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171-033
~ ~~ i`R,-f E Or ~l;l_A.~,E:{~ P,E_„~ I~./~1~L RfvD GAS GC?fVSE{-;VATI~~ne GC?lVIVIlS._~ i'=~ ~~~~~ ~'~~r~~~ ~.~'~~~~~ ~~ ~~~~~~~~`~~`~~~~~ ~~~~~°~ ~~~~~~ ~.~~ 1 a. Well Staius ~~ Oii ~ Gas C~ Plugged ~ Abandoned ~ Suspended ~ ~~m zoxaczs.io5 zoAnc2s.rio GINJ ^ WINJ ~ \,'VDSPL~ WAG ^ Other^ No, of Compietions: ~ 1 b. Weli C!ass: ~ Developm~ni ~ ~ Exploratory~ Service ~] Stratigraphic Test~ 2. Operator Name: Marathon Oil Company _ 5. Date Comp., Susp , or f~ ~ Aband.: p ~~% q ~ ~o ~ 12 Permit to Drill Number: 171-033-0 ~ 3. Address: P.O. Box 196168, Anchorage, AK 99519-6168 6. Da e Spudd d: 1/17/1972 ' 13. API Number: 50-733-20233-00-00 ' 4a. Location of Well (Governmentai Section): Surface: 2577' FSL & 2566' FEL, Sec 26, T10N, R13W, SM • 7. Date TD Reached: 3/7/1972 14. Well Name and Number: N. Trading Bay Unit S-08 Top of Productive Horizon: 111' FNL & 99' FEL, Sec 26, T10N, R13W, SM II, KB (ft above MSL): 115 . Ground (ft MSL): 15. Field/Pooi(s): G-NE/Hemlock-NE Oil . Total Depth: 245' FNL & 467' FEL, Sec 34, T10N, R13W, SM 9. Plug Back Depth(MD+TVD): 51' below mud line W Foreland Oil . 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 227683.388' y- 2534444.445 ~ Zone- 4 0. Total Depth (MD + TVD): . 11855 MD, 10970 TVD • 16. Property Designation: ADL017597 ' TPi: x- y- Zone- Total Depth: x- 224442.584 y- 2531698.149 Zone- 4 11. SSSV Depth (MD + TVD): 17. Land Use P~~~~~~~~ 18. Directional Survey: Yes ~ No ~ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Ottshore: 60 (ft MSL) 20. Thickness of P ro t(TV )~ ~~~ ~~~~~~ 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): ~laska ~il & Gas Cons. Gomm 22. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT TOP BOTTOM TOP BOTTOM PULLED 13-3/8 61 K-55 0 2046 0 2022 17-1/2 900 sks "G"/10% gel 660 sks "G" Neat tail 9-5/8 47 P110 0 10892 0 10087 12-1/4 750 sks "G"/0.2% HR-7 7 29 N-80 10775 11829 N/A N/A 8-1/2 350 sks "G"/0.2% HR-7 23. Open to production or injection? Yes ~ NoQ , 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) 3-1/2 600-10020 Baker DB C~3 9915 CIBP @ 9885 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~4~~~y~~°} {'~ ' i r`~ ~~(~~ , !'~ Lr~ ~ l) V ~ ~e1 DEPTH INTERVAL (MD) AMOUNT AND KWD OF MATERIAL USED 9/02/09 tagged TOC @ 51' BML 275-575; CIBP @ 575 41 bbis, 203 sks 1.132 yd, 15.9 ppg "G" Neat 8/22/09 tagged TOC @ 1344' RKB 1344-1797 24 bbls, 119 sks 1.132 yd, 15.9 ppg "G" Neat . 8/19/09 tagged TOC @ 1797' RKB 17g7-2185 24 bbls, 119 sks 1.132 yd, 15.9 ppg "G" Neat 8/09/09 tagged TOC C~3 9661' RKB 9661-9885 25 bbls, 124 sks 1.132 yd, 15.9 ppg "G" Neat 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period Oil-Bbl; Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24-Hour Rate ~ Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity - API (corr): 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No ^ Sidewall Cores Acquired? Yes ^ No ^ If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. r~~~~~~ >~io~ ~ ~ ~., v t -~ ~- ~ - Porm 10-407 Revised 2/2007 CON INU D ON ERSE jp • ZZ' a~ ~ ~~'~ • • 28. GEOLOGIC MARKERS (List ali formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ^ Yes ^~ No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top 0 needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base 0 Top of perf targeting G-zone G-2 10,220 9,478 G-3 10,295 9,546 G-4 10,330 9,577 G-5 10,376 9,619 Top of peifi targeting Hemlock zone H-1 10,418 9,657 H-2 10,492 9,723 H-3, H-4 10,583 9,805 West Foreland 10,810 10,011 Formation at total depth: West Foreland, last perf depth 11,320 10,482 30. List of Attachments: summary of abandonment, final P&A wellbore diagram 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tiffany Stebbins Printed Name: Tiffany Stebbins Title: Regulatory Compliance Representative Signature: ~°~~~ ll~~, ~ Phone: 907-565-3043 Date: 10/16/2009 INSTRUCTIONS General: This form is designed for submitting a complete and correct weli 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 1 a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for /njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 Marathon Oil Company • • Page 1 of 2 North Trading Bay Unit no. S-08 API 50-733-20233-00-00, Sundry Number: 309-144 Work Summarv 8/05/09 Open tubing to 800 psi and pump 25 bbls down tbg @ 0.75 bpm. Casing pressure came up with tbg pressure. Pressured up to 3000 psi without injecting into well. Shut down pump. Bleed off pressure and pressure up again to 1000 psi and chart for 15 min. Good test recorded. Bubble tested 13-3/8" csg while tbg and 9-5/8" still pressured up. 13-3/8" csg remained on 0 psi. R/U slickline with 2.25" G.R. and test lubricator to 1500 psi. Open well and RIH to 10020' RKB. POOH 8/06/09 R/U e- line thru v- door and drilling floor. Bleed off 300 psi on well. Test lubricator to 1500 psi. Open well and RIH with 2.281" CIBP to 9885' RKB and set bridge plug. POOH and shut in well. M/U 2 ft of perforating guns @ 4 spf and open weli. RIH to 9885' RKB and perforate tubing. POOH Break circulation down tbg and return out the 9-5/8" csg . 8/08/09 Circulate 90 bbis down tbg, returning oil up 9-5/8" csg. Rearrange deck to make room for cement and lay out hoses to take on water from boat when it arrives. M/P 25 bbls, 124 sks of 1.132 yield, 15.9 ppg, class "G" Neat cement down tbg, taking returns out of 9-5/8" csg, displacing TOC to 9535' RKB, leaving a 350' intermediate cmt balance plug from 9885' RKB to 9535' RKB, in both the 3-1/2" tbg and the 9-5/8" x 3-1/2" annulus. WOC 8/09/09 Open well and insure well is at 0 psi. R/U lubricator and e- line. M/U 2 ft perforating gun for 3-1/2" tbg Q 4 spf. RIH and tag TOC at 9661' RKB. Pull up to 2185' RKB (above collar) and perforate. POOH 8/16/09 R/U pump lines. Circulate 156 bbls and clean up well. Transfer disposal fluid around on deck to make room 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 1835" RKB, leaving a 350' intermediate cmt balance plug from 2185' to 1835' RK6, in both the 3-1/2" tbg and the 9-5/8" x 3-1/2" annulus. WOC 8/18/09 Move lubricator over and R/U pump hoses. Pressure up on csg to 1000 psi. Pressure fell off 300 psi in 10 minutes. Pressured up on tbg to 1000 psi. Pressure fell off 300 psi in 5 minutes. Bled off to 0 psi and pressured up on both csg & tbg together to 1000 psi. Both fell off 300 psi in 5 minutes. Bled off to 0 psi and reattempted 3 more times and pressure fell off at a slower rates. 8/19/09 Open well and pressure up to 1000 psi on 9-5/8" casing. Pressure fell off to 700 psi in 5 minutes. Continued pressuring back up 3 more times with same results but taking longer time to fall off. Pressure up on tubing to 1000 psi and pressure held solid. Pressure up on casing again to 1000 psi and pressure held solid. Bled pressure off well and determined that plug was leaking into area below itself and pressuring up on the plug below. Bled well to 0 psi. R/U wireline with 1-11/16" weight bar and RIH to 1797' and tag TOC. POOH and R/D wireline. Call office and request approval on contingency plan to re-plug the intermediate. Perform maintenance on equipment and repack fluid end on fluid pump, while waiting on approval to work on either of the remaining wells. 8/20/09 Clean deck and equipment while waiting on approval for S-8. Receive approval from AOGCC. Expro Wireline on the way to Spark. R/U and RIH with 2 ft of perforating guns ~ 4 spf and tag TOC at 1797'. Pull up to 1794' and shoot guns with 500 psi on tubing. Pressure fell to 0 psi. POOH. 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 1444" RKB, leaving a 350' intermediate cmt balance plug from 1794' to 1444' RKB, in both the 3-1/2" tbg and the 9-5/8" x 3-1/2" annulus. WOC ~ • Marathon Oif Company Page 2 of 2 North Trad~ng Bay Unit no. S-08 API 50-733-20233-00-00, Sundry Number: 309-144 8/21 /09 R/U and test intermediate plug to 1000 psi on both the tbg and the 9-5/8" csg & chart for 15 minutes each. Good test. R/U wireline with 1-11/16" weight bar and RIH to 1344' RKB and tagged TOC. POOH & R/D wireline. 8/22/09 R/U lubricator and pump hoses in preparation for AOGCC's arrival to witness test and tag depth. AOGCC arrived. R/U and test intermediate plug to 1000 psi on both the tbg and the 9-5/8" csg & chart for 15 minutes each. Good test. R/U wireline with jet cutter for 3-1/2" tbg and RIH to 1344' RKB and tagged TOC. Pull up to 600' RKB & cut tubing. POOH and R/D e-line. 8/23/09 Fabricate and put in floor on drilling deck so to handle tubing, while N/D tree from well. R/U lubricator and pump hoses. Circulate 45 bbls for bottoms up. Remove tree. R/U landing joint, elevators, and slings. Pull 20,000 Ibs with crane without success. R/D landing joint and R/U hanger jack. Jack up 60,000 Ibs against hanger without success. Determine tbg not fully cut. 8/24/09 Strip tbe cutter thru hanger jack plate and secure jack plate to tbg hanger. Apply 56,000 Ibs against hanger and RIH to 534' WLM (594' RKB) and re-cut tbg. Tubing and hanger came up, verifying cut. POOH and hung up at SCSSV. Dropped sleeve down hole on wire and still had 1 ft of tool that would not come thru SCSSV. Found splicing connections and connected to SCSSV fitting on hanger. Pumped open valve and finished pulling out of hole with e-line. 8/25/09 R/U handling tools and POOH with 3-1/2" tubing. Tested for NORM and none was found. Out of the hole. Wash down pipe. Backload onto workboat. Total pipe pulled out 535.66' (595.66 RKB) 8/26/09 RIH with G.R. in 9-5/8" & tag top of tbg at 534' WLM. M/U CIBP and RIH to 575' RKB and set. R/U lubricator and e-line. M/U 2 ft perf gun @ 4 spf and RIH to 575' RKB and fire gun with 500 psi on 9-5/8" csg. Pressure did not fall. POOH and M/U another gun. RIH to 570' RKB and re-shoot with 500 psi on csg. Pressure fell to 0 psi. POOH and circulate 5 bbls at 0 psi. 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 with 1-11/16" weight bar to 51' BML and tag TOC. Tag TOC at 51' BML with AOGCC present. POOH ~ • ~A ~~1~ RKB-MSL 115' WATER DEPTH 60' Max Angie = 45 ° @ 10009' TM D @ 11855' ND Q 10970' PBTD @ 11360' MASTP 896 psi MIT 6/17/2009 API # 50-733-20233 SurFace Casing @ 2046' 13 3/s" 61 ppf K55 Buttress 12.515" ID .1521 bbl/ft CMT 900 sks CTOC ~980' Gauge Hole Caiculations Tubing @ 10020' 31h" 9.3 ppf N80 EUE 2.992" ID .00870 bbl/ft Packer Fluid 8.5 ppg Salt Water CMT behind 9 5/s" @ 9375' NOTE: Liner "LAP" Good to 1500 psi 3/13/72 & 3/14/72 Marathon Oil Company North Trading Bay Unit Spark Platform Well S-8 "FINAL P&A CONFIGURATION" ~ All Depths measured RKB to top of equipment All depth are RKB unless otherwise noted ,~~~AOGCC Witnessed TAG TOC @ 51' BML ~ ~ T ° ~i 3 ~. ~~ ~, „ "~ j „qlu;''~I 8/27/2009 ~ ~ ~.' ~ ~300' Surtace Cement Plug ~. M& Pumped ~41 bbls 15.9 ppg "G" CMT ~~ 95/8'&95/8'X133/a" \ ~574' RKB to ~274' RKB ~ ~ ~ j~7 ' 8/26/2009 PERFORATED 9 5/e° @ ~574' RKB ~ Set CISP C~ ~575' RKB 8/22/2009 Cut and Pulled 3~/z" Tubin C~ ~600' RKB /~ /Q ~Z-~ Baker 9 51s" DB Packer @ 9915' Flopetrol 1" GLM w/BK@ latches 2205 7503 3775 7940 4999 8378 5847 8814 6503 9221 7066 9656 TOL @ 9957' Tubing Tail 10020' Intermediate Casin~ C~ 10892' 9 5/a" 47 ppf N80 &P110 Buttress 8.861" ID .0732 bbl/ft CMT 750 sks CTOC ~8406' Gauge Hole Calculations Production Liner @ 11829' 7" 29 ppf N80 Buttress 6.184" ID .0371 bbl/ft CMT 550 sks CTOC @ ~6844' Gauge Hole Calculations , ~~GI TMD = 11855' i~350' Additional Cement Plug ~~~1794' RKB to ~1444' RKB PERFORATED 3 ~/2° Tubing @ ~1794' RKB ~ M& Pumped ~24 bbls 15.9 ppg "G" CMT TAGGED TOC INTER PLUG @--1797' RKB 8/16/2009 ~388' CMT PLUG ~ M& Pumped ~24 bbls 15.9 ppg "G" CMT ~2185' RKB TO ~1797' RKB 8/9/2009 ~ PERFORATED 31/z" @ ~2185' RKB TAGGED TOC ZONE PLUG (~ ~9661' 8/6/2009 ~224' Bottom Hole Cement Plug ~ ~9885' RKB to ~9661' RKB M&P 25 bbl 15.9 "G" CMTSIur 8/6/2009 Perforated 3~/z' (~ ~9885' RKB Set CIBP (~ ~9885' RKB Pollard Wire Line tagged fill @ 10421' Reported on 6/17/2009 MIT 7" Brown Hanger @ 10775' Fill 11,292' -11360' 4/06/92 11740' - 11829' Cement EZBP @ 11360' PBTD = 11360' MARATHON SPARK S-8 FINAL P&A CONFIGURATION PAGE 1 9/30/2009 ~ fA a MEMORANDUM State o la~ Ataska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~ ~~~i ~ ~~~~~~~ FROM: Jeff Jones Petroleum Inspector Section: 26 Drilling Rig: N/A Township: 10N Rig Elevation: RKB 115' MD Operator Rep.: Dan Byrd DATE: September 2, 2009 SUBJECT: Plug & Abandonment S-08 Marathon Spark PLT TBF / NTBU , ~ PTD 1710330 / Sundry 309-144 Range: 13 Total Depth: 11855' MD Meridian: SM Lease No.: 017597 Casinq/Tubinq Data: Casinq Removal: Conductor: O.D. Shoe@ Casing Cut@ Feet Surface: 13 3/8" O.D. Shoe@ 2046' MD Casing Cut@ Feet Intermediate: 9 5/8" O.D. Shoe@ 10,892' MD ` Casing Cut@ Feet Production: O.D. Shoe@ Casing Cut@ Feet Liner: 7" O.D. Shoe@ 11,829' MD ~ Casing Cut@ Feet Tubing: 3.5" O.D. Tail@ 10020' MD ~ Casing Cut@ 600' RKB Feet Pluqqinq Data: Tvae Pluq Bottom of T.O.C. Mud Weight f6ottom unl Founded on Cement T.O.C. Deoth Verified? above plua Pressure Test Surface Brid e lu 598' MD 165' MD j Yes i 8.7 No Tvpe Pluq Founded on: Verified? Open Hole Bottom Drillpipe tag Perforation Bridge plug Wireline tag ,. ~-~., ,~ Annuius Balanced C.T. Tag t~~p'~+~~~~'' }~~~ `` `~' ~~~~ 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-08. 