255 11,329 - 11,056 - 11,074 - 11,136 - 11,180 - 11,240 - 11,305 - 11,349 11,357 - 11,397 TVD 9,526' - 9,568' 9,610' - 9,628' 9,651' - 9,672' 9,696' - 9,721' 9,728' - 9,737' 9,744' - 9,790' 9,802' - 9,828' 9,853' - 9,879' 9,892' - 9,935' 9,956' - 9,973' 9,980' - 10,014' ~Spark\S5.doc Attachment #2 SPARK WELL S-5 Daily Well Operations Report 2/25/92 Installed pressure gauges on tubing and 9-5/8" casing. Tbg = 0 psi. Csg. = 0 psi. Well shut in with all valves on tree closed. \Spark\S5.doc Ri ¢EIVED APR 1 ? 1992 ~Jl & Gas Cons. ~;ul,~missio. ' ~.chorag{~ ~C Attachment #3 RECEIVED APR 1 7 1992 ., · Oil & Gas Cons. rAnoborage . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM MISSION APPLICATION .FOR SUNDRY APPROVALS 1. Type of Request: Abandon m Suspend ~ Alter casing __ Repair well __ Change approved program __ 2. Name of Ope. rator . ~ Marathon Oil Company Addr~S.So. Box 102380 Anchorage, 'AK 9951 4. Location of well at surface 20608' FSL, 2,488' FEL, Sec. At top of productive interval 1,514' FSL, 786' FWL, Sec. At effective depth Operation shutdown ~ Re-enter suspended well ~ Plugging __ Time extension __ Stimulate __ Pull tubing ~ Variance __ Perforate __ Other _.~ At toti ¢~,l~t~, FS L, 5. Type of Well: Development 26-10N-13W-SM 35-1ON- 13W-SM 598' FWL, Sec. 35-10N-13W-SM 12. Present well condition summary Total depth: measured 11,562' feet true vertical 10,259 ' feet Exploratory ~ Stratigraphic ~ Service X Plugs (measured) 6. Datum elevation (DF or KB) 115' KB above MSL feet Unitor Pj:ope[t¥ name orth mrao~ng ~ay Unit 8. Well number S-5 9. Permit number 69-39 10. APl number ~3-- 20186 11,., FieLd/Pqol Mem~ocK & 6-Zone Effective depth: measured 11,437' feet true vertical 10,152 ' feet Junk(measured) 11,429' Baker Mod. "D" Pkr Casing Length Structural Conductor Surface 2,245' Intermediate 11,527 ' Production Liner Perforation depth: measured true vertical Size Cemented Measured depth 13 3/8" 1,090 sx 2,245' 9 5/8" 1,000 sx 11,527' Tubing (size, grade, and measured depth) 4-1/2", 12.6# N-80 Butt @ 11,337' Paf~~SS~Va~Pre q ,{n ~r..e.edl~c.p_th) ~¢ e¢~.,, r,r.; Camco TRB-6 SSSV @ See Attachment #1 True vertical depth 2,073' 10,127' RECEIVED D£C 1 7 t991 Alaska 0il & 6as 00ns. 6ommissi Anchorage 261' 11 069' Baker "F" Perm Pkr. 13. Attachments 1, 2, Description summary of Proposal -x- &3 Detailed operations program BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: January 2, 1992 16. If proposal was verbally approved Oil ~ Gas __ Suspended ~ Name of approver Date approved Service Injector - SI 17. I hereby certify that the foregoi.ng is true and correct to the best of my knowledge. Signed {~~FoRTitle0perati°n S En-'"!'n' eeri nq SuperV'coMMISSION 'SE ,,.. .... Date Conditions of approval: Notify Commission so representative may witness c~ TP. st Plug integrity ~ BOJ .... Location clearance ~ Mechanical Integrity Tes ,-- Subsequent form required 10-.. ~ Approved by order of the Commission Form 10-403 Rev 06/15/88 LOi,,ii',;;E O. SUBMIT IN TRIPLICATE Attachment #1 SPARK WELL S-5 G-2 G-4 G-5 H-1 H-2 H-2 H-2 H-3 H-4 10,826' 10,926' 10,974' 11,026' 11,064 11,082 11,150 11,210 11,255 11,329 11,357 MD - 10,876 - 10,946 - 10,998 - 11,056 - 11,074 - 11,136 - 11,180 - 11,240 - 11,305 - 11,349 - 11,397 TVD 9,526' - 9,568 9,610' - 9,628 9,651' - 9,672 9,696' - 9,721 9,728' - 9,737 9,744' - 9,790 9,802' - 9,828 9,853' - 9,879 9,892' - 9,935 9,956' - 9,973 9,980' - 10,014 \Spark\S5.doc RECEIVED D£O 1 ? 1991 Alaska Oil & Gas Cons. Commission Anchorage Attachment #2 SPARK WELL S-5 Well Securing Procedure · · Ensure pressure gauges on tubing and casing are calibrated. Ensure SCSSV control line pressure is bled to zero. Leave well SI - no other work required. ~Spark~S4.doc Attac}~ent. "~ I -, , __ II J RECEIVED Alaska Oil & Gas Cons. CommissiOn' Anchorage AtlahticRichfieldCompany North Amer~"'~ PrOducing Division South Alask .... ~strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 3, 1975 Mr. Homer Burrell State of Alaska Department of Natural 3001 Porcupine Drive Anchorage, AK 99504 Resources Dear Mr. Burrell: Enclosed is the State Sundry Notice oil well on Spark Platform which has a water injection well. Sincerely, James D. Keasler Smuth Alaska District Drilling Supervisor JDK/KP/skk of NTBU S-5 (12-36) been converted to Form 10-403 REV. 1-10~73 Submit "I ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) " ~LLLOWELL' ' GAS ~ OTHER Water InjectiOn Well 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. 0. Box 360, Anchorage, AK 99510 4. LOCATION OF WELL Atsurface Spark Platform: 2608'N & 2488' W from SE Cor, Sec 26, T10N, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 115 ' RKB 14. 5. APl NUMERICAL CODE ADL-50-133-20186 6. LEASE DESIGNATION AND SERIAL NO. AD.L 18776 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME 9. WELL NO. NTBU S-5 (12-36) 10. FIELD AND POOL, OR WILDCAT Trading Bay NE Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 35, T10N, R13W, SM 12. PERMIT NO. CheCk Appropriat~ Box To Indicate Nature of Noti~, Re 3orr, or Other Data NOTICE OF INTENTION TO= TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEQUENT REPORT OFt WATER SHUT,OFF ~ fRACTURE TREATMENT ~ sHOOT,NG oR AC,D,Z,NG ~ (Other) Convert to wat REPAIRING WELL ALTERING CASING ABANDONMENT* er Injection (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. 