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174-027
STATE OF ALASI:A ALASK IL AND GAS CONSERVATION COMMI~N WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: Oil ~ Gas ~ Plugged ~ Abandoned Q, Suspended ~ 20AAC25.105 2onnc2s.iio GINJ ^ WINJ ^ WDSPL~ WAG ^ Other^ No. of Completions: 1 b. Well Class: Development 0' Exploratory~ Service ^ Stratigraphic Test~ 2. Operator Name: Marathon Oil Company 5. Date omp., Susp., or Aband.: 9/2/2009• 12. Permit to Drill Number: 174-027-0 • 3. Address: P.O. Box 196168, Anchorage, AK 99519-6168 6. Date Spudded: 8/3/1974 13. API Number: 50-733-20265-00-00 • 4a. Location of Well (Governmental Section): Surface: 2570' FSL & 2563' FEL, Sec 26, T10N, R13W, SM 7. Date TD Reached: 11/2/1974 14. Well Name and Number: N. Trading Bay Unit S-09 • Top of Productive Horizon: 1571' FSL & 133' FEL, Sec 34, T10N, R13W, SM 8. KB (ft above MSL): 115 • Ground (ft MSL): 15. Field/Pool(s): G-NE/Hemlock-NE Oil . Total Depth: 1262' FSL & 342' FEL, Sec 34, T10N, R13W, SM 9. Plug Back Depth(MD+TVD): 51' below mud line 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 227686.231 y- 2534437.376 Zone- 4' 10. Total Depth (MD + TVD): ' 12717 MD, 10066 TVD . 16. Property Designation: ADL017597 , TPI: x- y- Zone- Total Depth: x- 224482.032 y- 2527923.053 Zone- 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: 18. Directional Survey: Yes ~ No ~ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: 60 (ft MSL) 20. Thickness of Permafrost (TVD): ~ ~ 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): ~~~$~(~ ~il ~t 1i8S 22. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT ~ TOP BOTTOM TOP BOTTOM PULLED 13-3/8 72 N-80 0 2720 0 2571 17-1/2 1500 sks "G"/10% gel 500 sks "G" Neat tail 9-5/8 47 N-80 0 11160 0 8894 12-1/4 900 sks "G" 7 29 N-80 10863 12714 N/A 10063 8-1 /2 570 sks "G"/1.0 % CFR-2 & 02 % HR-7 23. Open to production or injection? Yes~ No0 If Yes, list each 24. TUBING RECORD interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2 600-11899 Otis WD pkr C~ 11834 4 ` `! ~^ ~jj'~(; ' i %~l ~5 r ~~ ' i! ~ 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~ „ L U U~ . DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 9/02/09 tagged TOC @ 51' BML 275-575 41 bbls, 203 sks 1.132 yd, 15.9 ppg "G" Neat CIBP @ 575 8/23/09 tagged TOC @ 9555' RKB 9555-10318 24 bbls, 119 sks 1.132 yd, 15.9 ppg "G" Neat 8/09/09 tagged TOC @ 10418' RKB 10418-11899 25 bbls, 124 sks 1.132 yd, 15.9 ppg "G" Neat 26. PRODUCTION TEST Date First Production: Method ot 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 Q If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. Form 10-407 Revised 2/2007 N REVERSE /D• tL•O~ ~~ ~ion ~ fZ~'~~.`~`~ • • ~S. GEOLC)C~fG MP,RKLfiS (List ali f -~~~~ ormations and mark ^-~ ers encounter~d)~ 29.~~ y~ ~~ ~di3MATl01~ TESTS ~~ ~ a NRME __ _ MD TVD ~ti~eil tested? D Yes ~ 1' ^ No . if yes, ist intervals and formations fested, __ ~~~ briefiy sun;marizing test results. Attach separate stieets to this iorm, 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 12,139 9,623 G-4 12,245 9,704 G-5 12,304 9,750 Top of perf targeting Hemlock zone H-1 12,360 9,793 H-2 12,415 9,836 Tyonek 3,750 3,358 MGS 5,580 4,706 "G" Producing 12,136 9,621 Hemlock 12,355 9,789 Formation at total depth: Hem lock 12,717 10,066 30. List of Attachments: summary of abandonment, final P&A welibore diagram 31. I hereby certify that the foregoing is true and correct to the best of my knowiedge. Contact: Tiffany Stebbins Printed Name: Tiffany Stebbins Titie: Regulatory Compliance Representative Signature: ,`~ Phone: 907-565-3043 Date: 10/19/2009 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for lnjection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pooi 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 interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analyticai 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 informalion required by 20 AAC 25.071. Fonn 10-407 Revised 2/2007 Marathon Oil Company • • Page 1 of 2 North Trading Bay Unit no. S-09 API 50-733-20265-00-00, Sundry Number: 309-145 Work Summar 8/02/09 Open 9-5/8" csg with 650 psi and bleed off thru gas buster to 0 psi. Pump 86 bbls fluid down 9-5/8" csg and pressured up to 1000 psi. Pressure fell to 900 psi (same as tbg psi). Bled back to 0 psi, returning 25 bbls, and pressured up again with 10 bbls, to 1000 psi. Shut in csg. 8/03/09 R/U pump hoses and open 9-5/8" csg to 500 psi. Bleed down to 0 psi, returning 20 bbls. Pressure back up to 1000 psi (50 bbls). Pressure slowly equalizing into tubing. R/U on 3-1/2" tbg and pump 120 bbls with 900 psi at the start and 1800 psi at shut down. Pressure fell back down to 900 psi. 8/05/09 R/U slickline with 2.25" G.R. and test lubricator to 2000 psi. Open well and RIH to 11899' RKB. POOH R/D slickline and lay down lubricator. 8/06/09 M/P 25 bbis, 124 sks of 1.132 yield, 15.9 ppg, class "G" Neat cement down tbg, displacing to 10167' RKB 1~ before pump pressure came up to 3000 psi. Continued multiple times to squeeze in more cmt, but pressure never did fall. Shut in well with 3000 psi. 8/09/09 R/U on 9-5/8" csg and tbg and open well. Bleed off 2500 psi left on well from locking in squeeze job. 9-5/8" csg returning pure oil with gas. Returned 175 bbls of oil after re-rigging flow back tank to upper deck storage tank because of lack of disposal capabilities. Circulate down tbg until csg pressure on 0 psi. Shut in choke and pressure up csg and tbg together (because of gas lift valves) to 1500 psi and chart same for 15 minutes. Good test. Bleed pressure to 0 psi. R/U e- line with 1-11/16" weight bar and RIH to 10418' tag TOC. POOH 8/20/09 R/U e-line lubricator on well. M/U 2 ft of perforating guns @ 4 spf and RIH to 10418' RKB. Pull up 100 ft to10318' RKB and perforate. POOH Out of hole. R/D wireline. ~- 8/21 /09 Circulate holding tanks full of returned oil and transfer to ISO Tanks that were lifted up from boat. Load 70 bbls in each tank before loading back to boat. Loaded total of 199 bbls oil in tanks. 8/22/09 R/U lubricator and pump hoses. Offload ISO Tank from boat and set on work deck. Transfer oil into tank while circulating remaining oil out of 9-5/8" csg. Returns are clean. Shut down pmp and R/U pmp hoses to S-5 and begin injecting disposal fluid down tbg. Backload ISO Tank onto boat. Total of 66 bbls of oil put on boat. Still injecting disposal fluid. 8/23/09 R/U equipment and materials needed for cement job. M/P 24 bbls, 119 sks of 1.132 yield, 15.9 ppg, class "G" Neat cement down tbg, taking returns out of 9-5/8" csg, displacing TOC to 9918' RKB, leaving a 400' intermediate cmt balance plug from 10318' to 9918' RKB, in both the 3-1/2" tb~ g ncl~f'ie 9-5/8" x 3-1/2" annulus. WOC Clean all cmt equipment and work deck. 8/24/09 Pressure up to 1000 psi on tbg with csg pressure coming up the same (gas lift valves). Good test. R/U lubricator and e-line. RIH with 1-11/16" weight bar and tag TOC at 9495' WLM (9555' RKB). Pull up 500' & wait on AOGCC to arrive. AOGCC arrived. RIH and tag TOC at same depth. POOH and R/D e-line. Test intermediate plug to 1000 psi and hold on chart for 15 minutes. Good test. Bleed off pressure. N/D and remove tree. R/U hanger jack and lift 59,000 Ibs on hanger and witness hanger movement. Release hanger and R/D jack plate. R/U e-line and splice into SCSSV on hanger and pump open while backing out hanger lock pins. .r Marafhon Oil Company ~ • Page 2 of 2 North Trading 8ay Unit no. S-09 API 50-733-20265-00-00, Sundry Number: 309-145 RIH with 3-1/2" tubing cutter to 600' RKB and cut tbg. Tubing hanger came up 2 ft, verifying cut. POOH & R/D E- line, 8/25/09 R/U handling tools and POOH with 3-1/2" tubing. Laid out tbg on deck and tested for NORM. None was found. Total pipe pulled out 537.43' (597.43 RKB) 8/26/09 RIH with G.R. and tag top of tbg at 548' WLM. POOH M/U CIBP and RIH to 575' RKB and set. POOH. R/U lubricator and e-line. M/U 2 ft perf gun C 4 spf and RIH to 575' RKB and fire gun with 500 psi on 9-5/8" csg. Pressure fell to 0 psi. Circulate 3 bbls and shut down pump. R/D and lay down lubricator and e-line. 8/27/09 Circulate 70 bbls. M!P 41 bbls, 203 sks of 15.9 ppg, 1.132 yield, class "G" Neat cement for a 300' cmt balance plug in both the 9-5/8" and the 13-3/8"x 9-5/8" casings, from ± 574' RKB to ± 274' RKB. 9/02/09 ~ RIH to 51' BML and tag TOC. Pull up to surface and wait for AOGCC to arrive. RIH and tag TOC at 51' BML with AOGCC present. POOH . ~ "~1~0~ RKB-MSL 115' ~ Marathon Oil Company ~ North Trading Bay Unit Spark Piatform Well S-9 "FINAL P&A CONFIGURATION All Depfhs measured RKB to top of equipment Water Depth 60' Max Angle = 45 deg @ 3976 & 9029' TMD @ 12717' ND @ 10066' MASTP 1067 psi MIT 6/16/20D9 API # 50-733-20265 Surtace Pipe @ 2720' 13 3/s" 72 ppf N80 Buttress 12.347" ID .1480 bbl/ft CMT 2000 sks CTOC = Surface Gauge Hole Calculations Production Tubing Q 11899' 3 1/z" 9.2 ppf ABC Mod. N80 2.992" ID .00870 bbl/ft Packer Fluid 3% KCL Gas Lift Valves 2276' 3/8" port 9175' 3/8" port 4065' 3/8" port 9706' 3/8" port 5573' 3/8" port 10238' 3/8" port 6671' 3/8" port 10767' 3/8" port 7486' 3/8" port 11267' 3/8" port 8112' 7/16" orif 11768' 7/16" orif 8611' 3/8" port TOL 7" @ 10863' Intermediate Casin~ C~ 11160' 9 5/s" 47 ppf N80 Buttress 8.681" ID .0732 bbl/ft CMT 900 sks CTOC @ 8177' Gauge Hole Calculations 7" x 4" Otis WD Packer w/ seal bore extension @ 11834' Mule Shoe @ 11899' Perforations G-2 12139'-12189' G4 12245'-12260' G5 12304'12324' H 1 12360'-12390' H 2 12415'-12455' Production Liner (~ 12714' 7" 29 ppf N80 Buttress 6.184" ID .0371 bbl/ft CMT 570 sks CTOC @ 7548' Gauge Hole Calculations Circulated Cement to TOL MARATHON SPARK S-9 FINAL P&A CONFIGURATION All depth are RKB unless o.therwise noted Witnessed Ta~ TOC @~51' BML I/ ~348' Surface Cement Plug 95/8'CSGand95/s"X133/a"Annulus ~574' RKB to ~226' RKB M& Pumned 41 bbls 15.9 pp~ "G" CMT ~~ ~~ 8/26/2009 qo`' ,~ Pertorated 9 5/8" Casing @~ 574' RKB 9~145 ~ i ~' Set CIBP (~ ~575' RKB ~ ' j ~ 8/24/2009 ~ Cut & Pulled 31h" Tubin @~600' RKB ~~~' ^ Q SSS ~ K K8 8/24/2009 ~~ ~-~ AOGCC Witnessed Ta TOC C~ ~ '~ ~fa•t~ .n' ia y -~ 8/23/2009 ~ ~763' Intermediate Cement Piug ~10318' RKB to ~ 9555' RKB ~ M& Pumped ~24 bbls 15.9 ppg "G" CMT /20/ 9 Pertorated Tubing C~ 10318' RKB '" 8/9/2009 Tagged TOC ~ ~10418' RKB / 8/6/2009 ~1481' Bottom Hole Cement Plug ~11899' RKB to ~10418' RKB M& Pumped ~25 bbls 15.9 ppg "G" CMT ~ 8/5/2009 - RIH W/ GR to Mule Shoe C~ ~11899' RKB ~_~' ~~ ~ ~ ~~ ~ POLLARD WIRELINE REPORT ~,~ ~ ~ a~ ~~ ~~ ~~ ~` ~ ~ FILL TO 12390' MIT 6/16/2009 ~~ ~'~~ ~ ~ ~ ~ r ~ ~~~ ~ ,~ ~ WIRELINE FISH @ 12391' -12419' ~ ~~ ~ ~ ~~ ~' Fill to 12419' WLM (8-11-90) ~~'~ ~ ~ ~~~ ~ ~~ ~: ~ ... PBTD = 12629' ,. - TMD = 12717' . PAGE 1 9/30/2009 MEM RAND M~ State of Ala~ka O U Alaska Oil and Gas Conservation Commission TO: Jim Regg ~~~ ~ ~C~IIN(~ i P.I. Supervisor FROM: Jeff Jones Petroleum Inspector DATE: September 2, 2009 SUBJECT: Plug & Abandonment S-09 Marathon Spark PLT TBF / NTBU , PTD 1740270 / Sundry 309-145 Section: 26 ' Township: 10N Range: 13 ` Meridian: SM Drilling Rig: N/A Rig Elevation: RKB 115' MD Total Depth: 12717' MD Lease No.: 017597 " Operator Rep.: Dan Byrd Casinq/Tubinq Data: Casinq Removal: Conductor: O.D. Shoe@ Casing Cut@ Feet Surface: 13 3/8" O.D. Shoe@ 2720' MD Casing Cut@ Feet Intermediate: 9 5/8" O.D. Shoe@ 11,160' MD Casing Cut@ Feet Production: O.D. Shoe@ Casing Cut@ Feet Liner: 7° O.D. Shoe@ 12,714' MD Casing Cut@ Feet Tubing: 3.5" O.D. Tail@ 11,899' MD Casing Cut@ 600' RKB Feet Pluqainq Data: Tvpe Pluq Bottom of T.O.C. Mud Weight (bottom up) Founded on Cement T.O.C. Depth Verified? above plug Pressure Tes Surface Brid e lu 575' MD 166' MD Yes 8.7 No , I Tvpe Pluq Founded on: Verified? Open Hole Bottom Drillpipetag ~ ~ ~~.~ ~ ~~ ~~ ~~y~~ Perforation Bridge plug Wireline tag ;~~,~'i:~~~»~ ` ~~ Annulus Balanced C.T. Tag Casing Stub Retainer No Surface September 2, 2009: I traveled to Marathon's Spark Platform in Cook Inlet to witness a wireline tag to confirm proper placement of a cement surface abandonment plug in NTBU well S-09. Dan Byrd was the Marathon representative for the test today. Mr. Byrd informed me that the mud line datum is 115' MD from the tubing hangar and was corrolated to the tubing hanger and the SSSV. Mr. Byrd indicated that the 3.5" tubing is removed and a cast iron bridge plug (CIBP) is set at 575' MD in the 9 5/8" casing and holes were punched in the 9 5/8" casing and 300' (41 bbls) of 15.9 PPG class G cement was placed above the CIBP and in the 13 3/8 by 9 5/8" annulus. I witnessed the wireline tool tag bottom solidly at 166' MD. Summary: I witnessed a successful wireline tag to confirm placement of a surface cement abandoment plug in Marathon's Spark Platform well NTBU S-09 in the Trading Bay Field. cc; Distribution: -Well File (original) -Read File -DNR/DOG Attachments: none Rev.:01/26/09 by L.R.G. 2009-0902_P&A_surf plug_NTBU_Spark_S-09Jj.xls 10/16/2009 ~ • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg '~~'~~' ~(~~~~~~ DATE: P. I. Supervisor FROM: Lou Grimaldi SUBJECT: Petroleum Inspector August 27, 2009 Wellbore plug integrity Verification Intermediate Plug Marathon Oil Company Spark Platform, NTBU S-09 PTD #174-027, Sundry #309-145 / Mondav, Auqust 24, 2009; I witnessed the pressure test and tag of top of cement (T.O.C.) by wireline (W.L.) of the Intermediate cement plug in Marathon's Spark platform well # S-09, North Trading Bay Unit. A 1-11/16 inch tool string was run into the well on W.L. to a depth of 9496 feet wireline measurement (W.L.M.) where it fetched up hard. The plug was tagged 3 ~ times with out any signs of going deeper or sticking. Reportedly the inner annulus (I.A.) was in communication with the tubing; this was proved out as the I.A. pressure rose and declined with the tubing during the test and bleed-off. The tubing/I.A. was pressure tested to 1120 psi for 15 minutes. After an initial decline of 20 psi the chart recorder drew a straight line for the 15 / minute test. There appears to be a competent intermediate cement plug at 9556' R.K.B. __ (elevation 60') / 9496' W.L.M. (T.H.F.). ` Attachments: None ' ~ M:~ ; ~ ~ ~ E ~~ ~. Non-Confidential ° •~°~~° - ~ ~ ~ ~ ~~~~ Wellbore Int Plug NTBU Spark S-9 08-24-09 LG.doc 1 of 1 Revised plugging procedure & di~am Spark ~-9 • Page 1 of 1 Schwart~, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, August 20, 2009 9:29 AM To: 'Stebbins, Tiffany A.'; Aubert, Winton G(DOA) Cc: Laughlin, Gary A.; Paxton, Todd D. Subject: RE: Revised plugging procedure & diagram Spark S-9 ~~T~ ~~y- ~ Z- ~ Tiffaney/Todd, I concur with the revised program to P& A S-09 as outlined in the revised procedure below. (Basically, the procedure is moving the intermediate cement plug uphole 600 ft) Please keep me informed of any changes to this procedure if things do not go as planned. Thanks, Guy Schwartz ' V `" .~,~~~ _ . ~r)~,''` Senior Petroleum Engineer AOGCC 793-1226 From: Stebbins, Tiffany A. [mailto:tastebbins@mara#honoil.comJ Sent: Tuesday, August 18, 2009 10:30 AM To: Schwartz, Guy L(DOA); Aubert, Winton G(DOA) Cc: Laughlin, Gary A.; Paxton, Todd D. Subject: Revised plugging pracedure & diagram Spark S-9 Guy, Attached please find a revised plugging procedure and current and revised proposed wellbore diagram. «Marathon_CI_S-9_Permit Procedure 8-17-2009.docx» «Marathon_CI_S-9_WB 8-17-09.xlsx» Thanks, V a~~~, ~ ~e~.i.n,~, Regulatory Compliance Representative Marathon Oil Corporation Phone 907-565-3043 Cell 907-529-0522 Fax 907-565-3076 8/20/2009 ~~ MARA7HON OIL COMPANY NORTH TRADING BAY UNIT SPARK PLATFORM WELL S-9 AB NP)~~I_Mi~NT PROCEp_ E 08/17/2009 REVISION WELL DATA API # 50-733-20265 Elevation: 115' KB - MSL Production Liner: Water Depth: 60' MAX Angle: 45 ° C~? 3976' & 9029' TMD: 12717' ND: 10066' MA5TP; 1067 psi MIT 6/16/2009 Tubing: Packer Fluid: 3% KCL Packer: Surface Casing: 13 ~/s" 72 ppf N80 @ 2720' 12.347" ID, .1480 bbl/ft TOL: CMT 2000 sks CTOC C~? Surface Gauge Hole Pertorations: Intermediate: 9 5/s" 47 ppf N80 C~ 11160' Fill: 8.681" ID, .0732 bbl/ft CM7 900 sks PBTD: CTOC ~ 8177' Gauge Hole CURRENT STATUS • 7" 29 ppf N80 C~ 12714' 6.184" ID, .0371 bbl/ft CMT 57fl sks CTOC C~ 7548' Gauge Hole 3'/z° 9.2 ppf ABC N80 @ 11899' 2.992° ID, .00870 bbl/ft Otis WD packer ~ 11834' C~ 10863' 12139' to 12455' @ 12390' MIT 6/16/2009 12629' The well has no further utility and is to be 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 operation of the 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 any pressure through gas buster. Fill and test casings with weighted fluid. Report results. Note: Pollard Wire Line report indicates that they ran in the hole with a 1.50" Gauge Ring to 12390' RKB and tagged fill. Gauge Ring fell / dropped "slow" from 10860' RKB to 11900' RKB. 4. Perform JSA for proper wire line operation. Pressure up on SCSSY control line and lock SCSSV open. Rig up wire line lubricator and test to 2000 psi and run gauge ring to the end of tubing at ~11899' puil wire iine piugs as needed. POOH. Rig down wire line. 5. Perform JSA for mixing cement and pressure pumping. Rig up pump and lines on tubing. 7est pump lines to 2000 psi and establish an injection rate while monitoring 9 5/a" casing for communicatian. Record injection rate and pressure. Marathon Sperk we11 S9 Procetlures Pege 1 8/18/2009 . • 6. Mix and pump ~25 bbls of 15.9 ppg "G" cement and squeeze pertorations. Squeeze to 1000 psi over injection pressure or until top of cement is displaced to a depth of ~1041$' RKB. 7. WOC and test to 1500 psi. Record results using a continuous pressure chart recorder. 8. Perform JSA for electric line operation and explosive handling. Rig up electric line lubricator and test to 1500 psi. RIH with pertorating guns loaded with 2 ft of 4 SPF tubing punch and tag top of cement for bottom hole cement plug, (~ ~10418' RKB and record results. Pick up and shoot tubing at ~10318' RKB, POOH. 9. Perform JSA for cement mixing and pressure pumping. Rig up cement pump and lines. Test pump lines to 1500 psi. Break circulation down the 3 1/z" tubing taking returns up the 9g/s" casing. Mix and pump ~24 bbl 15.9 ppg "G" cement slurry for a~400' cement plug from -10318' RKB to ~9918' RKB in the 3~/s" tubing and in the 3'~z" X 9~/s" casing annulus. 10. WOC and test to 1000 psi. Document results using a conCinuous pressure chart recorder. 