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 hanger 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 598' MD in the 9 5/8" casing and holes were punched in the 9 5/8" casing and 300' (41 bbis) 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 165' MD. Summary: I witnessed a successful wireline tag to confirm placement of a surface cement abandoment plug in Marathon's Spark Platform weil NTBU S-08 in the Trading Bay Fieid. 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-08Jj.xis 10/16/2009 • • Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, August 20, 2009 11:11 AM To: 'Paxton, Todd D.' Cc: Aubert, Winton G(DOA); 'Stebbins, Tiffany A.' Subject: RE: S-8 P"~~ ~`~ ~_ O 3 3 Todd, I have reviewed the revised procedure dated 8/19/2009 for S-08 and concur with placing the extra intermediate cement plug placement just above the first intermediate plug (TOC at 1787' md). 1 noted that the "current schematic" does not show the first intermediate plug as shaded or the perforations in the tubing ( the details are listed however}. The "proposed schematic" looks fine. Please keep me posted on any other major changes as they come up. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 From: Paxton, Todd D. [mailto:tpaxton@marathonoil.com] Sent: Thursday, August 20, 2009 9:33 AM To: Schwartz, Guy L(DOA); Stebbins, Tiffany A.; 8776498446@airmessage.net Subject: Fw: S-8 Importance: High Guy, ~ ' ~~~;" ;;:.. :f ,?(;~~~'~ ; i,r ~ For your review. Thanks, Todd From: Randy Ellis to: Stebbins, Tiffany A.; Laughlin, Gary A. Cc: Paxton, Todd D.; Jeff Thompson ; Chuck Purdy ; Fred Monus ; Tammy Porterfield ~ent: Wed Aug 19 16:39:53 2009 Subject: S-8 Gary / Tiffany, I was contacted and advised that the intermediate plug set in the S-8 did not test. f have made modifications to the well schematic and revised the procedures. Please review and submit to the AOGCC requesting that we be allowed to continue with the proposed modifications. Thanks you again for your hetp in dealing with this issue. 8/20/2009 • . Page 2 of 2 let me know if you see any discrepancies that need atten#ion. Randy Randy Ellis Abandonment Engineer ~ D: +1 713 343 9514 ~ ~~~~~}~+~~r E: ~1 i~ randy.ellis@proserv- " ' offshore.com PROSERV OFFSHORE 13105 Northwest Freeway, Suite 250, Houston, TX 77040 T: +1 713 462 9990 F: +1 713 462 2007 www.proserv-offshore.com Please note our new company name and email address This email, any associated files and the information contained in them are confidential and is intended for the addressee(s) only. If you have received this message in error please notify the originator and delete the email immediately. The unauthorized use, disclosure, copying or alteration of this message is strictly forbidden. Emails to and from the company are monitored for operational reasons and in accordance with lawful business practices. Any opinions expressed are those of the individual and do not necessarily represent the views of the company. The company does not conclude contracts by email and all negotiations are subject to contract. We make every effort to maintain our network free from computer viruses, but accept no responsibility for any viruses which might be transferred by this email. 8/20/2009 • • V~ ~~ ~ ~~ MARATHON OIL COMPANY ~ NORTH TRADING BAY UNIT ~,/' SPARK PLATFORM WELL S-8 ABANDONMENT PROCEDURE 8/19/2009 "REVISION" ~ ~ ~r~~'~i ~;~ ~. WELL DATA API # 50-733-20233 Efevation: 115' RKB - MSL Production Liner: 7" 29 ppf N80 Buttress C4~ 11829' Water Depth: 6b' 6.184" ID .0372 bbl/ft Max Angle: 45 ° C~? 10009' CMT 550 sks TMD: 11855' CTOC C~ 6844' Gauge Hole ND: 10970' TOL: ~ 9957' MASTP: $96 psi MIT 6/17/2009 Tubing: 3~/2" 9.3 ppf N80 C~ 10020' Packer fluid: 8.5 ppg Salt Water 2.992" ID .0087 bbiJft Surface Casing: 13 3/s" 61 ppf Buttress C~ 2046' SCSSV: Camco TRDP-IA- SCSSV C~ 282' 13.515" ID .1521 bbl/ft CMT 900 sks Packer: Baker DB packer C~ 9915' Intermediate: CTOC (~ 980' Gauge Hole Pertorations: 10220' - 11320' 9 5/s" 47 ppf N80 & P110 C~ ~0892' Buttress 8.861" ID .0732 bbl/ft Fill: @ 10421' MIT 6/17/2009 CMT 750 sks CTOC ~ 8406' Gauge Hole PBTD: 11360' CURRENT STATUS The weli has no further utility and is to be abandoned following the procedure below. NOTE: The well History indicates a substance similar to para~n may be found in the weAbore Tubulars, This substance was successfully treated with a"XYLEIVE" based solvent in the past. ABANDONI4~FNT PROCEDUR~ 1. Mobilize tree technician to Iocation to ensure the operation of tree valves, flanges. Repair as needed. 2. Mobilize abandonment crew and equipment to location. Perform 1SA 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. Record results. Note: Pollard Wire Line ran in hole to 10421' RKB and tagged fill as reported on 6/17/2009. 4. Pertorm JSA for wireline operations. Pressure up on SCSSV control line and lock open. Rig Up wireline lubricator and test to 1500 psi. RIH with gauge ring to the EOT at ~10020' pull all plugs as necessary. POOH. Maratlwn Spark Well S-8 Procedures Page 1 8/20/2p09 • ~ 5. Pertorm JSA on electric line operation and explosive handling. Rig up electric line lubricator and test to 1500 psi. RIH with 3~/s" CIBP to ~9900' RKB Pick up to ~9885' RKB and set CIBP in the 3~/s" Tubing. POOH. 6. RIH with perforating gun armed with 2 ft of 4 SPF casing punch and tag CIBP set C~? ~9885' RKB and fire guns. POOH. RD electric line. 7. PerForm JSA for cement mixing and pressure pumping. Rig up cement pump and lines. Test lines to 1500 psi. Break circulation down the 3~/2° tubing while taking returns up the 9 5/a" casing annulus. Mix and pump a~25 bbl 15.9 ppg °G" cement slurry for a-224' cement plug from ~9885' RKB to -9661' RKB in the 3'/s° tubing and in tNe 3~/2" X 9 5/8° casing annulus. Displace with weighted fluid. 8. WOC. Pressure test cement plug to 1000 psi. Document results using a continuous pressure chart recorder. 9. Perform JSA on electric line operations and explosives handling. Rig up electric line lubricator and test to 1000 , ,~ psi. RIH with perforating guns loaded with 2 ft of 4 SPF tubing punch and tag top of cement for bottom hole ~"`#~ ,;~' f'~ 4~ plug ~~9661' RKB and record results. Pick up to ~2185' RKB and shoot tubing. POOH. 10. PerForm JSA for cement mixing and pressure pumping. Rig up cement pump and lines. Test lines to 1000 psi. Break circulation down the 3~2° tubing while taking returns up the 9 5/s" casing annulus. Mix and pump a~24 bbf 15.9 ppg "G" cement slurry for a--398' cement plug from ~2185' RKB to ~178T RKB in the 3~z" tubing ,.,µ., and in the 3~/z" X 9 5/s" casing annulus. Displace with weighted fluid. ~~' ,?~'` ~" t° ~~,~' ~ ~~~~;; ~ 11. WOC and test to 1000 psi. Document results usin~a continuous pressure chart.re~qrder~ ,,~~,_ ~~,~.,.~ __.,~.. .~ ;~~ ~_ 12. Perform JSA on electric tine operations and explosives handling. Rig up electric line lubricator and test to 1000 psi. RIH with perForating guns loaded with 2 ft of 4 SPF tubing punch and tag top of cement for Intermediate Cement Plug C~ ~1787' RKB record results and fire guns. POOH. RD electric line. ~~.~ 13. Pertorm JSA for cement mixing and pressure pumping. Rig up cement pump and lines. Test lines to 1000 psi. Fs~`~''` Break circulation down the 3'/2" tubing while taking returns up the 9 5/s" casing annulus. Mix and pump a~24 bbl 15.9 ppg "G" cement slurry for an additional ~350' cement plug from ~1787' RKB to ~1487' RKB in the 3 '/z" tubing and in the 3~/2" X 9 5/s° casing annulus. Displace with weighted fluid. ~;, X= ~ „,, ~ - 14. WOC and test to 1000 psi. Document results using a continuous pressure chart recorder. ~; ~.- » ..,~.. ~ ~ ~ . _ ~ _ . ~ . .. . .,w 15. Perform JSA on electric line operation and explosive handling. F2ig up eleetric line lubricator and test to 1000 psi. RIH with jet cutter and tag top of cement for intermediate cement plug C~1487' RKB and record results. Pick up to --600' RKB and cut 3~/z" tubing. POOH. 16. Rig down tree. 17. Perform JSA on proper pipe handing procedures. Pull 3~s" tubing and check for N.O.R.M. 18. Pertorm JSA on proper electric line operation and explosives handling. RIH with 9~" gauge ring and tag top of tubing stub at ~600' RKB. POOH. 19. RIH with 9 5/s" CIBP and tag tubing stub ~~600' RKB pick up to ~575' RKB and set CIBP in the 9 5/s" casing. 20. RIH with perforating gun armed with 2 ft of 4 SPF casing punch and tag CIBP fire guns. POOH. RD electric line. 21. Perform a JSA on cement mixing and pressure pumping. Rig up pump and lines. Test pump lines to 1000 psi. , NOTE: IF POSSIBLE A) Circulate clean, down the 13 ~/a" casing and up the 9~'a" casing with weighted fluid. Mix and pump ~41 bbl 15.9 ppg "G" cement slurry for a~300' cement plug in the 9 5/a" casing and the 9 5/s" X 13 3~$n casing annulus from -575' to ~275' RKB. B) If unable to circulate the 9 51a" X 13 3/s" casing annulus run in hole with work-string to CIBP pick up work- string ~10' and displace a-22 bbl 15.9 ppg "G° cement slurry for a~300' cement surFace ptug from ~575' to -275' RKB in the 9 5/s" casing only. 22. Pick up work-string -20' above TOC C~ ~275' RKB and circulate clean. POOH. Marethon Spark Well S-8 Rrocedures Page 2 8/20/2009 ~ ~ 23. WOC. Pertorm JSA for wire line operations. Run in hole with blind box and tag top of surtace cement piug @ ~275' RKB and record results. POOH. 24. RD. Well is abandoned. Marathon Spark Welf S-8 Procedures Page 3 8/20/2009 ~ ~:~~~~~~~~ RKB-MSL 115' WATER DEPTH 60' Max Angle = 45°@ 10009' TMD @ 11$55' ND @ 10970' PBTD @ 11360' MASTP 896 psi MIT 6/17/2009 API # 50-733-20233 ~ • Marathon Oil Company North Trading Bay Unit Spark Platform Well S-8 "CURRENT CONFIGURATION" All Depths measured RKB to top of equipment All depth are RKB unless otherwise noted Surface Casin~ @ 2046' 13 3/s" 61 ppf K55 Buttress 12.515" ID .1521 bbl/ft CMT 900 sks CTOC ~980' Gauge Hole Calculations Tubin~@ 10020' 31/s" 9.3 ppf N80 EUE 2.992" ID .00870 bbl/ft Packer Fluid 8.5 ppg Salt Water CMT behind 9 g/a" @ 9375' NOTE: Liner "LAP" Good to 1500 psi 3/13/72 & 3/14/72 Baker 9 5/a" DB Packer @ 9915' Flopetrol 1" GLM w/BK@ latches 2205 7503 3775 7940 4999 8378 5847 8814 6503 9221 7066 9656 TOL @ 9957' Tubing Tail 10020' Intermediate Casin~ @ 10892' 9 5/a" 47 ppf N80 &P110 Buttress 8.861" ID .0732 bbl/ft CMT 750 sks CTOC -8406' Gauge Hole Calculations Production Liner @ 11829' 7" 29 ppf N80 Buttress 6.184" ID .0371 bbl/ft CMT 550 sks CTOC @ --6844' Gauge Hole Calculations )C No More Than 100' Below ML ~a"&95ra'X133/s'=~41bblSlurry 5/a" only = ~22 bbl Slurry 575' RKB to -275' RKB 100' BML MAX ~rforate 9 ~/s" ~ ~575' RKB ~350' Additional Cement Plug ~1797' RKB to ~1447' RKB Perforate 3'/z" Tubing C~ ~1797' RKB ~24 bbls 15.9 °G° CMT Slur 8/9/2009 ~398' Intermediate Cement Plug ~2185' RKB to -1787' RKB Perforate 3 ~/s• Tubing ~ --2200' RKB ~24 bbls 15.9 pp "G" CMT Slur 8/9/2009 Perforated 3~" ~ ^-2185' RKB Tag TOC for Zone Plug ~~9661 RKB 8/8/2009 ~224' Bottom Hole Cement Plug ~9885' RKB to ~9661' RKB M&P 25 bbl 15.9 ppg "G" CMT Slurry Displaced TOC to 9661' RKB 8/6/2009 Perforated 3'/z' ~ -9885' RKB Set CIBP ~ ^-9885' RKB 8/5/2009 RIH Taggged Fill ~ -10020' RKB 1000 psi Test 95/e° Good Pollard Wire Line tagged fill @ 10421' Reported on 6/17/2009 MIT 7" Brown Hanger Q 10775' Fill 11,292' -11360' 4/06/92 11740' -11829' Cement EZBP Q 11360' PBTD = 11360' MARATHON SPARK S-8 CURRENT CONFIGURATION PAGE 1 8/10/2009 TMD = 11855' ~ t'~t41R1~,TWOPt RKB-MSL 115' WATER DEPTH 60' Max Angle = 45 ° @ 10009' TM D @ 11855' ND @ 10970' PBTD @ 11360' MASTP 896 psi MIT 6/17/2009 API # 50-733-20233 ~ Surtace Casing.