11,562' TD, 11,429 New PBD. Worked commenced ~ 10 AM 12-14-74. Cleaned out fill f~l~ lo6,7~ t~o to of cement ~ 11.225'. DPM Drilled out hard cement f/ll,225-1~,_~~P.., an~ cleaned out hole With circulation. Perforated f/11,214-1t,24~4,; 11,259-11,30.9'; 11, 333-11, 35~'; & 11,361-11,401' CHL measUre. Bakef~Model "F" wireline packers set ~ 10,785' & 11,058'; safety valve ~ 261' Otis "XO- sliding sleev~run open @ 10,999'; Baker Model "G" seal assembly with 10 seal units f/'11,072-11,087'; Otis "X" nipple ~ 11,178'; Otis "N" ni~le ~ 11,273'. Tested BOPE (Rams w/3,000 psi, *Tubing Measurement Hydril1 w/1800 psi) on 12-19-74 & 12-24-74. 16. I hereby certify that the foregoing is true and correct Orlg. Supvr. 1/3/75 DATE (This space for State office use) APPROVED BY .. CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side AtlanticRichfieldCornpany North Ame~ Producing Division South Alas~,- _.istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 December 20, 1974 Mr. Homer Burrell State of Alaska Department of Natural Resources Oil & Gas Division 3001 Procupine Drive Anchorage, AK 99504 Dear Mr. Burrell: Enclosed is the State Sundry Notice to convert the NTBU S-5 (12-35) oil well on Spark Platform to a water injection well. As per telephone conversation between John Miller and Dick Smith on 12-19-74 verbal approval was given to proceed with the work. Very truly yours, Drilling Supervisor JDK/DLS/skk Enclosures DEC q i:!: 19T4 Form 10-403 REV. 1-10~73 Submit "1 ntentions" in Triplicate & "Subsequent Reports,' in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. OIL r-'] GAs r-] WELLL--J WELLL.J OTHER Water .Injection Well NAME OF OPERATOR Atlantic Richfield Company 3. ADDRF--iS OF OPERATOR P. 0. Box 360, Anchorage, AK 99510 4. LOCATION OF WELL Atsurface Spark Platform: 2608lN & 2488'W fr SE cr, Sec 26, T10N, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) ll5 ' RKB 14. CheCk Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE ADL-50-133-20186 6. LEASE DESIGNATION AND SERIAL NO. ADL 18776 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME 'orth Trading Bay Unit 9. WELL NO. N~BU S-5 (12-35) 10. FIELD AND POOL, OR WILDCAT Trading Bay NE Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 35, T10N, 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 ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Convert to Water Inject,i,o.~ W ~ J__L SUBSEQUENT REPORT OF: WATER SHUT-OFF [~ REPAI RING WELL FRACTURE TREATMENTR ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: RepOrt results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. This well is presently producing about 170 BOPD and 1400 BWPD from "G" zone perforations between 10,826, and 10,998' and Hemlock perforations between 11,026' and 11,240' (bottom perforations from 11,210'-11,240' are cemented off). We propose to clean out this well t° 11,420~ and convert to water in- jection to improve the water flood sweep efficiency in the "G" and Hemlock reservoirs. Hemlock Bench H-3 will be reperforated from 11,210'-11,240' and new perforations will be added to the H-3 and H-4 benches between 11,255' and 11,397'. The perforations will be washed and cleaned up with acid if required. 3000 psi double ram and annulus BOPE will be installed and tested weekly. DNISI N Oi: OiL AND / -/ dames J~, ~eas_Ler--- (This spa~'~ State office use) D~. Drlg. Supvr. 12-20-74 DATE CONDITIONS OF A~_~ROVAL, IF ANY: See Instructions On Reverse Side APproved Jop~ Refurned UNION OIL & GAS DIVISION WESTERN REGION ANCHORAGE DISTRICT TO: _STATE OF ALASKA FROM' G, H. Laughb~um _ TRANSMITTAL DATE: WELL NAME: August_14, 1969 Arco TBU Transmitted herewith are the following- Run No. Final Sepia Blue Scale 1 Induction Electrical Log 2"- Dual Induction Laterlog BHC Sonic/Caliper Log BHC Sonic/Gamma Ray BHC Sonic/Caliper/Gamma Ray Log Formation Sonic Log (Fs) Compensated Formation Density Formation Density Log (Fd) Neutron Log Formation Neutron Log (Fn) High Resolution Dipmeter (HDT) CDM Safety Print CDM or Printout CDM or Polywog Plot CDM-Polar Plots. Proximity Microlog/Caliper Log Gamma Ray-Neutron Log Gamma Ray Collar Log Cement Bond Log Sidewall Neutron Porosity Log Laterlog 3 Mud log Core Descriptions, Conventional, No. Core Descriptions, Sidewall Core Analysis Formation Tests Directional Surveys Core Chips Sample Cut DIVI$10N OFOILANDG/$ RETURN RECEIPT TO' Union Oil & Gas Division - Western Region Anchorage District -'"'. P.O. Box 2647, Airport 'Annex Anchorage, Alaska 99503 Attn: Rochelle Carlton Form P--7 SUBMIT IN DUPLIC~ . '/STATE OF ALASKA (see o~er l.-! , OIL AND GAS CONSERVATION struction~ onI' .................. ..... T'' reverse side) l .............. WELL cOMPLETION OR RECOMPLETIoNREPORT' 'AND LOG * JRDL'" ~b~~o~18776 b. TYPE OF COMPLETION: OVeR [~] DEEP- n~cK EN nE$.v R. [~ Other WELL 2. NAME OF OPRR~TOR - ~*.~Unton 0il Company of C~lifqrnia ' ~.~DDRg~ OF OPeRaTOR . -- 9a0B aonali Stro-ot.,~:Anchoraae. gla~'ka 99503 ~. LOCATION OF WELL (Reporf looatio~ cl~akly:and in aO~or~agoe witA any State requirements)* At su~ace 2608'~ & 2438'W fr:SE cc, Sec At tob'.prod, interval reported below At .total dep~ ~ ~, IF INDr~N, AI~X>TTE~ OR 'l'l~i~J ~ J _ i in ~ PII I~ '8. UNIT,FAi~I OR L~-~SE NA!~J~ .. . -- -- Trading Bay Unit 9. WELL NO. Sec '35, T10N, R13W, SM 69-39 13. DA. TE $1~JDDED - [li. DATE T;D. RF_J~CHED |i5. Di~ CO'~3 SUSP ~ ~, 116.' ~VA~ONS (DF, RKB, ~T, GR, 4-22-69 --:' ~ -5-26-69 " - " ' "' 'D "-' D ' , .... 