11. Perform JSA for electric line operation and explosive handling. Rig up electric line lubricator and test to 1000 psi. RIH with jet cutter and tag top of intermediate cement plug @~991$' RKB and record results. Pick up and cut 3~~" tubing at -600' RKB. 12. Rig down tree. 13. Perform JSA for proper pipe handing procedures. Pull 3~s" tubing and check for N.O.R.M. 14. Perform JSA for proper electric line operation and explosive handling. RIH with 9~/s" gauge ring and tag top of tubing stub at ~600' RKB. POOH. 15. RIH with 9 5/s" CIBP and tag tubing stub ~~600' pick up and set CIBP Q~575' RKB. 16. RIH with perforating gun armed with 2 ft of 4 SPF casing punch, tag C~BP and fire guns. POOH. RD electric line. 17. PerForm JSA for cement mixing and pressure pumping. RU pump and lines. Test lines to 1000 psi. NOTE; IF P45SIBLE A) Circulate clean, down the 13 3/~" casing and up the 9 5/a" casing with weighted ituid. Mix and pump ~41 bbl cement slurry for a~300' cement plug in the 9~/s" casing and the 9 5/s" X 13 3/s" casing annulus from ~575' RKB to ~275' RKB. B) If unable to circulate the 9~/s" X 13 ~/s" casing annulus, RIH with work-string to CIBP, Pick up work-string ~~0' and displace a-22 bbl slurry for a~300' cement surFace plug from ~575' RKB to ~275' RKB in the 9 ~/e" casing only. 18. Pick up work-string ~20' above top of cement and circulate clean. Pull work string put of hole. 19. WOC. Perform JSA for wire line operations. Run in hole with blind box and tag top of surtace cement plug C~ ~275' RKB and record results. POOH. 20. RD. Welt is abandoned. Marathon Sperk Welf S9 Procedures Page 2 8/18f2009 ~ ~ MA~tATHOM RKB-MSL 115' Water Depth 60' Max Angte = 45 deg @ 3976 & 9029' TMD @ 12717' 1VD @ 10066' MASTP 1067 psi MIT 6/16/2009 API # 50-733-20265 Surtace Pipe @ 2720' 13 3/s° 72 ppf N80 Buttress 12.347" ID .1480 bbl/ft CMT 2000 sks CTOC = Surtace Gauge Hole Calculations Production Tubin~ @ 11899' 31/z° 9.2 ppf ABC Mod. N80 2.992" ID .00870 bbl/ft Packer Fluid 3% KCL Marathon Oil Company North Trading Bay Unit Spark Platform Well S-9 "PROPOSED 8/17/09 REVISION" Gas Lift Valves 2276' 3/8" port 9175' 3/8" port 4065' 3/8" port 9706' 3/8" port 5573' 3/8" port 10238' 3/8" port 6671' 3/8" port 10767' 3/8" port 7486' 3/8" port 11267' 3/8" port 8112' 7/16" orif 11768' 7/16" orif 8611' 3/8" port TOL 7" @ 10863' Intermediate Casin~ @ 11160' 9 5/s" 47 ppf N80 Buttress 8.681" ID .0732 bbl/ft CMT 900 sks CTOC @ 8177' Gauge Hole Calculations 7" x 4" Otis WD Packer w/ seal bore extension @ 11834' Mule Shoe @ 11899' Perforations G-2 12139'-12189' G4 12245'-12260' G5 12304'12324' H 1 12360'-12390' H2 12415'-12455' Production Liner @ 12714' 7" 29 ppf N80 Buttress 6.184" ID .0371 bbl/ft CMT 570 sks CTOC @ 7548' Gauge Hole Calculations Circulated Cement to TOL • Revised 8/17/2009 All Depths measured RKB to top of equipment All depth are RK8 unfess otherwise noted )C ~ No More Than 100' Below ML 5/a" and 9 5/s' X 13 3/s" _~42 bbi Slurry ~Ya' only = ~22 bbis Slurry 575' RKB to -275' RKB 100' BML MAX :rforate 9 5Ya" f~ --575' RKB Set CIBP ~ -575' RKB Cut 3'/z° Tubin C~? ~600' RKB ~400' Intermediate Cement Plug ~10318' RKB to - 9918' RKB -24 bbls 15.9 p °G' CMT Slurry 8/9/2009 Ta ed TOC ~ -10418' RKB 8/6/2009 -1972' Bottom Hole Cement Plug -12390' RKB to ~10418' RKB M&P ~25 bbls 15.9 pp "G" CMT Slur 8/5/2009 RIH W/ GR to Mule Shoe ~~11899' RKB POLLARD WIRELINE REPORT FILL TO 12390' MIT 6/16/2009 r,~~~~°~ ~~'~'` WIRELINE FISH @ 12391' - 12419' ~A~~~ Fill to 12419' WLM (8-11-90) ~ ;~;; v PBTD = 12629' TMD = 12717' MARATHON SPARK S-9 PROPOSED PAGE 1 8/17l2009 ~ ~ ~ Marathon Oil Company Updated 8/17/2009 North Trading Bay Unit Spark PlatForm Well S-9 NIARATNDN "CURRENT CONFIGURATION" RK&MSL 115' Water Depth 60' Max Angle = 45 deg @ 3976 & 9029' TMD @ 12717' TVD @ 10066' MASTP 1067 psi MIT 6/16/2009 API # 50-733-20265 Surface Pipe @ 2720' 13 3/8" 72 ppf N80 Buttress 12.347" ID .1480 bbl/ft CMT 2000 sks CTOC = Surface Gauge Hole Calculations Production Tubing @ 11899' 3~/2" 9.2 ppf ABC Mod. N80 2.992" ID .00870 bbl/ft Packer Fluid 3°/o KCL Gas Lift Valves 2276' 3/8" port 9175' 3/8" port 4065' 3/8" port 9706' 3/8" port 5573' 3/8" port 10238' 3/8" port 6671' 3/8" port 10767' 3/8" port 7486' 3/8" port 11267' 3/8" port 8112' 7/16" orif 11768' 7/16" orif 8611' 3/8" port TOL 7" @ 10863' Intermediate Casing @ 11160' 9 5/a" 47 ppf N80 Buttress 8.681" ID .0732 bbl/ft CMT 900 sks CTOC @ 8177' Gauge Hole Calculations 7" x 4" Otis WD Packer w/ seal bore extension @ 11834' All Depths measured RKB to top of equipment All depth are RKB unless otherwise noted 8/9/2009 Ta ed TOC ~ -10418' RKB Mule Shoe @ 11$99' Pertorations G-2 12139'-12189' G4 12245'-12260' G5 12304'12324' H 1 12360'-12390' H 2 12415'-12455' Production Liner @ 12714' 7" 29 ppf N80 Buttress 6.184" ID .0371 bbl/ft CMT 570 sks CTOC Q 7548' Gauge Hole Calculations Circulated Cement to TOL 8/6/2009 ~1972' Bottom Hole Cement Plug ~12390' RKB to -10418' RKB M&P ~25 bbls 15.9 "G' CMT Slur 8/5/2009 RIH W/ GR to Mule Shoe ~~11899' RKB POLLARD WIRELINE REPORT FILL TO 12390' MIT 6/16/2009 WIRELINE FISH @ 12391' - 12419' Fill to 12419' WLM (8-11-90) PBTD = 12629' MARATHON SPARK S-9 CURREN7 CONFIGURATION PAGE 1 8/17/2009 TMD = 12717' ~ ~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~~ ~~l~g~ p~ DATE: August 12, 2009 P. I. Supervisor ' ~ ~~ FROM: Lou Grimaldi SUBJECT: Wellbore plug integrity Verification Petroleum Inspector Marathon Oil Company Spark Platform, NTBU S-09 PTD #174-027, Sundry #309-145 ' Sundav, Auqust 9, 2009; I witnessed the pressure test and tag of top of cement by wireline of the bottom cement ptug in Marathon's Spark platform well # S-09, North Trading Bay Unit. There was pressure from the previous day's pressure test still on the well. I requested they bleed the annulus and tubing to confirm they were fluid packed. A poor boy degasser was lined up to the IA as there was a large amount of gas being bled with the fluid. Approximately 140 BBLs of crude oil was bled from the tubing. Reportedly the inner annulus (IA) was in communication with the tubing; this was proved out as the IA pressure rose and declined with the tubing during the test and bleed-off. The tubing/IA was pressure tested to 1520 psi for 15 minutes. After an initial decline of 20 psi the chart recorder drew a straight line for the 15 minute test. A 1 11/16-inch gauge ring was run into the we!! on wireline to a depth of 10358 feet (wireline measurement) where it fetched up hard. The plug was jarred upon 3- 4 times with out any signs of going deeper or sticking. Upon withdrawal of the gauge ring from the wellbore I inspected it and observed no signs of damage from tubing obstructions and saw white-like staining on the bottom. Summarv: There appears to be a competent intermediate cement plug at 10418 feet R.K.B. (elevation 60') / 10358' from tubing head. Attachments: None t '~ .-, i~ ~. ,r, rt ~, r~~:; '~'~ ~.~~L~.t~ ~' ~ ~G~,~ ~~~e.u ~ 2009-0812_P&A_bottom~lug_NTBU_5-09_Ig.doc 1 of l OMarathon MARATHON ® Alaska Production LLC Alaska Asset Team P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/565-3076 August 3, 2009 Cathy Foerster `" L01411` 4 F, I!, ' Fz'� � 11IT� ;=,v, State of Alaska Alaska Oil and Gas Conservation Commission 333 W. 7"' Avenue, Suite 100 Anchorage, AK 99501-3539 Re: 20 AAC 25.300 (Request for Information) — Status of Oil and Gas Wells Dear Ms. Foerster: 1 Z 4-_ OL-'( 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, �U_'J Carri Lockhart Alaska Asset Team Manager Attachment: Marathon plan for list of inactive wells cc: B. Schoffmann L. Ibele K. Skiba T. Stebbins Well Files Marathon Oil Company, Alaska Asset Tea"§ Anticipated schedule of well abandonment activities Confidential 8/3/2009 Timing IWO I Permit No. I Pad or location 2009-2011 S-1 RD 174-005 Spark S-2RD 174-024 Spark S-3 169-011 Spark S-4 169-034 Spark S-5 169-039 Spark S-7RD 169-096 Spark S-8 171-033 Spark S-9 174-027 Spark TS -1 168-048 Spurr TS -2 168-050 Spurr TS -3RD 168-065 Spurr TS -4 168-066 Spurr TS -6 168-090 Spurr TS-7RD 169-026 Spurr TS -8 169-027 Spurr TS -9 169-092 Spurr 2012-2015 BC 7 176-006 BCU Pad 7 CLU 3 181-058 CLU Pad 3 CLU 4 187-034 CLU Pad 3 KU 33-30 159-015 KGF pad 33-30 KU 42-30 181-091 KGF pad 33-30 KU 44-30 168-071 KGF pad 33-30 SU 23-15 161-014 Sterling Unit KU 41-18 171-010 KGF pad 41-18 KU 43-12 169-087 KGF pad 14-6 KU 11-6 165-017 KGF pad 34-31 KU 21-5 169-035 KGF pad 43-32 WF1-21rd 193-183 West Fork WF2-21 192-010 West Fork rr�- r _ - -, a rn �, • ~ ~ ~ ~~ ~~ ~~ ~~ ~~ ~~ ~ ~ ~ ~ & r ~~ ~ ~~s.~ ~ ~ ~~ ~~ ~ ~ ~ ~~ ~ SARAHPALIN, GOVERNOR 'I~ffany Stebbins Regulatory Compliance Rep. Marathon Oil Company P.O. Box 190168 Anchorage, Alaska 99519-6168 r ~~ O~ ~ , ~ `~t ~ Re: G-NE/Hemlock-NE Oil North Tracling Bay Unit 5-09 Sundry Number: 309-145 Dear Ms. Stebbins: ~~.'~~~' ,~u~ ~ €~~ 1QQS Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions af approval set out in the enclosed form. When providing notice for a representative of the Comrnission 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 Corrunission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the ne~ct 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 k DATED this ~ day of July, 2009 Encl. ~~~~a ~ ~~ c 'l~!~~ STATE OF ALASKA ;~~P~ ~!{ ~ ~~t~~j~ O~ ~ALASK~IL AND GAS CONSERVATION COMMIS~N ! ~ti' APPLICATION FOR SUNDRY APPROVAL~~s~a ~~~ & ~~~ ~~°~ ~ ~ '~~`"' "y:~`~ ~ 20 AAC 25.280 ~~'~~ ' `"~~ 1. Type of Request: Abandon ~• Suspend ^ Operational shutdown ^ Perforate ^ Waiver ^ Other ^ A{ter casing ~ Repair well [} Plug Perforations ^ Stimulate ^ Time E~ension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Marathon Oil Company Development ~, Exploratory ~ 174-027-0 , 3. Address: Stratigraphic ~ Service ~ 6. API Number: P.O. Box 190168, Anchorage, AK 99519-6168 50-733-20265-00-00 • 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: NOfth TI'ading Bay Ulllt 5-09 . Spacing Exception Required? Yes ^ No ^ Spark platform 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL017597 • RKB-MSL 115' ' G-NE/HEMLOCK-NE OIL . 12, PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): P1ugs (measured): Junk (measured): 12,717' ~ 10,066' . 12,629' 9,998' 12,419' Fill, 12,629' PBT 12,391-12,419' fish Casing Length Size MD ND Burst Collapse Structural Conductor Surface 2,720' 13 3/8" 2,720' 2,571' fntermediate 11,160' 95l8" 1i,i60' $,g9~' Production Liner 1,851' 7" 12,714' 10,063' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12,139 - 12,455' 9,623 - 9,867' 3 1/2" 9.3#, N-80 Buttress 11,899' Packers and SSSV Type: Camco TRDP ~ A SCSSV Packers and SSSV MD (ft): 23i' Otis WD Packer w/seal bore extension 11,834' Mule Shoe ~ ~'899 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q" Service ^ 15. Estimated Date for 16. Well Status after proposed work: Oil ^ Gas ^ Plugged ^ Abandoned Q- Commencing Operations: 17. Verbal Approvaf: Date: WAG ^ GINJ ^ W4NJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tiffany Stebbins ~? ~_~~ oS~a Printed Name Tiffany Stebbins Title Regulatory Compliance Rep. Signature ` Phone D e 907-565-3043 ' ~ Q COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~~ ~/~~ Plug Integrity [/~ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: ~L1 ~' ~Q ~- ~ ~ + ~/ l _ ~ S ~. P.~a ~~s~ ~.s p~r ~.z,s: eizc ~ ~ .A i~-~ w~ l~ 1~ . ,~~ ~ p APPROVED BY ~ n ~ Approved by~ COMMISSIONER THE COMMISSION Date: ~ ~, ~l zi• ~ Form 10-403 Revised 06f2006 ~ .~~~_ 3`.is s~ ~"~r~4~j ~_~.~~ubmi~ lic~fe~„~~ ~. ~y ~ ~ ~ ~ ~ 8. Perform JSA for electric line operation and explosive handling. Rig up electric line lubricator and test to 1500 psi. RIH with perforating guns loaded with 2 ft of 4 SPF tubing punch and tag TOC for bottom hole cement plug, @ 11800' RKB and record results. Pick up and shoot tubing at 10963' RKB. 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 3 1h" tubing taking returns up the 9 5/s" casing. Mix and pump 19.65 bbl cement slurry for a 300' cement plug from 10963' RKB to 10663' RKB in the 3 1/2" tubing and in the 3 1h" X 9 5/8" casing annulus, that covers the Liner "LAP" (200' Above and 100' below). Displace with weighted fluid. 10. WOC and test to 1000 psi, Document results using a continuous pressure chart recorder. 11. Perform JSA for electric line operation and explosive handling. Rig up electric line lubricator and test to 1000 psi. RIH with 3 1/z" jet cutter and tag top of intermediate cement plug @ 10663' RKB and record results. Pick up and cut tubing at 600' RKB. 12. Rig down tree. 13. Perform JSA for proper pipe handing procedures. Pull 3 1/z" tubing and check for N.O.R.M. 14. Perform JSA for proper 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/a" CIBP and tag tubing stub @ 600' pick up and set CIBP @ 575' RKB. 16. RIH with perForating gun armed with 2 ft of 4 SPF casing punch, tag CIBP and fire guns. POOH. RD electric line. 17. Pertorm JSA for cement mixing and pressure pumping. RU pump and lines. Test lines to 1500 psi. NOTE: IF POSSIBLE A) Circulate clean, down the 13 3/s" casing and up the 9 5/a" casing with weighted fluid. Mix and pump 41 bbl cement slurry for a 300' cement plug in the 9 5/a" casing and the 9 5/s" x 13 3/s" casing annulus from 575' RKB - 275' RKB. B) If unable to circulate the 9 5/8" X 13 3/s" casing annulus, RIH with work-string to CIBP, Pick up work-string 10' and displace a 22 bbl slurry for a 300' cement surface plug from 575' - 275' RKB in the 9 5/s" casing only. 18. Pick up work-string 20' above TOC and circulate clean. POOH. 19. WOC. PerForm JSA for wire line operations. Run in hole with blind box and tag top of surFace cement plug @ 275' RKB and record results. POOH. 20. RD. Well is~~bandoned. p~rn. R he.c:~ Spark Well 9 ~ ~ Page 2 ~ 4/17/2009 ~ ~ Marathon Oil Company North Trading Bay Unit rsa ~t~ a~ Spark Platform Well S-9 "CURRENT" RKB-MSL 115' Water Depth 60' Max Angle - 45 deg @ 3976 & 9029' API # 50-733-20265 Surface Pipe @ 2720' 13 3/8" 72 ppf N80 Cemented w/ 2000 sks ETOC = Surface (75% XS) Production Tubinq @ 11899' 3 1/2" 9.3 ppf L80 TOL 7" = 10863' Intermediate Casinq - 11160' 9 5/8" 47 ppf N80 Cemented w/ 900 sks CTOC = 8772' (30% XS) Perforations G-2 12139'-12189' G4 12245'-12260' G5 12304' 12324' H 1 12360'-12390' H2 12415'-12455' Production Liner Q 12714' 7" 29 ppf N80 Buttress TOL = 10863' Cemented w/ 570 sks Circulated cement to TOL TD = 12717' All Depths measured RKB to top of equipment Al/ depth are RKB unless otherwise noted Gas Lift Valves 2276 3/8" port 4065 3/8" port 5573 3/8" port 6671 3/8" port 7486 3/8" port 8112 7/16" orifice 8611 3/8" port 9175 3/8" port 9706 3/8" port 10238 3/8" port 10767 3/8" port 11267 3/8" port 11768 7/16" orifice 7" x 4" Otis WD Packer w/ seal bore extension @ 11834' Mule shoe 11899' WIRELINE FISH @ 12391' -12419' Fill to 12419' W LM (8-11-90) ~~ MARiCTHOM <~ RKB-MSL 115' Water Depth 60' Max Angle = 45 ° C~? 3976 & 9029' API # 50-733-20265 SurFace Pipe @ 2720' 13 3/a" 72 ppf N80 12.347" ID, .1480 bbl/ft Cemented w/ 2000 sks CTOC = Surface (75% XS) Production Tubing @ 11899' 31h" 9.2 ppf ABC Mod. N80 2.992" ID, .00870 bbi/ft Annular Volumes 3 1h" X 7" _.0252 bbl/ft .1418 ft3/ft 3 1h" X 9 5/a" _.0613 bbl/ft .3442 ft3/ft TOL 7" = 10863' Intermediate Casing -11160' 9 5/s" 47 ppf N80 8.681" ID, .0732 bbl/ft Cemented w/ 900 sks ETOC = 8772' (30% XS) 7" x 4" Otis WD Packer w/ seal bore extension @ 11834' Mule shoe @ 11899' Perforations G-2 12139'-12189' G4 12245'-12260' G5 12304'12324' H 1 12360'-12390' H 2 12415'-12455' Production Liner @ 12714' 7" 29 ppf N80 Buttress 6.184" ID, .0371 bbl/ft Cemented w/ 570 sks Circulated cement to TOL Marathon Oil Company North Trading Bay Unit Spark Platform Well S-9 "PROPOSED" PBTD=126< All Depths measured RKB to top of equipment All depth are RKB unless otherwise noted 300' Surface Cement Plug Pertorate 9 5/e" C~ 575' RKB 95/a"X133/s"=42 bbls~ 9 5/s" only = 22 bbls 575' RKB - 275' RKB CIBP @ 575' RKB • Gas Lift Valves 2276 3/8" port 4065 3/8" port 5573 3/8" port 6671 3/8" port 7486 3/8" port 8112 7/16" orifice 8611 3/8" port 9175 3/8" port 9706 3/8" port 10238 3/8" port 10767 3/8" port 11267 3/8" port 11768 7/16" orifice Intermediate Cement Plug Pertorate 3~/s " Q 10963' RKB 100' below and 200' above Liner "LAP" 100' X.0252 bbl/ft = 2.52 bbls 200' X.0613 bbl/ft = 12.26 bbls 300' X.00870 bbl/ft = 2.61 bbls Total Cement Slurry = 19.65 bbls ~ Bottom Hole Cement Plug 1 415' RKB -11800' RKB 5~Q' X.0371 bbl/ft = 19.292 bbls 100' X .00870 bbl/ft = .87 bbls Total Cement Slurry = 20.162 bbls ./ WIRELINE FISH @ 12391' -12419' Fill 12419' -12717' TD = 12717' ~ ~ Spark Platform Abandonment Review North Trading Bay Unit Marathon Oil Company Well NTBU S-O1RD (PTD174-005) - Sundry Application 309-138 Well NTBU S-02RD (PTD174-024) - Sundry Application 309-139 Well NTBU 5-03 (PTD169-O11) - Sundry Application 309-140 Well NTBU 5-04 (PTD169-034) - Sundry Application 309-141 Well NTBU 5-05 (PTD169-039) - Sundry Application 309-142 Well NTBU S-07RD (PTD169-096) - Sundry Application 309-143 Well NTBU 5-08 (PTD171-033) - Sundry Application 309-144 -~.r---`~JVell NTBU 5-09 (PTD174-027) - Sundry Application 309-145 Requested Action: Marathon Oil Company (Marathon) proposes to permanently abandon the above referenced wells on the Spark Platform in the Cook Inlet. Recommendation: I recommend approval of the above referenced Sundry Applications to allow Marathon to permanently abandon the wells. Discussion: Marathon proposes to permanently abandon the above wells on the Spark Platform by setting the required multiple cement plugs in the wellbore. (At a later date to be determined the Spark Platform structure will be removed; at this time the casing strings will be cut and pulled just below mudline to complete the total abandonment of the wells. ) The Spark Platform is one of two, the other being the Spurr Platform in the North trading Bay Unit (NTBU). Production began from the Spark Platform in January 1969 and peaked at nearly 12,000 bopd in November 1969 before beginning a rapid decline. By January 1992 production from the platform had fallen to less than 300 bopd and production was shut in. In November 1996 gas production, but not oil production, from the platform was reestablished but and peaked at over 5.2 mmcfpd in May 1998. The platform produced no water during the first year an a half of gas production but then quickly rose to over 200 bwpd. The initial attempt at gas production ceased in May 2000, a second attempt was made beginning in July 2003 but as soon as there was any significant gas production there was also significant water production, up to almost 400 bwpd. By September 2005 significant gas production had ceased on the platform but intermittent, averaging about 1 mmcfpd but only producing, usually, one day per month, production continued until July 2007. There have been no further attempts to resume production from the platform. Cumulative production from the platform is about 17.5 mmbo and 6.8 bcfg, 4.6 bcfg of which was associated gas recovered during oil production. ~ ~ There have been a total of twelve wells drilled from the Spark Platform, of which four have already been P&A'd (NTBU S-O1, 5-02, S-02DPN, and 5-07). Of the eight "active" wells that are the subject of this review two are waste disposal wells (NTBU S- 04 & S-OS), one is classified as a gas well (NTBU S-02RD) but has not produced since July 2007, and the remainder are classified as shut in. Decline curve analysis of the oil production indicates that remaining reserves in the known oil accumulations accessible from the Spark Platform range from zero for an economic limit of 300 bopd for the platform to 1,096 mbo for an economic limit of 50 bopd for the platform. The following table shows the remaining reserves at various economic limits. Economic Limit (bo d Remainin Reserves (mbo 50 1,096 100 869 200 410 300 0 Below is a graph of the decline curve analysis showing production extrapolated to a 50 bopd economic limit. Without specific economic information it is impossible to say what truly the economic limit is for the Spark Platform. However, in a May 23, 1992, letter from Marathon to the Department of Natural Resources (copy attached) Marathon stated that the platform had been uneconomic since 1990 and that at that time the break even oil price was in excess of $20/bbl. Although oil prices are substantially higher than that now operation costs have also increased dramatically since that time and the platform likely remains uneconomic today at any oil production rate that could be obtained from the existing facilities and wellbores. ~ ~ ~ ~ ~ 04'fE Several attempts have been made at sustaining substantial gas production from the platform but none of them have lasted more than a year of regular production, and you have to use a pretty broad definition of regular to get that as they were only able to maintain production for an entire month a handful of times in the 11 plus years they attempted gas production. Conclusion: The Spark Platform appears to be well beyond its economic life and permanently abandoning the wells at this time, to prepare for a future platform and casing removal , appears to be the prudent course of action. ~ ' D.S. Rob~~,~'~;M_-=` Sr. Reservoi~ngiiieer April 23, 2009 - Revised July 2, 2009 ~ - ~~ ~~, ~~ ~ ~ ~ ~~ ~e, b O ~ Cf :0.0783824A.e. c~ zse.an mva u oir.tv~ssz ee ov28i2o~a ~.,ei ra,~ as.aiae ixwa ' ~ CLm Rorl. : 17508.9 Pithl ~ i0 . . . . ~ ~ ' . CLm C~te : 07/31/1992 . I~esaves : 10B8.35 ~ro61 ~ . . - ~SMV~Date :02/28J2014 : . . . . . { . .. . E3JF2 : 189~2 MY~I . .. Farecast Entled By : F~te I . . ~ . C6 fvecast ~le : f~M Saved ~ ' ~ ~ Raserve TyPe : N~ne 10''~ _ 7 . .. . ' F}-g . . . . .. . . . . . . ~ : _ '~, 0~ - . y ~SVil:+ . . j • 1 l T 7°~ io'-~ ; v.~ ~ ~ . . . . . . . . t~ . . . ....'-,,,,-....`'"°..