@ 2046' 13 3/8" 61 ppf K55 Buttress 12.515" ID .1521 bbl/ft CMT 900 sks CTOC ~980' Gauge Hole Calculations Tubin~? Q 10020' 3~/2"9.3ppfN80EUE 2.992" ID .00870 bbl/ft Packer Fluid 8.5 ppg Salt Water CMT behind 9 5/s" @ 9375' NOTE: Liner "LAP" Good to 1500 psi 3/13/72 & 3/14/72 Baker 9 5/s" DB Packer C~? 9915' Flopetrol 1" GLM w/BK@ latches 2205 7503 3775 7940 4999 8378 5847 8814 6503 9221 7066 9656 TOL @ 9957' Tubing Tail 10020' Intermediate Casin~ Q 10892' 9 5/s" 47 ppf N80 &P110 ButtrPSS 8.861" ID .0732 bbl/ft CMT 750 sks CTOC ~8406' Gauge Hole Calculations Production,Liner @ 11829' 7" 29 ppf N80 Buttress 6.184" ID .0371 bbl/ft CMT 550 sks CTOC C~? ~6844' Gauge Hole Calculations MARATHON SPARK S-8 PROPOSED ~ Marathon Oil Company North Trading Bay Unit Spark PlatForm Well S-8 "PROPOSED" All Depths measured RKB to top of equipment All depth are RKB unless otherwise noted ~300' Surface Cement Plug TOC No More Than 100' Below ML 95/s'&9~/s'X13~/e'=-41bblSlurry 9 5/s° only =-22 bbl Slurry -575' RKB to -275' RKB 100' BML MAX Perforate 9 5/s' ~ ~575' RKB ~Cut and Pull 3'/s' Tubing ~-600' RKB ~ r j ~ t t.-. ~350' Additional Cement Plug ~x-+ r_ f``~~ ~1797' RKB to -1447' RKB ~ Pertorate 3'/z" Tubing ~ ~1797' RKB ~24 bbls 15.9 pp "G" CMT Slur 8/19/2009 Tagged TOC for Intermed C~D ~1797' RKB 8/9/2009 ~398' Intermediate Cement Plug ~~ •' ~2185' RKB to ~1787' RKB Perforate 3 ~' Tubing ~ --2200' RKB ~24 bbls 15.9 °G' CMT Slur ,,. ~ c~ 8/9/2009 Perforated 3~S° ~ ~2185' RKB Tagged TOC for Zone Plug ~~9661 RKB 8/8/2009 ~224' Bottom Hole Cement Plug ~9885' RKB to -9661' RKB M&P 25 bbl 15.9 ppg "G" CMT Slurry = Displaced TOC to 9661' RKB ~ 8/6/2009 ~ k f;; y Perforated 3'/s' ~-9885' RKB ~~. , .,.x, Set CIBP ~ -9885' RKB - 8/5/2009 RIH Taggged Fill C~D ~10020' RKB - 1000 psi Test 95/8" Good ~~~~, ~~~ i~~~~ !~~ti~;ti ~"~~~K~~ ~.tiiti Pollard Wire Line tagged fill @ 10421' Reported on 6/17/2009 MIT 7" Brown Hanger @ 10775' Fill 11,292' -11360' 4/06/92 11740' -11829' Cement EZBP @ 11360' PBTD = 11360' TMD = 11855' PAGE 1 8/10/2009 ~ ~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~~~ '~,~~~C~ DATE: August 18, 2009 P. I. Supervisor ~~ FROM: Lou Grimaldi SUBJECT: Wellbore plug integrity Verification Petroleum Inspector Intermediate Plug Marathon Oil Company Spark Platform, NTBU S-08 PTD #171-033, Sundry #309-144 Tuesdav, Auqust 18, 2009; I witnessed the attempted but failed pressure test of the intermediate plug on Marathon's Spark well S-08 in the North Trading Bay Unit. The plug had been set earlier and was reported to be a balanced cement plug. An 1100 psi pressure test was attempted with the tubing and annulus tied into each other which had a decline of approximately 25 psi per minute. The tubing and annulus were then tested separately with a lesser but unacceptable decline noted in both although the tubing seemed to be somewhat better. Dan Byrd (Marathon rep) will do some diagnostics tomorrow and if favorable call me to let me know outcome. If he can't find problem on surface equipment and problems downhole are evident Marathon will inform a Commission engineer. Attachments: None ~~'~~~~: ~~ ~ ~l :~ ~: ~~~~ 2009-0818_P&A_intermediate~lug_test_NTBU_5-08_lg.doc 1 of 1 ~ MEMORANDUM TO: Jim Regg ~~~ ~~~g~ ~ P. I. Supervisor jl FROM: Lou Grimaldi Petroleum Inspector . State of Alaska Alaska Oil and Gas Conservation Commission DATE: SUBJECT: ~., ~!~"`~ ~~~ ~M~s~r~ ~ ~1 `~ ,i ,< , ~ . August 12, 2009 Wellbore plug integrity Verification Marathon Oil Company Spark Platform, NTBU S-08 PTD #171-033, Sundry #309-144 " Sunda Au ust 9 2009: I witnessed the tag of top of cement by wireline of the bottom cement plug in Marathon's Spark platform well # S-08, North Trading Bay Unit. A 1 11/16-inch perForating assy (2ft @ 4spfl was run into the well to a depth of 9661 feet (wireline measurement) where it fetched up without any signs of going deeper or sticking. A second attempt to go deeper confirmed the cement top at ~ 9661 feet. The perforating assy was pulled up hole to 2187 feet (wireline measurement) and the tubing was perforated. Summarv: There appears to be a competent intermediate cement plug at 9721' R.K.B. (elevation 60') / 9661' W.L.M. (T.H.F.). Attachments: None 2009-0812_P&A_intermediate~lug_NTBU_5-08_lg. doc 1 of 1 C ~ Pag~ 1 ~f ~ Sch~roaartz, Guy L (DOA) Frorrao Paxton, Todd D. [tpa7cton a~marathonoil.comj ~ A~ ~~~$ Sent: Thursday, August 06, 200912:13 PM `~ ~ To: Schwartz, Guy L(DOA); Aubert, Wnton G(DOA) ~:' Cc: Laughlin, Gary A.; Stebbins, Tiffany A.; Berga, Pete; randy.elfis~proseiv.offshpre.com; ICeppers, Craig J.; Edelbrock, Roger; jeffthompson101@aol.com Subject: Re: S-8 Guy, You are cc~rr~ct on the step~ we'iB us~ to spot our bottorrr p@~g. Thaetks, ~~~~>`~~~~~~ ~'~ ~~~ ~ ~.~i ~~~~ ~'odr~ From: Schwartz, Guy L (DOA) To: Paxton, Todd D.; Aubert, Winton G(DOA) Cc: Laughlin, Gary A.; Stebbins, Tiffany A.; Berga, Pete; randy.ellis@proserv-offshore.com ; Keppers, Craig 7.; Edelbrock, Roger Sent: Wed Aug OS 17:58:5i 2009 Subject: RE: S-8 Todr~, 6 r~v~eyved th~ r~vised W~~I sketch for S-Q~ and I arr~ i~ ~greement with the path fo~wvarc! for the lowrer Cement p9ao~ as w~~l6r~~9 ora th~ dacaament. '9) S~tiir~g ~ C~~P ~t 9860' md 2) Perf t~at~ing ~t 986Q' md 3) ~ir~a~~~t~ ~9~ss G c~ra~~ni (24 bbls ~ for a 350' Pfu9- Th~ res~ ~f th~ P~ A sh~uld progress as outlin~d in the original procedure. Piease reply to this email to verify that I h~ve th~ ~t~ps ~c~rrect. G~y ~~F~~var9z 5er~~~r P~~roB~urn Er~gineer AO~~C 793-'~ 2~6 From: Paxton, Todd D. [mailto:tpaxton@marathonoil.com] Sent: Wednesday, August 05, 2009 2:29 PM To: Aubert, Winton G(DOA); Schwartz, Guy L(DOA) Cc: Laughlin, Gary A.; Stebbins, Tiffany A.; Berga, Pete; randy.ellis@proserv-offshore.com; Keppers, Craig J.; Edelbrock, Roger; Paxton, Todd D. Subject: FW: S-8 Importanaee High 1N~ton, To foilo~~,~-up our conversation earlier, hers's a revised V~1BD detaifi~~ our intentions. Please revie~v and cornment. Regards, Todd Pa~on 8/10/2009 ~ ~ Offshore Supervisor Marathon Oil Company 907-394-1322 From: Randy EI(is [mailto:randy.eliis@proserv-offshore.com] Sent: Wednesday, August O5, 2009 1:45 PM To: Laughlin, Gary A. Cc: Jeff Thompson; Paxton, Todd D.; Chuck Purdy; Fred Monus; Tammy Porterfieid sub3ect: s-s Importance: High Gary, I have attached a"revised Proposed" schematic for the S-8 weil. Page 2 af 2 We were unabfe to establish injection although we did make a wireline run to "'200' below the reported top perforations. 1 am suggesCing a CIBP just above the packer with ~25' cement on top, perforate and set a^'350' balanced plug above / in the tubing and the annulus. Thanks for the help and advise me as to your thoughts and or concerns, Randy Randy Ellis Abandonment Engineer ~ D: +1 713 343 9514 ~ ~~~~r~~+~ E: ~7 1 randy.ellis@proserv- ' offshore.com PROSERV OFFSHORE 13105 Northwest Freeway, Suite 250, Houston, TX 77040 T: +1 713 462 9990 F: +1 713 462 2007 www.proserv-offshore,com Please note our new cpmpany name and email address This email, any associated files and the information contained in them are confidential and is intended for the addressee(s) only. If you have received this message in error please notify fhe originator and delete the email immediately. The unauthorized use, disclosure, copying or alteration of this message is strictly forbidden. Emails to and from the company are monitored for operational reasons and in accordance with lawful business practices. Any opinions expressed are those of the individual and do not necessarily represent the views of the company. The company does not conclude contracts by email and all negotiations are subject to contract. We make every effort to maintain our network free from computer viruses, but accept no responsibility for any viruses which might be transferred by this email. g~1~~2~~9 t~~ ~~~~- 033 ~ Marathon Oil Company North Trading Bay Unit MA~aTHOM Spark PlatForm Well S-8 RKB-MSL 115' WATER DEPTH 60' ' ~ Max Angle = 45°@ 10009' ~ ° TMD Q 11855' ND @ 10970' PBTD @ 11360' MASTP 896 psi MIT 6/17/2009 API # 50-733-20233 Surface Casing @ 2046' 13 3/s° 61 ppf K55 Buttress 12.515" ID .1521 bbl/ft CMT 900 sks CTOC ~980' Gauge Hole Calculations Tubing @ 10020' 31/s" 9.3 ppt N80 EUE 2.992" ID .00870 bbl/ft Packer Fluid 8.5 ppg Salt Water CMT behind 9 5/e" @ 9375' NOTE: Liner "LAP" Good to 1500 psi 3/13/72 & 3/14/72 Perforations G2 10220'-10275' G3 10295'-10312' G4 10330'-10365' G5 10376'-10396' H 1 10418'10450' H 2 10492'-10526' H3 10583'-10706' H4 10706'-10758' Intermediate Casin~ @ 10892' 9 5/s" 47 ppf N80 &P110 Buttress 8.861" ID .0732 bbl/ft CMT 750 sks CTOC ~8406' Gauge Hole Calculations Pertorations West Foreland 10810'-842' West Foreland 10926'-948' West Foreland 11198'-230' West Foreland 11243'-300' West Foreland 11310'-320' Production Liner @ 11829' 7" 29 ppf N80 Buttress 6.184" ID .0371 bbl/ft CMT 550 sks CTOC @ ~6844' Gauge Hole Calculations Marathon Spark S-8 Proposed C,~3? `j, y8.s TMD = 11855' Page 1 g ~~ f~~s~:0 ~ 4 ~{ ~ ~~~~ P~~ All Depths measured RKB to top of equipment All depth are RKB unless otherwise noted )C No More Than 100' Below ML 6/a"&95/s'X133/s°=^-41bblSlurry 5/a° only = -22 bbl Slurry 575' RKB to -275' RKB 100' BML MAX and --350' Intermediate Cement Plug ~2200' RKB to --1850' RKB Perforate 3 ~/2' Tubing ~ ~2200' RKB ~24 bbls 15.9 pp "G" CMT Slur Flopetrol 1" GLM w/BKC~ latches 2205 7503 3775 7940 4999 8378 5847 8814 6503 9221 7066 9656 Baker 9 5/8" DB Packer @ 9915' ~Q~ ~ TOL @ 9957' _ _ Bail 25' Cement Leaving Toc C~ -9$60' Perforate 3~/s" Tubing C~ ~9860' RKB ~350' Bottom Hole Cement Plug -9860' RKB to -9510' RKB 7" Brown Hanger @ 10775' Pollard Wire Line tagged fill @ 10421' Reported on 6/17/2009 MIT Fill 11,292' -11360' 4/06/92 11740' -11829' Cement EZBP @ 11360' PBTD = 11360' / Marathon MARATNOR ® Alaska Production LLC Alaska Asset Team 3� P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/565-3076 August 3, 2009 Cathy Foerster `� 6 "' b� L State of Alaska Alaska Oil and Gas Conservation Commission 333 W. 7`l' Avenue, Suite 100 SoNeD U 1 I Anchorage, AK 99501-3539 Re: 20 AAC 25.300 (Request for Information) — Status of Oil and Gas Wells Dear Ms. Foerster: In response to your June 22, 2009 letter requesting a plan of action and timing for such activities associated with the referenced list of inactive wells, please find attached a table with the requested information. As indicated in the table, Marathon anticipates a measured program of P&A activities, averaging three -to -five well abandonments per year. Marathon has already begun such a program with its offshore wells, beginning with the Spark Platform wells in 2009. All of the onshore wells on the list are within active oil and gas leases that are regularly visited and inspected. Marathon anticipates updating plans for its inactive wells in the appropriate annual Plan of Development for each property. Any and all forward activities are subject to funding approval. Please also note that your June 22 letter erroneously referenced "KU 41-08". We believe that your June 22 letter reference to well "KU 41-08" was a typo and is intended to refer to Well KU 41-18. This well matches the referenced drilling permit (171-010). Should you have any questions or wish to review the attached plans with us, please feel free to call Lyndon Ibele at (907) 565-3042. Sincerely, �a Carri Lockhart Alaska Asset Team Manager Attachment: Marathon plan for list of inactive wells cc: B. Schoffmann L. Ibele K. Skiba T. Stebbins Well Files Marathon Oil Company, Alaska Asset Team Anticipated schedule of well abandonment activities Confidential 8/3/2009 Timing lWell I Permit No. I Pad or location 2009-2011 S-1 RD 174-005 Spark S-2RD 174-024 Spark S-3 169-011 Spark S-4 169-034 Spark S-5 169-039 Spark S-7RD 169-096 Spark S-8 171-033 Spark S-9 174-027 Spark TS -1 168-048 Spurr TS -2 168-050 Spurr TS -3RD 168-065 Spurr TS -4 168-066 Spurr TS -6 168-090 Spurr TS-7RD 169-026 Spurr TS -8 169-027 Spurr TS -9 169-092 Spurr 2012-2015 BC 7 176-006 BCU Pad 7 CLU 3 181-058 CLU Pad 3 CLU 4 187-034 CLU Pad 3 KU 33-30 159-015 KGF pad 33-30 KU 42-30 181-091 KGF pad 33-30 KU 44-30 168-071 KGF pad 33-30 SU 23-15 161-014 Sterling Unit KU 41-18 171-010 KGF pad 41-18 KU 43-12 169-087 KGF pad 14-6 KU 11-6 165-017 KGF pad 34-31 KU 21-5 169-035 KGF pad 43-32 WF1-21rd 193-183 West Fork WF2-21 192-010 West Fork , . • °~°~ ~ ~ ~ C°~ ~`~ ~` '~ /~ / ~~ ~~ ~ ~~ ~' ~~y ~ ~ ~~ ~~~~ ~!.1 ~ ~ ~ ~~ ^ ~ ~ ~~~ ~ ~ `~ i° SARAH PAUN, GOVERNOR ~ _. ~d ~t ~~+ ~ ~S~ 0~ ~D V[~-7 333 W. 7thAVENUE, SUITE 100 CO1~T5ERQATIOI~T COni1~II55101~ ~ ANCHORAGE,ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Tiffany Stebbins Regulatory Compliance Rep. Marathon Oil Company P.O. Box 190168 Anchorage, Alaska 99519-6168 1 1"~~~ Re: G-NE/Hemlock-NE Oil; W Foreland Oil t~ North ZYading Bay Unit S-08 Sundry Number: 309-144 ~~~~ ~ ~ "~ ~~~. ~. ~ 2D0,~ Dear Ms. Stebbins: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Corrunission 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 Comrnission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the ne~ worlflng day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. h~ chair DATED this ~ day of July, 2009 Encl. , ~ , ~ d'l ~ ~ APR 2 ~, 20~9 ~ ' ~ ~ ~ STATE OF ALASKA ~ ~'~('V ,~~ti ~ ALAS OIL AND GAS CONSERVATION COMM ION ~laska Oil & Gas C~~~. ~~s~!