18. T~-D~H, ~ & TVq~9: PLUG.~C~ ' ~ ~ ~ ~: ~ ~L~LE CO~L., [ 21. ", ~:" "" ' ll 43° MD* ~ ~w~v* ! ,o~,,~ ~oo~ '1 "~,,~ ~OOL, 11,562 MD¥'(1-0,25g? , ..JVD)~ (10'15~'._ : ~ VDi:: ~ ,J ** J ~ll -- ~. P~DU~NG ~V~(S), 'OF ~S ~M~TIO~P, ~OM, N~E (~ A~ ~)* . ~ ~. W~ DIRE~ON~ SURV~ ~DE ]0,826' MD (9625' _VD) - ]1,]80' MD~-~(9929' VD): Co-ming]ed "G" a Hemlock Yes ~. ~E ~C~C ~D OTH~ LOGS ~UN ~ ' .... . DIL, 8SL, FaC, HDI ~-;,.~. , - ~ , , C~G Rg~ (Re~rt 211 Strips set in well) __ HOLE S~E J ~~NG ~CO~ ;..~ ]3~'/8" . 6T~ . [J'55 J 2,245''' 18" [1090 sx "a" w/]0~ 9e] + 4 0 sx "G" neat 9-5~8"';; 47~.: N-80i~[ 1]~527" ' 1~-]/4' ]~0 Sx "G" neat 26. .. LINER ~co~ ' r ~ J 27. TUB~G 28. PE~ORATIONS OP~ TO PRODU~ON (inte~al, size and number:) 29. ACID, S~!OT, F~'~, C~T SQU~~,.~, ! DEPTH INTERVAL' (MD) J -None , . 10,826' -10,8~6'; 10,926'-10,946'; 10,976'-10,998'~; 11,026'~-11,056'; 11,064', 11,0;7~1"; 11,082'- 11,1-36'; 11.,150'-11,180'; TOtal 236' O1-4 HPF i so. P~ODgC~I~ON )urnping--size and type of pulnp) G.%S--1VICF. 1 DATE FIRST PI{ODUCTION J PRODUCTION METHO'D (Flowhlg, gas ~ 6-1-69 - |[ G,as Lifi;. · DAZE Or TEST, II-iOURS TESTED ICHOXE SIZE JPROD'N FOR OIL--BBL. ! -' ' [ ITEST PEi:~OD 6-8-69 , ! 24 ': [-Open-, ! - ~ J 1564 , 50 I 080 I '- ; 564 J 50 31. glSPOSI~IO~ Ot @tS (~olg, ~a6d ~o~ ~64 ~ent6d, .... Gas Lift - Fuel - Vent 32. LIST OF ATTACHMENTS I WELL STATUS (Producing or siiut-in) Producinq WATER--BBL. J GAS-OIL I~%TIO 150 I 2073 J 96 WAT~ EL. JOIL GRAVITY-AP1 (C~.) 1 I 2073 19.8 @ 60' JTEST WITNESSED BY j Jack Ritter None SIGNED ]H~ TITLE iSt. Drlg. Supt. DATE 7/10/69 *}See J~ctions a,g S~ce~ [o' A~dilio,a[ D~ta o, Reve,se Si~e) ** Co-mingled in well bo~ with Trading Bay "O" NE 0~1 Pool Zone *** Atlantic R~chfield Company Sub-Operator INSTRUCTIONS General: This form is designed for submitting a Complete and correct well completion report and log on all types of lands and leases in Alaska. : Item: 16: Indicate which elevntion is used as reference (where nOt OtherwiSe shown) for depth measure- ments given in cther spaces on this form and in any attachmentsl . Items :20, and :2:2:: If this well is completed for s.eparatc, production from more than one interval zone (multiple completion), so state in item 20, and in item: 22 show the prc.zlucing, interval, or intervals, '~- top(s), bottom(s) and narde (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additiOnal interval to be seperately produced, Show- - _. lng the acktitional data pertinent to such interval. ~ . Item26: "Sacks Cement": Attached supplemental, records fOr this well shoulld show the details of any mul- :.~. tiple stage cementing anc~ the location of the cementing tool. --' Item 28: Submit a separate completion report on this fOrm f°r each interval to be .separatelY produced. (See instruction for items 20 and 22 above). 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TF_~TED. PRESSURE DAT~iA~/D RECOV~<IES OF OIL, GAS. WATER AND MUD ' NAM~ I~,I]~AS. NONE Hemlock - . 11,025' 9,7~95' ~-- .. · : ~;~ . . 26. COI{E DATA. A~ACII BRIEF D~CRIP~O~S O~ LITHO~GY. POROSITY, FRAC~R~, ~P~T DIPS AND DE'fECal) SHOWS OF OIL, G~ OR WA~. : . . . NONE : .: , ]NSTBUCTIONS~: Prepare and submit the FINAL REPORT on the first Wednesday after silo-able has been assigned or veil ia Plulged. ~b-andoned, or Sold. FINAL REPORT should be submitted also when operations are suspended for an indefinite or appreciable tength of tine, On vorkovers ,hen an official teat ia not required upon completion, report completion and repreaentsti,e cast data in blocks provided. The FINAL REPORT form may be used for reporting the entire operation if apace ia available. DALLY WELL HISTORY - FINAL REPORT District Field County or Parish Kens! Lease or Unit TBU _ State Alacka Well No. ~.~...~5 Auth. or W.O. No,,19-7370 Title Drill. . · ... Operaton~_ Atlantic Richfield Company TARCO'S W.I. _~ · Prior Status Spudded or ' W.O. Begun Spudded Date ,, 4-22-60 Hour._~_~__if lOO~ . Date & Depth as of 8:00 A.M. 6-09-69 Complete Record for Each Day Reported Test: 1564 BOPD, 2073 BWPD, 57% BS&W, TP 160#, C~ 1105#. FINAL ~EP6RT. HLB ~ TRM OKG KLV ~, _, REL ' ULZZ Old TD New TD 11~562' PB Depth Released Rig Classifications (Oil, Gas, etc.) 4 PM Date 6-01-69 Oil Producing Method GL Kind of Rig_ Type Completion (Single, Dual, etc.) Official Reservoir Name(s) Rotary - Drillin6 Single Hemlock Fotentlal 'lest Data: , ' ' OIL OR TEST TIME PRODUCTION WELL NO. DATE RESERVOIR PRODUCING INTERVAL GAS OIL ON TEST GAS PER DAY · , 12-35 6-06-69 Hemlock 11,180-10,826' Oil 24 hrs 999 BOPD - ,, [ , PUMP SIZE, SPM X LENGTH CHOKE SIZE T. P. C. P. WATER % COB CORRECTEDGRAV~TY' ALLOWABLE EFFECTIVE DATE , , ,, , , - None 140# 1140# 64% BS&W .... . Distribution: The Above is Correct: Orig.: Drilling Section Dallas .·., cc:- District Office · ' ,,/c7~"~ Engineering Division - (720) SIGNATURE DATE Co-O~r(s) As Appropriate ~.t,r~ct~-~r~lq:in~ 2u?~rv~pr. Regional Office, Well Rec.ord File TITt,E PA(;I': NO..