~ i o' 899O9t929396959697989400D7020306050807080910111273~14 Marathon a Oil Company March 1, 2009 Commissioner: Cathy Foerster Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue Suite 100 k .,L -(--0Z7 Alaska Asset Team North America Production Operations P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/565-3076 Anchorage, AK 99501-3539 SCAHN� Re: Notice of Revised Suspended Wells Regulations and Request For Verification of Suspended and Shut-in Well Information Dear Cathy: MAR 0 2 2009 Alesim, �9�icls���p�y Marathon received your letter dated January 28, 2009 (Cert # 7005 1820 0001 2499 5999) requesting Marathon to validate information contained within it. Marathon has reviewed the data and found it to be accurate. Marathon is in the processes of reviewing and addressing the new regulatory requirements in "20 AAC 25.110 Suspended wells". If you have any questions, please do not hesitate to contact Gary Laughlin at 907-565-3036 or email him at galaughlin@marathonoil.com. Sincerely, Ben Schoffmann Operations Manager MARATHON OIL COMPANY j { SARAH PALIN, GOVERNOR 0 ALAS OIL AND GAS 333 IN 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 January 28, 2009 FAX (907) 276-7 54 2 CERTIFIED MAIL RETURN RECEIPT REQUESTED 7005 1820 0001 2499 5999 Ben Schoffman Marathon Oil Company PO Box 196168 Anchorage AK 99519-61.68 SOWED Re: Notice of Revised Suspended Wells Regulations and Request for Verification of Suspended and Shut -In Well Information Dear Mr. Schoffinan: Enclosed are the Alaska Oil and Gas Conservation Commission's revised regulations regarding suspended wells (i.e., 20 AAC 25.110). Also enclosed are a list of suspended wells and a list of long term shut-in wells operated by Marathon Oil Company. For each list, please verify the information for each well, and provide any corrections by April 1, 2009. Location inspections required under 20 AAC 25.110 should be coordinated with Jim Regg at 907-793-1236 or jim.regg@alaska.gov. If you have any questions regarding this notice, please contact Tom Maunder at 907-793- 1250 or tom.maunder@alaska.gov. Sincerely, Cathy P. Foerster Commissioner Enclosures Er IT zi- ru pie s ra C] U.S. Postal Service— O rU RsetkW DGIWery Fee (6rdorsement Required) CERTIFIED MAIL;,,. RECEIPT Provided) (Domestic Mail On)y; No Insurance Coverage ccom -,..—tmn visit our website at www.usps Er IT zi- ru pie s ra C] CereW Fee O (Endo s�m Fee srti0M �ired) O rU RsetkW DGIWery Fee (6rdorsement Required) $0.59 1 OR,P_ rq1bfa1 PosluOe P A?Ol/�'/ Ben Se�ofman Ln Marathon Oil Company 35vig-1v WT PO Box 196168 or Po Mx Na 2K; Anchorage AK 99519-616 :rr ® Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. Ic Print your name and address on the reverse so that we can return the card to you. E Attach this card to the back of the mailpiece, or on the front if space permits. 1. Article Addressed to: Ben Schoffman Marathon Oil Company PO Box 196168 Anchorage AK 99519-6168 A. X Agent B. Received by (Pnh d Name) C. Da of Deliv ry Y D. Is delivA address different from item 1? ❑ Yes If YES, enter delivery address below: ❑ No jrvice Type Certified Mail i Express Mail ❑ Registered \1" Return Receipt for Merchandise ❑ Insured Mail ❑ C.O.D. 4. Restricted Delivery? (Extra Fee) ❑ Yes 2. Article Number (Transfer from service label) 92113�—_ 7005 18 2 0 0001 2499 5999 PS Form 3811, February 2004 Domestic Return Receipt 02595-02-M-1540 Operator Suspended and Shut In Wells 2495 FEL MARATHON OIL CO T ION R 13 W SM SI Field Current Date of Sec 26 Permit API Number Well Name Status Status Surface Location .................................................. Lease(s).................................. "EXPLORATORY 2488 FEL Sec 26 T ION 202-129-0 50-133-20517-00-00 ABALONE 1 SUSP 3/9/2003 250 FSL 3000 FEL Sec 29 T 2 N R 12 W SM FEE-OSMAR KASILOF Sec 26 T ION R 13W SM 202-257-0 50-133-20520-60-00 KASILOF SOUTH 1 L1 SUSP 4/15/2004 520 FSL 1340 FWL Sec 28 T 3 N R 12 W SM ADL0384529 ADL0384534 KENAI C.L.U. T ION R 13W SM SUSP 206-121-0 50-133-20563-00-00 CANNERY LOOP UNIT 12 SUSP 9/8/2006 2490 FSL 2365 FWL Sec 4 T 5 N R 11 W SM ADL0324602 ADLO359153 T ION R 13W SM SUSP ADL0365454 FEE-TR119 NINILCHIK 208-023-0 50-133-20574-00-00 NINILCHIK UNIT G OSKOLKOFF 7 STERLING 161-014-0 50-133-10012-00-00 STERLING UNIT 23-15 TRADING BAY 174-005-0 50-733-20158-01-00 N TRADING BAY UNIT S-01 RD 169-011-0 50-733-20175-00-00 N TRADING BAY UNIT S-03 169-096-0 50-733-20197-01-00 N TRADING BAY UNIT S-07RD 171-033-0 50-733-20233-00-00 N TRADING BAY UNIT S-08 174-027-0 50-733-20265-00-00 N TRADING BAY UNIT S-09 168-048-0 50-733-20120-00-00 N TRADING BAY UNIT SPR -01 168-050-0 50-733-20122-00-00 N TRADING BAY UNIT SPR -02 168-065-0 50-733-20133-00-00 N TRADING BAY UNIT SPR -03 168-066-0 50-733-20134-00-00 N TRADING BAY UNIT SPR -04 168-090-0 50-733-20153-00-00 N TRADING BAY UNIT SPR -06 169-026-0 50-733-20181-00-00 N TRADING BAY UNIT SPR -07 169-027-0 50-733-20182-00-00 N TRADING BAY UNIT SPR -08 169-092-0 50-733-20200-00-00 N TRADING BAY UNIT SPR -09 Wednesday, January 14, 2009 SUSP 6/12/2008 2969 FSL 3023 FEL Sec 23 T 1 N R 13VV SM ADL0389180 SUSP 10/23/1966 2715 FNL 1520 FWL Sec 15 T 5 N R 10 W SM FEDA028135 SI 1/25/1992 2608 FSL 2495 FEL Sec 26 T ION R 13 W SM SI 2/25/1992 2613 FSL 2495 FEL Sec 26 T ION R 13 W SM SI 2/25/1992 2612 FSL 2488 FEL Sec 26 T ION R 13W SM SI 1/25/1992 2577 FSL 2566 FEL Sec 26 T ION R 13W SM SI 1/25/1992 2570 FSL 2563 FEL Sec 26 T ION R 13W SM SUSP 8/18/1992 615 FNL 2072 FEL Sec 34 T ION R 13W SM SUSP 8/19/1992 664 FNL 2007 FEL Sec 34 T ION R 13W SM SUSP 8/18/1992 618 FNL 2068 FEL Sec 34 T ION R 13W SM SUSP 8/13/1992 666 FNL 2003 FEL Sec 34 T ION R 13W SM SUSP 8/10/1992 642 FNL 2072 FEL Sec 34 T ION R 13 W SM SI 8/26/1992 622 FNL 2068 FEL Sec 34 T ION R 13W SM SUSP 8/26/1992 664 FNL 2000 FEL Sec 34 T ION R 13 W SM SUSP 8/18/1992 618 FNL 2076 FEL Sec 34 T ION R 13W SM ADL0035431 ADL0035431 ADL0018776 ADL0017597 ADL0017597 ADL0017597 ADL0017597 ADL0017597 ADL0017597 ADL0017597 ADL0017597 ADL0017597 ADL0017597 w w. Produ ion Manaqer Alaska Fiegion J Domesnc Production ~ Marathon MARRTNON Oil Company P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 March 23, 1992 Mr. Harold Heinze, Commissioner Department of Naturai Resources 400 Willoughby Avenue, 5th Floor Juneau AK 99801-1796 Oear Commissioner: SUSPENSION OF PRODUCTION OR OPERATIONS Enclosed for processing is an application for suspension of production or operations and a filing fee of 550. Pursuant to 11 AAC 82.670 Suspension of Production or Operations, Marathon Oil Company, P. 0. Box 190168, Anchorage, Alaska 99519, hereby requests approval of suspension of production or operations for a two-year period commencing June 1, 1992. The leases affected are ADL-17597, ADL-18776, and ADL-35431. The lands within the North Trading Bay Unit, as shown on Exhibits 1 and 2, are described as follows: T10N, R13W, Sec. 26: SW;, S2 NW;; Sec. 27: SE;, Sz NE:; Sec. 34: EZ; Sec. 35: WZ. ~ Two platforms have produced from the Unit to an onshore processing facility at Granite Point. The Spark Platform, purchased by Marathon in 1984, was recently shut in because it was uneconomic to operate. The Spurr Platform, purchased by Marathon and Unocal in 1988, is currently operating at a loss. Oil production from Spark Platform was approximately 330 BOPD prior to shut-in, while Spurr Platform is currently producing about 250 BOPO. Spark Platform Overall, Spark has been uneconomic since 1986 when oil prices dropped dramatically. Since that time Spark has lost ~2.0 MM on an operating income basis as shown in Exhibit 3. Not inciuded in this amount is the 56.7 MM invested during that time. The break-even oil price for 1991 was over S20 per barrel not inciuding the cost of investment recoupment through DD&A. Since reserves are defined as economically producible, no oil reserves can be assigned to Spark with an oil price below 520. The Unit does have economic gas reserves which could be developed from Spark. Gas reserves have been proved with a down structure fuel gas well on the Spurr Platform which has recovered 3.5 BCF. Current plans cail for developing remaining gas reserves by recompleting Spark Platform Wells A subsidiary of USX Coroorauon ', Mr. Haroid Heinz~ ~ March 23, 1992 Page 2 S-2RD and S-8 uphole near the gas reservoir structure top. In addition, gas separation and dehydration faciiities and compression wiil need to be installed on the platform. Proven Unit gas reserves are committed to both Unoca7 and Marathon con- tracts. Because both companies currently have sufficient deliverability to ,~ _meet_ contract demand, it is not economically justified to invest the " necessary $7.7 MM gross cost to develop Unit gas at this time. If gas ~~~ production was commenced from Spark Platform, Unit gas sold would displace • gas sales from other fields which have already been deveioped. In the ~ mid-1990's, Marathon will begin to need additional deliverability to meet contract demand. Plans are to develop Unit gas to meet this demand. Spurr Platform The Spurr platform has been uneconomic since 1990. It has lost 51.0 MM since that time as shown in Exhibit 4. Investments totaling 56.9 MM incurred since 1988 are not included in this calculation. As with Spark, the break-even oil price for 1991 was over ~20 per barrel, not inciuding DD&A costs. Therefore, no oil reserves can be attributed to Spurr. Spurr does have one gas well, TS-3RD, completed in gas sands. It is currently shut in because of down hole mechanical problems. . c- ~ nK ~r~ Losses are expected to increase in 1992 to $0.8 MM as a result of lower ~ ~~`~ prnduction and a projected ~12.00 per barrel oil price. This does not '~ inciude the substantial -monies required to stay in compiiance with oil ~ spill and process hazard management regulations recentiy enacted. These losses are not acceptable and as a result Spurr Platform and the attendant onshore production facility at Granite Point must be shut in. Until recently, the non-unit area developed by Spurr was thought to contain significant undeveioped reserves. Evaluation of 3-D seismic and the performance of Monopod Platform Well A-28R0 now indicates no further economic deveiopment potential exists. With once planned development potential eliminated, Spurr has no further utility for oil production under current economic conditions. Future gas production from Spurr is possible and will be evaluated as part of the overall development scheme. Marathon's Plans Durin4 Two-Year Susoension The main reason for the requested two-year suspension is to eliminate unnecessary economic losses until Marathon deveiops Unit gas. During this two-year suspension Marathon will continue to evaluate the gas market to determine the optimum timing of gas development. The gas market is dynamic and Marathon constantly evaiuates supply and demand. Marathon will also monitor oil prices to determine if resumption of oil production is feasible and will review alternate production strategies which could reduce operat- ing costs. This is applicable to both platforms. •~ ~~ ~ Mr. Haroid Hein~ ~ • March 23, i992 Page 3 A major undertaking during this suspension period wiil be the evaluation of abandonment options for Spark, Spurr and Granite Point Production Facility. This evaluation will attempt to optimize method and timing of abandonment. As no platform has been abandoned in the Cook Inlet to date, much research needs to be done prior to abandoning the first structure. It is stressed that this work does not preciude the pianned resumption of operations at Spark or the possible resumption at Spurr. A revised plan of development reflecting the changes proposed in this application is being sent under separate cover. If there are questions or if further information is needed, please contact R. J. Murphy at 564-6425. Thank you for considering this appiication. Sincerely, . .~- ,v , \;; '1 `-X : y ~ - W. Watson cc: Mr. James Eason Department of Natural Resources Division of Oil and Gas P. 0. Box 107034 Anchorage AK 99510-7034 A:LANDZ/MH07/BGP ~.___J NOATH TRAOING BAY UNIT 80UNDARY PRIOR TO AUGUST 2, 1976 '~ EXHIBIT 1 ATTACHED ANO MADE A PART OF UNIT AGREE~JIENT FOA THE i]EVELOPMENT AND OPERATiON QF THE NORTH TRAOING 8AY UNIT AREA ~" ~ 1 2T~ Zs + T 10 N R 13 ljill T9N R13W btAqATHON \\\~ \ aot~ssa~t ~_ ~ ~ ~ ~ NORTH TRADfNG 8AY UNIT BOUN~ AND HEMLOCK 3 'G' FORMATIO; PARTICIPATIN('a AREA BOUNDAR ~ EFFECTIVE AUGUST 2. '1976 ~" 34 \35 a ARATHp ~ UNION MARATHON ADl•77597~ \ • ~ ~ ADL•18776 \ ~ ~ MAPSOURCE DIVISION OF LANDS PROTRACTION SHEE7, GRtD NO. 5•13•5 STATE OIL ANO GAS LEASES ADl•17597. AOL•18776, QOL~J5~3t LEGEiV 0 O ~~ TRACT NO. PARTICJPATING AAEA NORTH TAADING 8AY UNIT AAEA HE~iLOCK & ~G~ PARTiClPATiNG aREA ~ COOK INLET, ALASKA PAFiTiC1PATING AAEA LATEST CONTRACTION DATE: AUGUST 2, 1976 ' OWNERSHIP AS OF:SEPT. 1, 1g88 RAA~A~'~i0~ ~lL C~~iiPA~Y ~ , i a ~ ~ ~ _ - zae :.aee aae ?.eee .aee _.zae _.aae '" uARA?HON 0[L C;,~p.~fy ' , ''aB~ s.eee `iQRTH TFiAD1NG aAY [,~1T I ~~ ' ` :YHIBIT 2 ~ ~vL ~sa3~ ~ ?OYALTY P.EDUC°',0` 1 ~ i ~ '. m 9 ~ m m - I ' -' e77e I 1 i ' m - ~ I , n _~ ~ i ~~ , ~P.4RK ~ ~ ~ I I ~ • // ~ 9 i ~ _ _ - I : ~J • I , ~ m ~ , ~ , ,~ - I d~~~ ~m i ~ 5_9 ~% ~ '~ ~' i ~ eS • ~ t~~' ~ _ ~ ~, , ~~f8~ a . ~ ,o a- i8D ' j ' ~ %/-~~ j~ m ''~ \ ~ ~ '' 'a~i .~, •~ i ~ " • ,~. r ~ , I _ ~ o - T ~. `\ /i ___1 e ~2 ~ FNCO ~' ~ 5 ~' ~ I ~ L \~ ~ I ' , ~ ~ t615/ ,t ' ,,, r ~ 'as29 , ~ I ~'~ _. ~ :aees ir ~„ ~' ,~ a,se .~ ~ Im ~ m ~ ~ ' ~ ~ ~ - ' ~~ ,, .~ . . , , -_;.~~, -- ,Pr~at-~" :~@5 ~ ~ - ~ I r:'' = ~~ ~ - , ~ ~ - . ~ . , , a3 _ ~{~ ' , _y, ~:..__. . ~ , ~ ~_7t~d., `~y . Z -G~ t91 M t~,`,~ ~~ ..~~~8 •9~7 . • 9 9 d~~ %r ~;~ 5~ -~7~ I ~ ~\ ~ "AA , ~ ~ ~' e ', 943~ ~ ~ r s ~ i ~ , ,• ti , , ~ ~ 91 9 L , / ~ ~ ~ • ~\A I / ~ ~ ' i f I D~ I ~ I , , 'C_~I r - a / `•,, pge ~ - •~. % ' ~d4d5 ~ I ~ m ~ ~ , `' j :~~ZI ./ 0 ~ iYS~ ~ i ~ 9 I ~ ' ^ ' \ ~ ~ ~ / /I 71 ~ L v~ , .. . ~ ~ / \ ~ •~ ~i~ f • a-7~/ ' I Is '~ r•: , ~Sgli ' ~ • :?aa4 ; : !~ 'S- , . , _~ '~' ' ~ I~ ~ i ~ Z~ ` :90Y I ~ ~a . ~~ . ~ I ~ : ~ I = ~ ~a l~T85-! ~ ~ j -ii~ !e r • ~ ~S~ i ~ I : I „ 1 <t ~ s ~ : a~i~ ~ i ±~ T :ON-R13W ~%'S9~ ~ i° l .~1DL 18~76 ~ '.aea 3,aae :.aae a.eaa ..aea z:aee ...eae .a.aea .s.aas Laughlin, Gary A. From: Laughlin, Gary A. Sent: Monday, May 18, 2009 8:35 AM To: winton.aubert~alaska.gov Cc: Laughlin, Gary A. Subject: FW: Conversation Fol~ow-up tmportance: High Sensitivity: Confidential • Attachments: Picture (Enhanced Metafile); Picture (Enhanced Metafile) From: Lauqhlin, Gary A, Sent: Monday, May 18, 2009 8:21 AM To: (winton aubert@~admin.state.ak.us) Cc: Lauqhlin, Gary A. Subiect: Conversatlon Follow-up Importance: High Sene~itivity; Confidentlal Winton, This is a follow up to our conversations May 13th and May 14th, 2009. ~ All Wells . It is my understanding you will be checking to see if you can strike the phrase "temporarily abandoned" in each well abandonment procedure and replace it with "permanently abandoned" far the Spark Platform sundries submitted in April 2009. We are currently running a gauge ring and temperature surveys for all wells on the Spark Platform. I expect to see the results Tuesday or Wednesday next week. After reviewing, I will send you an email on the order we plan to abandon the wells. We plan to have simultaneous well abandonment operations. The only certainty at this time is we will abandon S-5 last. . Marathon will be added an additional 70' of cement to the top of the cement surface plug, thereby increasing it to 370' to adhere to the regulatory citation 25.112 section (d). (d) Plugging of the surface of a well must meet the following requirements: N ~ p. ~ ~ ~ m ~ - „ ~ _ < . ~ ~ i y :u ` ~• ~ ;p ~ ~ ~ S _ _ r`~: e -. .. _' .., 1 _ d ss! - - ~? -, < _ ~ _ ` ' ,.. ,: _. - = zJ , j ' - t ~ : Z . j; ; ~ d l. ~ ; r. T s W ~{ ~ . . :l^:_ ~ ~ ' ~ ~ . l: F' ~ ~ ~ ~ ..=~ r,`. -• ~;~ : "' ~,, . o ~ < =~ - ~' p`c. . ~ 1 :a ` ~ ^, t ~. .. ." y ( r_ -- ]cz ' :a S ~ - . ` . ~ - i y ? - _ :~ r ~ . :: i ", _: tii ~ " ~w ~ T ~ ~. ; s , = ra - ~ti ~~ `8 ~ ~ -~ ~ S :_~ - '' ' ~ ~ ~ < < T ' ~ ` .S~ '- t ~.. e ~. ~ :~ t' '~ ` ' ~. S . ~ ~ _ ~ ~ ? - - ~~ s ,~ `r] ~ i~ Z e= _ r ' = -r .._ < -i ~ ~' ~ m ~ m x y .-t N 0 ~ S1I ~ c ~ a m' ~ v c ~ ~ m ~ c 3 ~ m ~ ~a ' ± ~ w ~ . ~ ~ ~ ~ m ~ ' o i om~v ~ ~ -ti' "`~ ~' ~ ~ j ~ W l :~ fµ" F 7':~ p~ 7 ~ ~ '~ . ai :~ i*.s c~ `'- -.~ . a ~ ~ : ~ ~ ~ _ ~ . ~ &~ ~ S.? ~ •r r c- - r - - '. ° ~ ..~ <s ~t s ~ a .- _ ~z ~ ~ ~: sr' d ='' ~ " s- :T ~y ~ ~ ~ ~` '~ y ' i1 "~ ~~ ~ .. , a ~ ~ , T .a ~.Y b'c [j ~ Y _J y . ~ ~ :M 1~ , ~ f +T~ ta '~ :F! ~ ~k .1 °~- w, ~ q'; ~ . : ~ .: r,y ~ , ~ ~ : ' y C3 ~ -`-. - i =~ C_~ ~ ~ ~ ' 4 ~ '{~y ~ 3 ~ m4 ~ "~ ~ ~ Ri ~ C ~ ~ 3 ~ ~ ~ Y 1 ~ ~ a s j ~c~ ¢ ~ K ~ ~ ,-, c~ ~ C ~i ~~--. ~ O ~ ~ ~ N ~ ¢ (D ~ O p~ «~ A ~ ~ ~ ~D ~ "r~ p CD O ~ ~ ~' i~ ~ Q ~ ~ ~ ~' ~ ~ ~ Oc ~ C ~ ? ~D ~ ~ ~ ~ ~ ~ ~ o ~ ~ CS. ~ ~ Mr. H+ tD ~ ~ ~ ~. ~ r'! ~~.. ~ R C~D ~ O ~ ~ ~ O tD ~ "i~ ~, ~ ~ ~ ~ ~ ~ a~ ~~ ~ o ~ ~ ~ Q v~ ca ~ ~ C ~' ~ ~ ~. ~ r• ~ ~ ~ ~ ~ ~ ~ 'S ~ O m ~ ~• O ar~a ~ . ~ ~- ~ ~. ~,' ~ UG ~ O ~ ~ S-9 We wiill be attempting to remove a fish located approximately 4' below the tubing hanger stuck in the early 90's from S-9. Thanks Gary ~ ~ Marathon Oil 1000 2000 3000 4000 5000 .-. d 6000 ~ w ..~ t ~ ~ 7000 ~ 8000 9000 10000 11000 12000 0 0 ~ W~TT" ~ S'9 ~ Field: ~ SparR~ ~ 06-16-2009 Pressure (psia) 500 1000 1500 2000 2500 3000 3500 4000 13000 ~ i ' I i ' I ' i I ' I i' ~ i' I I' I ' 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 190 Temperature (Deg. F) ~ressure 13 3/8" 9 5/8" 7" TBG PerFs ~ Mandrel Temperature 0 l{ l A~KA OIL AND GAS CONSERVATION COMMISSIGN REPORT OF'SUNDRY WELL OPERATIONS GL L 1. Operations performed: Operation shutdown -- Stimulate ~ Plugging Pull tubing ~ Alter casing ~ Repair well m Perforate m Other X .,5'~ '~,- ~'~ 2. Name of Operator ! 5. Type of Well: Marathon 0i ] Company I Development.x_ Exploratory __ 3, Address Stratigraphic __ P.O. Box 102380 Anchorage, AK 9951 Service. 4. Location of well at surface Leg1 Cond. #5 Spark Plattorm 2,570' FSL, 2,563' FEL, Sec. 26-10N-13W-SM At top of productive interval 1,571' FSL, 133' FEL, Sec. 34-10N-13W'SM At effective depth 1,309' FSL, 310' FEL, Sec. 34-10N-13W-SM At total depth 1,262' FSL, 342' FEL, Sec. 34-10N-13W-SM 6. Datum elevation (DF or KB) 115' KB above NSL feet 7. Unit or Property name North Trading Bay 8. Well number Unit 9. Permit number/approval number 91-414 '~ 7'~ ,~ ;~-,,~-- 10. APl number 50-333-20265 11. Field/Pool Hemlock & G-Zone 12. Present well condition sUmmary Total depth: measured true vertical Effective depth: measured true vertical 12,717 ' feet Plugs (measured) 10,066' feet 12,629' feet Junk(measured) 9,998' feet 12,629' - 12,714' CMT 12,391' - 12,419' Slickline fish 12,419' - 12,717' (fill) Casing Length Structural Size Cemented Measured depth True vertical depth Conductor Surface 2,720' Intermediate 11,160 ' Production 13 3/8" 1,500 sx 2,720' 2,571' 9 5/8" 900 sx 11,160' 8,894' Liner 1,851' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) " i ' Pa~kJ/~7~d &S'~/~tyl~aSn0d me~a]~ur~gdgepth) Otis WD Packer ¢ 11,834'; lA 13. Stimulation or cement squeeze summary Intervals treated (measured) 7" 570 sx 12,714' 10,063' G-1 12,139' G-4 12,245' G-5 12,304' H-1 12,360' H-2 12,415' SCSSV @231' Treatment description including volumes used and final pressure - 12,189' - 12,260' - 12,324' - 12,390' - 12,455' MD 9,623' MD 9,704' MD 9,750' MD 9,793' MD 9,836' - 9,661' TVD - 9,716' TVD - 9,765' TVD - 9,817' TVD - 9,867' TVD RECEtV£D APR 1 Alaska 0ii & Gas Cons. 'Anchorage 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2 5 5 0 10 3/3 815 110 Subsequent to operation 0 0 0 0 0 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run w Daily Report of Well Operations ~ Oil ~ Gas ~ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ned '~~~ Title Operations Engineering Supv Form 10-404~ev 06/15188 SUBMIT IN DuPLiCATE SPARK PLATFORM WELL S-9 Da/ly Summary of Operations 1/16/92 Well flowing to production. Close SCSSV. TP stable at 60 psi for 15 minutes, valve holding. Equalize and open SCSSV. Return well to production. 1/25/92 Shut in well. Bleed tubing and casing pressure to 0 psi. 1/26/92 RU to pump down tubing. TP and CP = 0 psi. PT line to 2500 psi. Pump 125 bbls filtered inlet water (FIW) down tubing at 5 BPM, 100 psi. Pump 125 bbls FIW treated with corrosion inhibitor down tubing at 2 BPM, 300 psi. RD off tubing and RU to pump down casing/tubing annulus. PT line to 2500 psi. Fill casing with 402 bbls inhibited FIW. SD pump, tubing and casing on vacuum. Wait 30 minutes and fill annulus with 40 bbls inhibited FIW. Wait 30 minutes and fill annulus with 12 bbls inhibited FIW. Monitor well. TP and CP = 0 psi. RD pump equipment. 