~:;s~~n APPLICATION FOR SUNDRY APPROVALS A~+~~+~~~~~ ~n Aac ~s ~Rn 1. Type of Request: Abandon ~. Suspend ^ Operational shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ~ Plug Perforations ~ Stimulate ~ Time Extension [] Change approved program ^ Pull Tubing ~ Perforate New Pool ^ Re-enter Suspended Well ~ 2. Operator Name: 4. Current Well Class 5. Permit to Drill Number: Marathon Oil Company Development ~, Exploratory ~ 171-033-0 • 3. Address Stratigraphic ~ Service ~ 6. API Number: P.O. Box 190168, Anchorage, AK 99519-6168 50-733-20233-00-00 ' ' 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: NOI'th TYadltlg Bay Ulllt 5-08 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; W FORELAND OIL ' 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,855' • 10,970' • 11,360' 10,519' 11,360', 11,740-11,829' Fill 11,327-11,360' Casing Length Size MD ND Burst Collapse Structural Conductor Surface 2,046' 13 3/8" 2,046' 2,022' Intermediate 10,892' 9 5/8" 10,892' 10,087' Production Liner 1,872' 7" 11,829' 10,946' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,220 - 11,320' 9,478 - 10,482' 3 1/2" N-80 Buttress 10,020' Packers and SSSV Type: Camco TRDP 1A SSSV Packers and SSSV MD (ft): 282' Baker DB Packer 9,915' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ~ Exploratory ^ Development ^~ ' Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: Oil ~ Gas ^ Plugged ^ Abandoned ^~ ' 17. Verbal Approval: Date: WAG ^ GINJ ~ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tiffany Stebbins Printed Name Tiffany Stebbins Title Regulatory Compliance Rep. Signature ~ Phone D te ~ 907-565-3043 - p~ D -' ~ ~ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3~- /'~ Plug Integrity ~ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: -~ ~'1~~'ev`n~t ~~? vr~evL~ P lt~y~ il~4c.~~~.,~' cz~~pr'o/c-~ ~ls ~tio- ~C Z~.IIZ~~.~ iJ l Subsequent Form Required: /cY °4D~~' APPROVED BY ~~~ Approved by: COMMISSIONER THE COMMISSION Date: l ~ r ~q o ~ ,~ y u ~'7 Form 10-403 Revised 06/20Q6~ ~ C~~ ~-lSubmit irT ~t~~ }: t ~.~~I~ ~~, ~«~~ ~ ~ mog _ a ° • • MARATHON OIL COMPANY NORTH TRADING BAY UNIT SPARK PLATFORM WELL S-8 ABANDONMENT PROCEDURE 06/22/2009 WELL DATA API # 50-733-20233 Elevation: 115' RKB - MSL Production Liner: 7" 29 ppf N80 Buttress ~ 11829' Water Depth: 60' 6.184" ID .0372 bbl/ft Max Angle: 45° ~ 10009' CMT 550 sks TMD: 11855' CTOC ~ 6844' Gauge Hole ND: 10970' TOL: C~ 9957' MASTP: 896 psi MIT 6/17/2009 Tubing: 3~2" 9.3 ppf N80 ~ 10020' Packer fluid: 8.5 ppg Salt Water 2.992" ID .0087 bbl/ft SurFace Casing: 13 3/8" 61 ppf Buttress C~ 2046' SCSSV: Camco TRDP-IA- SCSSV ~ 282' 13.515" ID .1521 bbl/ft CMT 900 sks Packer: Baker DB packer @ 9915' Intermediate: CTOC C~ 980' Gauge Hole PerForations: 10220' - 11320' 9 5/e" 47 ppf N80 & P110 ~ 10892' Buttress 8.861" ID .0732 bbl/ft Fill: C~ 10421' MIT 6/17/2009 CMT 750 sks CTOC ~ 8406' Gauge Hole PBTD: 11360' CURRENT STATUS 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 the operation of tree valves, flanges. Repair as needed. 2. Mobilize abandonment crew and equipment to location. Perform JSA and rig up equipment. 3. Check tubing and casings for pressure. Bleed off any pressure through gas buster. Fill and test casings with weighted fluid. Record results. Note: Pollard Wire Line ran in hole to 10421' RKB and tagged fill as reported on 6/17/2009. 4. Perform JSA for wireline operations. Pressure up on SCSSV control line and lock open. Rig Up wireline lubricator and test to 1500 psi. RIH with gauge ring to the EOT at ~10020' pull all plugs as necessary. POOH. Marathon Spark Well S-8 Procedures Page 1 6/30/2009 . • 5. PerForm JSA on cement mixing and pressure pumping. Rig up pump and lines on tubing. Test pump lines to 1500 psi. Establish an injection rate while monitoring the 9 5/a" casing for possible communications. Record injection rate and pressure. 6. Mix and pump -17 bbl 15.9 ppg "G" cement slurry and squeeze perForations to 1000 psi over injection pressure or until top of cement is displaced to a depth of -9763' RKB. 7. WOC. Pressure test cement plug to 1500 psi. Document results using a continuous pressure chart recorder. 8. Perform JSA on electric line operations and explosives 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 top of cement for bottom hole plug @~9763' RKB and record results. Pick up to ~2200' RKB and shoot tubing. 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 1/2" tubing while taking returns up the 9 5/s" casing annulus. Mix and pump a~24 bbl 15.9 ppg "G" cement slurry for a~350' cement plug from ~2200' RKB to ~1850' RKB in the 3 1/2" tubing and in the 31h" X 9 5/s" casing annulus. Displace with weighted fluid. 10. WOC and test to 1000 psi. Document results using a continuous pressure chart recorder. 11. Perform JSA on electric line operation and explosive handling. Rig up electric line lubricator and test to 1000 psi. RIH with jet cutter and tag top of cement for intermediate cement plug @~1850' RKB and record results. Pick up to ~600' RKB and cut 3 1h" tubing. POOH. 12. Rig down tree. 13. Pertorm 1SA on proper pipe handing procedures. Pull 3 1h" tubing and check for N.O.R.M. 14. Pertorm JSA on proper electric line operation and explosives 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' RKB pick up to ~575' RKB and set CIBP in the 9 5/s" casing. 16. RIH with perForating gun armed with 2 ft of 4 SPF casing punch and tag CIBP fire guns. POOH. RD electric line. 17. Pertorm a JSA on cement mixing and pressure pumping. Rig up pump and lines. Test pump lines to 1000 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 bbi 15.9 ppg "G" cement slurry for a~300' cement plug in the 9 5/s" casing and the 9 5/s" X 13 3/s" casing annulus from ~575' to ~275' RKB. B) If unable to circulate the 9 5/a" X 13 3/s" casing annulus run in hole with work-string to CIBP pick up work- string -10' and displace a~22 bbl 15.9 ppg "G" cement slurry for a~300' cement surface plug from -575' to ~275' RKB in the 9 5/e" casing only. 18. Pick up work-string ~20' above TOC @~275' RKB and circulate clean. POOH. 19. WOC. Pertorm 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 abandoned. Marathon Spark Well S-8 Procedures Page 2 6/30/2009 s MaR~THflN ;:•~ RKB-MSL 115' WATER DEPTH 60' Max Angle = 45 ° C~ 10009' TMD ~ 11855' TVD C~ 10970' PBTD ~ 11360' MASTP 896 psi MIT 6/17/2009 API # 50-733-20233 Surtace Casing C~ 2046' 13 3/s" 61 ppf Buttress CMT 900 sks CTOC ~ 980' Gauge Hole Calculations Tubing C~ 10020' 31h"9.3ppfN80EUE Pertorations G2 10220'-10275' G3 10295'-10312' G4 10330'-10365' G5 10376'-10396' H 1 10418' 10450' H2 10492'-10526' H3 10583'-10706' H4 10706'-10758' NOTE: Liner "LAP" Good to 1500 psi 3/13/72 & 3/14/72 Intermediate Casin,g ~ 10892' 9 5/s" 47 ppf N80 &P110 Buttress CMT 750 sks CTOC - 8406' Gauge Hole Calculations Pertorations West Foreland 10810'-842' West Foreland 10926'-948' West Foreland 11198'-230' West Foreland 11243'-300' West Foreland 11310'-320' Production Liner C~ 11829' 7" 29 ppf N80 Buttress TOL = 9957' CMT 550 sks CTOC @ -6844' Gauge Hole Calculations Marathon Oil Company North Trading Bay Unit Spark PlatForm Weil S-8 "CURRENT" All Depths measured RKB to top of equipment All depths are RKB unless otherwise noted Camco TRDP 1A SCSSV, 2.812" ID @ 282' Flopetrol 1" GLM w/BN 2205 7503 3775 7940 4999 8378 5847 8814 6503 9221 7066 9656 TOC behind 9 5/e" @ 9375' Baker 9 5/s" DB Packer @ 9915' Packer Fluid 8.5 ppg Salt Water TOL @ 9957' Tubing Tail 10020' Pollard Wire Line tagged fil! C~ 10421' Reported on 6/17/2009 MIT 7" Brown Hanger @ 10775' Fill to 11,292' - 11360' 4/06/92 11740' - 11829' Cement EZBP @ 11360' PBTD @ 11360' Marathon Spark S-8 Current Page 1 6/22/2009 TMD 11855' w ~ ~A~TM~M R :~ RKB-MSL 115' WATER DEPTH 60' Max Angie = 45 ° C 10009' TMD ~ 11855' TVD ~ 10970' PBTD C~4 11360' MASTP 896 psi MIT 6/17/2009 API # 50-733-20233 ~ Surface Casing @ 2046' 13 3/a" 61 ppf K55 Buttress 12.515" ID .1521 bbl/ft CMT 900 sks CTOC -980' Gauge Hole Calculations Tubing ~ 10020' 31h"9.3ppfN80EUE 2.992" ID .00870 bbl/ft Packer Fluid 8.5 ppg Salt Water CMT behind 9 5/s" @ 9375' NOTE: Liner "LAP" Good to 1500 psi 3/13/72 & 3/14/72 Pertorations G2 10220'-10275' G3 10295'-10312' G4 10330'-10365' G5 10376'-10396' H 1 10418' 10450' H2 10492'-10526' H3 10583'-10706' H4 10706'-10758' Intermediate Casin~ ~ 10892' 9 5/a" 47 ppf N80 &P110 Buttress 8.861" ID .0732 bbl/ft CMT 750 sks CTOC ~8406' Gauge Hole Calculations Pertorations West Foreland 10810'-842' West Foreland 10926'-948' West Foreland 11198'-230' West Foreland 11243'-300' West Foreland 11310'-320' Marathon Oil Company North Trading Bay Unit Spark Platform Well S-8 "PROPOSED" Production Liner @ 11829' 7" 29 ppf N80 Buttress 6.184" ID .0371 bbl/ft CMT 550 sks CTOC @ -6844' Gauge Hole Calculations Marathon Spark S-S Proposed ~ All Depths measured RKB to top of equipment All depth are RKB unless otherwise noted -300' Surtace Cement Plug TOC No More Than 100' Below ML 95/s"&95/s"X133/s"=~41bblSlurry 9 5/s" only =~22 bbl Slurry --575' RKB to ~275' RKB 100' BML MAX Pertorate 9 5/a" C~4 ~575' RKB -350' Intermediate Cement Plug -2200' RKB to -1850' RKB Pertorate 3 ~/s" Tubing ~ ~2200' RKB -24 bbls 15.9 pp "G" CMT Slurry Flopetrol 1" GLM w/BK@ latches 2205 7503 3775 7940 4999 8378 5847 8814 6503 9221 7066 9656 Baker 9 5/a" DB Packer @ 9915' TOL @ 9957' Tubing Tail 10020' -658' Bottom Hole Cement Plug -10421' RKB to ~9763' RKB 17 bbls 15.9 pp "G" CMT Slurry Pollard Wire Line tagged fill ~ 10421' Reported on 6/17/2009 MIT 7" Brown Hanger @ 10775' TMD = 11855' Fill 11,292' - 11360' 4/06/92 11740' -11829' Cement EZBP @ 11360' PBTD = 11360' Page 1 6/22/2009 • • Spark Platform Abandonment Review North Trading Bay Unit Marathon Oil Company Well NTBU S-OlRD (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 S-OS (PTD169-039) - Sundry AppGcation 309-142 Well NTBU S-07RD (PTD169-096) - Sundry Application 309-143 ,~~Vell NTBU 5-08 (PTD171-033) - Sundry Application 309-144 Well NTBU 5-09 (PTD174-027) - Sundry Appiication 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 bapd 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. ~ ~ ~y ¢ a • ~ ~~~~st ~~as ~ ~ :~ , ~ ~~ ~ :~ ~ Cf : 0.0783624 A.e. Zea.ss~ awa U ~ :01/37/7982 . . t6 :0228/2014 Fnal l~te : 49.9199 bbVd dm Rotl. : 77508.9 M%~I p^ . . GLm ~te : 01/31/t992 . ... . . f~serves :1086.35~A~W ~ . . . ~ . . fbserves ~e1e : 02/28~2014 R . ~ . . . . . ~ . . B.1R : 188052 Mtl~l I .. . . Forecasl BWed 6Y : F+ate . . . . ~B Farecast C~te : N t SeveA ~ ~ . F~serveType : Wne ~ 10' 1 9:a ~ ~ , ~~ , , - 1 ` ' 1 .~,~ a S IO~y a L ~ ~v„".