__-I~ _(NUMBER Al,I, I)AII.Y WEI.I. II[,q'l'OilY FOi'iMS t:ON~ECIITIVI~I.Y AS TIIEY ~IE I'IWI'AliI:J) FOIt EACtl WEI,L. )~ / INSTBUCTIONS: This form is used during drilling or workover operations, If test ag, coring, or perforating, show formation name in d~seribing work performed. Number all drill stem tests sequentially, At ach description of all cores. Work per- tormed by Producing Section will be reported on "INTERIM" sheets until final completion. Report official or representative test on "FINAL" form. (1) Submit "INTERIM" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. DAILY WELL ltlSTORY.- INTERIM District Alaska County or Parish Kenai. Borough State Alaska Field McArthur Ri ver Lease or Unit TBU S-5 We 11 NolO5 Date & Depth at 8:00 A.M. (Continued) 5-27-69 5-28-69 5-29-69 6-02-69 6-05-69 6-06-69 .Complete Becord for e~ch. Day While 'Drilling or Workover in .Progress DIL @ 11550-2238, Sonic 11550-8000 (did not work), ran Density 11550-8000 & now re-running Sonic. TD 11,562' MW 74#, Vis 48, WL 5.8 cc's Running 9-5/8" csg Reran Sonic Log 11550-8000 & HDT Dipmeter 11550-8000'. Finished logging ~ 4PM 5-27-69 (24 hrs). Hole took approx 150 bbls mud during logging. Ran 12-1/4" bit & CO fill 11550-11562'. Cond mud 2-1/2 hrs. POH & installed 9-5/8"-csg rams. 11,562 TD. Mud 74#, Vis. 48", WL 5.8cc. 9-5/8" cs~. cmtd @ 11527, baffle collar @ 11,439. Ran 280 its. (11,488') 9-5/8" 47#, P-110 & N-80 buttress T & C csg. Landed in Uni-head w/295,000#~, cmtd w/lO00 sxs ---- Class "G" cmt premixed w/l% CFR-2. Displaced w/4930 cu. ft. mud (4700 calc) Bumped plugs w/2000 psi. Float did not hold. Float held after circ & diff fill-up worked while going in hole. CIP @ 8'15 p.m. 5-28-69. Stood cmtd 3-1/2 hrs. Installed OCT 9-5/8" x 12" pack-off assy. Tstd w/3000 psi for 15 min. Installed 5" d.p. rams. TD 11,562' MW 74#, Vis 37, WL 5.7 cc's Ran 8-1/2" bit & 9-5/8" csg scraper to 11,437'. Circ & cond mud 3 hrs. Tstd csg w/1500 psi, OK, PO LD DP. Ran Dresser-Atlas CBL-CCL~LOg 11,437-8300'~7,t,op~ cmt @ 8400 (This report for 5-30). 5-31: TD 11,562' MW 74#, Vis Perfd 4 Hpf il ,240-11,210' w/' Dresser-Atlas '4# NCF csg gun. Ran gauge ring & junk catcher to 11,250'.. Ran & set 9-5/8" Baker Model "D" prod pkr @ 11,190' w/3'x3-1/2" tbg tail & 3-1/2" Otis "Q" nipple @ 11,200' w/Dresser-Atlas WL setting tool. Installed 4-1/2" t. bg rams. 4-1/2" tho hung @ 10,,756'. Ran & hung 10,686' net (352 its) 4-1/2" 12.6# N-80 buttress tbg @ 10,756 w/4-1/2" Otis "N" nipple @ 10,756'; 9-5/8" 47# Otis RH-1 St. pull release pkr @ 10,718', Camco GL mandrels 010,502' 9896 9686 8855 8429 7936 6944 5968 4240 & 2087' 4-1/2" Otis ball valve @ 464'. 6-01' TD 11,562' Diesel oil Removed BOP & riser, installed Xmas tree, tstd tree w/5000 psi, OK. Tstd line w/3500 psi, OK. Displ mud w/Inlet wtr & Inlet wtr w/715 bbls diesel oil. Pulled dummy sleeve in ball valve. Ran Otis "N" plug, set 9-5/8" Otis pkr 10,718' w/2500 psi. Pulled "N" plug, tstd tbg & pkr w/1500 psi, OK. GL'd diesel oil to 6000'. 6-02' TD 11,562' GL'd 289 bbls diesel oil w/950 psi on csg. Bled off csg. Had no indication of entry from interval 11,210-11,240' Perfd 4 hpf 11,180- 11,150', 11136-11082, 11074-11064, 11056-11026, 10998-16976, 10946-10926 & 10876-10826 w/2" Dresser-Atlas thru tbg NCF gun. TP increased from 0-250 psi @ 35 psi increase w/each gun run. RR @ 4 PM, 6-01-69. Moved rig to S-2. 6-03: Well would not flow. Commenced prod by GL & began unloading well. Max prod rate 75 BFPH, 40% oil. Varied lift gas rate between 1.4 & 2.4 MMCFPD rate, annulus fluid level @ second valve 4240'. 6-04' Cont to lift, no change. RU Otis & pulled top valve @ 2087'. Lost 1 dummy valve in hole. Set 2d dummy valve @ 2087'. ~D Otis & opened well w/gooc flow. Csg pressure slowly built up to 1200#, input gas rate decreased & well dead. Rocked well & KO. Last 16 hrs prod @ 2352 BFPD,,37% or 870 BOPD, no choke, 130/140# FTP, 980# CP. Cont to test. Cont {o test. 24-hr test' 999 BOPD, 1775 BWPD, 64% BS&W, TP 140#, CP 1140#. Distribution: Orig.: Drilling. Section - Dallas cc:- District Office Engineering Division - (720) Co-Owner(s) - As Appropriat, e tlegiona]. Of.flee, Well llecord File PA(iE N() ..... ~ ...........(NIIMBEI( Al.I, DAII,Y WEI.I. III,%TOIIY I"(HIM,s (;()N.qI:.I:IFrIVI.',I,Y AS TIII,:Y AItE I'I{I".I'AIII",I) FOIl I<A(]I WI, IA,. ) The Above is Correct,: .fj:'::;c,ri~ ( .I,',~/, .,.? ...~ ~;-,,..-'. .... 6/1 2/69 '(/~ sl(;~A'rm.~: 'ri l l i nEl.__[~pe rvi sor _ District TI TI,E INSTI1UCTIONS: This form is used during drilling or workover operations. If teat~ng, coring, or perforating, show !ormati.n name in describing work performed. Number all drill stem terra sequentially. Attach description of all cores. ~.,~k per- formed by Producing Section ,ill'be reported on "INTERIM" sheets until final completion. Report official or repr¢~,entative test on "FINAl." form. (1) Submit "INTERIM" sheets ~hen filled out but not leas frequently than every 30 days, or t2) on ~edneaday of the week in which oil string is set.. Submit weekly for workovers and following setting of oil string until completion. DAILY WELL HISTORY - INTERIM District Alaska County or Parish Kenai Borough State Alaska Field N.Trading Bay U.Zone ~ Hemlock Lease or Unit TBU S-5 Well No ~[ 2___23~ Date & Depth at 8:00 A.M. 5-14-69 5-15-69 5-16-69 5-19-69 5-2O-69 5-21-69 5-22-69 5-23-69 5-26-69 5-27-69 Complete Record for each. Day While Drilling or Workover in Progress 9319' (0') Mud 74#, Vis 48, WL 8.4 cc's GI.H w/jars ~.