1/27/92 through 2/3/92 TP increased to 90 psi o.ver 4 days and stabilized. CP increased to 40 psi over 2 days and stabilized. Closed S¢SSV. Bled TP and CP to 0 psi. 2/22/92 TP and CP = 0 psi. Close all tree valves. FINAL REPORT. \Spark\Sg.doc RECEIVED APR 1 7 1 92 Alaska Oil .& Gas Cons. Commission ;Anchorage At'Cachment #2 iR" 9.3~ ABC Moa. 1-20 tuSing Tubing pick u~ wt. iSS,OO0#' Tubing Qown wt. -7,S00# 7" line tod - 10863' 9-5/8" 47# N-80 csg '1160' All Perfs. G-2 12139' - 12189' ~-~ 122¢5' - 12260" G-5 1230¢' - 1232¢' H-1 12360' - 12390' .~-2 1241-~"- 12455' RECE)VED 'Alaska Oil & Gas Cons. Anchora~ ~qC ~fW, Is tubing hanger C3I' Camco I~I)P - IA $C~SV 2.813 ID 2720' 1]-~/8# 72~ N-80 asS. JJb~Flo~ecrol-~ohnacou S]~-IA 1.. ~tBST BLV 1" Valvelv/BKo2 L G.L. Valves 2275' 3/8 Por~ a065' ~18 Pore ~573' ]/8 Port 6671' 3/8 Pore 7~86' 3/8 Pore ~112' 7/16 Oriface ~611' 3/8 PoT= 9175' 3/8 Pore 9706' 3/8 Por~ 10,238' ~/~ Pore 10,767' 3/8 Por~ L1,267' 3/8 Pore 11,768' ~/80r~acm 11828' locator 7' I 4" Otis "WO' packer wtseai bore ext. ~ 11834' ' 11899' m:le shoe. 12629' PBTD 12714' 7" 29# H-80 liner ~,~7' T~ STATE OF ALASKA 0 R If} IN ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ 2. Name of Operator ! 5. Type of Well: Marathon Oil Company I Development X ~ Exploratory Z 3. Address __. _J Stratigraphic P.O. Box 102380 Anchorage, AK 9951q Service-- 4. Location of well at surface Leg - ,..,.,,,,-,. ,-., -,v~,, ~ .......... 2,570' FSL, 2,563' FEL, Sec. 26-10N-13W-SM At top of productive interval 1,571' FSL, 133' FEL, Sec. 34-10N-13W-SM At effective depth 1,309' FSL, 310' FEL, sec 34-10N-13W-SM At to al ~,¢Z~:~ FSL, 342' FEL, Sec. 34-10N-13W-SM Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing __ Variance __ Pedorate ~ Other 16~ pCtu..m...elev, ation (D,F,,.orKB) Ih' KI3 above FI3L .7 Uoi,t cf.,Property name Nbrtn ~raolng ~ay Unit 8. Well number S-9 9. Permit number 74-27 G-Zone feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12,629' 12,717 ' feet Plugs(measured) 10,066' feet 12o391' 12,629 ' feet Junk(measured) 9,998' feet 12,419' - 12,714' CMT - 12,419' Slickline fish - 12,717' (fill) Casing Length Structural Conductor Sudace 2,720' Intermediate 11,160 ' Production Liner 1,851' Perforation depth: measured true vertical Tubing (size. grade, and measured depth) 3 1/2" 9.3# L-80 e11,899' Size Cemented Measured depth True vertical depth 13 3/8" 1,500 sx 2,720' 2,571' 9 5/8" 900 sx 11,160' 8,894' 7" 570 sx 12,714' 10,063' G-1 12,139' - 12,189' MD G-4 12,245' - 12,260' MD G-5 12,304' - 12,324' MD H-1 12,360' - 12,390' MD H-2 12,415' - 12,455' MD P~k~r~a~S:~SaV6(~'~a~d r~a~e~::l'?Pth~ SCSSV @231' 13. Attachments 9,623' - 9,661' TVD 9,704' - 9,716' TVD 9,750' - 9,765' TVD 9,793' - 9,817' TVD 9,836' - 9,867' TVD 1, 2 Description summary of proposal _.~ Detailed operations program __ BOP L:.r' I V g IJ 14. Estimated date for commencing operation ,January 2, 1992 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: DEC 1 ? 199t Service Gas __ Suspe~iiBka__0il & Gas Cons. Commi~ Anchorage 17. I hereby certify that the foregoing isjr.,ue and correct to the best of my knowledge. Si ned Title0perations Engineering Superv ~,/ ' FOR COMMISSION USE ONLY Conditions ~f approval: Notify Commission so representative may witness Plug integrity __ BOP Test ~ Location clearance ~ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE , ~ Attachment #1 ~ SPARK PLATFORM WELL S-9 WELL SECURING PROCEDURE 1. Hold safety/operational meeting. 2. Close SCSSV. Bleed pressure to zero on the tubing. Monitor tubing for psi buildup for 30 minutes to ensure SCSSV holds pressure from below. Equalize pressure and open SCSSV. 3. Shut off lift gas and allow well to die. 4. RU to pump down tubing. PT surface lines to 2500 psi. 5. Pump two wellbore volumes (tubing and casing below packer) of 8.5 PPG salt water. Inject KW-132 corrosion/scale inhibitor at 0.754 concentration during second wellbore volume. Monitor casing pressures during pumping. 6. RU to pump down the tubing-casing annulus. PT surface lines to 2500 psi. 7. Fill tubing-casing annulus with 8.5 PPG salt water (including 0.754 KW-132 corrosion/scale inhibitor) by alternately pumping salt water and bleeding gas pressure. Do not exceed 1500 psi casing pressure. Monitor tubing pressure while pumping. Bleed any remaining pressure from pumping off of tubing and casing. Monitor pressures for buildup. 9. Bleed SCSSV control line pressure to zero to close the SCSSV. 10. RD pumping lines. Close all tree and casing valves. 11. Install pressure gauges on tubing and all casings. 8, \oe60\62.doc RECEIVED DEC 1 7' 1991 Alaska Oil & Gas Cons. Commission Anchorage Well S-9 '(Completed 1-10~"~q FMC 4~'X4~" Buttress tubing hanger 231' Camco TtLDP - lA SCSSv 2.813 ID 2720' 13-3/8" 72# N-80 csg. Flopetrol-Johnston SPM-1A 1.0" Gl w/BST BLV 1" Valves w/BK-2 Latche G.L. Valves 11'2276' 3/8 Port 4065' 3/8 Po%t 5573'. 3/8 Port 3%" 9.3# ABC Mod. L-80 tubing. Tubing pick up wt. 108,000#' Tubing down wt. 77,000# 6671' 3/8 Port 7486' 3/8 Port 8112' 7/16 Orifice. 8611' 3/8 Port 9175' 3/8 Port 9706' 3/8 Port 10,238' 3/~ Port 10,767' 3/8 Port 7" line top - 10863' 9-5/8" 47# N-80 csg 11160' 11,267' 3/8 Port All Perfs. DIL G-2 12139' - 12189' G-¢ 12245' - 12260" G-5 12304' - 12324' H-1 12360' - 12390, _H-2 1241-5'-- 12455' RECEIVED 11,768' 3/80riface 11828' locator 7" X 4" Otis "WD" packer w/seal bore ext. @ 11834' D.P.M 11899' mule shoe. 0./~.9o 12629' PBTD 12714' 7" 29# N-80 liner Alaska Oil & Gas Cons. ~nnhnraoO Marathon Oil Company Alask ~gion Dome~, .... Production RO. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 December 5, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 ~ Dear Mr. Chatterton: Enclosed is the AOGCC "Report of Sundry Well Operations" with attachments for Spark Platform Well S-1 and S-9. Should you have any questions regarding the report, please contact me at (907) 561-5311. Sincerely, D. K. Corlett District Operations Engineer Attachment DKC/em/6/ml RECEIVED Alaska.Oil & 8as Cons. Co~'r~IssIort A subsidiary of USX Corporation STATE OF ALASKA ALA...,A OIL AND GAS CONSERVATION COMMIS,...JN REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate m Plugging __ Pull tubing ~ Alter casing __ Repair well ~ Pull tubing I' 5. Type of Well: J Development ~ . J Exploratory ~ J Stratigraphic ~ Box 102380 Anchorage, AK 99.~1,0,_ _ ,Ser,.,v.,ice._~. 2. Name of Operator Marathon Oil Company 3. Address P.O. Pedorate m ~her x__Xylene Treatment 6. Datum elevation (DF or KB) 115' KB above MSL feet 7. _Unit or Property name North Trading Bay Unit 8. Well number 9. Permit number/approval number 8-526 J 10. APl number 5Ol.33-20265 11. Field/Pool Hemlock & G-Zone 4. Location of well at surface 2,570' FSL, At top of productive interval 1,571' FSL, At effective depth 1,309' FSL, At total depth 1,262' FSL, 2,563' FEL, Sec. 26-10N-13W-SM 133' FEL, Sec. 34-10N-13W-SM 310' FEL, Sec. 34-10N-13W-SM 342' FEL, Sec. 34-10N-13W-SM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface 2,720' Intermediate 11,160 ' Production Liner 1,851 ' Perforation depth: measured 12,717 ' feet Plugs (measured) 10,066' .feet 12,629 ' feet Junk (measured) 9,998 ' feet SiZe Cemented 13 3/8" 1,500 sx 9 5/8" 900 sx trUe vertical Tubing (size, grade, and measured depth) Packer3s 1/2" 9.3¢~ L-80 @11,899' anU SSSV (type and measured depth) Otis WD Packer @ 11,834'; 7" 570 sx 12,629' - 12,714' CMT. .R. ECF, I .E.D None DEC u 9 1,v,c ,cJ Measured de~t~8~ .OJl.&/~l'~l~)~j§jC_~ej~//shsJ0r/ ":Anchorage 2,720' 2,571' 11,160' 8,894' 12,714' 10,063' G-1 12,139' - 12,189' MD 9,623' G-4 12,245' - 12,260' MD 9,704' G-5 12,304' - 12,324' MD 9,750' H-1 12,360' - 12,390' MD 9,793' H-2 12,415' - 12,455' MD 9,836' IA SCSSV @231' - 9,661' TVD - 9,716' TVD - 9,765' TVD - 9,817' TVD - 9,867' TVD 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment #1 "Summary of Daily Well Treatment description including volumes used and final pressure Operations" 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 10/18/88 120 1233 1010 140 Subsequent to operation 11 / 6 / 88 149 1281 1200 15. Attachments: ~ 1 ~ 16. Status of well classificatiOn as: Copies of Logs and Surveys run ~ I Daily Report of Well Operations .z;... Oil ~ Gas ~ Suspende, d ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/~ ~c.//~,./~---' ' Service Title District Operations Engineer 110 Date 12/~'/~ Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Attachment #1 10/27/88 NTBU Well S-9 Summary of Daily Well Operations RU CTU and PT to 5000 psi OK R Annulus press _ 9~~ · IH w/CT to · - uu psi, cas' 2000'. Pump 50 bbls diesel @ 1/2 BPM. diesel (i00 bbl ...... . zng press· = 1120 psi. RIH while pumping 50 bbls · . o Local) and tag ~D @ 12,446' CTM. Pump Xylene @ 1/2 BPM and displace coil POOH from 12,446 to 12,139' while spotting I4 bbls Xylene across perforated interval @ 1/2 BPM. SD pump due to mechanical problems. Close CT and pipe rams on CT. (Pipe @ 12,139' CTM) Displace lines w/diesel· Waiting on parts. . 11/I/88 Resume Xylene Treatment. Pu 8100'-812~, ~%oo~ -7650' CTM. RIH and Y ~ u~m while pumping @ 3/4 BPM. P s ,BPM. Set RIH to 12,139' CTM ~- and bbls Xylene into perforations. POOH w/CT RD. Put well on production. 38A/Spark · rump remaining 14 REEEIVED 112 ',~' DEC ~laslm Oil & Gas Oons. Commission ' -,, ~nchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [~ Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator Marathon Oil Company 3. Address P.O. Box 102380 Anchorage, AK 99510 4. Location of well at surface Leg 1 Cond. #b Spar[< t-'iattorm 2,570' FSL, 2,563' FEL, Sec. 26-10N-13W-SM At top of productive interval 1,571' FSL, 133' FEL, Sec. 34-10N-13W-SM At effective depth 1,309' FSL, 310' FEL, Sec. 34-10N-13W-SM At total depth 1,262' FSL, 342' FEL, Sec. 34-10N-13W-SM 5. Datum elevation (DF or KB) 115' KB above MSL feet 6. Unit or Property name North Trading Bay Unit 7. Well number $-9 8. Permit number 74-27 9. APl number 50-- 133-20265 10..Pool Hemlock & G-Zone 11. Present well condition summary Total depth: measured true vertical 12,717' feet Plugs (measured) 10,066' feet 12,629' - 12,714' CMT Effective depth: measured 12,629' true vertical 9,998' feet Junk (measured) None feet Casing Length Structural Conductor Surface 2,720' Intermediate 11,160 ' Production Liner 1,851' Perforation depth: measured true vertical Tubing (size, grade and measured depth) Size 13 3/8" 9 5/8" Cemented Measured depth True Vertical depth 1,500 sx 2,720' 2,571' 900 sx 11,160' 8,894' 7" 570 sx 12,714' 10,063' G-1 12,139' - 12,189' MD 9,623' - 9,661' TVD G-4 12,245' - 12,260' MD 9,704' - 9,716' TVD G-5 12,304' - 12,324' MD 9,750' - 9,765' TVD H-1 12,360' - 12,390' MD 9,793' - 9,817' TVD H-2 12,415' - 12,455' MD 9,836' - 9,867' TVD 3 1/2" 9.3# L-80 @11,899' Packers and SSSV(type and measured depth) Otis WD Packer @ 11,834'; lA SCSSV @231' 12.Attachments 1 & 2Description summary of proposal [] Detailed operation~sp~o,~gr~[nl[5~ ~Hi~OP sketch [] 13. Estimated date for commencing operation July 1988 14. If proposal was verbally approved~u~.u~[ ~Voz]c ~epo~ on Name of approver ~o~ No. f~' ~d~ Dated sk~ 0it & ~as Coho. ~ '~;~ ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge fl Signed ~/~~~ Title District Operations Engineer Date Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI Approved by ORIGINAL SIGNED ~Y I. ONNLE C. SMITH Form 10-403 Rev 12-1-85 Approved Copy Returned by order of the commission Date ~'- -c"--oc:' ~ Submit in triplicate Attachment # 1 Well S-9 Procedure 1. SI de-emulsifier and scale inhibitor to gas lift five days prior to work. Notify GPPF 24 hours prior to shipping xylene. 2. RU Otis WL. PT lub. to 2500 psi. SI well. 3. Replace #6 GLV w/new BST GLV. Replace #14 GLV w/dummy valve. RD. 4. RU tanks to hold 2000 gal xylene and 5600 gal diesel. 5. RU Dowell pumping unit. PT to 3000 psi. 6. Pump the following w/o exceeding 3000 psi or 1BPM: 1. 15 Bbls Xylene 2. 90 Bbls FIW. 7. SI well for 15 min. 8. Flow xylene back. 9. Pump the following w/o exceeding 3000 psi or 3 BPM: 1. 33 Bbls Xylene 2. 108 Bbls diesel 10. SI for 1 hour. 11. Produce 20 Bbls of diesel. 12. Pump 25 Bbls of diesel. 13. RD Dowell. SI hr 12 hrs. 14. Bring well on slowly after 24 hrs. Begin injecting de-emulsifier and scale inhibitor w/lift gas. MRO/em/38A/Spark Attachment #2 SPARK PLATFO I,.,~' Wireline Lubricator w/Associated BOPE ~GREASE HEAD (Hydraulically Activated} LUBRICATOR MANUALLY OPERATED BOP .,. PUMP IN SUB. SINGLE COMPLETION GATE VALVE I ,, Gas Cons. Commission Anchorage ,'-", STATE OF ALASKA .--% ALAE 'OIL AND GAS CONSERVATION COM ;SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Alter Casing [] Other [] 2. Name of Operator Marathon Oil Company 3. Address P.O. Box 102380 4. Location of well at surface Anchorage, AK 99510 ~.eg i oond. #5 Spark PiatfoLm Perforate [] Pull tubing 5. Datum elevation (DF or KB) 115' KB above MSL 6. Unit or Property name North Trading Bay Unit 7. Well number S-9 8. Approval number 564 9. APl number 50-- 133-20265 2,570' FSL, 2,563' FEL, Sec. 26-10N-13W-SM At top of productive interval 1,571' FSL, 133' FEL, SeC. 34-10N-13W-SM At effective depth 1,309' ¥SL, 310' FEL, Sec. 34-10N-13W-SM At total depth 1,262' FSL, 342' FEL, Sec. 34-10N-13W-SM 10. Pool Hemlock & G-Zone 11. Present well condition summary Total depth: measured true vertical 12,717 ' feet 10,066' feet Plugs (measured) 12,629' - 12,714' CMT Effective depth: measured 12,629 ' true vertical 9,998' feet feet Junk (measured) None Casing Length Size Structural Cemented Measured depth True Vertical depth Conductor Surface 2,720' 13 3/8" 1,500 sx Intermediat~ 11,160' 9 5/8" 900 sx Production i Liner 1,851' 7" 570 sx 2,720' 11,160' 12,714' 2,571' 8,894' 10,063' Perforation depth: measured G-1 i true vertical G-4 ~: G-5 ~ H-1 Tubing (size, grade and measured depth) H-2 3 1/2" 9.3~f L-80 @11,899' Packers and SSSV;(type and measured depth) Otis'WD PaCker @ 11,834'; lA SCSSV @231' 12,139' - 12,189' MD 12,245' - 12,260' MD 12,304' - 12,324' MD 12,360' - 12,390' MD 12,415' - 12,455' MD 12. Stimulation or cement squeeze summary Intervals treated "(measured) Treatment description including Volumes used and final pressure 13. 9,623' - 9,661' TVD 9,704' - 9,716' TVD 9,750' - 9,765' TVD 9,793' - 9,817' TVD 9,836' - 9,867' TVD KELEIVEU JAN 3 0 1987 Alaska 0il & Gas Cons. Commission And. horace Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 12/12/86 45 19 87 Subsequent to operation 1/18/87 174 84 912 820 70 1170 130 14. Attachment~ #1, #2 Daily Report of Well Operations [] Copies of Logs and Surveys Ruj3 ©. 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed District Operations Engineer Title Submit in' Duplicate Form 10-404 Rev. 12-1-85 Attachment #1 Daily Report of Well Operations 1986 Well S-9 12-12-86 Accepted rig to S-9 ~orkover @ 1800 hrs 12-11-86. Began skidding rig to-S-9. 12-13-86 Skidded rig to NTBU Well S-9. RU drilling equip. Bled tbg pressure to 0 psi and csg pressure to 200 psi. Pumped 125 bbls fresh water w/3% KCL into tbg. Started filling annulus. 12-14-86 Filled 9-5/8" csg x 3-1/2" tbg annulus w/696 bbl fresh water. Reverse circulated 949 bbl to prod'n system - returns not clean. Circulated down tubing w/returns to prod'n system - recovered 179 bbl of 100% oil. Circulated down tubing w/returns to mud pits. 12-15-86 Circulated one hole volume. Mixed and pumped a marker-dye pill - had returns after 494 bbl. Apparently circulating through gas lift valve @ ±7077'. SI well & checked for flow - dead. Set BPV. -ND X-mas tree. NU BOPE. Pulled BPV. Tested BOPE. . · 12-16-86 MU landing jt. RU and circulated to prod,n system to clear annulus of oil. Worked tbg-f/130,000# to 204,000#. Could not release packer. RU WL. RIH & tagged electric line (left in hole in 1983) @ 220'. POOH w/WL. 12-17-86 RU braided WL for fishing electric line. Fished electric line out of hole to 2712' WLM. Encountered fill in tubing. Attempted to circulate - could not. Reverse circulated 50 bbl to prod'n system. RIH w/WL fishing tools & tagged electric line @ 2723' WLM.' POOH w/electric line fish - approximately 3000' of fish had been pulled @ 0600. Recovered piece of electric line ±4300' long - top of wire @ +7000'. Continued fishing for electric line w/braided line unit. Recovered ±5,500' of line in three trips -.top of electric line @ 11,897' WLM. RD braided line unit. RU electric line & RIH w/2.7" Jet cutter. Cut tbg @ 11,740' WLM. POOH & RD WL. LD tbg hanger. Circulate bottoms up. RECEIVED JAN :'.~ 0 1987 Alaska Oil & Gas Cor~s. u,~:msslo!i Page 2 12-19-86 Circ 1 hole volume. POH & LD 365 jts tubing & 11 GLM's. MU BHA to fish remaining tubing & packer. PU DP & RIH. 12-20-86 PU 5" DP. RIH w/pkr fishing tools. Circ above fish. Latch fish @ 11,716' DPM. Could not cir. Pulled 25,000#. Pkr released. POH w/fish. 12-21-86 Fin POH w/fish. Rec WL fish stuck in pkr. PU 6" bit. RIH. Wash and ream fill 12,210'-12,625'. Had intermittent very hard bridges. Circ to clean hole. 12-22-86 Cont c±rc to clean hole. POH 16 stds. Lost #1 SCR panel. Repair panel. Fin POH. LD 6" bit. PU 8-1/2" bit and csg scraper. RIH. 12-23-86 RIH w/9-5/8" csg scraper & 8-1/2" bit tagged TOL @ 10,867' DPM. Clean mud pits. Approx 200 bbls of sand in pits. Displace 9-5/8" csg w/drill water to aid filtering. POH. PU 6" bit & 7", 29# csg scraper. RIH. 12-24-86 Fin RIH w/7" csg scraper. Displace hole w/filtered 3% KCL. POH. RIH w/retrievable packer. Setting retrievable packer to test csg. 12-25-86 Set ret pkr @ 11,995'. Test csg to 2200 psi for 30 min. Rel pkr. POH 3 stds. Set inside BOP dart valve. RIH 3 stds. Set pkr @ 11,996'. Test csg to 1500 psi. Secure drill floor. Winterize rig. Rel rig crews @ 1700 hrs on 12-24-86. Will shut down until 1-5-87 to allow adequate approval time for S-8 recompletion. This will allow skidding to S-8 w/o LD drill pipe. Final report until 1-5-87. 1987 01-06-87 Activate-rig. Pump down DP, took 21 bbls to fill hole. Release pkr & circ volume of hole & DP. POH. LD pkr. RU loggers. Run GR & CCL. Tagged bottom @ 12,611' WLM. Logged to 11,300' DIL, CBL is 4' shallow. POH. RD loggers. Tested BOPE. RU to run tbg conveyed perf guns. RECEiYEB JAN 0 1987 Alaska 011 & Gas Cons. Commission Anchorage Page 3 01-07-87 RIH w/5" tbg conveyed-perf guns on DP. Locate guns and perf 8 SPF, 120° phasing, w/22 gram charges ~ G-I, 12,139'-12,189'; G-4, 12,245'-12,260'; G-5, 12,304'-12,324'; H-I, t2,360,-12~390'; H-2, 12,415'-12,455'. Allow well to die. Initial flow 8# SP thru needle valve and. presently 2# thru needle valve. Strong blow in bubble bucket. Prep to rev circ and POH. 01-08-87 Allow well to die after perforating. Rev circ to kill well. Rec 60 bbls oil. Hole began taking fluid @ 40 BPH. Spot 30 bbls litesal pill. POH. Hole no longer taking fluid. RU WL. RIH. Tag @ 12,559' DIL (70' of fill on btm). Fill 104' below btm. perf. RD WL. Prep to run completion assy. 01-09-87 RD WL. RIH w/Otis permanent packer & seal bore ext on DP. Pkr set @ 11,834' DPM. Tested pkr for 15 min, OK. POH. Hole losing fluid @ rate of 16 BPH. Mix litesal pill while monitoring hole. RIH to 11,810' & spot pill. POH w/no fluid loss. RU to run 3-1/2" completion string. 01-10-87 Run 3-1/2" prod tbg, gas lift valves and sub surface safety valve. Gator hawk tbg to 4000#. Sting into pkr. Press tbg to t00# w/no flow up ann. Space out and land tbg. Prep to ND BOPE. 01-11-87 ~ BOPE. NU tree and prod flowline. Test to 3000#. Flow test well. Bringing well on @ 30 BPH. Cum fluid @ 0600 is 143 bbls. Release rig to S-8 WO @ 1200 hrs 1-10-87. 01-12-87 Cont unloading Well S-9. Unload 373 bbls last 24 hrs. Cum prod 516 bbls. Presently have trace of oil, CP 1160#, TP 375#. Total tbg and csg vol 779 bbls. 01-13-87 Fin unloading and begin testing Well S-9. Unload and prod 830 bbls last 24 hrs. Cum fluid prod 1346 bbls. Tbg/ann vol 790 bbls. 2 hr test: 1284 BFPD, 85% WC, 193 BOPD, TP 240, CP 1120. Water cut steadily decreasing since 2400 hrs. FINAL REPORT. MRO/em/38A/Sundr2 Oil ~ $?ARK pLATFORM WELL $-9 1-10-87 By: J. R. Windstrup Attachment #2 FMC 4-1/2'x4-1/2' Buttress tubing hanger . 3-i/2" 9'.3~ ABC Mod. L-80 tubing .T%lbing pick up wt. 108,000~.~. ..Tubing down wt. '77,000~ ALL PENS. DIL G-2 12,139~-12,189' SPARK PLATFO~ WELL $-9 1-10-87 G-4 12~245'-12,260'*'* G-5 ~2,304'-12,324' H-1 12,360'-12,390' 12,415'-12,455~. By: J. R. Windstrup 231' Camco TRDP - lA $C$$V 2720' 13~3/8" 72# N-80 csg. Johnston-MaccO G.L. Valves -" 2276'; ~065'; 5573'; 6671'; 7486'; 8112'; 8611'; 9175'; 9706'; 10,238'; 10,767'; 11,267'; 11,768' ... 