~.. ~ . . . . . . ~~ ~w 10'-~r--r-~~~-~- -- - t96907~72T374757677787980878283868588678889908192939495969798940OD10203040506070809701172~314 04TE Several attempts have been made at sustaining substantial gas production from the platform but none of them have lasted more than a year of regular production, and you have to use a pretty broad definition of regular to get that as they were only able to maintain production for an entire month a handful of times in the 11 plus years they attempted gas production. Conclusion: The Spark Platform appears to be well beyond its economic life and permanently abandoning the wells at this time, to prepare for a future platform and casing removal , appears to be the prudent course of action. ~ ' D.S. Roby~~/~' : Sr. Reservoir~ngineer April 23, 2009 - Revised July 2, 2009 • W. n Prod~n Manaaer Alaska Fiegion J Domesuc ProducUOn ~ Marathon M4RATXON Oil Company P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 March 23, 1992 Mr. Harold Heinze, Commissioner Department of Naturai Resources 400 Willoughby Avenue, 5th Floor Juneau AK 99801-1796 Dear Commissioner: SUSPENSION OF PRODUCTION OR OPERATIONS Enclosed for processing is an application for suspension of production or operations and a fiiing fee or 550. Pursuant to 11 AAC 82.670 Suspension of Production or Operations, Marathon Oil Company, P. 0. Box 190168, Anchorage, Alaska 99519, hereby requests approval of suspension of production or operations for a two-year period commencing June l, 1992. The leases affected are ADL-17597, ADL-18776, and ADL-35431. The lands within the North Trading Bay Unit, as shown on Exhibits 1 and 2, are described as follows: T10N, R13W, Sec. 26: SW;, SZ NW;; Sec. 27: SE;, SZ NE;; Sec. 34: EZ; Sec. 35: WZ. ~ Two platforms have produced from the Unit to an onshore processing facility at Granite Point. The Spark Platform, purchased by Marathon in 1984, was recently shut in because it was uneconomic to operate. The Spurr Platform. purchased by Marathon and Unocal in 1988, is currently operating at a loss. Oil production from Spark Platform was approximately 330 BOPD prior to shut-in, while Spurr Platform is currently producing about 250 BOPD. Spark Platform Overall, Spark has been uneconomic since 1986 when oil prices dropped dramatically. Since that time Spark has lost ~2.0 MM on an operating income basis as shown in Exhibit 3. Not included in this amount is the g6.7 MM invested during that time. The break-even oil price for 1991 was over ~20 per barrel not including the cost of investment recoupment through OD&A. Since reserves are defined as economically producibie, 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 weil on the Spurr Platform which has recovered 3.5 BCF. Current plans call for developing remaining gas reserves by recompleting Spark Platform Wells A subsidiary of USX Corooration Mr. Harold Neinz~ ~ March 23, 1992 Page 2 S-2RD and S-8 uphoie near the gas reservoir structure top. In addition, gas separation and dehydration facilities and compression wiil need to be installed on the platform. Proven Unit gas reserves are committed to both Unocal and Marathon con- tracts. Because both companies currently have sufficient deliverability to ,L 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 ~6.9 MM incurred since 1988 are not inciuded in this caiculation. As with Spark, the break-even oil price for 1991 was over S20 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. _~ '°``~ Losses are expected to i ncrease i n 1992 to $0.8 MM as a resul t of 1 ower ~ ,~`~ prnduction and a projected ~12.00 per barrel oil price. This does not ` include the substantial -monies required to stay in compliance with oil ~ spill and process hazard management regulations recently enacted. These losses are not acceptable and as a resuit Spurr Platform and the attendant onshore production facility at Granite Point must be shut in. Until recently, the non-unit area developed by Spurr was thought to contain significant undeveioped reserves. Evaluation of 3-D seismic and the performance of Monopod Platform Well A-28RD now indicates no further economic deveiopment potential exists. With once planned development potential eliminated, Spurr has no further utility for oil production under current economic conditions. Future gas production from Spurr is possible and wiil be evaluated as part of the overail deveiopment scheme. Marathon's Plans During Two-Year Susoension The main reason for the requested two-year suspension is to eliminate unnecessary economic losses until Marathon develops Unit gas. During this two-year suspension Marathon will continue to evaiuate the gas market to determine the optimum timing of gas development. The gas market is dynamic and Marathon constantly evaluates suppiy and demand. Marathon wiil also monitor oii prices to determine if resumption of oil production is feasible and will review alternate production strategies which could reduce operat- ing costs. This is applicable to both platforms. Mr. Haroid Hein~ • March 23, i992 Page 3 A major undertaking during this suspension period will be the evaiuation of abandonmeni options for Spark, Spurr and Granite Point Production Facility. This evaluation wiil attempt to optimize method and timing of abandonment. As no platform has been abandoned in the Cook Inlet to date, much research needs to be done prior to abandoning the first structure. It is stressed that this work does not preciude the planned resumption of operations at Spark or the possible resumption at Spurr. A revised plan of deveiopment reflecting the changes proposed in this application is being sent under separate cover. If there are questions or if further information is needed, please contact R. J. Murphy at 564-6425. Thank you for considering this application. Sincerely, . -__.~ -v ~ ~;_'1~~.~`~ W. Watson cc: Mr. James Eason Department of Naturai Resources Division of Oil and Gas P. 0. Box 107034 Anchorage AK 99510-7034 A:LAND2/MH07/6GP r S-9 We v~iill be attempting to remove a fish located approximately 4' below the tubing hanger stuck in the early 90's from S-9. Thanks Gary ~ U ~ U ~Marathon Oil ~ W~Ti ~. ~S-8 ~ Field:~Spar~ ~06-17-2009 ~ Pressure (psia) 0 1000 - Pressure-Temperature Profile 1. Going in hole to 10420' MD 2. Well Shut-In _ _. 2000 3000 - - 4000 a ~ ' 5000 - - - - ~ ~ d ~ .~ t ~ 6000 - - i - ~ 7000 - - i - 000 -- --- ~ ~ - : 9000 - -- - - 10000 - - 11000 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 Temperature (Deg. F) ~ Pressure - Perfs 13 3/8" 9 5/8" 7" °-----_TBG p Mandrel Temperature a Marathon OilCompany March 1, 2009 Commissioner: Cathy Foerster Alaska Oii and Gas Conservation Commission 333 W. 7'h Avenue Suite 100 Anchorage, AK 99501-3539 \-�1-a 33 Alaska Asset Team North America Production Operations P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/565-3076 Re: Notice of Revised Suspended Wells Regulations and Request For Verification of Suspended and Shut-in Well Information Dear Cathy: MAR 0 2 2009 oil a s _, cons. Marathon received your letter dated January 28, 2009 (Cert # 7005 1820 00012499 5999) requesting Marathon to validate information contained within it. Marathon has reviewed the data and found it to be accurate. Marathon is in the processes of reviewing and addressing the new regulatory requirements in "20 AAC 25.110 Suspended wells". If you have any questions, please do not hesitate to contact Gary Laughlin at 907-565-3036 or email him at galaughlin@marathonoi1.com. Sincerely, Ben Schoffmann Operations Manager MARATHON OIL COMPANY 'll11A;u'fs L)Ir pf�1�5113 �I ALASKA OIL AND GAS CONSERVATION COMUSSION January 28, 2009 CERTIFIED MAIL RETURN RECEIPT REQUESTED 7005 1820 0001 2499 5999 Ben Schoffman Marathon Oil Company PO Box 196168 Anchorage AK 99519-6168 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Notice of Revised Suspended Wells Regulations and Request for Verification of Suspended and Shut -In Well SCUM I}�. Dear Mr. Schoffman: Enclosed are the Alaska Oil and Gas Conservation Commission's revised regulations regarding suspended wells (i.e., 20 AAC 25.110). Also enclosed are a list of suspended wells and a list of long term shut-in wells operated by Marathon Oil Company. For each list, please verify the information for each well, and provide any corrections by April 1, 2009. Location inspections required under 20 AAC 25.110 should be coordinated with Jim Regg at 907-793-1236 or jim.regg@alaska.gov. If you have any questions regarding this notice, please contact Tom Maunder at 907-793- 1250 or tom.maunder@alaska.gov. Sincerely, *le�-14644' Cathy P. Foerster Commissioner Enclosures Ir Er . . Er .. Ln Ir 45g L USE Er Tru Postage i $0.59 / JPS PosT9 ocertified F-$2.70 En $2.20 (E ,i ? Iq I o nj ( ,� Reevut� $0.00 %�C (NN / ����'' QQ 9g5� a TOW Postage f Ben Schoffmanl o e Marathon Oil Company tom- i%1a� PO Box 196168 orpowurMo ---'va«; An AK 99519-616 K Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. it 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. t. Article Addressed to: Ben Schoffman Marathon Oil Company PO Box 196168 Anchorage AK 99519-6168 A.- X�1 Agent � ` 11 Addressee B. Received by (Pnib d Name) C. 7of Delivi ry 14-7 D. Is delive/y address differen{from item 1? 0 Yes If YES, enter delivery address below: 0 No Irvice Type Certified Mail Express Mail 0 Registered Return Receipt for Merchandise 0 Insured Mail 0 C.O.D. 4. Restricted Delivery? (Extra Fee) 0 Yes 2. Article Number (Transfer from service label) li ?005 1820 0001 2499 5999 PS Form 3811, February 2004 Domestic Retum Receipt 02595 -02 -M -t540 Operator Suspended and Shut In Wells MARATHON OIL CO Field Current Date of Permit API Number Well Name Status Status Surface Location .................................................... Lease(s)................................... 'EXPLORATORY 202-129-0 50-133-20517-00-00 ABALONE 1 SUSP 3/9/2003 250 FSL 3000 FEL Sec 29 T 2 N R 12 W SM FEE-OSMAR KAS/LOF 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 ADLO384529 ADL0384534 KENAI C.L.U. 206-121-0 50-133-20563-00-00 CANNERY LOOP UNIT 12 SUSP 9/8/2006 2490 FSL 2365 FWL Sec 4 T 5 N R 11 W SM ADL0324602 ADL0359153 ADL0365454 FEE-TR119 N/NILCHIK 208-023-0 50-133-20574-00-00 NINILCHIK UNIT G OSKOLKOFF 7 SUSP 6/12/2008 2969 FSL 3023 FEL Sec 23 T 1 N R 13 W SM ADL0389180 STERLING 161-014-0 50-133-10012-00-00 STERLING UNIT 23-15 SUSP 10/23/1966 2715 FNL 1520 FWL Sec 15 T 5 N R 10 W SM FEDA028135 TRADING BAY 174-005-0 50-733-20158-01-00 N TRADING BAY UNIT S-01 RD SI 1/25/1992 2608 FSL 2495 FEL Sec 26 T ION R 13W SM ADL0035431 169-011-0 50-733-20175-00-00 N TRADING BAY UNIT S-03 SI 2/25/1992 2613 FSL 2495 FEL Sec 26 T ION R 13 W SM ADL0035431 169-096-0 50-733-20197-01-00 N TRADING BAY UNIT S-07RD SI 2/25/1992 2612 FSL 2488 FEL Sec 26 T ION R 13W SM ADL0018776 171-033-0 50-733-20233-00-00 N TRADING BAY UNIT S-08 SI 1/25/1992 2577 FSL 2566 FEL Sec 26 T ION R 13W SM ADL0017597 174-027-0 50-733-20265-00-00 N TRADING BAY UNIT S-09 SI 1/25/1992 2570 FSL 2563 FEL Sec 26 T ION R 13W SM ADL0017597 168-048-0 50-733-20120-00-00 N TRADING BAY UNIT SPR -01 SUSP 8/18/1992 615 FNL 2072 FEL Sec 34 T ION R 13W SM ADL0017597 168-050-0 50-733-20122-00-00 N TRADING BAY UNIT SPR -02 SUSP 8/19/1992 664 FNL 2007 FEL Sec 34 T ION R 13W SM ADL0017597 168-065-0 50-733-20133-00-00 N TRADING BAY UNIT SPR -03 SUSP 8/18/1992 618 FNL 2068 FEL Sec 34 T ION R 13W SM ADL0017597 168-066-0 50-733-20134-00-00 N TRADING BAY UNIT SPR -04 SUSP 8/13/1992 666 FNL 2003 FEL Sec 34 T ION R 13 W SM ADL0017597 168-090-0 50-733-20153-00-00 N TRADING BAY UNIT SPR -06 SUSP 8/10/1992 642 FNL 2072 FEL Sec 34 T 10 N R 13W SM ADL0017597 169-026-0 50-733-20181-00-00 N TRADING BAY UNIT SPR -07 SI 8/26/1992 622 FNL 2068 FEL Sec 34 T ION R 13W SM ADL0017597 169-027-0 50-733-20182-00-00 N TRADING BAY UNIT SPR -08 SUSP 8/26/1992 664 FNL 2000 FEL Sec 34 T ION R 13 W SM ADL0017597 169-092-0 50-733-20200-00-00 N TRADING BAY UNIT SPR -09 SUSP 8/18/1992 618 FNL 2076 FEL Sec 34 T ION R 13W SM ADL0017597 Wednesday, January 14, 2009 ,* , ~ ~ EXHIBIT 1 ATTACHED ANO MAOE A PART OF UNIT AGAEL~~lENT FOR THE flEVELOPMENT AND OpERAT10N OF THE NORTH TRADING 8AY UNIT AREA -~ NORTH TRADtNG BAY UNIT BOUNDARY PRIOR 7Q AUGUST 2, ~976 '~" ~ 1 27\ zs + T 10 iU R 13 V~/ T9N R13W MARATHON ~~~\ \ aDt~~sa~~ _ ~ ~ ~ NORTH TRADING BAY UNIT 80UN~ AND HEMLOCK ~ 'G' FORMATIO. PART1CtPATING AREA BOUNDAR I EFFECTIVE AUGUST 2, 1976 ~ 34 \35 ~ ARATHp UNION MARATHON \ADL•1759~~ \AOL 18776.