~..,~.. Spotted 25 bbls bit lube pill. Worked stuck pipe 4-1/2 hrs. Bmpr sub remained free. Ran Dialog at top of Monel collar @ 9169'. No results. Reran Dialog, back-off shot & free pt indicator. Found pipe' free to bumper sub. Backed off @ DC X-over sub @ 9065'. POH w/bumper sub & x-over sub. Fish in hole' 12-1/4" bit, 10' x 12-3/16" Drilco square stabilizer; 9' x 12;3/16" Drilco square stabilizers; 2' X-over sub; 30' x 7-3/4" monel collar; 31' x 7-3/4" steel DC; 5' x 12-1/4" Servco stabilizer; two 31' x 7.-3/4" steel DCs; 5' x 12-1/4" Servco stabilizer. Top of fish @ 9065'. Ran in w/Bower~jars, Baash-Ross bumper sub, 11-1/2" stabilizer, 150' 7-3/4" DCs, 11-1/2" stabilizer, bumper sub, & 145 its HWDP. .. 9445' (126') Mud 74#, Vis 47, W-L.8.4 cc's Drlg Ran jars &'B'sub' Screwed into fish @ 9065' Jarred fish free in 1-1/2 hfs, POH. Recovered all' fish· Bit was pinched ~/8" undergauge. Directionally drld 9319-9445' . 9573' (128') Mud 74#, Vis 40, WL 8.0 cc's GIH Directionally drld 12-1/4" hole 9445-9573' Lost 10-1/2 hrs working on SCR units', while POH w/#28 bit on #1, #3, & #51 #2 & #4 inoperable· SCR #1 replaced #1 & #2 hard firing module. SCR #2 blew fuses· Had bad cannon connector.~ Now GIW w/#1, #2, #3 & #4 SCR units working· 10,242' (669') Mud 72.5#, Vis 43, WL 7.9 cc's Drlg Directionally drld 12-1/4" hole 9573-10,242'. Survey' 10,174' 32-1/4° S30W, VD 9073.46, S3811 06, W1827 97 · ~ , · · · 10,416' (174') Mud 72#, Vis 42, WL 8.0 cc's Tripping w/bit Directionally drld 12-1/4" hole 10,242-10,416'. Measured out of hole· Corrected depth to 10,313' (24'). Tstd CSO & pipe rams w/3p00 psi & Hydril 'w/2500 psi, OK. Survey: 10,416' 32-1/2° S29W, VD 9277 83, S3924.40, W1890 80 , ' · · · 10,646' (230') Drlg Mud 73#, Vis 41", WL 7.8 cc's Directionally drld 12-1/4" hole 10,416-10,646'. Survey: 10,628', 32-1/4°, S29W, VD 9457.15, S4023.30, W1945.62. 10,771' (125') GIH Mud 73#, Vis 44, WL 7.6 cc's Direc~tionally drld 12-1/4" hole 10,646-10,771' · 11,003' (234') GIH Mud 74#, Vis 43, WL 6.9 ec's Direetionally drld 12-1/4 hole 10,77Z-ZZ,003'. . Survey: 1~,003', 3~-1/2©, VD 9776.30, 11,540' (537') Drlg Mud T2#, Vis 39, WL 5.8 cc's Directionally drld 12-1/4" hole '11,003-11,540'. , o Survey: 11,4.65 , 30-1/4 , S30W, VD 1G,174.55, S4396.92, W2160.52. 11,562'. TD (22') Re-running Sonic Log Mud 72#, Vis 41, WL 5.7 cc's Directi6nally drld 12-1/4" hole 11,540-11,562' ' 'Made 12 stand wiper run. Cond mud. Measured out of hole .(.1! long did not correct). Ran Schl. (Cont'd) Distribution: Orig.: Drilling Section- Dallas cc:- District Office Engineering Division (720) Co-Owner(s) - As Appropriate Regional Office., Well. l/ecord l?il{~ PAGI'.' 'NO ......,~ ........... (NIIMIII.:B ^1.1. DAII,¥ WEI,I. IIIWI'(HIY I.'(HIM.'4 (:(~N:;I':I:II'I'IVI.:I,Y AS TIII':Y Alii< I'III,:I'^IU.:I) FI)Il I.'.A(:ll WI.:I.I,. ) The Above is Correct,: /" /,],;, :' · '~":~'"";' :~ '~ ' 5/14. / 6 9 _ , ,_,'~,.;..,.~-% :~-,./~ . , ,. ~-- ...... S1 GNATIIBI", ,/// I)ATE D i s t r i c'{t"" 1') r i. ] I i n g__.6._u..ge....'l:y :_i _ag_r_ ............................... TI TI,E INSTRUCTIONS: This form ia uaad during drilling or workover operations. If teat ng, coring, or perforating, show ~rmation name i~ describing work performed. Number all drill stem tests sequentially. At ach description of all cores. W,,:; per- formed by Producing Section will be reported on "INTERIM" sheets until final comp etlon. Report official or repre.~entative test on "FINAL" form. (1) Submit "INTERIM" sheets when filled out but not less frequently than every 30 days, or (2.1 on Wednesday of the week in which oil string is set. Submit weekly for workovera and following setting of oil string until completion. DAILY WELL HISTORY - INTERIIq District Alaska. County or Parish Kenai Born,]gh State Alaska _ Field N.Trading .Bay U. Zone ~ Hemlock Lease or Unit~. TBII Well Nol.2~- 5 Date & Depth at 8:00 A.M. 5-01-69 3-02-69 5 -05-69 5-06-69 5-07-69 5-08-69 5-09-69 dtJi. Zljj j 5-12-69 5-13-69 Complete Record for each Day While Drilling or Workover in Progress 5860' (842') Drlg Mud 73#, Vis 43, WL 9.7 cc's Directionally ,drld 12~ /,4" hole 5018-5860· Survey' 5652' 30-1/~°1 S25W, VD 5087.22, S2092.41, W621.12. 6590' (730') Drlg Mud 72#, Vis 41, WL 9.9 cc's Directionally drld 12~1~4" hole 5860~6590'. Survey' 6423' 24 1/ o S31W, 'VD 57 8 48, S2378 76, W784 54 · · · · 7784' (1194') Mud 72#, Vis 39, WL 10.6 cc's Drlg Directionally drld 12-1/4" hole 6590-7784'. Tstd head, lines & ROPE w/2800 psi, hydril w/1800 psi~ OK. Survey' 7771' 28-1/4© S38W VD 6990 51, S2854 87, Nl127 29 8017' (233') Orienting Turbodrill Mud 71#, Vis 37, WL 10.2 cc's Directionally drld 12-%/4" hole 7784-8017'. Survey' 8017' 29-1/4TM S40W VD 7205 14, S2949 94, W1204 56 8153' (136') Waiting on gas turbines· Mud 71#, Vis 42, WL 10.6 cc'~ Directionally drld 12-1/4" hole 8017-8153'. Turbines shut down @ 11 PM. Control panel malfunctioned & cannot determine cause to make control p, anel shut down turbines. Survey' 8153., 27-3/4©, S35W, VD 7325.93, S2998.45, W1239.91. 8321' (1.68') GIH Mud 71.5#, Vis 42, WL 10.4 cc's Started in hole w/drlg assly @ 3 PM, 5-7-69. Had both turbines running. #1 will not carry load. Have been operating on #2 turbine. Directionally drld 12-!/4" hole 8153-8321'. Survey: 8321', 2.8©, S35W, VD 7472.26, S3063.05, W1285.5. 