10,863' 7" ·liner top 11,160' 9-5/8" 47~ N-80 csg. 11,B28' locator 7" x 4" Otis "WD" packer w/seal bore ext. @ 11,834' D.P.M. 11,899" muleshoe · . Re-perforated (1-6-87) w/Baker 5" TCP guns 8 $PF @ 120° w/22 GR. charges 12,629' PBTD 12,714' 7" 29# N-80 liner Alaska Oil & Gas Cans. Corr~missior~ Ancl]orage STATE OF ALASKA ----, ALAS. OIL AND GAS CONSERVATION COM, ,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing j~ Amend order [] Perforate ~ Other [] 2. Name of Operator Marathon Oil Company 3. Address P.O. Box 102380 A~chorage, AY, 99510 4. Location of well at surface Leg t Cond. #.~ :spark t'latform 2,570' FSL, 2,563' FEL, Sec. 26-10N-13W-SM At top of productive interval 1,571' FSL, 133' FEL, Sec. 34-10N-13W-SM At effective depth 1,309' FSL, 310' FEL, Sec. 34-10N-13W-SM At total depth 1,262' FSL, 342' FEL, Sec. 34-10N-13W-SM 5. Datum elevation (DF or KB) 115' KB above MSL feet 6. Unit or Property name North Trading Bay Unit 7. Well number S-9 8. Permit number 74-27 9. APl number 50-- 133-20265 10. Pool Hemlock & G-Zone 11. Present well condition summary Total depth: measured true vertical 12,717' feet Plugs (measured) 10,066' feet 12,629' - 12,714' CMT Effective depth: measured true vertical Casing Length Structural Conductor Surface 2,720' Intermediate 11,160 ' Production Liner 1,851' Perforation depth: measured true vertical Tubing (size, grade and measured depth) 12,629' feet 9,998' feet Size 13 3/8" 9 5/8" 7" G-1 G-4 G-5 H-1 H-2 3 1/2" 9.2# N-80 @12,098' Packers and SSSV(type and measured depth) Baker FH Packer @ 12,026' "B-6" Junk (measured) 12,265' - 12,629' Fill Cemented Measured depth True Vertical depth 1,500 sx 2,720' 2,571' 900 sx 11,160' 8,894' 570 sx 12,714' 10,063' i2,139' - 12,189' MD 12,245' - 12,260' MD 12,304' - 12,324' MD 12,360' - 12,390' MD 12,415' - 12,455' MD 9,623' - 9,661' TVD 9,704' - 9,716' TVD 9,750' - 9,765' TVD 9,793' - 9,817' TVD 9,836' - 9,867' TVD BV @ 254' RECEIVED 12.Attachments #1 & 2 Description summary of proposal [] Detailed operations program [] BOP sketch [] NOV1 o 1.qRR Attachment #3 13. Estimated date for commencing operation November 1986Alaska Oil & Gas Cons. Commission 14. If proposal was verbally approved Anct]0raoe Name of approver Date approved 15. I hereby certify that th.e foregoing is true and correct to the best of my knowledge Signed ~/~¢,1~/~ Title District Operations Engineer Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceJ . ~, e, 7 .',~ ~.: :~-- ..' J/ ~ ..... '":~ by order o . ~' ", ~" ~;:: '"~~' Commissioner the commission Date Approved by.~: .~;: ~:~;: ~:, ¥~;:':~'~?~ Form 10-403 Rev 12-1-85 Submit in triplicate ATTACHMENT #1 S-9 Workover Procedure 1. Skid-rig 80 to Leg #1, RU over Well S-9. 2. Fill tubing and Csg w/ 3% KCL fluid. 3. Kill well by reverse circ 3% KCL fluid through orifice @ 11,895' md. 4. Set BPV ND tree NU & test BOPE. 5. Release Baker FH packer. 6. Spot ± 25 cu. ft. cement in bottom of tubing. W.O.C. 7. POH and LD tubing & completion equipment. 8. PU drill pipe, fish remaining W.L. and clean well out to 12,629' PBTD. POH. 9. RIH w/7" Csg scraper, circ. well clean. POH. 10. RIH w/ RBP - Set RBP @ 11,900'. Test Csg. POH. 11. MU 4" TCP guns and equipment on dp. RIH. Perforate the following: Interval DIL Depth Length G-1 12,139' - 12,189' 50' G-4 12,245' - 12,260' 15' G-5 12,304' - 12,324' 20' H-1 12,360' - 12,390' 30' H-2 12,415' - 12,455' 40' 12. Reverse circ to production facilities POH. L/D TCP equipment. 13. MU & RIH w/ completion equipment. 14. Set BPV. ND BOPE NU & test tree. 15. Unload & test well. Release rig. 16. Run GLS, PBU, and prod. logs after well stabilizes. Static bottom hole pressure 3,450 psi MDC/em/38/Sundry RECEIVED NOV l 0 1986 Alaska 0il & Gas Cons. Commission Anchorage Attachment #2 North Trading Bay Unit Spark Well S-9 (Current)- _ - 254' "B-6" BV . ~-- 2,720~ 13 3/8" 72~ N-80 csg. 3 1/2" 9.2~ N-80 cbg. North Trading Bay Unit Spark Well S-9 (Proposed) . , ' ' f 250' TP~V 2,720' 13 3/8" 72~ N-~ 3 1/2" 9.2~ N-80 cbg. 10,863' 7" liner cop 11,160' 9 5/8" 47# N-80 csg. 12,026' Baker FIt Packer 12,065' Otis "X" Nipple 12,098' Baker Shear Sub 10,863' 7" liner top 11,160' 9 5/8" 47~ N-8. 11,950~ Pel~nanent Pack, 12,01§" WI, reentry gu~ All Perfs DIL · 12,13~'-'~'12,189' ~ 12,2&5'-~-12,260' 12,304'-~-12,32&' --~ 12,360' -'~-12,390' 12,415' - 12,4.55' 12,130' 12,132' 12,265' 12,629' 12,714' Perf gun hung up (6/19/83].. All Perfs DIL · · DIL 21' Marker Jr. . . G-2' · .12,139' - 12,189' --~ 12,132' DIL 21' Marker Fill (6/4/83) 12,245'-~12,260' ,-~ ~-5 12,304'-2-12,324' ~ 7" 29~ N-80 csg. 12,360' - 12,390' H-2 12,415'-~-12,A5~'' 12,629' PBTD 12,714' 7" 29~ N-80 csg ... RECEIVED NOV 1 0 1986 Alaska Oil & Gas Cons. Commission Anchorage Attachment #3 MARATHON OIL cOMP ANY SPARK PLATFORM MUD PAN ~FLOWLINE DRILLING NIPPLE 13 5/8"x5,000~' ANNULAR PREVENTER (HYDRIL) 3.x5,0OO'f'-K ILL LINE '(PIPE RAMS) (BLIND RAMS) CLAMP CONNECT OR 13 5/8' DOUBLE"G~TE' (ClW) CHOKE LINE 3"X5,000'f' DRILL DECK FLOOR cLAMP CONNECTOR RECEIVED NOV 1 o 1986 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Offi:ce Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 June 1, 1983 State of Alaska Department of Natural Resources Oil & Gas Division 3001 Porcupine Drive Anchorage, AK 99504 Subject: North Trading Bay Unit Well S-2RD (11-35) and S-9 (44-34) Gentlemen: Attached are the Sundry Notices of our intention to reperforate existing producing intervals in Wells S-2RD and S-9. We intend to open to production a non-perforated interval (H-2) in Well S-2RD. Very truly yours, M. D. Haas Area Engineer MDH:MCW:ml Attachment STATE OF ALASKA ALASKA 6"'% AND GAS CONSERVATION CO,~,,M ISSION 1. DRILLING WELL [] COMPLETED WELL OTHER 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 3. Address 8. APl Number P.O. Box 100360 Anchorage, Alaska 99510 s0- 133-20265 4. Location of Well At Surface: Spark Platform, 2570' N and 2563' W . of SE Cr. Sec. 26, T10N, R13W, SM 5. Elevation in feet (indicate KB, DF, etc.) 115 RKB 12. 6. Lease Designation and Serial No. ADL 17597 9. Unit or Lease Name North Trading Bay Unit 10. Well Number - S-9 (44-34) 11. Field and Pool Trading Bay Hemlock and 'G' zones Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [~ Alter Casing [] Perforations E} Altering Casing Stimulate. [] Abandon [] Stimulation [] Abandonmem, Repair Welt [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10.407 with a submitted Form 10~407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any' proposed work, for Abandonment see 20 AAC 25.105-170). We intend to reperforate the following intevals with 4 spoof: 12140-12190 (G-2) 12245-12265 (G-4) 12301-12321 (G-5) 12370-12390 (H-l) 12420-12440 (H-2) RECEIVED JUN 0 Anchorag0 14. I hereby certify that the foregoing is true and correct to the best of my kno..,~-Iedge. SiCned Title ~ The space below for Commission use Date Conditions of Approval, if any: APproved by ORIGINAL SIGNED BY LOflHIE C, SMITH Approved Copy Returned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 REV. 1-10-73 Submit "Intentions" 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.) o~L 1':3' GAS !'-'1 WELLI-,~I WELL!' I OTHER 2. NAME OF OPERATOR ARCO Alaska, Inc. 3. ADDRESS OF OPERATOR 711 W. 8th, P, O. 4. LOCATION OF WELL BOX 360, Anchoraqe, AK 99510 Atsudace Spark Platform Cond. #4, Leg #3, 2606' FSL and 2492' FEL of Sec 26, T10N, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 115' RKB 114' DF 14. CheCk Appropriate Box TO Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20172-01 6. LEASE DESIGNATION AND SERIAL NO. ADL 18776 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME North Tradinq Bay 9. WELL NO. S-2Rd (11-35) 10. FIELD AND POOL, OR WILDCAT 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 34, T10N, R13W 12. PERMIT NO. )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSE(~UENT REPORT OF: FRACTURE TREATMENT L~[ ALTERING CASING SHOOTING OR ACIDIZING ~ ~ ABANDONMENT* (Other) Pressure Buildup (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. The following intervals were perforated 4 SPF July 9, 10, 11, 1981: DI.L Depths Feet PerfOrated 11078-11098 20' 10737-10762 25·! 10694-10714 20' 10643-10668 25' 11002-11012 10' 10560-10570 10' 110' 16. I hereby certify that the foregoing is true and correct SIGNED..~.~''1"'''''---' RECEIVED AUG 2 5 1981 Alaska Oil & Gas Cons. Commission Anchorage (This space for State office use) APPROVED BY , CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side Form ! 0-403 . Submit "1 ntentions" in Triplicate REV. 1-10-,73 ~- & ,,Subse~luent Re~3orts" in Duplicate STATE 0 F A LASS- 0IL AND GAS CONSERVATION COMMITTEE 5. APl NUMERICAL CODE 50-133-20265 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.) 6. LEASE DESIGNATION AND SERIAL NO. ADL 17597 7. IF INDIAN, ALLOTTEE OR TRIBE NAME WELL1 I OTHER NAME OF OPERATOR ARCO Alaska, InC. 3. ADDRESS OF OPERATOR / .' 711 W 8th, P. O. Box 360, Ancb. oraqe, AK 99510' 4. LOCATION OF WELL Atsurface Spark Platform, of SE Cr Sec 26, 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 115 RKB 2570'N and 2563'W T10N, R13W, SM CheCk Appropriate Box To Indicate Nature of Notice, Re 14. 8. UNIT, FARM OR LEASE NAME North Trading Bay 9. WELL NO. · S-9 (44-34) 10. FIELD AND POOL, OR WILDCAT Trading Bay 'NE Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 34, T10Nr R13W, SM 12. PERMIT NO. )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF E~ REPAIRING WELL I I FRACTURE TREATMENT L__J ALTERING CASING SHOOTING OR ACIDIZlNG lz%z~l ABANDONMENT* (Other) Production--~-±og (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. The following intervals were perforated 4 SPF July 13 & 14, 1981: DIL Depths Feet Perforated 12360 - 12380 12304 - 12324 20' 20' RECEIVED AUG 5 ]98l Alaska 0il & Gas Cons. Commission Anchorage 16. I hereby certify that the foregoing is true and correct TITLE (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side ALASKA OIL AND GAS CONSERVATION COMMISSION Chairman/Commiss~d~F' Thru: Lonnie ~. Smith ~ Commissioner ~~ Bobby Foste~.~~' Petroleum Inspector August 14, 1980 Witness No Flow Test on ARCO's .Sparks Platform Well #S-9. Thursday August 7, 1980 I traveled this date to ARCO's Sparks platform to witness a no-flow test on well S-9. Upon arriving on the platform I discussed the test procedure wi~h Mr. Kirk Glass, Production Supervisor, and Mr. Greg Moore Chief Operator. Mr. Glass tn- formed me that the liquid meter on the test separator was not working, so it was decided to install a new chart on the vent on the test separator, close the gas lift supply gas off to the well and let the well flow until it would not produce against the 50 psig separator pressure. When the well would not flow against the test separator pressure the drain was opened to'the skimmer tank. The well head pressure bled to 0 psig, flowing approximately 10 bbls of fluid. At this point Otis had finished rigging up their lubricator and was ready to pull the SSSV. Due to the swab valve leaking the well had to be shut in at the master valve while the_ lubricator was being installed and test- ed. The well was shut in for 1 hour and 15 minutes and in this time the tubing pressure rose to 190 psig. After pulling the SSSV, the well was bled to the test separator and then to the skimmer tank with approximately 15 bbls of fluid being produced. I then marked the sight glass on the skimmer tank and observed same for 2 hours with no fluid being gained. I then went to the well room and the SSV was closed. After 15 minutes the needle valve on the swab cap was opened and a small blow of gas escaped with no fluid. I then requested Mr. Glass to leave the well in the skimmer tank for another hour and if no fluid was gained to put well back into production. The chart from the test sepa- rator would be pulled at that time and mailed to the AOGCC office. In summary I witnessed the satisfactory no-flow test on ARCO's S-9. ARCO Oil and Ga,~"'~mpany Alaska Distri~.J Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 12, 1980 Mr. Hoyle Hamilton, Chairman Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99501 ~-NFER~ Re: Spark Platform, S-9 well Dear Mr. Hami lton: Enclosed are two copies of the Sundry Notice'of the clean-out and reperforation work and two copies of the Monthly RePort of Drilling and Workover Operations on the S-9 well. Sincerely, C. R. Knowles District Drilling Superintendent CRK/LAE/dac Enclosures ('4) ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form ~. 0-403 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. OwIELLLF~IWELLGAS n~ OTHER 2. NAME OF OPERATOR ARCO Oil & Gas Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL Atsurface Spark PlatfOrm; 2570' N & 2563' W from SE CDr, Sec 26, TION, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 115' RKB i4. CheCk Appropriate BOx To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20265 6. LEASE DESIGNATION AND SERIAL NO. ADL 17597 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME North Trading Bay Unit 9. WELL NO. S-9 (44-34) 10. FIELD AND POOL, OR WILDCAT Trading Bay NE "G" Hemlock 11. SEC., T., R., M., (BOTTOM HO~LE OBJECTIVE) Sec 34, TION, R13W, SM 12. PERMIT NO. 74-0027 )orr, or Other Data NOTICE OF INTENTION TO.' TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR AClDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSE(~UENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) Clean out fill & reDerforation (NOTE: Report results of multiple completion on Well Completion or RecomDletion Report and Log form,) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give Pertinent dates, including estimated date of starting any proposed work. . On April 24, ]980~ RU Otis snubbing equipment and tested w/2000 psi. Stripped into ]2%008' and filled work string W/Dri]]-S pill. Stripped into top of hard fiji at ]2,253' & PU to ]'2,243'. Displaced Dri]]-S pi]] w/Dri]-S W0 and circulated we]] clean w/Dri]]-S W0 fluid. Washed fill from ]2,253'-]2,424'. Circulated well clean. Spot. 25 bb]s Dri]]-S pi]] from ]2,624'-]2,000'. Perforated ]2']89"- ]2,]69' DIL, ]2,260' - ]2,245' DIL, ]2,]69' - ]2,]49' DIL, ]2,]49"- ]2,]39' DIL and ]2,455' - ]2,435' DIL. Released wet] to production department at ]200 hfs, May 7, ]980. 24 hour test, May 9, ]980' 2302 bb] gross, ]335 bb] water, cu . R E E' I V F D SIGNED . / _ _ TITLE Dist Drlg Supt DATE May 12: lORO (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY; COMMISSIONER TITLE DATE See Instructions On Reverse Side ~rm No,' P--.4 lq.E'V. ~- I-?0 STATE Or-ALASKA OIL AND GAS CONSERVATIOI~I COMMII~EE S~BMI~ IN DUPLICAT~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIOHS WgLL wgLL OTHBi~ NAME OF OPE~ATOR ARCO Oil and Gas Company P. O. Box 360, Anchorage, Alaska 99510 LOCAT/ON OF W~-.J..,L Spark Platform' 2570' N & 2563' W from $[ Cor. Sec 26, TION, R13W, SM! AP1 NU,~{ERICAL CODE 50-133-20265 J6 T.~.A. SE DESIGNATION AN'D SEBIAL NO. ADL 17597 IF INDIAI~T, ALOi lk~. OR TRIBE NAME 8. ~.,~IT FA/~ OR LEASE NAJ~E North Trading BaS Unit S-9 (44-34) 10 FLlg..L.D A_ND POOL,~)R WILDCAT Tradina Bav NE "G'.' Hemlock -11 SM, T.. R.,-M. (BbTTOM HOL~ Sec 34~ T1ON~ R13W~ SM 12. PERMIT NO 74-0027 "13. REPORT TOTAL DEPTH AT END OF MONTH. CH.A~NGF_,S IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AN'D VOLU1VIES USED. pER~OHATIONS. TESTS AN~D RESULTS FISHING JOBI5 JUNK IN HOLE AND SIDE-TI~ACICED HOLE A~TD ANY OTI-EER SIGNIFICANT CHAN~ IN HOL]~ CON'DITIONS On April 24, 1980, RU Otis snubbing equipment and tested w/2000 psi. Stripped into 12,008' and filled work string w/Drill-S pill. Stripped into top of hard fill at 12,253' &. PU to 12,243' Displaced Drill-S pill w/Dril-S WO fill frOm 12,253' pill frOm 12,624' 12,245' DIL, 12,1 12,435' DIL. Rel May 7, 1980. 24 hour test, May 9, 1980: 967 bbl oil, w/58% cut. and circulated well clean w/Driil-S WO fluid. Washed -1'2,424'. Circulated well clean. Spot. 25 bbls Drill-S ~ ~'2 Perforated l~]89'- 12,169' DIL, 12,260' - ,2,00_ :149' DIL, 12,1 - 12,139' DIE and 12,455' - eased well to production.department at 1200 hrs, 2302 bbl gross, 1335 bbl water, -!4.1 hereby certi£y th~tthe~~and ~o.rre~: S~Oh'~D :~_m Di~f~int- - n~la R,,nf D~ ~-L;~OV ' NOTE ~Re~ort on this fan is required for .~ calendar ~nthl regordlfls of Iht Itotus of operations, and must ~ flied in dupli~te with the oil and gas conservatbn commi~ee bythe IS~ of the suoc~ding mon~, ~le~ Otherwise d~r4~ted. ARCO Oil and Ga~ ;~pany $ou~h Alas: .... ~5trict Pos[ Office L:~ox 3G0 Anchorage. Alaska 9(,)510 Tel(.;phone 907 277 5-837 April 22, 1980 Mr. Hoyle Hamilton Chairman Alaska Oil & Gas Conservation Commission State of Alaska 3001 Porcupine Drive Anchorage, Ak 99501 ,'¢' I 4 10EOL----- I ,qT.~.T Tr.-C- /2, Re' Sundry Notice, Spark Platform S-9, S-1 & S-3 Dear Mr. Hamilton' Transmitted herewith are three (3) separate Sundry Notices (in triplicate) filed by ARCO Oil & Gas Company, requesting an approval for the subject workovers. In the event your office should need additional infor- mation in conjunction with this matter, please do not hesitate to contact us. Very truly your/s, C. R. Knowles Dist. Drlg. Supt. CRK/KUP/dac Enclosures ARCO Oil and Gas Company is a Division of AtlanticRichlieldCompany Form ;[0-403 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 I~ GAS D WELL WELL OTHER NAME OF OPERATOR ARCO 0il & Gas Company ADDRESS OF OPERATOR P. 0. Box 360, Anchorage, Ak 99510 4. LOCATION OF WELL Atsurface 5park Platform, 2570' N & 2563' Sec 26, T1ON, R13W, SM. W from SE Cr. 13. ELEVATIONS (Show whether DF, RT, GR, et~) 115' RKB 14, Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20265 6. LEASE DESIGNATION AND SERIAL NO. ADL 17597 7. IF INDIAN, ALLOi/EE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME North Trading Bay Unit 9. WELL NO. S-9 (44-34) 10. FIELD AND POOL, OR WILDCAT Trading Bay NE "G" Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 34, TION, R13W, SM 12. PERMIT NO. )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Clean out fill & reperforation SUBSEQUENT REPORT OF: WATER SHUT~)FF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING, CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletlon 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 was completed in November 1974 as a "G:'-Hemlock Producer, and a fill was tagged @ 12,260' RKB during the recent wireline survey. AOGC intends to clean out this fill which presently covers G-5 & H-1 producing zone using Otis 4-1/16" 'hydraulic Workover unit and Dril-S workover fluid with full returns to the mud pit. This hydraulic workover unit contains 10,000# BOP stack with shear rams, safetY rams, stripper rams and equalizing rams. Upon completion of clean-out operation, G-5 & H-1 zones will be reperforated with possible additional perforation in H-2 zone. The operation will commence on or about April 22, 1980 and will take approximately seven (7) days. Subsequent Work lteportecl on Form No. ~ Dated ~~.~0 ~l~ka 0it & G::~s ~.ons, ¢ommissioa foingJ true and c rect 16. I hereby certify that ~~ SIGNED ..... b. K. ~n0wle~ TITLE Dist Drl§ Supt DATE. April 22, 1980 (This space for State office ~e~e) ~ ~-~ ~.. /,~/~,. , COMMISSIONEll '¥_ .t..:/,-' -- / APPROVED BY ,--/",~'~'~,~,-,,.~ '/~q TITLE . CONDITIONS OF A~ROVAL, IF aN~=~y ¢RD~R OF THE See Instructions On Reverse Side DATE Approved Copy Returned AtlanticRichfieldCompany i ~ North Ameri;~'"~roducing Division South Alasf ,,strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 December 19, 1974 Mr. Homer Burrell State of Alaska Depar~.~ent of Natural Resources 0il & Gas Division 3001 Procupine Drive Anchorage, Alaska 99504 Dear Mr. Burrell: Attached is the November Report of Drilling Operations and the Well Completion Report for the NTBU S-9 (44-34) well which was recently completed on the Spark Platform. ~'Keasler ~'South Alaska District Drilling Supervisor JDK/DLS/sk Attachments Form ~o. ~W. ZtV, &- I- 70 STATE O, ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS SUBMIT IN I~'P'LICAT"E wr-LL NAME OF OPhiR Atlantic Richfield Company 50-133-20265 S L.F..AiE DESiGNA'I'ION AND SE'RIAL N~)'. ' ' ..... ADL 17597 P. O. Box 360, Anchorage, AK 99510 4 ~CA~ON ~ WEll,, ................ At Surface: Spark Platform, 2570'N & 2563'WS of SE cr Sec 26, T10N, R13W, SM $. L~,'IT P~M OR LEASE N~J~I~-" ' North Trading Bay Unit 9 ~WELL NO ' '" ' 13. REPORT TO~AL DEFTH AT DID OF MONTH. 'CHANGES IN HOLE SIZE. EASING A~ ~H~'~ 'JOBS INCLL~ING D~ ..... SET ~ VOL~ ~S~. P~O~O'S, ~TS ~ ~SUL~ F~G JO~ ~ ~ 'O~ AND SIDE-~C~ HO~ -~D ~Y O~ SIGNtFIC~T ~~ ~ HO~ ~N~ITIONS s-9 Trading Bay NE Hemlock S T10N, R13W, SM P~ NO ?4-aT November, 1974: Drilled 8-1/2" directional hole f/12,4 log f/12,714-11 160'. Ran 200' of FDC logging tools. ~an 7" 29#/ft N-80 Butt landing collar ~ 12,632'. Cemented lin w/l% CFR-2 & 0.2% HR-7 ~ 15.8 ppg. Cir Cleaned out liner to 12,629'. Tested c for 15 minutes, OK. Ran water shut off gas lift completion assembly to 12,096 ~ 12,031'; Gas lift valves ~ 11,896', 77'-.12,717' TD. Ran Schlumberger DIL log f/12,714' & stuck tools. Fished ress liner f/10,863'-12,714' with er with 570 sacks class "G" cement culated cement around top of liner.. asing and liner lap with 2500 psi test. Test dry, lap OK. Ran 3-1/2" ' as follows: 7"'Hydraulic packer 11,447', 11,037', 10,592', 10,201', 9,781', 9,329', 8,877', 8.178', 7,074', 5,365', 2,874'; and TRB-6 safety valve ~ 254'. Installed and tested tree w/5000 psi. Perforated following intervals through tubing with 4 JSPF (DIL measurement): 12,139-12,189', 12,245-12,260', 12 304-12,324', 12,360-12,390'. (llS' total). Ran 5 hr -~tatic BHP survey ~ 121,380' ~/Heml~-Bench H-1 perforatimns open from 1~,380-L'12,390' w/pressure build up to 2577 psi. Reran 4 hr static BHP survey ~ 12;.380'. w/all~'above:perforations open w'~pressure build up to 2789 psi. Released'Rig ~ 1700 hr~ ll,17-.y4. FINAL REPORT. Tested BOPE on November 3 and 10. DEC 2 0 tqm D!\'I$1GI,~ ,~r OIL AND GAS ANCHORAo~ lt. Ih ' ,there, ins'"' ',~,t ' ' ' ' 12-19-74 · s, Dist. Drlg. Supvr.~n,r~.]. '~ ~ .... / ....... - ,,~.~,~,o ~. -~=~,M~- , ....... ~RePo~t-On this f~ is required for ea~ cajtndar ~tht regardles~ 'of the mtat~ of ope~ a~ must ~ fil~ in du~i~le ~th't~ oil an4 gas conservatbn commi~ by ~e i5~ of the suee~4ing mn~, ~tem otherwie4 d~re~d. Form P - 7 la. TYPE OF WELL: Oli, W gLI. W ELL DR V Other S I STATE OF ALASKA I'i !% <s,., o.th.:'r I',~'J APl N~CA~ CODE OIL AND OAS CONSE.VATION ADL b, TYPE OF COMPLETION: .~.w® ~.o~,,~ ~-~ ~,,~ ~,~.~ WELl, OVER EN BACK P, ESVR. Other 2. NAME OF OPERATOR Atlantic Richfield Company . , 3. ADDRESS OF OPERATOR P. 0. Box 360, Anchorage, Alaska 99510 4. L0C*rION 0r WELL (Rel~ort location c~early and in accordance with any ~tate requirements)* At surface 2570' N & 2563W fr SE er Sec 26, TION, R13W, SM At top prod. interval reported below 1571' N & 133' W fr SE er Sec 34, TION, R13W, SM At total depth , 1262' N & 342' W fr SE er Sec 34, TION, R13W, SM UNIT,Fa OR LF~kSE NAME North Trading Bay Unil 9. WELL NO. S-9 (~-3~) 10.FIELD A2qD POOL, OR WlDC&T Trading Bay NE Hemlocl SEC., T., R.. M., (BOTTOM HOLJE OBJECTIVE) Sec 34, TION, R13W, SM 12. PERiVIIT NO. 74-27 INTERVALS DRILLED BY · 18 TOTAL DEPTH NLD & TVD[19, pLUG, ~XCK MD & TI/Dm. IF~ iVFULa~I~'I~rLvE. CO1VI~,L.. 21. '~o VlV' 'MD / 12 629' MD / ~ow~ ao~*~ ~ooL~ c,~,,~ Too,.,~ ~,/ . - / ' / 358' - 12,717' ~~o ~V~L<S>. ~ ~ SURVEY NADE "G" Prod 12,136' -~12,330' MD 9621' - 9~70' TVD Hemlock 12,355' - 12,717' MD 9789' - 10,066' TVD . ~ YES 24: TYPE ELECTRIC AND OTHIg~ LOGS RUN DIL &: FDC 2~. CASING RECORD (Report all strings set in wall) C~SII4G SIZE WEIGHT, LB/FT, HOLE SIZE 13- 9-5 26. LINER F~E C O~O 28. PEI~FORATiONS OP~;LN TO P (inte v , 'ze - ~asPF (1/2") 12,139'-12,189' G-2 12,2~5'-12,260' G-h. 12,~0~'-12,324' G-5 12,360'-12,390' H-1 30. DATE FIRST PI%ODUCTION 11-15-74 Piq. ODUCTION DATZ OF TI:ST, [HOURS TESTED ' [CI-tOKE SiZE ]PI%OD'N FO,l% l l ~V, TUBING leASCO P~ESSUaE ICAL~T~ OI~BBL. ~SS'l 4 0 1 /m-~ou~ ~ , I I I 31. WSPOSmqON O~ OAS (Sold, used lor tuel, vented, etc.) Used for fue~ , CEMLNTING RECOILD ! A~JOUNT pULT,~D 1500 sx" w/10% ' I Gel & 500 sx "G" 27. TUBING RECOPt,D SCi2EEN (~ffD) SIZE [ DEPTH SET (MD) ] PACKER SET (MD) 29. ACID, Si!OT, FilAC~URE, C~,IENT SQUEEZe, ETC. D~o~i iNT~V.~ (MD) } AMOUNF 2~D }lIND OF MA~EP~AL US~ 32. LIST OF ATTACHMENTS PI%ODUCTION 1VIE1 [-[0{~) (Flowit~g, gas lift, pumping--size and type of pump) Gas Lift OIL--EDL. G.~.S--N~CF. I I GAS--~vICF. I J Vc'ELL STATUS (.Producing or ~'~'?)r o duc i ng }V£JI'EI%--BBL. I GAS-OIL IL%TIO [ 0 366 WA'r ~:rc--B BL, [ OIL GRAVITY-AP1 (COl~q,) I o I 36 .o I TEST WITNESSED BY !! TLE So. AK drlg Supervisor DATE 12_-._1_7_~74 ....... *(See Instructions and Spaces [or Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct ,,veil completion repor) end log or:~ all types of lenJs and leoses in Alosko. Item: 16: Indicate which elevotion is used as reference (where not otherwise shown) for depth measure- ments given in c, ther spaces on this form and in any a)tachmer~ts. Items 20, ~,nd 22:: If this well is completed for seperetc, production from more than one interval zone (multiple completion), so stote in item 20, and in item 22 show the p, cducir~g interval, or intervels, top(s), bottom(s) and nome (s) (if any) for only the interval reported in item :30. Submit e seperete report (poge) on this form, edequetely identified, for each edditic~nal inte~vel to be seperetely produce, J, show- ing the odditionel dote pertinent to such interval. Item26: "Socks Cement": Attoched supplementol records for this well should show the details of any mul- tiple stage cementing 0nct the Iocotion of the cementing tool. Item 28: Submit a seperete completion report on this form for each interval to be seperately produced. (See instruction for items 20 and 22 obove). , $4. SUMMA. I~V OP 'pok~A~'ibN TE, S,i,s iN('LUI)iNCl INTEI~VAI. TESTED, PH.ESSUIIE DAT~ ~ ~COVE~-~I]E..~ OF OIL'. WA'I']gl). AND MUD Tyonek 3750' 3358' MGS 5580 ' 4706' "G" Prod 12,136' 9621' Hemlock 12,335 ' 9789 ' ae. cort~ n^.^. ^~'^c..nm~)' r)mnammo,~s ;or ~m,o,-ocv, ,-onosn',v. r.-,,c~.r~s. ~,~.~r i',~.s JOB No__A.-?-$-?I4 DATE 11,-1, 5-74; DIVISION r,.-F L,I~ ~HD OAS ANCI, IOR,a.C;E ]~EPO~T , ~ 'and' PLAN SUB-SURFACE SURVEY N.T.B.U. S-9 CO,~IPLETJON REPORT NOVEMBER 8~ 1974 qTLANTIC RICHFIELD CO. NORTH TRADING BAY WELL S,~9 .. PREPARED FOR ADDCO BY F', TRUE .~EA$, D~IFT VERTICAL !~EPTH ANGLE DEPTH D M RECORD OF SURVEY CALCULATIONS PERFORMED BY I 8 M ELECTRONIC COMPUTER .... SUB DRIFT TOTAL COORDINATES . SEA DIREC ...................... DISTANCE ANGLE DEG/IOOFT ....... D! )NC BEG, D 317,00 $ 0 E 861,56 S 16 E-' '50e97 $ 60.00 $ 43~ 0 0 4t~,00 gl7 3 ~0 916087 977 5 45 976,56 I0~0 8 15 1038,g! 72,13 W 85,12 S 57 5~ 3 W 70,79 W 92,80 $ 49 ~2 59 W 97,$0 5 ~ 51 12 W 51.76 W 19i,72 $ 15 ~9 ~5 W 70,38 S 67062 97.12 $ ' 62,42 _ 1232 12 0 1227,08 II12,08 $ 11 E 1385 1~ O 1376,15 1261,15 $ 10 E - 131,01-5 0,000 0.127 3,315 70,0~ ~,~17 71,36 _ . 3,770 75.90 1.600 ..... 0*669 142.60 .... 1725 21 0 1697.75 1552,75 $ 5 E 240,~0 $ .... 46,88 W" ' 24~,83 S 11 2 27 W ..... 2.56~ ' 237,7a Ia~l 2~ 15 1839.99 1724.99 5- 5 E ' 30~.12 S ...... ~1.30"~-'306,92 2052'27. 45- 1991.~2 1876,3~ "$'5-'E ...... 383,44'$ .... ~'36 W--- 2125 29 ~0 205~.a6 19~9.86 $ 0 E ~19,39 $ ...... 34.36 W ..... ~20,79 S 2250 28 30 2165.~6 2050,66 $ 6 W-" 477,~6'$ ......... 38,87 W 2312 25 15 2221.54 2106.5~ $ 14 W 2479 28 0 2368,99 2253.99 $ 19 W 2700 33 1~ 2555.81 2438.81 $ 19-W 28'13 29 0 2652.64 2537.6~ $ 24 W 29~5 32 15 276~.28 26~9.28 S 23 W ~105 36 30 2~92,g0 2777,90 $ 23 W ~263 40 ~5 }012,59 2897,59 $ 22 W 503.02 $ .......... ¢5.27 577.15 S ...... 70.79 691,72 $ 110,24 7~I,77 S 132.53 806,61 S 160,05 894,22 $ 197e2~ 989,8~' $ 235.87 ... 505,06 5 5 8 36 W 581,48 $ 6-59 36 W 2,12~ . 700,46 S 9 3 20 W 2.376 753,52 S lO 7 48 W ~,399 822,36 $ 11 13 23 W 2,492 915,71 $ 12 26 19 W 2.656 1017.56 S 13 2~ 12 W 2,719 5.976 475,3{ 553,31 673,84 728,62 799,02 997,14 _ . RECORD OF SURVEY . · . AS, 'DRIFT VERTICAL SUB DRIFT .... TOTAL COORDINATES ......... C L"-O"'S'U R'E-$ ............ SEVERITY '" SECTION PTH ANGLE DEPTH SEA DIRE¢ .......................................... DISTANCE ANGLE ............. 'DEG/IOOF? "DISTANCE .................. D M ..................................... DEGe M 325 42 30 '30~8,30 2043,30 $ 23 W 1028,40 S --252,24 W 1058,88 5 13 46 52 W ............. 3;Olg ...... 1039~01 52~ ~5 0 3202~52 ~087,52 $ 22 ~ ~51 ~5 15 ~259~1! 3t7~,~! S 22 ~ 777 46 0 ~376~6~ ~261~b~ $ 22 ~ ~70 45 ~5 3~41~53 3326,53 $ 22 W 979 45 0 3518,61 3~03.61 S 24 w 100 44 15 3605.28 3490e28 $ 22 W 1160,)5 $ 306~99 W 1200~28 S 14 ~9 8 W 0~919 1181,75 _ . 1'387~15'S -·398,62 W 14~3.2~ $ 16 I 58 W 0~269 1426,0a ...... -.. _ .. _ ..... 1535,84 S 461,60 W i603,71 S 16 43 41 W 1,316 '1587,~3 257 43 15 3719,63 3604,63 $ 23 W -'1634,86 S ...... 540 ~1 45 3928~92 3a13,92 S 23 W $53~41 0 4014,21 3899,21 $ 24 W 77g 41 30 4108,58 3993,58 $ 24 ~ ~36'42 0 ~225,25 4110,25 S 25 N Og3 41 30 4342,83 4227,83 $ 22 W 250 41 15 4460,87 4345,87 S 23 W 409 41 30 457~,~6 4464,96 $ 23 ~ 567 43 0 45~5,5~ 45'80~5! $ 23 ~ 722 43 30 4807,g4 4692.94 $ 27 W 778 43 15 -4848,73 4733,73 E 26 N 941 43 30 4~66,g7 4851,g? S 25 W 130 44 0 5102,92 4~8~,~2 ~ 25 W 2~5 43 30 5222,61 5107,61 S 25 N 475 43 15 5353,72 523~,72 $ 26 W ~64 43 30 54~0,81 5375,81 $ 29 W ~87 43 30 5724,20 5609,20 $ 27 ~ 302 41 45"5957,02 5842,02 S 29 W 503.63 W ..... i7i0e68-S 17 7 18 W ..... 0,774 ............... 1732,22 $ 546,98 W 1816,53 $ '17 31 27 W ....... 0,539 ...........1801,50 1809,45 $ -579.76 W 190OEO? S 17 45 57 W 0,956 1885o~6 1877,18 $ 609,91W ' 1973.78 S i7 59 58 W 0,885 195~,45 $ .... 643;87 W '2056,83 S 18 14 33 W 0,397 2042,96 . ...... 2048~66 S 688,27 W 2161e19 $ 18 ~4 13 ~ 0-530 2148,01 2145,12 S "727,24 W 2265,04 $ 18 ~3 40 W 1.312 2240,4i $ 767,69 W 2368,28 S 18 54 51W ' '0,450 2337,39 $ 808,85 W" 2473,38 S 19 5 17 W 0,157 2436,58 $ 850,96 ~ 2580,90 S 19 15 5 W 0,949 2531,64 S ' 899,39 ~ 2686~66 $ 19 33 29 W 1,797 .... 2566,13 $ 916~22 W 2724,79 S 19 38 55 W 1,305 2667,82 '$ 963,63 ~'" 2826.52 $ 19 5~ 36 W ....... 0,~8 2786,81S 'I019.12 W 2967,3! S 20 5 14 W 0.265 2888,89'5 -1068,91 W - 3080,30 S 20 18 17 W 0,517 2999,7~ S- 1122,97 3113,53 S I186.05 ~204.67 S 1236,56 ~310.77 S 1290,6~ 3401,31S 1336,76 3497.99 S 1~g0.35 3203,05 S 20 31 25 W 333i,79 S 20 51 12 W 3553,~4 5 21 17 50 ~ 3654,57 5 21 27 19 W 376~18 $ 2~ ~0 35 2251,91 23~5,37 2460.67 2568,37 271Do~ 2825.56 2~56~85 3070,40 0.139 ..........3193,71 1.0~8 3323,48 0,333 3427,~ 0.850 35~6,~2 0,336 3647,97 ~o~07 3758o22 SUrVeY ALL CALCULATtONS PERFORMED BY. I ...................................... TRuE DOG LEG [As'-'DRIFT VERTICAL SUB DRIFT ........ TOTAL-COORDINATES ................. C L' O--5'-U R"E"-S .......... SEVERITY ...... SECTION !~T~J_ANGLE DEPTH .... SEA ........ DIREC "ii.,i~i'iii'~.ii]"~-~ii~'"~ii'~iii..~__i ..... ._'~i'_i__~'J~iL~i,'~i~ii~-ff~ii~DISTANCE_'.. ..... "ANGLE './"~'~.DE6!.JOOFTi'_~'..ii .... DISTANC~ P~59 ~9 15 6078e60 5963,60 $ 30 W ~?~2 36 0 6~01~06 6186e06. S ~5 W FSX5 37 0 6~9~36 6~4~e~6 $ 22 W ~067 ~9 0 65~0~75 6~25~75 $ 21 ~ J~36 38 ~5 6688,15 6573~15 $ 28 W 3677e95 S 1~98,71'~ ..... 3971~58 $ ~ 10 I~ ~ 3910e~2 ~ 1597~02 ~ ~223.~6 S 22 12 54 ~ ~014,$7'$ '1652~56 W 4341,67-S 22 22'21--W ........... 2.32? 0~731 5o5~7 2.802 0,~90 0,899 i392 37 30 68t'1.92 6696.92 $ 29 ~ '-4097,93 S -1698e60"N ......... ~436e02 $ 22 30"50'N .... 0.894 )554 38 45 6938,26 6823,26 $ 31 W 418~85 S 1750,82 W 4536,~3 $ 2~ ~2 Il I~ 1,085 3857,16 3967,0v t03l.lO ~074,9'7 4137,07 4219,32 4~37,~5 ~32,17 ~533~00 )736 40 30 7076,65 696i,65 $ 31N ~893 43 0 7191.47 7076.47 $ 34 ~ )975 43 30 7251~1~ 7136,16 $ ~0 W )029 45 0 7289,32 7174.32 $ 27 ~ )0~ 45 0 7299.93 7184,93 S 26 W )101 ~5 0 7340.24 7225,2~ $ 22 W 6286e16 $ 1811.70 W 4653~33 ~ 22 54 67 W 0,962 4650.5~ 4422,86 ~ 1900~95 W 4814e08 $ 23 15'29 W 5,462 .... 4~12,10 4456.88 $ "-1918e29 ~ 4852.18 S 23 17 15 ~ 4*769 -" 4850.26 4466,42 $ -1922,94 W '4862,77 $ 23 17 36 W .... 4,71~ 4860,86 4503,79 $ 193ge03 W 4903,07 $ 23 16 58 W -" ~o962 -- 4901,12 )250 44 30 7446~5! 73'31,51 S 21W '~601,29'S- 1975.~6 W )376 43 30 7537,9~ 7422,91 S 23 W )469 43 30 7605.37 7~90,37 S 24 W )599 43 0 7700~44 7585,~4 S 25 W J758 4J 15 78~9,98 770~,98 $ 26 ~ JgX~ 41 - 0 7957.7~ 7822.72 S 27 W )0~7 39 0 80~X.08 7926~08 S 2~ H )236 38 0 8190,01 8075.01 $ 27 W )38~ 40 0 8306.45 8191.45 S 29 W )484 40 15 8379,72 8264,72 $ 27 W )SaO 39 0 8656°39 ~541.39 $ 29 W [170 ~2 0 890~.62 8786.62 S 30 W 4681,12 S 2009°35 4739~61 S 2035,39 4819.96 S 2072,86 4914,18 $ 2118,81 5005,37 S 2165,28 5081,84 S 2199~32 5185.52 $ 2252.15 5270~7 $ 2299e51 5325.2~ 5 2327.68 5522.18 S 243~°29 5007,~2 $ 23 l~ 6 W- 5094.15 $ 23 13 52 W 5158.17 S 23 1~ 26 W 5246.78 S 23 16 13 W 5351.50 S 23 19 26 W 5453,6~ $ 23 23 3~ W 5537.34 S 23 2~ 7 W 5750.7~ $ 2~ ~ 11W 5812.65 $ 23 F6 22 W 60~5.73 S 23 48 22 W 6255.~0 $ 2~ 1 28 W 0,580 1,358' 0.740 0,652 1,179 0,~51 2,089 1,121 1.555 1,368 0.502 0.930 5005,31 ~091,9' 5156,00 5244.66 53~9,~8 5~51,76 55~5,~5 5651.7~ 57~9 ~ 1 ~ 5811~17 603~.63 625~.57 .............. RECORD OF SURVEY .ALL CALCULATIONS PERFORHED gY ! B N ELECTRONi. C CONPUT/R TRUE ............... ~AS' DRIFT VERTICAL SUB DRIFT ~PTH ANGLE DEPTH SEA DIREC L270 ~9 15 8978,06 886~06 S 31 L40B 37 0 9088~28 8973~8 $ ~! L573 ~9 0 9~16.50 9~0~50 S ~1 ~077 ~ 0 9575~7~ 9~60,7~ $ ~5 ~7~7 ~0 15 10066,2~ 9951,22 $.3~ W · DOG LEG · TOTAL COORD!_NATE$ ,, C L 0 $ U R E-B ...... SEVERITY SECTION - · DISTANCE ....... ANGLE DEG/~OOFT D~STANC~. $'?~,2e~2 S 2556,?5 58~0~ 5 2621~58 5929~9 ~ 2675,i6 60~30 S 2728,11 627~,.66 $ 2h 2 16 W 6~9=37 S 24 5.. 7 W - 4~960 6~0Io83 $ 2~ 10 29 W ~,630 6504-.9~ S 2~ 17 0 W 62~7,05 S 2829,35 ~ -6857,91'$ 2~ 21 58 W 6~59e79 $- 2898,66 W ' 698~e'77 $ 2~ ~ 22 W 6~20,49 'S 29~8.9~ W 7065e33 S 24 40 9 W 6588,48'S 30~8,02 W 7263~58 $ 24 5~ 5~ W O~OOO 627D~95 650~,56 6857,6t 698~.6! 7065~28 7227~I '726~e58 )TTOM HOLE CLOSURE 726~58 FEET AT S .. __ .... . 715 ............... 815 915 1016 !.~EASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF-SUB"SEA DEPTH, ............................................................ i ............ ~' ..... ' .... ~-'~ ............................................... TRUE ....... ~E~SURED ' VERTICAL SUB ~D-TVO ..... VERT ICA~ .......................... ' ........ DEPTH ........... DEPTH S~A DIFFERENCE' - CORRECTION .... TOTA~ COORDINATES 515. 400, 0 .............................. 0 ................................. 38,71' ~ .... 7~.14 615. 500, 0 .................................. 0 ............................. 39,54 S ....... 74,86-- ~ ...................................................... : ...... 715, 600, 0 ................................... 0 .............................. 40,36 S 74,57 815. 700. ........ 0 ........................... 0 ....................... 41.19 S" 74.29 W 915, 800, 0 ................................. 0 ............................ 45,08 $ .... 72,17 'W .......................................... ~ ............ ~-- 1015. 900, '1-= ................................. 1 ................ ~ ................... 56.53 S ............. 70*67 W .......... 111~ ........ lil~ 1000, "' 2 ........................... 1 ................................... 73.7S' 5 ........... 66.97"~ .......................... ~ ........................................ ;-- 1220' 121~. 1100. ....... 5--: .......................... S ................................. 94.60 S ...........62.91'-'~ ~- 1~22 1'31~. 1200, 7 .......... 2 .................... !17,11 S' - 58.90 '~- ......1426 ..... 1415, 1300, 11 ...................... .4 .................. 142,84 $ 55,41 ....... 1530 1515, 1400~ 1~ .............................. 4 ......................... 173,30 S ..-.~52,75 .W .............................. : ..................... 1636 1615, 1500~ 21 ......................... 6 ......................... 208,65 S 49,65 W ....... 174~' 1715. 1600~ 29 ........................... 8 ........................... 248.03 $ -'' 46.21 W .... 1854 m 1815, 1700, ' 39 ................ 10 ................. 292,91'S -- '42,28 ........... 1966 ..... 1915. 1800, 51 .............. 12 ............................. 34S.4~ S-' 37,86 ............ 2079 .... 2015. 1900, 64 .............. - ..... 13 ..................... 396.83 ~ 34,36 W ................................................. .......... 219& ........... 211~. 2000, 79 ................... 15 ............................... 452.3~ '-S ...... 36,24 W ...................................... ......... 2305 '" ~215. 2100,. 90 ......... 11 ........................ 500.03 S ~4.,52 W 2418 .... 2315, 2200. lOS ................13- 550.01 S 61,~5 W . .......... 2534 ' 2415. 2300, 119 ................... 16 ........................ 605,67 S 80,61 W ....... 265~" 2515.' 2~00, 1~9 ......... 20 ........................ 667,66 S 101,96 W ..... 2770 - 2615. 2500, 155 ........ 16 ........................ 722,71 S 124.04-'~ ................... ............ 2887 ...... 271~. 2600.- ' 172 .................. 17 ...................... 777,98'-S 147.90 "W 3008 2815, 2700, 193 21 ....... :' ................... 8ql,l~ S 174,71 W ........ 3134 ........ 2g15, 2800s ' 219 .................26 ................... 911.87 S...... 204,37 W ........ _ ........... 3266 ..... 3015. 2900, 251 .................... S2 .................991.B7 S 236,73-W ............ 3404 ...... 3115, 3000m 289 .......................... S8 .................... 1079.68 S 274,01-W-: .................. - ........ 3546 .... 3215,- 3100, 331 ........... ~2 .................... 1172.02 $ '311.70 W ............................ 3688 .......... 3315, ....3200~ ''-STS .......................... 4~ ...................... 126~20 S 349,75 ......... 3832 SqlS, 3SO0, .... 417 ........................ 4~ ............................ 1361,89 S'" 388,41 W ........ 411S ...... 3615. 3~00, 498 39 154q.26 S 465,17 W ........ 6251 .... 3715. 3600~ 536 ................... 38 .............. 16S0.85 S 501,9~ ....... 4387 ...... 3815. 3700, 572 ..... 36 ............ 1715.40 S' -539.48 W .... ._ ........................................................ . .......................................... . . ~UDED DEPTH.AND OTHER DATA FOR EVERY EVEN 100 FEET 'OF SUB .SEA DEPTH, ........ TRUE - ' ........................... HEASUREO __ VERTICAL. ,SUB lUtD-,rvD. ..... VERTICAL _'i".i.' ........ ~' ~'.J'" _ ........ DEPTH ................... DEPTH. _SEA DIFFERENCE_~'..'..;_CORRECT.ION ..... TOTAL . COORDINATES ~788 ........ 4115e 4000, 67~ ........................... ~4 .................... 1958~69 ~ ~.922- 4215, ~100~ ?07 ~ 20~0,29.S' 5056 ~15. ~20'0, 7~1 ~ 2122,28 $ 718~01 5322 4515, 4400, 807 ~3 228~,48 S 786~40 ......... 5~57 ........... 4.615, ~500, 812 ..................... 35 ........................... 2367e~6 $ ........ 559~ ..... 6715~ ~600~ 879 ............... 37 .............. ~5~,OD $ '"~7'~2 ~815, ~700, 917 ......... ~8 .................... 25~7,80 S 5869 ~91~. 4800. 954 ~.7 2623.12 S 9~2,79 -6008 ' ' 5015. 4900~ 993 ............ S9 ............. 2709,85 S 6t~? 5115. ~000, 1032 S9 2797.10 S 102~.1~ 6285 5215. 5100, 1070 S8 .... 2882.t0 S 1065.?~ 6~22 5315. 5200. 1107 37 ........ 2967,00 S 1107.01 6559 '- 5~15. 5~00. 11~ .............. ~7 ...... ~050.60 S 6698 5515, 5~00. 118~ ~9 .......... DIDD,g5 S- 1197,~7 ...... 68~6 5615, 5500~ 1221 ....... ~8 ...... ~218.~ $ ..... 6976 5715e 5600, 1259 ....... ~8 ....... ~302.98 S 1286.66 7111 5815. 5700. 1296 .... 37 ................ 3~86.21 S ..... 7266 '~ 5915. 5800. 1331 ~5 ........ 3~65.18 S 1372.17 ....... 7~77 6015, 5900. 1~62 " ' ~1 ................... ~539.01 S 1~1~.03 ...... ?506 ..... 6115, 6000, 1391 ........... 29 ...................1609,01 $ 1~55,6~ .... ~635 -' 6215, 6100~ 1-~20 ............. 29 ................ ~677,6B $ - .... 7759 6315, 6200, 144~ .......... 2~ ...................... ~7~6.80 $ 1531,66 7886 6415. 6300. 1471 27 3816.10 S 1560.~6 -8011 6515. 6~00. 1699 ........... 28 - ~890.9~ S 1589.5~ ....... 8162 6615. 6500, 1527 ......... 28 ............... ~96~.0~ S 1626.99 ..... 8270 6715, 6600. 1555 ...... 28 ......... ~032.88 $ 1662.5~ .... 8~96 -' 6815. 6700e 1581 26 -' 4100,05 S '-'1699,87 852~ 6915, 6800, 1609 ~8 .............. ~168,8a S '8655 ~015, 6900, 16a0 .... ~I ......... ~2~1,02 S 1TSa,58 8788 7115. 7000, 1673 33 -' ~315.81 S 18~1.69 8925 7215. 7100. 1710 97 4593.16 S 1883.80 ' "9065 7315. 7200. X750 %0 ..... %~80.38 5 X928.58 9206 7~15~ 7300, 1791 %1 %572~37 5 X96~,36 :EASURED DEPTH AND OTHER DATA FOR EVERY EVEN ]100 FEET OF' SUB SEA DEPTH, .............. .................................. TRUE - HEASUEED - VERTICAL SUO HD-TVD- VERT ] CAL DEPTH - DEPTH SEA DIFFERENCE ~ CORRECTION- TOTAL. COORDINATES 9~6~ ...... 