\ MAPSOURCE OtVIS10N OF IANDS PROTRACTION SHEET. GAID NO. S•13•5 STATE Oll ANO GAS LEASES AD~-17597, AOl•18776, QOl•35431 LEGENC O ~~ TRACT NO. PARTICIPATING AHEA NORTH TAADING 8AY UNIT AAEA HEI~LOCK & ~G~ PARTiC1PATiNG aREA ~ ~ COOK INLET, ALASKA PARTiC1PATiNG AREA LATEST CONTRACTION DATE: AUGUST 2, 1976 ' OWNERSHiP AS OF:SEPT. 1, 1988 ~AA~A ,T~i~~ ~1L C~~iPA~Y - . . ~~ ~ , ~ ~ . ~ - - ~ae :.aee ~.aae a.aee .aee _.~ae :.zae "' uARATHON OIL C;,1~pNy ~ '' aa• s. eae `iOFtTH ~ TRADINC BAY l,tiTf I " ~?CHIBIT ? ~ ADL ~Sa3~ ' ` 'OYALTY P,EDUC"I0~ ~ ' m 9 ~ m ~ I m ~ I . I I ~ ~~ ~' ~~ - I 'm 9 ~, i I ;; --_: ~~ ~a ~ .` ``~ ~i \~\ ~~ ` o ~ ~, ~ 9i 9~ 9L a~ ~~ 91 91 v L ,; '? ~"°+s~ ~ - - ~v _~3 ~ " , ~\ : ~ i ~! , ~; ~ / ~••~ ' e9~31 •; ,' i ~ / I / '!' 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Subject: FW: Conversation Follow-up Importance: High Sensitivity: Confidential Attachments: Picture (Enhanced Metafile); Picture (Enhanced Metafile) • «~:~. .,.~~, {~` . .. . .., ~~ .. , ~_~ _ ,._ From: Laughlin, Gary A, Sen#: Monday, May 18, 2009 8:21 AM To: (winton_aubert@admin.state.ak.us) Cc: Laughlin, Gary A. Subied: Conversation Follow-up Importance: High Seeaitivity; Confidontial VNinton, 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" for the Spark Platform sundries submitted in April 2409. We are currently running a gauge ring a~d temperature surveys for all wells on the Spark Platform. I expect to see the results Tuesday or Wednesday next week. After reviewing, I will send you an email on the order we plan to abandon the wells. We plan to have simultaneous well abandonment operations. The anly cerkainty 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: • ~ ~ a~ ~ ~ ~ ~ c ~ pp a~ c ~ C ~ ~ ~ ~ bA N ' ~. ~ O •y '~ c C~ ~ O ~ ~ N 6~ ~ ~ ~ N ~"r C O ~ ~ ~ N ~ ~ N ~ ~ "" Q .~ ,s: ~ ~' ~ w L ur N rn = ~ r ~ ~ ~ -T. ~ 'D ~ ~ N ~ ~.~' '~S" `t ~ / Q N ~ U ~ G~ '~~ N ~ N ~ ~ ~ f •~ ~ e ~ O ~ ir.l ~ ~- ~ ~ j } O ~ = ..~ ~: ~ Q fA ~ - i ~. i. .'I ~ ~ ~ ~.i ~ Y ~ ~ ., '~ , g. ~ _ G ~ ~ ~ • i . ~ "-aY Y ^ y 3? y S ~ ~ ~r ~ .: ~ ~~ _ c} 1 13 ri ~ ~ .,_. ~ ~ ~ ,~. ~ G i ~y ~ ~y ~ A~~ - j. =~ ~ ~~ Z ./~ . ~ y ~~: MU O ~-. ~~ t~= '. ; ~ ~ ~ ~ 4: : t'd ~~~ Q~ U r ~'-~` f '. ti • ~ ~ g = r . A e =y fy ~ c~ 72r~ ~ :ir~~~ °} V ~ a ~ : ~ ' ~ ~~- • ,~,i ~ ~ . . _ _ i Y '~' '_~a.~ ~.. 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N · ~ STATE OF ALASKA ALASKA OIL AND GAS cONSERVATION COMMIS31L,.,N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate __ Plugging __ Pull tubing __ Alter casing __ Repair well __ Pedorate ~ Other X...~. -¢'",,,~'¢,¢ ;~" -" / ~ 2. Name of Operator / 5. Type of Well: Marathon 0i1 Company l Development X~ Exploratory __ 3. Address Stratigraphic_ P.O. Box 102380 Anchorage, AK9951 Service~ 4. Location of weil at surface Leg 1 tend. ~b .~pari( ~'iatform 2,577' FSL, 2,566' FEL, -Sec. 26-10N-13W-SM At top of productive interval 111' FNL, 99' FEL, Sec. 26-10N-13W-SM At effective depth 133' FNL, 294' FEL, Sec. 34-10N-13W-SM At total depth 245' FNL, 467' FEL, Sec. 34-10N-13W-SM 6. Datum elevation (DF or KB) 115' KB above MSL 7. Unit or Property name North Trading Bay Unit 8. Well number S-8 9. Permit number/approval number 91-413///'~ ;~-.~ 10. APl number 5o/-33-20233 11. Field/Pool W/F, G-Zone0 Hemlock feet 12. Present well condition sUmmary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface 2,046' Intermediate 10,892 ' Production Liner 1,872' Perforation depth: measured 11,855 ' feet Plugs (measured) 10,970' feet 11,360 ' feet Junk (measured) 10,519' feet Size Cemented 11,360' (Bridge Plug) 11,740' -11,829' (Cement) 11,292' - 11,360' (Fill) Measured depth True vertical depth 13 3/8" 900 sx 2,046' 2,022' 9 5/8" 750 sx 10,892' 10,087' 7" 550 sx 11,829' 10,946' 13. true vertical Tubing (size, grade, and measured depth) p371/2", N-80 0 10,020' acKers an(3 SSSV (type and measured depth) Baker Packer @ 9 915' TRBV 0 282' Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 94 0 654 1000 0 0 0 0 Tubing Pressure 80 0 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations _.~ 16. Status of well classification as: Oil x Gas__ Suspended_ _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Operations Signed ~""~ Title .or Engineering Supv. Date ¢///~,/¢ ~ SUBMIT IN 60PIJC~TE Attachment #1 Spark Well S-8 Perforations TVD Interval 9,478' - 9,528' 9,546' - 9,561' 9,577' - 9,609' 9,619' - 9,637 9,657' - 9,685 9,723' - 9,754 9,805' - 9,964 10,011' - 10,041 10,118' - 10,139 10,370' - 10,399 10,411' - 10,464 10,473' - 10,482 G-2 G-3 G-4 G-5 H-1 H-2 H-3, 4 West Foreland West Foreland West Forel and West Foreland West Forel and DIL 10,220 10,295 10,330 10,376 10,418 10,492 10,583 10,810 10,926 11,198 11,243 - 10,275 - 10,312 - 10,362 - 10,396 - 10,450 - 10,526 - 10,758 - 10,842 - 10,948 - 11,230 - 11,300 11,310 - 11,320 PMS/em/49B/Sundry RECEIVED APR 1 ? 1992 Alaska Oil & Gas Cons. Comm[ssiO~ ~horage SPARK PLATFORM WELL S-8 Daily Summary of Operations 1/15/92 Well flowing to production. Close SCSSV. TP stable at 70 psi for 15 minutes, valve holding. Equalize and open SCSSV. Return well to production. 1/25/92 Shut well in. RU to pump down tubing. Casing pressure equals 850 psi and tubing pressure equalS 250 psi. PT lines to 2000 psi. Pump 140 bbls filtered inlet water (FIW) down tubing at 5 BPM, 750 psi. Pump 140 bbls FIW treated with corrosion inhibitor down tubing at 2 BPM, 750 psi. TP to 0 psi when pumping stopped. Pump 40 bbls FIW. S/D and TP went to vacuum. CP = 800 psi. Bleed CP down flowline to 100 psi. 1/26/92 RD off tubing and RU to pump down 9-5/8" casing/tubing annulus. Fill annulus to surface with 608 bbls treated FIW. Monitor TP and CP. TP = 0 psi, CP = 0 psi. Pressures stable. 1/27/92 TP = 0 psi. CP = 0 psi. Disconnect gas lift line and flowline and install blind flanges. 1/28/92 Pressure began building on tubing and casing. 1/29/92 TP stabilized at 190 psi. CP stabilized at 70 psi. 1/30/92 Bleed TP to 0 psi. Bleed CP to 30 psi. Pressures slowly building. 1/31/92 through 2/7/92 Pressures slowly building. TP stabilized at 140 psi. CP stabilized at 70 psi. Attempted to bleed tubing and casing pressures. Could bleed to 0 psi, but pressures on both tubing and casing would increase to 100 psi. Closed SCSSV and bled TP to 0 psi. TP increased back to 100 psi. Cycled SCSSV, but still had pressure buildup on tubing. Started getting oil in returns from casing while bleeding. Make plans to pump sea water to kill well. RECEIVED APR 1 1 1992 Alaska Oil A Gas Cons. Com~SSiOtt Anchorage} Spark[ Platform Well S-8 Daily Summary of Operations Page 2 2/8/92 through 2/14/92 Pump inlet water down tubing. Tubing taking inlet water on vacuum at I BPM. Bleed oil from casing to surge vessel. Allowed well to take inlet water on vacuum. Casing stopped flowing oil and pressure stabilized at 20 psi. Well took approximately 4500 bbls inlet water with no indications of the formation plugging off. Well on a vacuum. Prepare to pump mud kill pill. 2/15/92 RU to pump down tubing. Pump 60 bbls kill pill (0.9 bbl water, 20# bentonite, 100# sized Ca¢03, I # XC polymer, 3.75# starch per barrel of pill). Displace with 175 bbls inlet water with pressure increasing to 900 psi. SD and pressure fell to 0 psi. Well still taking fluid. Mix and pump another 60 bbl pill. Displace with 54 bbls inlet water. RD off tubing and RU on casing. Pump down casing and fill casing. Dump hydraulic pressure to SCSSV in attempt to seat valve. SCSSV still not holding pressure. RD pump equipment. TP and CP on vacuum. 2/16/92 through 2/20/92 TP and CP remained at 0 psi. 2/21/92 RU w/reline. PT lubricator to 500 psi - OK. Run 2.80" gauge ring past SCSSV at 282'. Run 2.86" gauge ring to SCSSV at 282'. RIH with Camco CSC lock and A-2 blanking plug. Stuck in tubing just below tree. Shear off and POH. Pull equalizing prong. Attempt to jar plug free. No progress after 6 hours of jarring. TP and CP : 0 psi. 2/22/92 Measure location of fish to be approximately 4 feet below tubing hanger. RIH with prong. Attempt to jar plug downhole - no progress. Damaged prong from jarring. RU section 1/4" braided line and braided line packoff. Lowered pulling tool with platform crane and latched fish. Pulled with crane and line parted in rope socket. Plug did not move. Retie rope socket. Repeat pulling attempt with same results. Shear off plug. RD and release w/reline. TP and CP = 0 psi. Close all tree valves. FINAL REPORT. NOTE: Informed Russ Douglas (AOGCC) of MOC's intentions to monitor pressures during platform visits, and leave well in currents condition until well operations resume or well pressures become a problem. \oe62\29.doc RE(EIVED APR 1 7 1992 ~J! ~& Gas Cons. {SommkSSm~ ,, ~horago '.;ei£bo~e ~ (completed i/2. ) :- ~.~,:lco CoC io.:n and A-£ "luc L/":/,-.` (stuck in tba pup below fia~o.e~ '~"~ 282 Camco ~F-IA SSSV (Flapper) 2.812 ID 3-1/2" 9.3[~ L-80, EUE Tubing 2,046' 13-3/8" 61fl c. sg FloPe trol-Johnston SFH-IA 1.0" GLHs w/BST BLV--I" Va]yes w/B-K-2 Lathes /Il 2,205 3/8" !72 3,775 " z~3 4,999 fl4 5,847 f75 6,':503 ,, fi6 7,066 ,, f77 7,503 " t,-'8 7,940 " it9 8,378 " illO. '8,014 " /111 9,221 " /112 9,656 3/8" Ori lice 9,915' Baker 9-5/8" DB Packer 9,957' 7" liner top 10,020' Tbg tail Perforations (DIL) 10,220" - 10,275' G-2 ~] i0,295' - 10,312' G-3 10,330' - 10,365' G-4 10,376' - 10,396' G-5 10,418' - 10,450' 11-1 J10,492' - 10,525' 11-2 10,583' - 10,706' lt-] '10,706' - 10,758' 11-4 '-~10,775' 7" T£eback Ext. RECEIVED APR ] 1 ] 92 .Oil.& Gas Cons, ~omffiissio~ ,810' - 10,842' -- West Foreland ~.10,892' 9-5/8" 41# N-80, F-IlO csg 10,926' - 10,948'.-- West Foreland , Ferforatious (DIL). q 11,198' - 11,230' West Foreiand 11,243' - 11,300' West Foreland ii,310' - 11,320' west Foreland , 1~,3~7' Fill ~/2~/07 f',ll ~, ~l,~s q- 11,360' EZ.BF '' 11,740' PBTD fl,E2?'. 7" 29~, d-BO, Buttress csg 11,3~' 5'~ ~ EVO 4 i STATE OF ALASKA 0 ~ I 6 I ~ ALAU~,A OIL AND GAS CONSERVATION COMMISSION APPLICATION .FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing m Repair well __ Change approved program __ Pull tubing ~ Variance __ 2. Name of Operator I 5. Type of Well: Marathon Oil Company I Development~ I Exploratory m 3. Address . ! Stratigraphic __ P.O. Box 102380 Anchorage, AK 9951~ Service__ 4. Location of well at sudace Leg I C°nd. #6 Spark 'P I attorm Operation shutdown ~ Re-enter suspended well __ Plugging ~ Time extension ~ Stimulate ~ Perforate ~ Other X 2,577' FSL, 2,566' FEL, Sec. 26-10N-13W-SM At top of productive interval 111' FNL, 99' FEL, Sec. 26-10N-13W-SM At effective depth 133' FNL, 294' FEL, Sec. 34-10N-13W-SM At total depth 245' FHL, 467' FEL, Sec. 34-10N-13W-SM 12. Present well condition summary Total depth: measured true vertical 11,855' feet 10,970' feet Effective depth: measured true vertical Casing Length Structural Conductor Surface 2,046' Intermediate 10,892 ' Production Liner 1,872' Perforation depth: measured 11,360' feet 10,519' feet Size 6. Datum elevation (DF or KB) 115' KB above MSL feet 7. Unit or Property name North Trading Ba.y Unit 8. Welt number 9. Permit number 71-33 10. APl number 5o'/33-20233 11. Field/Pool W/F, G-Zone, Hemlock Plugs(measured) 11,360' (Bridge ,Plug) 11,740' - 110829 (Cement) Junk(measured) 11,292' - 11,360' (Fi 11 ) Cemented Measured depth True vertical depth 2,022' 10,087' 13 3/8" 900 sx 2,046' 9 5/8" 750 sx 10,892' 7" 550 sx 11,829' 10,946' true vertical Tubing (size, grade, and measured depth) 3-1/2" N-80 e 10.020' , Packers and SSSV (type and measurea depth) ' Baker Packer 0 9,915', TRBV 0 282' See Attachment #1 RECEIVED D £0 1 7 t991 Alaska Oil & Gas Cons. Commission Anr. hnrnnn 13. Attachments 1, 2 Description summary of proposal &3 14. Estimated date for commencing operation January 2, 1992 Date approved 16. If proposal was verbally approved Name of approver Detailed operations program __ BOP sket~,l~ __ 17. I hereby certify Signed 15. Status of well classification as: Oil S..._I Gas__ Suspended_ Service and correct to the best of my knowledge. Title 0perati ons Conditions pprovai: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10-, OBIGINAL SIGNED BY LONNIE U. S;v~;Ti'! Approved by order of the Commission Form 10-403 Rev 06/15/88 Engineering Superv. Date /¢'f/~// Approval No, Apo~ oreo CoP'Y 'Returned / C~Date SUBMIT IN TRIPLICATE Attachment #1 Spark Well S-8 Perforations TVD Interval 9,478' - 9,528' 9,546' - 9,561' 9,577' - 9,609' 9,619' - 9,637' 9,657' - 9,685' 9,723' - 9,754' 9,805' - 9,964' 10,011' - 10,041' 10,118' - 10,139' 10,370' - 10,399' 10,411' - 10,464' 10,473' - 10,482' G-2 G-3 G-4 G-5 H-1 H-2 H-3, 4 West Foreland West Foreland West Foreland West Foreland West Foreland DIL. 10,220' - 10,275' 10,295' - 10,312' 10,330' - 10,362' 10,376' - 10,396' 10,418' - 10,450' 10,492' - 10,526 10,583' - 10,758 10,810' - 10,842 10,926' - 10,948 11,198' - 11,230 11,243' - 11,300 11,310' - 11,320 PMS/em/49B/Sundry RECEIVED Alaska Oil & Gas Oons. Anchorage ~ Attachment #2 ' SPARK PLATFORM WELL S-8 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 0.75% 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 0.75% KW-132 corrosion/scale inhibitor) by alternately pumping salt water and bleeding gas pressure. Do not exceed 1500 psi casing pressure. Monitor tubing pressure while pumping. 