8650' (329') Drlg Mud 72#, Vis 39, WL 10.1 cc's-i' 'Directionally drld 12-1/4" hole 8321-8650'. Inst"isolation trans- former in #1 control panel. Put both turbines in parallel planning to install isolation transformer on panel #2. #2'down @ 4'50 AM to cool for repair work. #1 shut down @ 5'20 AM. Malfunction of logic in control panel~ Started #2 & drld w/power from #2. Survey' 8515', 28-3/~6 S36W VD 7644 34, S3138 54, W1339 99 9247' (597') POH Mud 73#, Vis 40, WL 7.8 cc's Directionally drld 12-1/4" hole 8650-9247'. Ail personnel par.- tic,i~oated in fire drill held aboard platform 5-11-69. SCR #2 blew 2 fuses & 37 pin cannon connector. Did not have equip to make repairs. Switched #5 SCR to #2 position. Drld w/4 SCR. Switched to Range 1 to pull pipe. Blew 13 fuses in #1 & #2 SCR units. Survey: 9211', 30©, S39W, VD 8250.61, S3408.13, W1550.04. 9319' (72') POH w/bit #26 Mud 74#, Vis 46, WL 8.6 cc's Pulled bit #24B. Found cones worn flat & locked· Ran 11-7/8" Bowen reverse circ junk basket· Ran on btm @ 9247 1 hr. POH & recov.small pc of cone^ Ran Bit #26 & drld 9247-9319'. Survey: 9291' 29-1/2~ S34W, VD 8320 24, S3440 78 W1572 07 Distribution: Orig.: Drilling Section - Dallas cc:- District Office Engineering l)ivision - (720) Co-Owner (s) As Appropriate Regional Office, Well l/ecord File The Above is Correct: ~,/ (' j__~/ ~ .- . , / DATE S I GN A'FU I{E 1) i. s t 'r i ctt''' I)r i_ 1 j!j.._!.]g__~.!.!.l!.Cl:Y..i~9.g_.r_ ............................ TI 'rl.l'; PAGE NO, 9 (NIIMI{EI1 AI.I. DAII.Y WEi.i. IIIST()ItY FOIIM.q CON:41.:CIITIVI-:I.Y AS 'I'III.:Y ABI.: Iqll.:l'Altl.:l) I.'()1~ FA(:II ~'1.:1.1. ) :111 .1','/, :' Prlnt.d II~A -INSTI1UCTIONS: Prapare and submit the INITIAl, BEPOI/T on the first Wednesday after a ~'ell is spudded or workover op,:~'ationa are ,started. Daily work prior to apuddin8 should be summarized on the form giving inclusive dates only. DAILY WELL HISTORY-INITIAL REPORT District Alaska County or Parish Kenai Borough State A1 aska Fie ld McArthur Ri ver Lease or Unit TBU S-5 Well No.12-___35 Auth. or W.O. No.19-7370 Title Drill. Operator Spudded or W.O. Begun_ Atlantic Richfield Company Spudded Date 4-22-69 Hour 8 AM TARCO'S W.I. Prior Status if a W. O. 1.00% Date & Depth as of 8:00 A.M. 4-22-69 4-23-69 4-24-69 4-25-69 4-28-69 4-29-69 4-30-69 Complete Record for each Day Reported Moved rig to Conductor #3, Leg //3, inst 20" riser & hydrill. 892' (498') GIH w/Turbodrill. Mud 72//, Vis 43, WL 10.2 cc's Spudded @ 8 AM, 4-22-69. Directionally drld 12-1/4" hole 394- 892'. Survey' 892', 3-3'/4©, S6W, VD 891.11, S29.36, E2.48. 1722' (830') Drlg Mud 73#, Vis 56, WL 12.2 cc's Directionally drld 12-1/4" hole 892-1722'. Survey' 1648', 13-3/4©, S23W, VD 1631.22, S167.92, W41.43. 2300' (578') Opening hole Mud 74#, Vis 61, WL 14.4 cc's Directionally drld 12-1/4" hole 1722-2300. Opened hole (18") 435-1400. Survey' 2300', 30°, SLOW, VD 2226.34, S428.63, W84.63. 3500' (1200') Drlg Mud 71#, Vis 37, WL 16.7 cc's Opened 12-1/4" hole to 18" 435-2265. Circ. made 5 stand wiper run. Had 5' fill. Cond mud, made 5 stand wiper run. No fill, POH. 9th stand pulled tite (300,000#) worked thru tite spot w/pump on in 15 mins. POH. Reran HO to 2265. Cond mud. 13-3/8" cs9 cmtd @ 2245'. Ran & cmtd 13-3/8" 61# K-55 buttress csg @ 2245 w/lO90 sx. Class "G" cmt premixed w/lO% Gel, followed w/400 sx Class "G" neat cmt. Preceded cmt w/lO0 'cf wtr, mi.xin~ time 75 mins. Displ cmt w/lO0 cf wtr & 1878 cf mud in 35 mins. CIP 11~50 AM, 4-26-69/had good circ thruout. Had cmt returns last 678 cf displ. Used Baker guide shoe & flex-i-flow collar @ 2207. Used 14 centralizers spaced @ 200' intervals. Used one btm & one top rubber plug. Bmpd plugs w/1500 psi. Float held O.K. Landing in Unihead w/full wt of csg. Removed 20" hydrill & riser. Inst 13-3/8" x 20" packing. RR to S-2 @ 2 PM, 4-26-69. Moved rig over cond @ 6 AM, 4-27-69. Directionally drld 12-1/4" hole 2300-3500. Tstd hydrill w/2000 psi. Inst 13-3/8" riser &,BOPE. Tstd w/1500 psi. Tstd pipe rams w/2600#. Circ & cond mud. Survey' 3541' 36© Sl5W VD 3269 08 S1078 43 W247 61 4318' (818') Drlg Mud 74#, Vis 39, WL 15 cc's Directionally drld 12-1/4" hole 3500-4318'. Survey' 4132', 31©, Sl8W, VD 3766.51, S1393.86, W343.'44. 5018' (700') Drlg Mud 74#, Vis 38, WL 10.3 cc's Directionally drld 12-1/4" hole 4318-5018'. Ran Sperry Sun survey on 13-3/8" csg 400-2300'. Survey: 4940', 29©, S21W, VD 4471.38, S1765.97, W476.02. Distribution: The Above is Correct: Orig.: Drilling Section- Dallas cc:- l)istrlct Office Engineering l)iv ision (720) (:o-Ownor (s) As Appropri at, e l~,gio~al Ol'l'icc, Wvll Ih.cord I"il,, PA(it; N(). ... ] .... (NIIMIII.'Ii All I)AII.Y WI,.I,I. Ill~-~'I'()IiY I,(HiM~-4 ('()N>;I ('IFI'IVI.I.Y AN I'Ill]Y AI{I I'lil]'Altl, l) I()l{ I.'A(:II ~l.l.l.. ) ... _ .., ,,'~ .. .x · 5/14/69 SIGNATUHE /,[/. DATE District Okilling Supervisor ............ Form No. P--4 REV. 9-30-67 STATE O'F ALASKA SUBMIT IN DEPLICATE O~L AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS NAME OF OPERATOR * Union Oil Conlpanv of California' 3. ADDRE~;S OF OPERATOR 507 Wesi~ Northern Liohts Blvd.: Anchnran~: Al_~$ka qq~;N~ 4. LOCATION O'F WELL v .. - .... 2608'N & 2488'W fr SE Cr. of Sec. 26, TION, R13W, SM OKG --~~'- ~. APl NUA'I~ICAL CODE ADL ~50-133- 20186 6] LEA~E DESIGNATION ADh 18776 ?. IF INDIAN, A~TrE~ OR 8. IINIT,FAI~M OR LEASE N.