7515. 7~00, 1829 .................. ~8 ................. : ......... ~661'.11 9682 ..... 7615. 7500, [867 .................. 38 ....................... ~7~7.7~ ~ ' 9618 .............7715. 7600, 1903 ............ 36 ......................... ~831,43 S 97~1 .......... 78~5~ 7700~ ~936' - ................. ~3 ........................ ~9~0,2~ S ~88~ ........... 79~ ~800* ~969 ............................... 33 ........................ ~987~77 S- 10013 ...... 8015. 7900. 1998 .................... 29 .............................. 5062~54 $ 101¢1 ..............~115. 8000, 2026 .................... 28 ......................... 5133.29 S 10269 ............ 8215. ~100, 2054 28 ........................ 5203,85 S 10399 ..... 8315. ~200, 20~6 ...................... ~0 ..................... 5277.41 S 10529 ..............8415, 8300. 211~ 30 ........................ 5351.22 S 1055~ .......... 8515. 8~00. 21~3 ................... 2g ................5422.0¢ S 10787 ...... ~615. 8500. 2172 ..... 29 ...................... 5~92.87 S 10919 .......... ~715, 8600. 220~ ............. 32 .............. 5567.89 S" 11053 ...... ~15. 8700. 22~8 ......... 3~ ............... 56~5.86 S 11185 ................ 8915. ~800. 2273 ................... 35 ..................... 5724, O4 S 11316 ..... 9015. 8900. 2~01 .... 28 ............... 5793,05 $ 11~2 .... ¢~15. 9000. 2~27 ............. 26 .................... 5858.93 S 11571 9215, 9100, 2356 ........... 29 ...................... 5928,35 S 11708 9315. 9200, 2~93 ............ 37 ......................... 6011,23 S 1~52 ........ ~415. 9300. 26~7 ............ ~ .................... 610~.67 S 1299~ ...... 9515. 9400. 2~80 ............... ~3 ............... ~' 6196.66 1212~'-' .......... 9615. 9500, 2~13 ................. 33 ................... 627¢.70 S-- 28¢7;D0 ~-- ~22~9 ................... 9715, ......9600~.'-'25~ ........................ 31 .... 6~5.07 $ .... 2893.00 12389 ............... 9815, 9700, 2573 ............... 29 ................... 6610.95 S 2941.7¢ 12519 .............. 9915. 9800.--260¢ ................ ~i .......................... 6~8i-.11-S "-298~.29 126~0 ....... 10015.-'- 9900.-263~ ................. : ....... 31 ................6552.il S" 303¢.~0 · . . . . . :~ - . .................................................................................................... -. ............. :~' ..~._ - .~. '~_~ · . 2000'85-'W 2039.18 W 2078,~5 W 2116.90 W 2190,7~"W '2225"5~ 2)02.80 W 2380.78 W 2~20.04 W .... -- .._ 2462,68 W 2507,70 W ............................................................... 2552.~5 ......................................................... 2593.2~"W 267~.53 2716.86 .............................. 2761,39 2805,65 W .t,NTERPOLATED VALU£$ FOR EVEN .1000 F£ET OF ~-iEASURED DEPTH, DEPTH ,,., [ 000 2000 ~000 ~000 5000 6 000 7000 8 9000 100OO Ilooo I~000 DEPTH 980,95 W 8775, 86.60, 5614,90 5 2489,82 W 9~18, 9~03, __ 6200.10 $~ 2807~33 W ~ :- ........................ . _ .....~ _ . _- . . ..... ......... .-' . .-._' . - J ..... :- .............. ~ ........ , .... . ...... - ....:'.._:' . ................... ~.' -'_ ................' -:-- ' J VERTICAL SECTION' SCALE I" -I000' ATLANTIC RICHFIELD COMPANY NTB WELL S-9 71'ANGENT'IAL'"METHOD ...... , ...................... ~ ', ' ', ......... ~ ~. ; i " ' ~ .- . ' ''~' ~i . . . ,' .... ~ -. ~ , .. ~ .... · ...... .~ . . ' ........ -" i ' · ..' '. ;~ ' '~" -i '' : ' . · ' : ' ...... . , , .. ...... . , ~ , · . . ~ . ~ , . , ~ , . ~ ; ' ~ · TVD =____10,059' · ' :" : : ' ' SCALE ~'"=~v,u='"'"" ; ' :i''-,, '"' ' ' ATLANTIC RICHFIELD COMPANY : .... ! ..... ~ NTB WELL S-9 : . . TANGENTI AL"i METHOD ,~ ,'.~- .:-, . ~ ..... ;. , , - ~ !, ' :.;.,; { '::. · : ,;~ ! ...... , . · ~;. ' i . ,:.' .... ; - - : "-" , ~ .... : .... :..,~ ,_ ~ ' : ~ ; · ,, :., : ~. : ...~ , . .-. ,-, .. -. ., ~ . :.. · ..;- . ; .' j ,~'' ; .: .... ~ .~' - ; , ~ ................... ~ ; ......... ¢.. . . ~, .' .., ; ~ . . - :-.. ..~, ~ ·, .. . .;~ .................... ~.:4.,.,:.~ ............. ~ - ~ ............................. ~ ..... ; ..... 60~ . ~ : ~ '~ ............... ' ' ' ............ ' ............... ~ ' . ~, .. . ,- ........... _._ :... . . -, ~ . ........ ; ..... , : .... i , .............. . ............ . .............. . 7600 ..:;-~. , '~ . . .... ~ . · . . ................ -, . ' ' HORIZONTAL VIEW ....................... 440O 1600 EO00 2400 2800 4000 ( .... 1 ·: ........................... · , , 5600 ' " } .. ' J 8400 ' .. : · e~oq } .... . = . . . . TVD = 10,059' TMD = 12~71 7' , COHPLETION REPORT' NOVEMBER 8, 1974 ATLANTIC RICHFIELD CO. NORTH TRADING BAY WELL S"9 KELLY BUSHING ELEV. 115 FT. DECLINATION 24 DEGREES EAST RADIUS OF CURVATURE HETHOD OF COMPUTATION PREPARED FOR ADDCO BY F. H. LINDSEY $ ASSOC. .............. ~ ......................................................................................... ................................... .................... RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER ........... TRUE f,'EA$. D~IFT VERTICAL DEPTH ANGLE DEPTH D M DOG'LE~ SUB DRIFT TOTAL COORDINATES ............. C L 0 S U'-R-E S ...... SEVERITY ........ SEC'YIOi SEA DIREC ................. DISTANCE " ANGLE DEG/IOOFT ........ DISTAN~ DEG, .......... D M $ 432 0 0 432.00 317,00 S O.OOE 826 0 30 B25.99 710.99 S19,00£ 887 2 30 886,97 :-771,97 S35,00E 917 3 30 916.92 801.92 S19.00E 977 5 45 976.73 861.73 516.00E 10~0 8 15 1039.25 924.25 1101 10 15 I099.~5 98~.~5 $17,00E 1232 12 0 1227,99 1112,99 Sll,00E 1385 13 0 1377.36 1262,36 1569 17 0 1555.05 1440,05 $ 5,OOE 1725 21 0 1702.52 1587,52 5 5.OOE aa1 2~ 15 1846.50 1731.50 S D.OoE 2052 27 45 ~000,17 1~85,17 S 5,00E 39.71 $ 75,09 W 84.95 S 62 7 34 ~ .... 0.i52 ............ 67,4' ~1.13 $ ..... 74.37-W-.' ' .8~.99 S 61 ~ t2 ~--- ~.793 ~2.53 $ .... 7~.66 ~ 85.06 S 59 59 59 ~ ...... 5,06~ ............ 69.4, ~7.14 S 72.20 ~ 86,23 S 56 51 38 ~ 3.801 5~,73 S 7leE7 ~ 89e86 S 52 28 ~9 ~ 6.2~9 79,5 64.~0 5 ........ ?0,00 ~ ...... 95,12 $ ~7 23 1 ~ 6.957 87e7 88.92 $ ..... 63,89 W - 109,~9 $ 35 ~I 52 W 1,685 121,48 5 ..... 57,85 W ..... 13~.,55 $ 25 28 0 W .......... 0.671 ........... 168,67 ~ ........ 51.64 W 176.40-S 17 I 25 W -2.352 219.25 $ ......... 47.21W ' 224.28 S 12 '9'-12 279.03 S ......... 4.1,98 ~ ..... 28~e17 $ 8-~3 27 ~ 2.083 ............... 353,69 S ...........S5.45-~ 355.47 107.~ 13~,5 17~.8 218.9 271.0 336.0 2125 29 ~0 2064.2~ 1949,2~+ S O.OOE ' 388.62 $ ....... 33,95 W- 390.10 S 4 59 .2~'W ....... 4o215 .................. ~67.1 2187 29 0 2118.3~ 2003,~ S ~,OOW ~18.90 $ :'- 3~,72' W .... ~20.3~ S'-'~ ~ 19 W ............... 2',46~ .................... 395,0 2250 26 30 21T4.09 2059.09 S 6,00W 448.14 S ........ 37e02 W' 449,67 $ ~ 43 23 W .... 4,460 ............. 422.5 2312 25 15 2229.87 2114.87 $14,00W 474,76' S ~' ,41.72 W ............ 476.59 5 ~ 1' 19 W ......... 5,74~ ..................... 448.6 2479 28 0 2379.15 2264,15 $19..00W 546.49-'$ ........... 62'96'W ...... 550,1.1 $ 6'34 21W 2700 33 15 2569.26 2~54'.26 SX9.OOW 652.90 $ ............... ~9',"60 '~ ....' 660.'46 5- 8 4'0' 27 W 2813 29 0 2665,97 2550,97 S21,OOW 707,22 2945 32 15 2779,54 2664,56 $23,00W 768,88 3105 36 30 2911.57 2796.57 $23.00W 852,01 3263 40 45 303~o98 2919.98 S22.00W 9~3.11 3325 42 30 3081.32 2966.32 523.00W 981.16 ' 343~ 44 30 3160.38 30~5.'38 S23.00W 1050,22 ........... 121,00 147.81 183.10 220.83 236.69 ...... 2,209 ...... .522 2.376 .... 634*6 4.266 692.9 ..... ~,498 .......... 760.2 .... 2.656 850.~ .... 1065.1 265,91 717.50 $ 9 %2 32 W 782,96 $ 10 52 55 W 871,47 5 12 7 ~3 W 968.62 $ 13 lO 43 W 1009.28 $ 13 33-26 W .... _ 1083,36 $ 1~ 12 30 W 1.835 . [co o o¢ su vE - . ....ALL..¢ALCULATIONS. PERFORMED.BY I B M ELECTRONIC COMPUTER - .. , ..... TRUE <~A$. DRIFT. VERTICAL SUB DRIFT .:~EPTH ANGLE DEPTH SEA DIREC D H DEG, ~528 45 0 3227.14 -311.2,14 $22,00W 1111,36 3651 45 15 3313,92 3198.92 S22.00W 1192.17 3777 46 0 3402.04 3287.0~ $22,00W 1275.68 3870 45 45 3466.79 3351.79 S22.00W 1337,57 TOTAL (:0ORDINATES 291,23 323,88' 357,62'W 382.63 3979 45 0 3543.36 3q28.36 S24.00W 1408,98 S 412,94 4100 44 15 3629.48 3514,48 $22.00W 1487.22 S ~6.15 ~257 63 15 3742.89 3627.89 $23.00W 1587.52 $ 487.69 ~414 42 ~5 3857.71 3742,71. $24.00W 1685.7i S 530.39 45~0 41 45 3950°97 3835.97 $23.00~ 1763.~0 S *'564.17 4653 ~1 0 ~035.77 3920.77 $24.00W 1831.89 S 593.95 4779 ~1 30 ~130.50 4015.50 S2~oOOW 1907.79 $ 627.7~ 4936 42 0 ~247.63 ~132.63 $25.00W 2002.92 $ 671.09 DOGLEG ¢ L 0 $ U R E $ SEVERITY DISTANCE ANGLE DEG/XOOFT DISTAN( . _ . O M $' 1148.88 ].235.39 $ 15 11 56 W 1324°86 1391,23 S 15 57 50 W 1~68,25 1552.70 S 16 ~1 55 W 1660e7~ 1767,18 S 17 27 56 W.. 0,535 1925,78 S 17 57 51 W 0.879 2008,41 S 18 12 48 t~ 0.397 2112,36 S 18 31 26 W- 0,53~ 0'924 ..... I131,21 0.203 0.595 0°269 1.461 1.303 0.770 1218.3~ 1308,2~ 1452°5] 1537,4; 16~5,9~ 1753.0( 1837.6~ 1912.3; 1995.~ 2099e9~ 5093 41 30 4364.76 ~249°76 $22,00W 2098.78 S 712.78 W 2216,51S 18 45 29 W '" 1,300 -- 220~.'~ 5250 41 15 4~82.57 ~367.57 523.00W 2194.65 S 752.49 W-'~ 2320.08 5 18 55 32 W 0.448 2308.1( 5409 ~l 30 4601.89 4~86.89 S23.00W 2291.40 S 793.55 W" 242~.92 S 19 6 7 W 0.157 ......... 2¢13.2~ 5567 ~3 0 4718°84 6603,8~ S23,00W 2389.18 S 835.06 W 2530.91S 19 15 55 W 0.9~9 ...... 2519.4] 722 5778 ~3 15 ~872.4~ 4757.44 S26,00W 2519,83 S -897,i0-W 2674,76 S 1.9 35-47 W ........ X,300 '-' 2664,0~ 59~! ~3 30 4990,92 ~875o92 $25~00~ 2620.87 $ .... 9~5.29 N -2786.13 S 19 ~9 59 w -- ...... 0°450 .......... 2775.9~ 6~30 44 0 5127.4~ 5012,65' $25.00W 2739'32 $ "XO00,52'W ........ 2916.32-$'20 .... 3'-52'W ...... 0~265 ............ 2906.6~ 6295 ~3 30 5246o6~ 5131.64 $26.00W 28~2,30 S X0~9,64 W 3029e93"'~ 20 X& 7 W 0,51~ ......... 3020.7! 6~75 43 15 5377.47 5262e47 $26,00W 2953~1 ~ IX03~83 w 3152.95-$ 20 29 35 W ..... 0°~39 666~ 681~ 69~7 43 30 5748.18 5633.18 7136 43 0 5856,70 5741.70 527.00~ 7302 ~X 45 5979.33 5864.33 $29,00~ 345~.62 S 1369.08-W 7459 39 15 6098.71 5983.71 S30,O0~ 3543.35 S 1419,28 7635 39-'0 6235.2~'-6120,24" S32.00W" 3638.55 $'1476,48 360~,86 S 21 2.5 1.5 W 3716,02 S 21 37 7 W 3817,03 S 21 49 42 W 3926,71 $ 22-'- 5 1'2' ~/ ........ 0,727 '-' 1.103 3273,9; 0,333 ............. 3377,~ 0.8~3 3496,8~ 0.336 3598.8~ 1.093 37~0.5~ 1.6~0 3812.~ 3922.5: ......................... RECORD OF SURVEY ..................._ ALL CALCULATIONS PERFORMED BY Z B M ELECTRONIC COMPUTER . · ................ TRUE .................................................................... DOG LEG ~AS. DRIFT VERTICAL SUB DRIFT TOTAL COORDINATES - ¢ L O $ U R E $ - SEVERITY SECTIO~ _}EPTH ANGLE DEPTH SEA DIREC ' " DISTANCE ANGLE DEG/10OFT DISTAN¢ .......... D M DEG. ......................................... D M S'- ~ [703 37 15 6288.73 617~.73' S28.00W 3676.89 S I497.47 W 9968.28 $ 22 10 i2 W '' ~,337 - ' 77~2 35 0 6320.0~ 6205.03 S25.00W ~g5.71 $ 1507.85 W ~991.~8 S 22 11 43 W ....... 5.488 ........ ~987.5' 7815 ~7 0 6378.71 6~63.7! S22.00W 3735,5~ S 1525.16 W ~03%.88 S 22 12 ~4 W 2.853 7916 3B 0 6658.84 63~84 S22.00w 3792,56 S 1568.[9 W 6096.37 S 22 12 22 W 0.990 ~092.4( 80~7 39' 0 6561.36 6646.36 521.00W 3868.41S 157B.08 W ~177.91S 22 11 33 W 0.905 ..... 4173.81 8236 33 ~5 6708.50 6593.50 S28.OOW 3976.28 $ 1627.24 W ~296..36 S 22 15 22 ~ -- 2.~16 8392 37 ~0 6831.22 6716.22 S2g. OOW ~060.92 S 167~.19 W ~392.11 $ 22 2~ a~ W 0.889 855~ 38 ~5 6958.66 68~3.66 $31.00~ 4147.53 S 172~.20 ~ ~491..26 S 22. 3'3 62 ~ i'-i .... 1.100 8736 ~0 30 7098.83 6983.83 $31.00~ ~247.02 S 1782.98 ~' 6606.10'5 22 46' 2~ ~ ........ 0.962 ............. 8893 43 0 7215.96' 7100~96 $3~.00~ 4335.17-S 1839.i4 ~ ~709.16 $ 22 59 18 ~ ..... 2~078 892~ ~ 0 7238.6~ 712~.$3 $3~.00~ ~352.70 S 1850.96 ~ ~729.91 $ 2~ 2 14 ~-' 0.000 ............ ~727.8! 8975'63-30-'7275.78 7160.78 S30.OOW ~382.33 S 1869.47-W ~76~.42 5 2~ 6 lO ~-' 5.512 ......... 4762.5( 9029 45 0 731~.~5 7199.65 S27.00W 6415.~ $ xea?. 5 W 4801.93 $ 2~ 8 ~2 W "~,854 90~h ~5 O- 73~5.06 7210.06 S26.00~ ~421.93 S 1892.18 W 4812.52 $ 2~ 9'~8 W" ~.714 ........ ~810.7t 9101--'15 0 7365.37 7250.37 $22.00w 4~61~7~ $ 1908.57 W a85ao82~s 2~ 9 34 W ..... ~.962 .... [- ~250 44 30 7471.X8 7356.18 S21.O0~ 4559.34 S 19~7.02 W 6957.67 $ 2~ 7 27 W 0.576 ~955.7; .376 63 30 7561.82 76~6.82 $23.00~ 46~0.~g S--1979.80 ~ 5065~17 $ ~3 6 17'~ .... 1.342 .......... 9~69-~3" 30 7629.28 751~,28 $26.00~ ~699°20 $ 2005.33 ~ ' 5109.19 $ 23 ....6 35 ~ ..... 0.740 .......... 5107.1! ~599 6~ O' 7723.97 ?608.97 S25.00~ 4780.25 $ 20~2.27 ~ 5198.23 $ 2~ 8 1 ~ ......... 0,$~9 ......... 5196°2; 9758 61 15 7841.89 '7?26.89 526.00~ 4876.50 S 2088..18;~ 5306.79-$"23 10 52 W ............ 1.174 ......... 5302°8! 991~ 41 0-' 7959.40 7a~..60 S27.00~ 6968.32 & 2133.96 ~ ' 5407.22 S 23 1~ 39'--~ ........... 0.649 ............ 100~7 39' O- 8061.28 7965°28 52~.00~ 50~5°47 S 21.70°76 ~ ..... 5~92.63 S 23 16 45"'~ .......... 2,0t8 ................ 5690.8' 10236 38 0 8209.19 8096.19 $27.00~ 5151.65 $ 2221.~0 W' 5610"19 $ 23 19 ~2--'~ ......... 1.102 ..........5608.5~ 103a8 ~0 ...... 0 - 8327,31 '8212~1- 529,00~ 5236.11-'$ 226~;"3I'""~ ...... 5705.52 S-23 2~ '1~-'~ .......... 1'57~ .......... : 5703.9' 10684'i0 15 8600.72 8285.72 S27.00~ 5290,73 S 2295.35 ~ '~'5767°19 S 23 27 12 ~ ..... 1.37~ ............... 5765°7~ ... 10860'39 0 8676.91 8559.91 $29.00~ 5691.18 S -2~01.93 ~- 5993.53 S 23 37 31 ~ ......... 0.695 ................ 11170 42 0 8925.82 8810.82 S30.00~ 5677.69 S 2507.~6 ~ 6206.73 $ 23 ~9 ~0 ~ ...... 0.933 .... 6205.9~ 11202 42 0--8949,60 8834,60 S28,00W 5696,42 S -2.517,84 W 6228,06 S 23 50 46 W '4,182 ...... 6227,3 I1270'-39 15' 9001,21 8886,21 S~I,O0~ 5734,94 $'-2539,6~ ~ .... 6272,11 $ 2~ 5~ ..... 7-~ ............. ~'870 ............. 6271,4 . . . RECORD OF SURVEY ' ALL CALCULATIONS PERFORI'.IED BY ! 13 M ELECTRONIC COMPUTER TRUE DOG LEG ' 'EAS. DRIFT VERTICAL SUB ORIFT TOTAL COORDINATES ..... C L O S U R E S SEVERITY '- SECTI0~ '~EPTH ANGLE DEPTH SEA DIREC ...... DISTANCE ANGLE- DEG/IOOFT *' DISTAN( D .M - DEG, ................................... O N 5 ~t408 37 0 9109,76 8994.76 S31,OOW 5807.97 $ 2583.51W 6~6.65 $ 23 58 50 W 1.630 6~6.11 i~1573 39 0 9239,77 9124.77 S31.00~ 5895.04 S. 2635.83 W 6457,48 S 11744 43 0 9368.80 925~.80 S27.00~ 5993.12 S 2690.19 W 6569.22 5 11894 ~7 0 9~74.85 9359,85 S25.00~ 6088~3 S 2736.68 ~ 6675.21 S 2~ 12 IZ W ...... 2.851 12009 ~5 0 9554e73 9439.73 526,00~ 6163.09 S 2772,29 ~ 6757,90 $ 24 13 9 W 1,841 L2077 42 0 ~604,05 9489',05 $25,00~ 6205,33 $ 2792,44 W '6804.69 $ 24 13 12275 40 0 9753.47 9638,47 $33,oo~ 6.318,84 S 285~'36 ~ 6934,04 S 12407 39 15' 9855.14 9740,14 $37,00~ 6387,79 S 2903,64'w. 70.16.77 .S 12660 40 i5 10049.6& 9934,66 S33.00~ 6520,28-S 2996.41W 7175.83 12717 ~0 15 10093,16 9978.16 S33,00~ 6551,17 S 3016,67 ~ 7212,28 S 6~57,0~ 6568*9] 6674,9~ 6757,6~ 6933,8~ 7016.6~ . . 7175.8~ 7212,2~ ~OTTOM HOLE CLOSURE 7212.28 FEET"AT S 2~ 43 24, t~ ~ :.E SURED DEPTH AND OTHER DATA FOR EVERY EVEN 1OO FEET OF SUB SEA DEPTH. TRUE ...... t~,EASURED VERTICAL SUB HD-TVD VERT j CAL ........ - '~ ' .......... 'DEPTH .......... DEPTH SEA DIF_FERENCE -'.~ CORRECTJON~.__~-_-/-.' TOTAL cOORDINATES .................... ......... 515 ..... 515~ ....... 715 815 815, ( ......... 915 .... 915. 1016' - 1015, ....... 111'/ ..... 1115, .... I219 '-- 1215, - ' 13~-1 " 1315, ' ' 1424 ....... 1415° ............ 1527 ................. '1515, ..... 1632 "'- 400 ........0 .................... 0 ...... 38,10 S 500 ....... 0 ....................... 0 ............... - .... : 38.39 S 600 O .................0 ................. 38,90 $ 700 0 0 39.62 $ 800 0 0 42.41S 900 0'" .................... 0 ............... 51,43 S 1000 ........i .......................... ~ ......... ' ............ 67,12 $ 1100 -" 3 ....... 2 ...................86,23 1300 ...... 8 2 130.34 1400 ..... 12 ................................... 4 ...................... 156,79 1500 -' 16 .................... ~ ..................... 187.87 75'37 75.35 75.27 75,12 73 · 70 71,41 ...... 69,19 64,43 60.37 _ 56'. 37 52.85 49,96 .........1738 ......... :1715, ........ 1847 ............ 1815' .......... 1957 ...... 1915, ~069 ...... 2015, .............. 2183 ...... 2115, ....... 2295 .... 2215. .......... 2~07 ......... 2315 ............ 2520 ........ 2~5 ........... 2636-' 2515 ............ 2751 ................... 2615 ............ ~869 .................... 2715 .......... 2987 ................... 2815 .............. 3109 ........... 291'5 ............ 3237 .................... 3015 .-1600 ;-k.'i:23--- ..... 7- - ..... 223. '- 1700 .... :31': ............................... 8 .................................. 265, 1~00 ............ 41 ......................... i0 ................................... 311, 1900 53 12 361, 2000 68 15 ................................. 416, 2100 80 ......... 12 467. 2200 ' ' 91. ................ II ....................... :' 5'i~, 2300 104 ................. 13 ...................................... 564, 2400 120 ........................ 16 ........................ ~ ..... 620, 250'0 ...... 139 ........................... 1'9 .......................... 679, 2600- 15~ ............................. I5 ..................... 732. 2700", i72 ............................ 18 .................................... 789. · '2800 19~ 22 854, ' ..... 2900 221 ...................... ' ........... 27 ................................... 927, 06-'S .... 39,18-~ 54 S 34,85 96 $ ........34,62 W ....................................................... 65 S .... 40,09__.W ............................ : ............................ ~ ........... 95 S 52'80 w 99 S 69,33"-~ ........................ ' .................................... -;-- 42 S ...... 88,42 98 S ..... ~' 109~55--~ 61-$ ...... ' .132,19'"~ .... ................................ : .......................... 8.3 $ ......... 156,70 S ......... 1 '4'03 51 $ 214,49 W 3371 ........................... 3115. 3000"" 255 .............. : .................... 34 .......... ~ .... : ........... 1009,99 3511 ................. 3215J ....... 3100 -'29'~: ....................... : ............. 4'0 ......... ~,~ .1.100,12 3652 ...................... 3315; ......... 3200 .... i ...... 3'3'7 ................. ~ .............. ~'2 .... '?" ...... 1192,8'3 3795 .......... 3415, 3300' 380 .......................... 43 ........................................ 1287,68 393~ ........................... 351~,' 3400 '42~ ............................. ~'~ ...... ; ................ 138~,87 ~080 '-' 3615, 3500- 465 ................................ 41 ...... : ........... 1474,12 4218 ....................... 3715, .3600'.'.'.503 .... : ...................... 38 ................................. 1562,8~ 4356 ............... 3815, 3700-' 541 38 ......................... I6~9~47 S 248.,83 ,W -- :S ......... 286,67-~ " 'S ............ 324'15-'W _ $ 362,47 ~ S ...... 401,51-'-W .............................................. S 440,81'"W S ~-477,28 .~ S ......... 51~.39-W .............................. :: ........ ~ .............. 3915, ..... 3800 576 : ........................ ,.-;---~'.~: ---~ ..... - -- '-- ~ - ' -- -- ~ ,=7 . --: . ~.,, , . ' .' ':£ASU~£D DEPTH AND O~HER DATA FOR EVERY EVEN lO0 FEET OF SUB SEA DEPTH. MEASURED DEPTH ...... 4625 - '~758 ..... t+892 -- 5026 '" 5160 ( 5293 ..... 5426 5699 5836 ......5974 .... 6113 .... 6;~51 '- 6389 6526 ...... 6802 ...... ...... 7079 '- 72~5 ..... 7350 ...... 7~80 .......... 7609 ................ ............. 7736 ...... ....... 7860 ...... 79~7 ............. 8A~ .......... ............... 837~ ........ 8/+98 ......... 8627 ........ 87~7 - 889.2 90~0 ' ' 917~ TRUE ........... · VERTICAL SUB_ HD-TVD. VERTICAL. ' DEPTH SEA DIFFERENCE CORRECTION T OTAL COORDINATES .......................... 4015. 3900 610 '- 6115. 4000 643 4215, 6100 677 4315, 6200 711 ................ 34 4415, 6300 745 ............... S~ ........... ~515, 4600 778 4615. ~500 811 ......... 33 ............... 6715, 6600 866 ......... 35 ............ 4815, 4700 883 6915. 4800 921 38 ...... 5015, 4900 959 ........ 38 .............. 5115. 5000 997 38 ........ ..' 1036.- 39 'i-~"~ .... -i-;i';"';- 2815.02.. 1111 ...... 37 .................... 298~.73 1169 ...... 38 ............ 3068.53 1815,06 S 586.50 W ........ ' ................ 1895.09 S 622,09 W 1976,24 S 658,74 W 2057,72 S 695.65 W ........................................ 