8. Bleed any remaining pressure from pumping off of tubing and casing. Monitor pressures for buildup. 9. Bleed SCSSV control line pressure to zero to close the SCSSV. 10. RD pumping lines. Close all tree and casing valves. 11. Install pressure gauges on tubing and all casings. \oe60\62.doc R ¢ IV D DEO 1 1 Alaska Oil & Gas Cons. Commission Anchorage Attacament PJ SPARK PLATFORM Well S-8 /~ Wellbore (completed 1/24/87) , I 282' Camco TRDP-1A SSSV (Flapper) 2.812" ID 3-1/2" 9.3# L-80, EUE Tubing ~_ 2,046' 13-3/8" 61# csg FloPetrol-Johnston SPM-1A 1.0" GLMs w/B-K-2 latches #1 2,205' #2 3,775' #3 4,999' #4 5,847' #5 6,503' #6 7,066' #7 7,503' #8 7,940' #9 8,378' #10 8,814' #11 9,221' #12 9,656' 9,915' Baker 9-5/8" DB Packer 9,957' 7" liner top 10,020' Tbg tail Perforations (DIL) 10,220" - 10,275' G-2 210,295' - 10,312' G-3 10,330' - 10,365' G-4 ~10,376' - 10,396' G-5 10,418' - 10,450' H-1 J 10,492' - 10,526' H-2 10,583' - 10,706' H-3 , -~.'10,706 - 10,758' H-4 ~10,775' 7" Tieback Ext. ,810' - 10,842' -- West Foreland ~10,892' 9-5/8" 47# N-80, P-il0' csg 10,926' - 10,948' -- West Foreland Perforations (DIL) 11,198' - 11,230' West Foreland 11,243' - 11,300' West Foreland RECEIVED 11,310' - 11,320' West Foreland 11,327' Fill 1/22/87 11,36o' Ez BP Alaska 0ii a aaa Cons. Comm~ssio~'~ 11,740' PBTD Anchora,qe 11,829' 7" 29#, N-80, Buttress csg 1 I) 655J 'I'D PHS/ 2/t4/8: Doyle L. Productio, anager Alaskan District Production United States Marathon Oil C°mpany P.O. Box 102380 Anchorage, Alaska 99510 Telephone 907/561-5311 April 15, 1987 State of Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen: Conservation Order No. 225 Tyading Bay Field Trading Bay "G" NE Oil Pool Trading Bay Hemlock NE Oil Pool Trading Bay West Foreland NE Oil Pool Marathon Oil Company, in accordance with Conservation Order No. 225, rule 2, has recompleted North~rading Bay Unit Well S-8 for commingled produc- tion from the pools referenced above. Production began on January 24, 1987 at a stabilized, initial production of 372 BOPD, 1396 BWPD, 76 MCFD. In accordance with rule 3, concerning allocation of production, Marathon proposes an allocation of 25 BOPD to the West Foreland Oil Pool and the remainder of the Production to the Trading Bay "G" NE and Hemlock Oil Pools. This allocation is based on an engineering analysis of the enclosed sub- surface production logging survey and a subsurface pressure survey. The pressure survey indicated a bottom-hole flowing pressure of 2700 psi in the West Foreland Oil Pool. This is higher than the anticipated bottom- hole flowing pressure of 1700 psi, resulting in a lower than expected West Foreland production rate. Doyle L. Jo~ BWR/lb/RE13/19 STATE OF ALASKA ALASK OIL AND GAS CONSERVATION COMk,, SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Alter Casing [] Other [] 2. Name of Operator Marathon Oil Company 3. Address P.O. Box 102380 4. Location of well at surface Plugging [] Perforate I~ Pull tubing 5. Datum elevation (DF or KB) 115' KB above MSL 6. UnitorProperW name North Trading Bay Unit 7. Well number $-8 8. Approval number 675 9. APl number 50-- 733-20233 Anchorage, AK 99510 Leg 1 Cond. #6 Spark ?lanform 10. Pool West Foreland 2,577' FSL, 2,566' FEL, Sec. 26-10N-13W-SM At top of productive interval 111' FNL, 99' FEL, Sec. 26-10N-13W-SM At effective depth 133' FNL, 294' FEL, Sec. 34-10N-13W-SM At total depth 245' FNL, 467' YEL, Sec. 34-10N-13W-SM 11,855 ' feet 10,970' feet Plugs (measured) 11,360' (Bridge Plug) 11,740' - 11,829' (Cement) 11. Present well condition summary Total depth: measured true vertical feet Junk (measured) feet 11,327' - 11,360' (Fill) Effective depth: measured 11,360' true vertical 10,519' Casing Length Structural Conductor Surface 2,046 ' Intermediate 10,892' Production Liner 1,872' Perforation depth: measured Size Cemented 13 3/8" 900 sx 9 5/8" 750 sx 7" 550 sx 11,198' - 11,230' MD 11,243' - 11,300' MD 11,310' - 11,320' MD Measured depth True Vertical depth 2,046' 10,892' 2,022' 10,087' 11,829' 10,946' 10,370' - 10,399' TVD 10,411' - 10,464' TVD 10,473' - 10,482' TVD true vertical RECEIVED Tubing(size, grade and measured depth) 3-1/2" N-80 @ 10,020' Packers and SSSV(type and measured depth) Baker Packer @ 9,915', TRBV @ 282' FEI3 2 ]987 Alaska Oil & Gas Cons. Commission Anchorage 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 2/11/87 372 76 1396 1110 psi 105 psi 13. 14. Attachments~ #2, 3 Daily Report of Well Operations i~ Copies of Logs and Surveys Run [] 15.1 hereby certify that the foregoing is true and correct to the best of my knowledgeo-,--/-~ /~::~- ~ 7-- ~ Signed ~),/~c4l~ TitleDistrict Operations Engineer Date z/zo/~? Form 10-404 Rev. 12-1-85 Submit in Duplicate Spark Well S-8 Per£orations DIL G-2 G-3 G-4 G-5 R-2 R-3, 4 West Foreland West Foreland West Foreland West Foreland West Foreland 10,220' _ 10,275' 10,295' _ 10,312' 10,330' - 10,362' 10,376' - 10,396' 10,418' _ 10,450' None 10,582' _ 10,758' 10,810' _ 10,842' 10,926' _ 10,948' 11,198' _ 11,230' 11,243' - 11,300' 11,310' - 11,320' PMS/em/49B/Sundry RECEIVED FEB 2 ~ !9~.7 Alaska Oil & Gas Cons. Commission Anchorage Attachment #2 1987 Report of Sundry Well Operations Daily Operations NTBU Well S-8 WO 01-11-87 Accepted rig from S-9 @ 1200 hrs 1-10-87. Bleed press from ann and tbg. Fill w/drill water. RU to perf tbg to kill well. 01-12-87 RU WL. Perf tbg @ 11,780'-11,782'. RD WL. Circ w/drill water to prod to clean oil from well. Presently displace drill water w/3% KC1 fluid. 01-13-87 Disp hole w/3% KCL fluid w/returns to prod. Shut down, check flow. No flow on tbg, 1/8" stream on ann. Set BPV. ND tree, NU BOPE. Test BOPE. Pull BPV. CBU. Observe well. Flowing @ 1/4" stream. POH 10 its. LD SSSV. Observe well. Still flowing 1/4" stream. POH. LD 2-7/8" tbg. 01-14-87 Thaw frozen air lines. POH. LD 2-7/8" tbg. Test BOPE. PU pkr milling and retrieving assy. RIH. PU kelly. 01-15-87 Wash down to top of pkr. Milled on pkr. Pkr broke free. POH. LD pkr & fishing tools. RIH w/6" bit. Tag fill @ 11,316'. Washed fill to PBTD of 11,368'. 01-16-87 Fin CBU. POH. RIH w/8-1/2" bit and 9-5/8" csg scraper to top of liner @ 9953'. CBU. POH. PU 6" bit and 7" csg scraper. RIH. Tag @ 11,362'. PU to 11,357'. CBU. Prep to filter comp fluid. 01-17-87 Filtered WO fluid, filter unit plugged frequently due to number of particles in fluid. Change out fluid. Filter WO fluid. 01-18-87 Cont filtering WO fluid. POH. PU 7" pkr. RIH. Set pkr @ 10,962'. Test csg to 2300#. POH. PU 4" TCP guns. RIH. Attachment #2 (Continued) 01-19-87 Fin RIH w/TCP guns. Locate guns. Perf West Foreland w/4 SPF, 90° phasing, 32 gram charges @ 10,810'-842'; 10,926'-948'; 11,198'-230'; 11,243'-300'. Had very slight blow in top of bubble bucket, no blow in bottom of bucket. Flow well 3 hrs. SI 6 hrs for press BU. Surface press built to 5 psi. Bled off in 5 min. Rev circ. Took 13 bbls to fill hole. Total influx from formation 5 bbls. Had gas cut fluid w/intermittent oil at bottoms up. Est oil recovery at less than one bbl. Prep to circ long way prior to POH. 01-20-87 Fin rev circ to clean oil from drill string. CBU. Returning fluid from annulus dirty. RU filtering equip. Filter fluid. POH. LD TCP guns. Ail guns fired. PU 538' of 4" TC¥ guns. RIH to perf G-Hemlock. Will perf w/4754' of dry DP for 1000# underbalance. 01-21-87 Fin RIH w/TCP guns. perf G-Hemlock w/4 SPF, 90° phasing, 32 gram charges @ 10,220'-275'; 10,295'-312'; 10,330'-362'; 10,376'-396'; 10,418'-450'; 10,582'-758' DIL. Flow well 4 hrs. Had strong blow in bubble bucket, surf press increased to 20 psi and fell to 5 psi. Rev circ. Took 27 bbls to fill hole. Fluid influx from FORM 35 bbls. Recovered good shows of oil in returns - no est of vol avail. SD pumps. Hole taking fluid @ 18 bbl/hr. Spot litesal salt pill. No fluid loss. POH. LD TCP guns. 01-22-87 RU WL. RIH w/GR-CCL. Tag fill @ 11,327' DIL. Fill below all perfs. RD WL. RIH w/9-5/8" DV pkr on DP. Locate @ 9920'. Pkr would not set. POH. RIH w/second pkr on DP. Set @ 9920'. Test csg to 2200#. Rel setting tool. Prep to POH. LD DP. 01-23-87 POH. LD DP. Chg PR's to 3-1/2". RIH w/3-1/2" completion string. 01-24-87 Cont running 3-1/2" comp string. Space out and land tbg. ND BOPE. NU tree and production lines. Release rig @ 0600 hrs 1-24-87. Turn well over to production. FINAL RIG REPORT. em/49B/Sundry Attachment ~3 SPARK PLATFORM Well S-8 Wellbore (completed 1/24/87) 282' Camco TRDP-1A SSSV (Flapper) 2.812" ID 3-1/2" 9.31! L-80, EUE Tubing ~_ 2,046' 13-3/8" 61# csg FloPetrol-Johnston SPM-1A 1.0" GLMs w/B-K-2 latches #1 2,205' #2 3,775' #3 4,999' #4 5,847' #5 6,503' #6 7,066' #7 7,503' #8 7,940' #9 8,378' #10 8,814' #11 9,221' #12 9,656' 9,915' Baker 9-5/8" DB Packer 9,957' 7" liner top 10,020' Tbg tail Perforations (DIL) 10,220" - 10,275' G-2 ~10,295' - 10,312' G-3 10,330' - 10,365' G-4 --~10,376' - 10,396' 10,418' - 10,450' H-1 10,492' - 10,526' H-2 '~10,583' - 10,706' H-3 !10,706' 10,758' H-4 t10,775' 7" T±eback Ext. '--.10,810' - 10,842' -- West Foreland i~10,892' 9-5/8" 47# N-80, P-il0' csg 10,926' - 10,948' -- West Foreland Perforations (DIL) 11,198' - 11,230' West Foreiand 11,243' - 11,300' West Foreland 11,310' - 11,320' West Foreland 11,327' Fill 1/22/87 11,360' EZ BP 11,740' PBTD 11,829' 7" 29#, N-80, Buttress csg RECEIVED ... FEB 2 Alaska Oil & Gas Cons. Commissi.~r~. Anchorage PMS/ 2/14/87 .-'-- 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 [] 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 I gond. #6 Spark t'J. acform 2,577' FSL, 2,566' FEL, Sec. 26-10N-13W-SM At top of productive interval 101' FNL, 241' FEL, Sec. 34-10N-13W-SM At effective depth 133' FNL, 294' FEL, Sec. 34-10N-13W-SM At total depth 245' FNL, 467' FEL, Sec. 34-lON-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-8 8. Permit number 71-33 9. APl number 50-- 733-20233 10. Pool · West Foreland 11,360' (Bridge Plug) 11,740' - 11,829' (Cement) None True Vertical depth 2,046' 24 022' 10,892' 10,087' 11,829' 10,946' RECEIVED Date approved Date 17-/17/~_~ 67J'- Subsequent Wo~l~ ~tc~."~"~:,~:. J by order of . the commission Date/ 11. Present well condition summary Total depth: measured true vertical 11,855' feet Plugs (measured) 10,970' feet Effective depth: measured 11,360' true vertical 10,519' feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner 1,872' Perforation depth: measured See Attachment #1 Length Size Cemented Measured depth 2,046' 13 3/8" 900 sx 10,892' 9 5/8" 750 sx 7" 550 sx true vertical Tubing (size, grade and measured depth) Alaska Oit & 5as Cons. bu~nmlssion Anchora0e 2 7/8" N-80 @ 11,130' Packers and SSSV (type and measured depth) Baker "FB - 1" Packer @ 10,998, Camco "TRDP - 1A-SSA" TRSV @ 310' 12.Attachment~ #2 & 3 DeScription Summary of proposal I~ Detailed operations program [] BOP sketch ~ Attachment #4 13. Estimated date for commencing operation December 1986 14. If proposal was verbally approved Name of approver 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/~'~ ~--- Title District Operations Engineer Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI Approved by Form 10-403 Rev 12-1-85 Submit in triplicate Attachment 1 Spark Well S-8 Perforations West Foreland West Foreland West Foreland 11,198' - 11,230' 11,243' - 11,300' 11,310' - 11,320' PMS/em/49/Sundry Attachment #2 Well S-8 Recompletion Procedure A commingled West Foreland, Hemlock, and G-Zone well. 1. Skid rig over Well S-8. Fill tubing and casing w/drill water. 