~.ME T~adina B~y Ilnit 1O. Fiau~D-A~ND-I~OOL. OR WILDCAT Trading Bay Hemlock OBJ'EC'TrVE ) Sec. 35, 11 ON, R13~, S~ 12. P]~VIIT NO. 69-39 REPORT TOTAL DEPTH AT END OF MONTH, CI-ZA~NGES IN HOLE SI~E, CASING ANT) C~%IENTING JOBS INCLUDING DEPTH SET A_N'D VOLUMES USED. PERFORATIONS, TESTS A/N'-D RESULTS. FISHING JOBS, JUNK IN HOLE A~ND SIDE-T'R~CKED HOLE AND A.NY OTHER SIGNIFICANT ~ES IN HOL~ CONDITIONS. Tradinq Bay Unit 5-5 (12-35) May, 1969 Directionally dri';lled 12-1/4" hole 5860-9247. Lost & recovered small piece of cone. Directionally drilled 12-1/4" hole 9247-9319. Stuck pipe. Backed off at 9065. Ran jars & bumper sub. Screwed into fish at 9065. Recovered all fish. Directionally drilled 12-1/4" hole 9319-11,562. Ran Schlumberger DIL 11,550'2238, Sonic 11,550-8000, Bensity 11,550- 8,000, & HDT Dipmeter 11,550-8,000. Ran 12-1/4" bit & cleaned out fill 11,550-11,562. Ran ~~_d_ 9-5/8" ..47#_ P-.!10~__~c80 casing at 11,527' (baffle collar @ 11,439) with 1000 sxs Class "G" cement premixed w/l% CFR-2.--~Tstd csg w/1500 psi. OK. Ran Dresser Atlas CBL-CCL log 11,437-8300, top cement @ 8400. Perforated 4 HPF 11,240-11,210 w/ Dresser Atlas 4" NCF csg. gun. Ran gauge ring & junk catcher to 11,250. Ran & set 9-5/8" Baker Model "D!' production pkr @ 11,190 w/3' x 3-1/2" tbg tail & 3-1/2" Otis "Q" nipple @ 11,200. Ran & hung (10,686' net) 4-1/2" 12.6# N-80 tbg @ 10,756 w/4-1/2" Otis "N" nipple @ 10,756; 9-5/8" 47# Otis RH-1 st. pull release pkr @ 10,718, Camco GL mandrels @ 10,502, 9.896, 9686, .8855, 8429, 7936, 6944, 5968, 4240 & 2087, 4-1/2" Otis ball valve @ 464. Removed BOPE & riser, installed Xmas tree, tstd tree w/5000 psi. OK. Displaced mud w/ Inlet water & Inlet water w/715 bbls. diesel oil. Pulled dummy sleeve in ball valve. Ran Otis "N" plug, set 9-5/8" Otis pkr @ 10,718 w/2500 psi. Pulled "N" plug. Tstd tbg & pkr.w/1500 psi. OK. GL'd diesel oil to 6000. GL'd 289 bbls diesel oil w/950 psi on csg. Bled off csg. Had no indication of entry from interval 11,210-11,240.. Perforated 4 HPF 11,180-11,150, 11,136-11,fl88, 11,074-11,064, 11,056-11,026, 10,998-10,'976 & 10,876- 10,826 w/2" Dresser Atlas thru tbg NCF gun. TP increased from 0-250 psi @ 25 psi increase w/each gun run. RIG RELEASED @ 4:00 p.m. 6-1-69. ) ~m~ I'l !1/ / ~'i/ .... :,= ' . g. Cpt. ~,.,.~ 6/12/6 9 NOTE~Rep~rt on/this form~ required for each calendar month regardless of the status of operation~, anO must ~ fileO in duplicate with the Division Of Mines & Mi~als by the 15th of the succeeding month, unless othe~ise directed. Atlantic Richfield Com~any~l , Sub-Operator Form No. P--4 REV. 9-30-67 STATE OF ALASKA SUBMZ~ nc Dm~LICA~ O~L AND GAS CONSERVATION COMMITTEE MONTHLY RE!PORT OF DRILLING AND WORKOVER OPERATIONS APl NLK%{ERICAL CODE ADL 50-133-20186 6. LEASE DESIGNATION A.R'D SERIAL ADL 18776 1. 7. IF INDIAN, ALOTT'EE OR TRIBE NASIE OIL ~ GAS [] WELL WELL OTHER 2. NAME OF OPERATOR *Union Oil Company of California 3, ADDRESS OF OPEI~ATOR ~07 West Northern Lights Blvd. ~ Anchorage~ Alaska 99503 4.LOCATION O,F WELL 260~'N & 2488'W from SE Corner of Sec. 26, T10N, R1BW, SM 8. LTNIT,FA/~'%¢ OR LEASE NAAIE Trading Bay Unit 9. %VELL b,'O. S-5 #12-97 10. FIELD A_ND POOL, OR WILDCAT Trg~di~ng. B~y gem_lock I1. SEC., T., R., 1%¢., (BO'FTOM HOLE O]SJ~CTIVE ) Sec. 35, T10N, R13W, SM 12. PER/VIIT NO. 69-39 13, REPORT TOTAL DEPTH AT END OF MON'IX-I, CI-IA/~GES IN HOLE SI~,E, CASING AND Ck--'MENTING JOBS INCLUDING DEPTH SET A_ND VOLU1VIES USED, PEB~ORATIONS, TESTS A/WI) RESULTS. FISHING JOBS, JLTNK IN HOLE A-ND SIDE-T'R~CKED HOLE AND ANY OTHER SIGNIFICANT CHAN~F,S IN HOI~ CONDITIONS. TRADING BAY UNIT S-5 (12-35') APRIL, 1969 Spudded ~ 8:00. A,M. 4-22-69. Directionally drilled 12-1/4" ho~1~3~-2300. Opened hole to 18" 394-2265. Ran & cmt'd 13-3/'8" 61# K-55 Buttress csg. '"~ 2245/~/1090 sxs. Class "G" Cmt. premixed with 10~, followed w/400, sxs. Class "G" N~a~Y~cmt. '~ ~(Shoe ~ 2245' cOllar ~ 2207'. ) La'nded casing. Installed BopE. Tested with~500 psi. Tested pipe rams with 2600#. Directionally drilled 12-1/4" hole 2300,5860.. /~ // *Atlantic Richfield Company - Sub0perator HLB /,.:,.~~- ~ TRM ~ OKG KLV . ' HWK r-' RI=L , ._,'~" / ¢ FILE RECEIVEO 15 1969 DIVISION OF O!!. AND GAS ANCHGt~.GE 1~. I hereby certify e SIGN~ Dist. DRlg. Supt. DA'I'~ 5/14/69 ,, i1111/ NOT[J~I~et orti~on thi JS required for each calendar month, regardless of the status of operations, and must ee filed in duplicate with the Division of Mines & /linerals by the lSth of the succeeding menth, unless otherwise directed. OtVIStON. ~ Olt. ~ ~ April Z,?., 1969 Re: Trading t~ay Ll~tt S-$ Ne. 12-35 Unica Ot 1 Cempaqy of Calt forntm, Operator Oear Sir: £nclose~ is ~ approved application for permit te drill t~ ref~~ ~ell, ~1t sa~pl~ and core chips are not required. Futura appitcattoas mr permt~ to drill deviated holes Should cenferm wltb Secttea gO~ ef Uae ,0tl and Gas Conservation ~tegulatio~s. - .Ortlltag of both the refereace~ wel 1 and the S-Z welt has been approve~ as necessary to afford protection against operations nat ~eier t~ Tra~tn9 gay Unit Agreem~t, Pursuant to the last seato~ce of Secttoa 10 of said unit ag ~reement, future wells within t~e unit area ebtch are not necessary ~ protect against drainage ~ust be ~Ithtn the appro~ plan of development m~:spe¢tftcally approved by t~ Ot~~r Otvt$1ea ef Lands. Very truly yours E~losure ,c~ Dirtier DiVision of La~s Paamer L. 8ur.retl Ofrector FORM SA- lB ~-:.: ~EMORANDUM TO: I-- FROM: State of Alaska ~~ OF iMTU~4L IF~ES BIVlSION OF OIL ANO GAS DATE : SUBJECT: Eacl~ are ~ alqtemml at~lt~atiam far pemit ta drill, & leclttea ami & ~, la the .ameaat af SSO ~ ltl-tag fee far ~ abe~e eefer- ~e11. ~lesur,es FORM SA - ~ B /;;;~.