2139.85 S 729,55 W ................................................ 2220.77 S 763,57 W ..................................................... 2301,78 S 797.96 W .......................................... 2385.89 S 833,66 ~ ........................... - ........... 2~71,28 S 87~.83 W 2555.6~ S 916.42 ~ ........................................ 26~1.~7 S 95~,90 ~ .......................................... 2728.43 S 995.44 W s-: '. o .6. ".. :2.... :'_' ."::._ '..':.-1'2111 S1077.97 W S1119.~9 $ 1163.76 W $ ...... 1210,01 1255.69 X298,8~ W .......... 13~1,38--~ ...................................................... : .......... 1386.38 1425.96 1467,82 i535,36 156~,47 1629.59 ~--~ ..... =-'=' ". " _ 1&67~00 ~ .... .- .- $ 1705,42 .............................................. ................................................... $ 1790.07 S 1838.6~ S 1887.70 W = ................ ........................................... __ S 1926.~0 W 52.15,' 5100 5315. 5200' 5615. 5300 5515, 5400 5615. 5500 5715. 5600 5815. 5700 5915. 5800 6015, 5900 6115, '' 6000 6215. 6100 6315. .6200 6~15, 6300 6515, 6400 6615. 6500 6715, 6600 68'15'~ ....... 6700' 6915. 6800 7015. 6900 7115. 7000 7215. 7100 7315. 7200 7415. 7300 1187 .................. 38-L ........................ 3151,97 1226 ......... 39 ................... 3236,69 126~ ............. 38 .............................. 3321,07 1300 ................... 36 ........................... 3~03.56 1335. ..................... 35 ...................... 3~82.05 1365 ............ 30 .............. .'"= ........... 355~,86 1394 .......... 1421 1~5 24 ............................. 3760. 1472 ........ 27 ...............3833, 1501 ................ 29 ............ ~: ..... : ........... 3908. I529 ..................... 28 ............... ~--'~ ............ 3980, 1'583 ............. 27 ................................ ~117. 1611 ........... 28 ............................. ~186. 1642 "31 ............................ ~258. 1676 ................ 34 .................... ~33~. 1715 1756 .... ~I ............. ~507. ......... 29 ............................ 3626,61 27 ................. :'~':" .............. 3692,39 77 39 70 7i 52 99 72 92 S. ~.~EASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET oF SUB SEA DEPTH, ~EASURED DEPTH TRUE · VERT. ZCAL ,SUB .~40--TVD VERTICAL DEPTH .SEA DIFFERENCE__., . CORRECTION .... '".' TOTAL.`. COORDINATES 9311 9587 ..... 9722 9987 .......10116 ...... 102~3 10372 1050~ - -- 10633 _ 1167~ 1195~ '-- 1~09~ 12~81 ............. 1261~ 7515, 7615, 7715, 7815, 7915, 8015, 8215, 8315, 8415. 8515, 8615- 8715, 8815o 8915, 9015, 9115, 9215, 9315, 9415, 9515, 9615, 9715, 7~00 1796 7500 183% 7600 1872 7700 1907 7800 1940 7900 1972 8000 2001 8100 2028 8200 2056 8300 2088 8~00 2118 85OO 2148 29 508~.78 S 2.7 5155.50 S 28 5227.12 S 32 5301.~8 $ 30 5375.81 $ 30 5~48.46 S 8600 ...2176 ' ....."..28 8700 2207 ' 31 8800 22~0 ......... 3.3- ' 8900 2273 33 9000 2299 -- 26 9100 '2326 ................... 27 ............ 5519,93 559'3~1i"'i 5669e02 57~.55 5811.07 5877.85 9200 2356 .............. 30 ................. " 6950,42 9300 2393 ....... 37 ......... 6032,83 1962.65 W 1999,76 W 2038.73 2077.80 2116.48 ............. 215~.87 2188~71 ....... 2223.37 2261.$5 . 2300.8~ 2339.49 __ 2378.45 2417"92 ~ ' ' .................... ................ 2502.46 ................ · ............... 2585.37 ~ ........................... ~. ...... 2625.50 2667.59 _ ........................................ 2710.05 9~00 '2t+37 9500. 21~77 ........................ 9600 2509 9815.- 9700 2540 ................ 31/ ................................ 6361.19 $ 288~.15 10015, 9900 2599'-" ............... 30 6495.52 5 ...... 2980.08 ~NTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH. ............ TRUE '-- MEASURED VERTICAL SUB DEPTH- DEPTH- .-~ SEA' - TOTAL COORDINATES ............... - .................... ~ . .. ..... 1000 999. 884. 49.56 S 71.66-W 2000 1953. 1838. 330.00 S 37,53 ............. 3000 ...... 2825. 2710. ..... 796.~+3 S- 159.51 ..... ~000- :3558. 366:3, 1~+22..~5 S- 418.93 5000 ~295. 6180, 2061.86 S '688.7~ ........ 6000 5033, ~918," 2657.73 S '-- 962.48 , ( ..... 7000 - 5757, 56~2,-- 3272.85 S 1276.27 ...... 8000 652~, 6t, 09, 38A0.9~ S 1567.~3 ...... 9000 7293. 7178, ..... ~397.6~ S-' 1877,95 ......... 10000 -" 802~. 7909. 5018.36 S- 2158,39 11000 8797. 8682+ 5580.~1 S ..... 12000 95~8. 9~33. 6157.36 S' 2769,50 . ................................................................................................................................... ..................................................................... a " ' . * " ' ' ''' ." , ' ' ' ' · t'.,' .... .......................................................... . .... . . ....... 1200 , . .~. , VERTICAL SECTION "' SCALE 1"=1000' '~ ' ~ ATLANTIC RICHFIELD COMPANY , - ' ':'~ NTB WELL S-9 '~'~ .............. ' ....... "~"'~ ......... ' ........................ ; ............ RADltJ'S OF~CURVATURE METHOD ' ~ ,', · .:';, ..: · ,%;¢ . ; . '" ' i ';" ;; 4800%; ; · , , · ; -"':.-; ........... ;; ........... ~....¢.... ................. . ................ .. -,.,, .... .' . . . ,, ...... ' . . I .., .... 1 _~ ......... '..-. ............ x. -. ' i..;.i' '¥',''7':'',~ ' -'. · !; ' : ~.... -..' ' .': ' *. · ~ ' ' ' ': i' ' · '. ~ -. · ~, · , ,: i TVD = I0,e87,', . ' ' - TMD=IZ,717 HORIZONTAL VIEW SCALE I"= 500' ATLANTIC RICHFIELD COMPANY NTB WELL S-9 RADIUS OF CURVATURE METHOD 3200 ,-~w ,1~00 6OO '~000 '~ ~4.oo 2800 3600 TVD = I0,087 TMD: I? ~'*' 92OO 7600 · 84O0 8800 4800 52O0 4400 6400 5600 6000 AtlanticRichfieldCompany North Amer[)'~?roducing Division South Alask~J ,.~strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 1, 1974 Mr. Homer Burrell State of Alaska Department of Natural Resources Oil & Gas Division 3001 Porcupine Drive Anchorage, AK 99504 Dear Mr. Burre!l: Attached is the on the NTBU S-9 from the Spark October Monthly Report of Drilling Operations (44-B4) well which is currently being drilled Platform. Very truly your;s, ~Keasler(~' ~/District Drilling Supervisor JDK: vaf Attachment N[ V 0 tg?a ~"orm No, P---4 I~V'. ~- 1-70 STATE OF "'ALASKA OIL AND OAS CONSERVATION COMMrI-rEE SUBMIT IN DUPLICAT~ MONTHLY REPORT O'F :DRILLING AND WORKOVER OPERATIONS AP1 NUi~,IERICAL CODE 50-133-20265 6 LEASE DESIGNATION AND SEHIAL NO. ADL 17597 1. ?. IF INDIA~. ALOTTEE OR TRIBE NAME WgLL WI~LL OTHER 2. NAME OF OP]~%ATOR 8. L,~IT. FARM OR LEASE NAME Atlantic Richfield Company North Trading Bay Unit ~. ADDRESS OF OPE~TOR P. O. Box 360, Anchorage, Alaska 99510 W of SE WELL NO s-9 (44-34) 10, F~.r) AND POOL. OR WILDCAT 4. LOCATION OF WELL At surface: Spark Platform, 2570' N & 2563' CR Sec 26, T 10 N, R13W, SM Trading Bay NE Hemlock II.S~.,T.,R.,~..¢~OMHO= OBJEcr~ Sec 34, T10N, R13W, SM PERMIT NO. 74-27 '~'13. i~EPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AIN-D VOLUMES USED. PER~ORATIONS. TF~TS AND HESULTS. FISHING JOB~. JUNK L~T HOLE A.ND SIDE-TRACKED HOLE A~D ANY OTH~i~ SIGNIFICA/~T CHANGI~'~ IN HOL~ CON'DITIONS. 0ctober, 1974 Drld 8-1/2" dir hole f/11492'-12193'. Stuck drill string. Fished. Unable to recover fish. Backed off with tgp of fish ~ 11339'. Placed 75 sx "G" plug on top of fish. Top of cement ~ 11245'. Cut window in 9-5/8" csg f/11160'-11230'. Mixed and pumped 150 sx densified "G" cmt plug f/11055'-11233'. Drilled cement f/11055' to KOP ~ 11170'. Drld 8-1/2" dir hole f/~l170' to 1247'7'. Tested BOPE on October 2, 10, 20, 25, and 30th. Y ~"~ So"ut~ Alaska District :u'~~__,~,~_~-,r,,~ .... ~ Drilling Supervisor DAT~ November 4, T~'E---Rel)ort on this form is required for -each calendar ~th~ regardless of the status of operations, and mu,t ~ filed in duplt~tt with the oil and gas conservotbn commiflee bythe 15~ of the suec~ding mofl~, ~ltg otherwise directed. 1974 AtlanticRichfieldCompany North Ameri"~"ProdUcing Division South Alaslt ,strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 October' 2, 1974 Mr. Homer Burrell State of Alaska Department of Natural Resources Oil & Gas Division 3001 Porcupine Drive Anchorage, AK 99504 Dear Mr. Burrell: Attached is the September Monthly Report of Drilling Operations on the NTBU S-9(44~.54)'well which is currently being drilled 'from the Spark PlatfOrm. . Very truly~ ~~/ District Dre~nrg SuperVisor JDK/skk At t achment OCT 3 I974 Di¥1ISIGN 0~' OiL AND &45 ,1[ ~ ~°' ~'--~ STATE Ob ,ALASKA ~N'. &- 1-70 OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS SUBMIT IN IIUPLICATJ~ 50-133-20265 LEASE DESIGNATION AND SERIAL NO. ADL 17597 1. ?. IF INDIA)~, ALOTTEE OR TttlBE NAME OIL ~ Ga, ~ W~LL W~LL OTH~ 2,NAME OF OPERATOR Atlantic Richfield Company ~'~ADDRESS OF"OPERATOR ' m P. O. Box 360, Anchorage.., AK 99510 4. LOCATION OF WELL At surface' Spart: Platform, 2570'N & 2563'W of SE cr Sec 26, T10N, R13W, SM 8. L,~IT.FARM OR LEASE NAME North ..Tr...a.d. in.g .Bay._ Uni_t S-9 (44-5.4.)__. 10. FI~IX) A2~D POOL. OR WILDCAT _Trading BaY NE Hemlock_ 11. SEC., T., R., M.. (BOCci'OM HOLE O~TrV~ Sec 34, T10N, i!{R13W~, SM 12 PI~MIT NO. ..... 74-27 13. REPORT TOTAL DEPTH AT F_~ND OF MONTH, CPIA~NGES iN HOLE SIZE, CASING AN'D CEMENTING JOBS INCLUDING ~EPTH SET ANI) VOLLrMES USED, PERFORATIONS, TESTS A/qD I~ESULTS. FISHING JOB~. JUNK IH HOLE A.ND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CH.A. NGES IN HOLE CONDITIONS. September, 1974 Drld 12-1/4" dir hole f/7,888~-11,353~. Ran D1L log f/TD to 13-3/8" csg shoe. Ran 292 its 9-5/8" 47# N-80 Butt csg set @ 11,335' RKB. Cemented csg w/900 sx cmt. Test csg to 3000 psi. Drld out csg shoe & tested formation below shoe w/.55 psi/ft. Drld 8-1/2" dir hole f/11,353'-11,492'. Tested BOPE on 9-5-74, 9-10-74,9-20-74, & 9-30-74. OCT 3 1974 DI¥1SION OF OIL AND GAS A CT i i illll I iii i i II II IIII *--Report on this form is required for .~ch calendar month~ regQrdless of [he status of operations, and must be filed )~) alu;liters with the oil and gas coneervetlon committee by the mSth of the succeeding month, unlee$ otherwise directed. AtlanticRichfieldCompany ~ /..~, North Amer 'Producing Division South Alas[ ~,strict Post Office BOx 360 Anchorage, Alaska 99510 Telephone 907 277 5637 September 10, 1974 Mr. Homer Burrell State of Alaska Department of Natural Resources Oil & Gas Division 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Burrell' Attached is a copy of the Monthly Report of Drilling Operations of the NTBU S-9 (44-34) Well which is being drilled from the Spark Platform. JDK/gld Attachment SEP 1 11974 i}fflSION OF OIL AND GAS Form No, P--4 1%EV~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUP. LICAT~ MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS 1. WKLL W~'LL OTHg~ 2. NAME OF OP~,ATOR Atlantic Richfield Company 3. ADDRESS OF ObER-a-TOR P.0. Box 560 Anchorage, Alaska 99510 4. LOCATION OF WF_,L~ At surface: 2570'N & 2563'W of SE'cr Sec'.26, T10N, R1SW, SM % AP1 NUMEH/CAL CODE 50-155-20265 6 LEASE DESIGNA~'ION AND S~IAL NO. ADL 17597 IF INDIA~, A~TIE~ OR TRIBE NAME 8. L~IT F~ OR LEASE 9 WE~ NO. ~ i0 FL~J~D ~D ~, OR WILDCAT Trading Ba7 NE Hemlock ~ SEC, T.. R., M. (~OM HO~ o~ Sec 54,~ T10N, R15~ SM 1~, P~IT NO 74-27 13. REPORT TOTfL DEP"UH AT END OF MONTH. CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AN]) VOLU1VIES USED, PEHFOHATIONS, TESTS ANT) RESULTS FISHING JOB~ JI3~K IN HOLE AND SIDE-TRACKED HOLE A~ND A_N'Y OTHER SIGNIFICANT CH2i. NGES I~ HOLE CONDITIONS August, 1974 . Spudded'.-@6AM 8/5/74.. Drilled.,17 1/2" hole to 856'. Drilled 17 1/2" hole directionally from 856' to 2750'. Ran 72 joints (2677'], 72#, N-80 15 5'/8" Buttress casing. Float shoe Set'at 2720'. Cemented with'iS00 sx'Class "G" with'10% Gel and 500 sx Class "G" neat. Drilled 12 1/4" hole directionally'from 2720' to to'7888'. TeSted' Hydrill with 1500 psi and BOPE with 5000 psi on 8/15/74 and 8/19/74.. 558 1 ! 197 DW tOIq 01: OiL AND GAS AIqCI?OR 14. I h g S~GN~.- ~-~~.,~- -.-~------ -~ ~TU~ ~*~. September 10. 1974 ... / ~_~5 U,:~.' ~A~~ 50. Ui. StTiCT.'IItl I' I~o ~~rSc~ - - . / ~E ~Report on this f~m iI required for~ calendar Jth~ regardless of Ibe status o~ oplr~ions, °nd mull ~ tiled l~ duplJ~le with the ~ oil and gas aonservatbn commiflee by the I~ of )he SuecNdiflg ~n~, uflle~ ~therwlie dirscted. AtlanticRichfieldCompany North Ame~Producing Division South Alaska oistrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 5, 1974 Mr. Homer Burrell State of Alaska Department of Natural Resources Oil & Gas Division 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Burrell: Attached is a copy of the Monthly Report of Drilling and WorkoverOperations notifying you that drilling of the NTBU S-9 (44-34) Well has commenced from the Spark Platform. Very truly your , District Drilling Supervisor JDK/gld Attachment AU8 9 OIL AND GAS STATE OF' ALASKA suBMrr lin DUPLICA'I~ OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS AP! NUivIERICAL CODE 50-133-20265 LEASE DESIGNA'I'ION AND SEiqlAL NO, ADL 17597 WKLL WELL OTHER 8. L~,,'IT FA_r~/[ OR LEASE ,. N~E OF OPm?OR ATL ,ANT, IC RICHFII~LD COMPANY .. P.O. Box 360 Anchorage, Alaska 99510 4. LOCATION OF WTM At surface 2570'N & 2565'W of SE cr Sec 26, T10N, R13W, SM S-9 10 F~ AND POOL. OR WILDCAT Trading Bay NE Hemlock n sec. T.. p,.., r.i. (BOTTOM l-tot,g Sec 54,T10N R13W SM 1,. PEPd~IT NO 74-27 REPORT TOTAL DEPTH AT END OF MONTH. CHA3qGES IN HOLE SIZE. CASING AND C~WI~NT~NG JOBS INCLUDING DEPTH SET AN~ VOLUMES USED. PERFORATIONS. TESTS AND RESULTS FISHING JOB~ JLrNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTI{ER SIGNIFICANT C'I'L~NGES IN HOI2~ CONDITIONS Drilling Operations commenced from the Spark Platform on the NTBU S-9 (44-34) Well at 6 AM 8/3/74 AUO 9 )974 oil and gas conservat/on committee bythe 15th of the succeeding month, u~le~ otherwise directed. ~uly g3., 1~74 Not-da Tradtmj Bay Atlantic Rtc~teld #74-~7 Dear Str: Enclosed is ~ approved applt~t;Icm for permtt to d~tll the above referenced ~ell, at a date yet to be determltmd at a locatton in Sectton ~, Tmmshtp 1ON, Range t3~, S.i1. I~ell samples, core chtps, and a amd log are not requt~. A dlrecttonal survey Js required. Pollution of ;any waters of ~ State ts 'prohibited by AS 46, Chapter 03, Article 7 and the regulations-~lgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal I/ater Pollution Control Act, as ~. Prior to come~J~ operations you may be contacted by a representaUve of the Departaent of Envtroramntal Conservation. P~ursuant to .AS 38.40, Local Hlre Under State Leases, the Alaska Oepar~ of Labor Is be!rig notffled of the issuance of thts penatt to dr111. Ve?~ truly **ypurs, ~ / T~ R. Harsha11, Executtve Secretary Alaska 0tl and Gas Conservation Coaetttee TRlq~,Jh ~losure cc: Oepar~t of Ftsh a~ ~, Habitat S~tJoe w/o encl. Oepa~t of Environmental Conservation w/o encl. ~rta~qt of Labor~, Supervisor, Labor Law Cm~11ance 01vlsi. on w/o eric1. AtlanticRichfieldCompany North America~ ~ducing Division South Alaska Dio.rict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 12, 1974 Mr. Homer Burrell Division of Oil & Gas Department of Natural Resources State of Alaska 5001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Burrell: The Atlantic Richfield Company requests your approval of the attached Application for Permit to Drill the NTBU S-9 (44-34) Well. The $100.00 filing fee and well location map are attached. Our proposal to drill S-9 is part of the pressure maintenance project approved by Conservation Order No. 108 and will increase recovery from the "G" and Hemlock NE Oil Pools of the North Trading Bay Unit.' The S-9 well will encounter the top of the Hemlock Zone about 1000' south-West of producing well S-7-RD. We are presently completing the S-2 Redrill and wish to begin work on S-9 about July 22 as soon as the work on S-2 Redrill is finished. Your early approval would be appreciated. Very truly yo~ s, B.J./~mith District Drilling Supervisor BJS/gld Attachment Form 10-- 401 REV, I--I--71 STATE OF ALASKA SUBMIT IN TRIPLI(/~ (Other instructions 02, reverse side) OIL ~ W~LL OIL AND GAS CONSERVATION COMMITTEE PERMIT TO ,DR!LL'~OR DE~PE',N DRILL ~ DEEPEN 8INOLIII WSL~OAS [--'"] 0'rn nj ZONI~ MUI,TI?I,J ZONE NAME OF OPEa~ATOR ATLANTIC RICHFIELD COMPANY 3, ADDRESS O~ OPERATOR P.O. BOx 360, Anchorage, Alaska 99510 4, LOCATION OF WELL At surface 2570'N & 2563W of SE cr sec 26,T10N, R1SW, SM At proposed prod. zone 3780's & 60'W of NE cr Sec 34, T10N, R13~t SM 13. DISTANCE IN MILES AND DIRECTION F~OM NEAREST TOWN OR POST OFFICE* 28 miles NW from Kenai, Alaska A.P.I.~ 50-133.20265 , ADL 17597 6. LF~E D~IGNATION AJ~D S~AAL NO. 7. IF INDIAN, A.LJ.~'l-k-~:~: OR TRIBE NAM~ 8. UNIT FARM OR LEASE NAME North Trading Bay Unit g. WELL NO. S-9 10. FIEI~D AND POOL. OR WILDCAT Tradin.g Bay NE Hemlock 11. SEC., T., R.. M., CBO~TOM HOLE OBJECTIVE) Sec 34. T10n. R13W~ SM 12. 14. BOND INFORMATION: TYPE Statewidesurety and/or No. Federal Insurance Co. 15. DISTANCE FROM PROPOSED* LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. 50 (Also to nearest drig, unit, ii any) 18. DISTANCE FROM PROPOSED LOCATION* TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 1000 21. ELEVATIONS (ShOw ~hether DF, RT. ~'R, et~.) 8011-38-40 NO. OF5120 ACRES IN LEASE. PROPOSED DEPTH 13700 115 ' KB 23. PROPOSED CASING AND CEMENTING PROGRAJ~ ~o~: ..$100,000 17. NO. ACRES ASSIGNED TO THiS WELL 40 20. ROTARY OR CABLE TOOLS , Rotary 22. APPROX. DATE WORK WILL START* July 22, 1974 We propose to directionally drill from 432' to TD 013,700'. The angle will build"t<6 50°. Top of the Hemlock will be 9795' TVD + with TD at 10,305'.TVD +. We propose use a 20" 2000 psi WP annular preventer on t--he 24" conductor while dr--illing 17 1/2" hole to 2700' +. ~ere Will be 12" 3000 psi pr~~a~~ ~the 13 3/8" and 9 5/8" casing with pipe and blind rms. ' JUL 1 i 74 · ~ ABO~ SPA~ D~BE ~O~S~ PR~R~: If ~I ~ to dee~n give 've~ical dept. Give bio, ut preventer V~am. ,. , (This space ~or S~te offl~ u~) CONDI~ONS OF ~V~. IF A~: U Y~ ~o ~ U ~ ~o~SEE ~SMI~AL D~o~ su~wY ~~ ' ' ~.~.L ~6~ . ~No g~' ~ - ~v~oA~ July 23, 1974 .~ -~~ ~~~ ~ gxecutive Secretary m,~ July 23, 1974 - .... SIZE OF HOlE I_SIzE OF CAS!NG2,,,WEIGHT PER FOfyr GRAI)E S~'rTING D~ ' qooniity o{ cement 17 1/2 13 3/8 ' 61 ' K-SS 2700 1850 sx " ',~',~ 12 1/4 . 9 5/8 47.. N_80 12000 %~or,,O 9Q.0 sx /?'<~; ;~.~:~o'. 8 1/2 7. 29 N-80' TOD 11,'800. 400 Sx /:.?.;~ ~,.~ ~_~c,.c~ -- ~Liner . Btm 1 3.650 , , APPLICATION FOR PERMIT TO DRILL WELL NTBU S-9 (44-34) Proposed Program for Drilling 1. Directionally drill 17 1/2" hole from 432' to 2700'+. Set 13 3/8" casing and cement to surface. 2. Directionally drill 12 1/4" hole from 2700' to 12000'+. Set 9 5/8" casing and cement w/400 sx cement. 3. Directionally drill 8 1/2" hole from 12000' to 13700' TD +. Set 7" liner and cement to top of liner. 4. Run 3 1/2" completion assembly. 5. NU X-mas Tree and test to 3000 psi. 6. Perforate and complete in the "G" and Hemlock Zones. JUL 8 · TTIO N- R ISW SUPERIOR-TEXACO ARCo 24 ,~NOBTH TRADING BAY UNIT ARCO IARCO !UN ION - MARATHON I 25 I // I / / ~ ~PRoPOSED S-9 i ! i 36 -FTION-RI2W I ARCO - SOCAI_ I I i I I I I 19 I I ATL ANTICRICHFIE L DCOMPANY ~LASKA DISTRICT WELL LOCATION MAP NORTH TRADING BAY UNIT PROPOSED WELL S-9 JULY 1974 SCALE I000 2000 -~. Lease & Well No. CHECK LIST FOR NEW WELL PERMITS Yes No Remarks Is well to be located in a defined'pool ................. Do statewide rules apply ........................ Is a registered survey plat attached .................. X~K Is well located proper distance from property line ........... /~ _ - , Is well located proper dis. tance from other wells ............ Is sufficient undedi'~Eated acreage available in this pool ........ Is well to be deviated ......................... /m~o~ Is operator the only affected party ................... Can permit be approved before ten-day wait Does operator have a bond i'n force '. ................. Is 'condu¢[or stroh§ provided ..................... ~/ Is esou~h ceme:~t used to c~rculate on conductor and surface ...... ~)/ " Will cement tie in surface and intermediate or production strings . . . Will surface csg, internal burst equal ,5 psi/ft, to next string .... 6o/lopse : .Will ~11 c~sin~ ~ive tdequ~te s~et~ jn collapse ~nd tension ...... ~' ¢oes BOP[ have sufficient pressure rat~n~ ............... itional Requirements: ,.. ~.~]~ _ rova~ Recommended: ............ - - .... . ..... I ..... i i . - __, . '.: ~ ....