-~?;" MEMO-RANDUM TO: J'- state' of Alaska OIVISI~ OF OIL ~ ~ DATE FROM: JJJJiJlJ~' L. ll.t'~ll .SUBJECT, Trading B~y Uatt S-.5 No. 12-35 ~on (Jtl ~ 04' Caltforfii&, [nc~ ts J eol~' of ~ appJ. ewsl eppllcat;Ion for peru~.t, to dr111 fro' the above FefetrJJmed ue11. AtlanticRichfieldCompany North Americ.-_ Producing Division Alaska District Post Office Box 360 Anchorage, Alaska 99501 Telephone 907 277-5637 April 17, 1969 State of Alaska Department of Natural Resources Oil and Gas Division 1001 Porcupine Drive Anchorage, Alaska Attention: Mr. T. R. Marshall, Jr. Gentlemen: Re: Trading Bay Unit S-5 ~12-35 Section 35, T10N, R13W, SM Enclosed please find the Application for Permit to Drill, in triplicate, together with plats of the location, and a check in the amount of $50 to cover the filing fee. Texaco, being the only off-set operator affected, has been notified by copy of this application by certified mail. Very truly yours, R. D. J~nStone Distri~-Jx --Drilling Supervisor Atlantic Richfield Company Robert T. Anderson District Land Manager Union Oil Company RDJ:tll encs (3) RECE VE APR 1 ~VO (]NV 110:10 NOlglAI(I DIVISION OF OIL AND GAS ANCHOR~E Form P~I REV. 9930-67 STATE OF ALASKA OIL AND GAS CONSERVATIO'N ,CO,MMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK 1R. TYPE OF WORK DRILL i~ DEEPEN C3 PLUG BACK [--I b. TYPE OF WELL WELL WELL OTHER ZONE ZONE RECEIVE (Other instructions on reverse side) API 50-133-20180qPR 1 8 1969 5, Di¥1$1ON OF OIL AND GAS e. ~ D~X~~ S~ NO. 8. UNIT, FARM OR LEASE NAME ~rad~nE Bay Unit 9. WELL NO. v 3-5 //12-35 10. FIELD AND POOL, OR WILDCAT :e'Trading Bay Hemlock HOLE OBJECTIVE) 3ec. 35, T10N, R13W, SM 12. o=,a00,000. oo 17. NO,- ACRES ASSIGNED TO THiS WELL ~' 80 201 ROTAR~ OR CABLE TOOLS RqtarY~, 2. NAME OF OPERATOR *Union 0il Company of California 3. ADDRESS O~F OPERATOR 2805 Denali Street. Anchorage Alaska 99502 4. LOCATION O'F WELL At surface 2608'N & 2488W fr SE Cr, Sec. 26, T10N, RiBW, SM At pr(~posed prod. zone 1600'S & 660E fr NW Or, Sec. 13. DISTANCE IN MILES AND D.~!!~E.~!_ON F-~OM, NEAR~ST TOWN OR.POST OFFICE* ~0 miles NW from ~ena%, A±~s~ - , : , , , 14. BOND INFOI~VIATION: Statewide Federal Insurance Co. //8011-:38'40 TYPE Suret~ and/or No, - ~ ';'I18, NO.~'OF; ~CRES IN- LEASE DISTANCE FROM PROPOSED* " ' '-[~' f '~' - ' '' 15. LOCATION TO NEAREST ...... 960" -!'-1' ' ' '" 9'60~ PROPERTY OR LEASE LINE; FT. '- '~ ' (Also to nearest drig, unit, if any) .......... 18. DISTANCE FROM PROPOSED I~OCATION* ' '" ~' - · TO NEAREST WELL DRILLI*NG,· COMPLET~q~ ~- 7; ; :1 ! i9. PRoPOSED-DEPTH OR APPLI]~D FOR, FT. ..... i:00! ........ -:'l''' li'600'i:~D . 21. ELEVATIONS (Show whether DF, RT, C-R, etc.) 22. APPROX. DATE WORK WILL START* 115' KB 4-21-69 - '': '1~.%O1~ S~3 C~Xt~tl -' ':=O--':=''~'----- AND CEMENTING ~ut, r,4.,u.vz~ '~' ' SIZE OF HOLE SIZE OF CASIN~ i":'~VEI"GHT pEi~'~OoT':' GRAIy~ J f; SETTING DEPTIi ' QUANTITY OF CISM~'N~I _ :8" ]_~-~/8" 6z~ J-ss m'oo, ' ~.oOo"~x~. Logging ~ TD . Mud loggers from ~9,000' " **To be co-mingled in the well bore with Trading Bay "G" NE 0il Pool Zone. 20" Hydril on 20" casing 13-3/8" gates w/.5" rams -and CS0.~rams tested to:3,0'00 psi 13-3/8" Hydril .) *Atlantic Richfield Company - Sub OPerator IN ABOVE SPACE DESCRIBE PROPOSED PROGRANi: If proposal is to deepen or plug back, give data on present productive zone and proposed r~ew productive zof~e. If Pr(~posal is to drill~r deepen direct:ormlly, give pertinent data on subsurface locations and measuxed and true vertical depths. ~Give bl~9~,~'"'preventer ]~gFarm 24. I he/~~fy that~l~F~e~f~g is True a?,~o~//~' S!G -~ ('"'--"~'""~DATE , prll 18~ 1969 =~ ,, Landman (This space for State office use) CONDITIONS OF APPROVAL, IF ANY: SAMPLES AND CORE CHIPS REQUII~D [] YES ~[ NO DIRECTIONAL SURVEY REQUIRED ~YES [] NO OT~IER REQU~TS: A.P.I. NUMERICAL CODE g~O -- 13%- "L..e April 21, 1959 April 21, 1969 S¥O (INV liO -I0 NOIglAI(I April 17, 1969 TEXACO INC. P. O. BOX 664 ANCHORAGE, ALASKA 99501 RECE, VE APR 1 DIVISION OF OIL AND GAS ANCHOJtAGE ATLANTIC RICHFIELD COMPANY ~LL S-5, NO. 12-35 SPARK PLATFORM TRADING BAY - ALASKA mllllJ..~ IIA.I . _ _ ' ..... 3" : ' : - ' ..... State of Alaska Division of Oil and Gas 3001 Por~pine Drive Anchorage, Alaska Attention~ Mr. Homer Burrell Oentlemen~ Reference is made to Atlantic Richfield's application to drill the subject well. In accordance with Section 2060 of the Conservation Regulation, please be advised Gat Texaco has no objection to Se well location. Very truly yours, TEXACO Inc. Claude H. Brown District Landman CHB:gem coz Atlantic Richfield Company Anchorage, Alaska ~ ~ 22 27 O. .. -T-TIO N- R 13W SUPERIOR'- TEXACO / / ,/ ':~,.TEXACO--O // / ,. ~ /// / / t / / /,/ / '/ / / / / / / 34 / / / / ,/ / \ \ b 23 i I ! I i TRADING I I BAY UNIT UN ION - MAR;~ThON 25 A~CO i ARCO I t I S-4 t "SPARK PLATFORM" S-3~--- ' /. , // //" '" :i S-t/// // ," i ~" : ,'ARCC: / ,,. / / / S-5 35 ARCO - SOCAL 19 36 3O ATL ANTICRICH FIE L DCOMPANY ALASKA DISTRICT WELL LOCATION MAP TRADING BAY UNIT State S-5 (12-:55) SCALE 1"=2000' 0 I000 _ 2oo~ FOR WELL PERHITS Yes No Remarks apply :./:i.t't a'.l. 1 casz:':g g:tve adequate. ~" ' ...... ............... ..... uy c.,3,.: ........ ,;£,<: ,?.'nd tension Karl. L. VonderAhe Robert E. Larson