2. RU W.L. Perf circ holes in tbg @ ±10,900'. RD W.L. Circ well dead. 3. Set BPV. N/D tree. N/U and test BO?E. 4. POH and lay down 2 7/8" tubing and completion equipment. 5. RIH w/bit and 9 5/8" casing scraper to TOL. POH. 6. RIH w/7" scraper to packer @ 10,998'. Circ well clean w/filtered 3% KCL fluid. POH. 7. RIH w/ 9 5/8" retrievable packer to 9,900'. Test csg to 2,300. psi for 30 min. POH. 8. MU TCP guns and eq. on D.P. RIH. Run GR correlation log. ?erf the following zones w/4 SPF, 32 gm charges, 90° phasing, 1,000 psi underbalanced. Interval DIL Depth G-2 G-3 G-4 G-5 H-1 H-2 H-3, 4 West Foreland West Foreland 10,220' - 10,275' 10,295' - 10,312' 10,330' - 10,362' 10,376' - 10,396' 10,418' - 10,450' None 10,582' - 10,758' 10,810' - 10,842' 10,926' - 10,948' Allow well to die. Reverse out. POH. L/D TCP equip. 9. MU 9 5/8" packer on DP. RIH. Set & test packer @ 9,920'. POH. L.D. DP. 10. RIH w/3 1/2" gas lift completion assembly. Make sure the tubing tail is at least 30' inside the top of the 7" liner. 11. Set BPV. ND BOPE NU & test tree. 12. Unload and test well prior to releasing rig. 14. Run GLS, PBU, and production logs after well stabilizes. (2-3 weeks minimum) FMS/em/49/$undry ~ ~ E ~!\~/~ D Attachment #3 North Trading Bay Unit Spark Platform Well S-8 .3-3/8'.. 61~. K-55 2046' BUt=. CS9. -:- 2-7/8", 6.4~, But=. T~g. "'' · TOL 9957' (No hgt. ) '.. 7' Tie-back Ext. 10 · 775' 9-5/8#L 47m. :l-~O. 10.~9~._ ~ P-II0 Butt. Csg. Baker #FB-X# Pkr. 10,998' DIL w/ I0' SBw~ 11·010 DIL Bell Gu/de : E)ehind-Liner Perforations 10,220'-10,396. G-Zone 127' - 5 intervals 10. 418'-10,7S8, Hemlock 241' - 6 intervals SPARK P.LATFOP~! Wel 1 S-8 trent) 310 ' 2505 ' 4002 ' FMC 'UH-TC-IA" T~g hgt.. 4-1/2" But'. X-over 4-1/2' Butt.p C~co "T?~P- lA- SSA" 2-7/8" EUE 8rd t x b. (2. 312" ID} Ncl-lurry "F:.;tlO-i.O" GiJl's '~/ 1' JR-STD GL;"s w/ 31<-2 latches (2.379' ID] 5110 ' 6155 ' 7057' 7713 8254' 8798' 9339' 9823" 10,329' 10,808' ~5 ~7 #10 11,050 ' 11,052 11,124 ' 11,130 ' Baker "G-22" Locator Baker 4.00" x 3.00" saal assy. (10' 1¢i '. Otis X-Nipple, 2.313" ID Half-cut Mule Shoe· 2.437" ID We~t Foreland Perforations (DIL) 11,198' - 11,230' 4 HPF 11,243' - 11,300' 4 iiPF Deviation ~ 2~o 11,310' - 11,320' ' 4 IlPF ~],323 Top of fill 9/86 11,360' Top "EZ" Drill Bridge Plug 11,372' DST Perf= (4) (ch=. squeezed) 11,740' Initial PBTD TT~:ca OT-l~-u -. .. S~ARK ~ LATFC.~I Well ?--8 (proposed) ~ 300' TRBV 2046' 13 3/8" 619 csg 3%" 9.3~ Tbg · . . 9900 ' pkr 9957' 7" liner Top 9990' Tbg Tail Perforations (DIL) 10,220' - 10,275' G-2 10,295' - 10,312' 10,33U·' - 10,365' G-4 10,376' - 10,396' 0-5 10,418' - 10,450' H-1 ~ - 10,492' - 10,526' H-2 , - 10,583' - 10,706' H-3 < ¢ · ' 10,706' - 10,758' H-4 - 10,775' 7" Tieback Ext. .. - 10,810' - 10,8&2' -- Wes~ 10,892' 9 5/8" 47~ csg ~0,926' - 10,948' -- West Fore] - 10,998' Baker FB-1 pkr perforations (OIL) .11,198' - 11,230' West Forelanc - 11,243' - 11,300' West FOrelan( - 11,310· - 11,320' West Forelan¢ - 11,323' fill (Top 11,323') · ll,360'EZ BP - 11,740' PBTD 1!,829' 7" 29~ Attachment #4 MARATHON OIL COMPANY SPARK PLATFORM MUD PAN U t~ FLOWLINE DRILLING NIPPLE 13 5/8'x5,000+ ANNULAR PREVENTE~ (HYDRIL) CLAMP CONNECTOR [~ (PIPE RAMS) ~[~ : - . . ~ ~ 13 5/8' DOUBLE-G/~TE-(CIW) "' ................. !-1 --' I-'1 CHOKE LINE 3'X5 ~-~,ooo.-~,~ .,.~ L~ ~'"~ "^~ ~ ~ ~RI~L ~K FLOOR ~~ ~O~~TOR L ~--, STATE Of ALASKA ALAE , OIL AND GAS CONSERVATION CON, SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate:~ Pull tubing [] Alter Casing [] Other [] 2. Name of Operator Marathon Oil Company 3. Address P.O. Box 102380 Anchorage, AK 99510 4. Location of well at surface Leg 1 Cond. #b 5part~ t'J. atform 2,577' FSL, 2,566' FEL, Sec. 26-10N-13W-SM 5. Datum elevation (DF or KB) 115' KB above MSL 6. Unit or Property name North Trading Bay Unit 7. Well number S-8 8. Approval number 404 9. APl number 50-- 733-20233 At top of productive 101 ' FNL, At effective depth 133' FNL, At total depth 245 ' FNL, interval 241' FEL, Sec. 34-10N-13W-SM 294' FEL, Sec. 34-10N-13W-SM 467' FEL, Sec. 34-10N-13W-SM 10. Pool West Foreland 11. Present well condit Total depth: ion summary measured 11,855' feet true vertical i0,970 ' feet Plugs (measured) 11,360' (Bridge Plug) 11,740' - 11,829' (Cement) Effective depth: measured 11,360' feet true vertical 10,519' feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 2,046' 10,892' 1,872' measured true vertical Size Cemented 13 3/8" 9 5/8" 900 SX 750 SX 7I' 550 sx 11,198' - 11,230' MD 11,243' - 11,300' MD 11,310' - 11,320' MD Measured depth True Vertical depth 2,046' 10,892' 11,829' 2,022' 10,087' 10,946' 10,370' - 10,399' TVD 10,411' - 10,464' TVD 10,473' - 10,482' TVD Tubing (size, grade and measured depth) 2 7/8" N-80 @ 11,130' Packers and SSSV(type and measured depth) Baker "FB - 1" Packer @ 10,998, Camco "TRDP - 1A-SSA" TRSV @ 310' 12. Stimulation or cement squeeze summary Intervals treated (measu red) Treatment description including volumes used and final pressure fOV 0 3 ~986 Alaska 0il & Gas Cons. Anchorage 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 9/7/86 30 43 3 800 psig 65 psig Subsequent to operation 10/15/86 57 87 3 860 psig 55 psig 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,~/L/fcq L/'~/'-- Title District Operations Engineer Date Form 10-404 Rev. 124-85 Submit in Duplicate ATTACHMENT Spark Well S-8 Reperforation Daily Report of Well Operations October 11, 1986 1. R/U wireline unit and pressure test lubricator to 5,080 psi. 2. RIH and perforate the West Foreland formation w/2-1/8", 0° phased guns at 4 SPF as follows: 11,310' _ 11,320' MD 11,270' _ 11,300' MD~ 11,243' _ 11,270' MD 11,198' _ 11,230' MD 3. Return well to production. MDC/em/49A/Sundry RECEIVED NOV 0 ~ 1986 Abska 011 & Gas Cons. (~ommlulon Anchorage ,-'-, 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 [] Amend order [] Perforate~] Other [] 2. Name of Operator Marathon Oil Company 3. Address P.O. Box 102380 4. Location of well at surface Anchorage, AK 99510 beg I cond. #6 ~park ~iatform 2,577' FSL, 2,566' FEL, Sec. 26-10N-13W-SM Attop of productiveinte~al 101' FNL, 241' FEL, Sec. 34-10N-13W-SM At effective depth 133' FNL, 294' FEL, Sec. 34-10N-13W-SM Attotaldepth 245' FNL, 467' 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-8 8. Permit number 71-33 9. APl number 50-- 733-20233 11. Present well condition summary Total depth: measured true vertical 10. Pool West Foreland (Bridge Plug) - 11,829' (Cement) 11,855' feet Plugs (measured) 11,360' 10,970' feet 11,740' Effective depth: measured 11,360' feet Junk (measured) None true vertical 10,519' feet True Vertical depth Casing Length Size Cemented Measured depth Structural Conductor 2,022' 10,087' 10,946' Surface 2,046' 13 3/8" 900 sx 2,046' Intermediate 10,892' 9 5/8" 750 sx 10,892' Production ~ Liner 1,872' 7" 550 sx 11,829' Perforation depth: measured See Attachment #1 true vertical 5':? i 9 1986 A!as,'<a Oil & Gas Cons. Co¢~?:nisSion Ancho::~ge Tubing (size, grade and measured depth) 2 7/8" N-80 @ 11,130' Packers and SSSV(type and measured depth) Baker "FB - 1" Packer @ 10,998, Camco "TRDP - 1A-SSA" TRSV @ 310' 12.Attachment~ #2 Description summary of proposal ,k-I Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation October 1, 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/~c~~ Title District Operations Engineer Date Commission Use Only I Approval No. [] Location clearance ~Z: ~j/ by order of Commissioner the commission Date Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test .e~:~roVed Co,r, i' ~eturnec~ / Approved by~ ~;~'~I[ I~, SMIT8 Form 10-403 Rev 12-1-85 Submit in triplicate ATTACHMENT #1 WELL S-8 Peforations West Foreland Formation 11,198' - 11,230' MD 11,243' - 11,300' MD 11,310' - 11,320' MD 10,370' - 10,399' TVD 10,411' - 10,464' TVD 10,473' - 10,482' TVD MDC/em/49/Sundry ATTACHMENT #2 WELL S-8 Reperforating Procedure AFE #8059-6 1. R/U wireline unit. (The crane will be used to hold the sheave.) 2. Pressure test lubricator to 2,500 psi. 3. RIH with sinker bars on E-line. Tag fill. POH. 4. Reperforate the following West Foreland intervals with 4 SPF, 0° phasing, underbalanced, with 2 1/8" expendable charges. 11,310' - 11,320' DIL 10' 11,243' - 11,300' DIL 57' 11,198' - 11,230' DIL 32' 99' 5. R/D W.L. 6. Produce and test well. MDC/em/49/Sundry STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COIv, MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] 2. Name of Operator COMPLETED WELL 7. Permit No. OTHER [] Marathon Oil Company 3. Address P. O. Box 102380 Anchorage, AK 99510 4. Location of Well Surface: Leg 1, Cond. #6., Spark Platform 2577' FSL, 2566' FEL, Sec. 26-10N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 115' KB above MSL 12. ADL-17597 71-33 8. APl Number 50-733-20233 9, Unit or Lease Name North Trading Bay Unit 10. Well Number $-8 11. Field and Pool West ForeIand Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~] Altering Casing Stimulate [] Abandon [] Stimulation ~] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing ~ (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). NTBU WELL S-8 'WORKOVER Workover operations began on May 4, 1985 and were completed on July 25, 1985. See attachment for record of operations. RECEIVED $ EP 0 ]985 Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. r~----'~' ' Title .., _ The space below for Commission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1 ~0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate NTBU WELL S-8 WORKOVER RECORD OF OPERATIONS 1. The well was killed with drill water w/ 3% KC1. 2. Set BPV. ND tree· NU and test BOPE. 3. POH and LD 3-1/2" production tubing· 4. RIH w/ 3-1/2" DP and milled packer at 10,415'· POH and LD packer. 5. RIH w/ 3-1/2" DP and milled packer at 10,545'. POH and LD packer. 6 RIH and wash fill from 10 590' to 10,695' (top of 4-1/2" fish) · ~ , · 7. Wash over 4-1/2" fish to 10,706'. POH and LD fish. 8. Wash fill from 10,760' to top of packer at 10,844'. 9. RIH and milled packer at 10,844'. POH and LD packer. 10. RIH and wash fill to 11,347'. 11. Run casing caliper log, surface to 10,155'. 12. RIH w/ 7" liner and cement in place at 9,957' - 10,530'. 13. Pumped 200 sxs cl "G" cement behind liner. 14. RIH w/ 8-1/2" bit and drilled hard cement from 9,833' to TOL at 9,957'. 15. RIH w/ 6" bit to 9,957', drilled stringers to 9,962', RIH to 10,568', drilled hard cement to 10,780'. Tagged bottom at 11,347'. Tested liner to 1500 psi, O.K. 16. Set packer at 10,998'; DIL. 17. RIH w/ 2-7/8"'production tubing and gas lift equipment. Space out and land hgr with seal assembly inside packer at 11,000' 18. tubing measurement. Set BPV. ND BOPE. NU and test tree. 19. RIH w/ 2-1/8" guns and perf. 11,285' - 11,287' with 4 SPF, 0O phasing. RECEIVED sEP o 985 Alaska OJJ & Gas Cons. Commission · - . 0© 20. RIH W/ 2 1/8" guns and perf 11,275' - 11,300' with 4 SPF, phasing. 21. Run HP gauge, flow test well 1.05 BFPH, 5%. WC. - . 0© 22. RIH w/ 2 1/8" guns and perf 11,310' - 11,320' with 4 SPF, phasing. 23. RIH w/ 2-1/8" guns and perf. 11,243' - 11,275' with 4 SPF, 0© phasing. · . 0© 24 RIH w/ 2-1/8" guns and perf 11,198' - 11,230' with 4 SPF, phasing. 25. Unload well to production separator. Total feet of perfs.: 32' 11,198' - 11,230' DIL 57' 11,243' - 11,300' DIL (11,285' - 11,287' DIL 10' 11,310' - 11,320' DIL 99' of perf. interval. 4 SPF 4 SPF 8 SPF) 4 SPF Production after workover opera~ions: 50 BFPD 0% WC 50 BOPD 0 BWPD 26. RU and pressure test CTU and equipment. 27. Pump 95 bbls 15% HC1 acid, flush with 5 bbls of diesel and dis- place with 21 bbls of 3% KC1 in drill water. Production after acid wash: 36 BFPD 5% WC 34 BOPD 2 BWPD 28. Pump 24 bbls xylene, 60 bbls of 15% HC1, 149 bbls of 6 - 1-1/2% Mud Acid, 60 bbls of Clay Acid, wash with 18 bbls of diesel and soak 8-1/2 hours. 29. Return the well to production. Production after Mud Acid treatment: 89 BFPD, 44% WC, 50 BOPD, 39 BWPD RECEIVED $_P 0 5 985 Alaska Oil & Gas Cons. Commission Anchorage .- ~---.. STATE OF ALASKA ALASKA AND GAS CONSERVATION C ~vllSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] 'ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Marathon Oil Company 71-33 3. Address 8. APl Number P. O. Box 102380 Anchorage, AK 99510 50-733-20233 4. Location of well at surface Leg 1, Cond. ~6, Spark Platform 9. Unit or Lease Name 2577' FSL, 2566' FEL, Sec. 26-10N-13W-SM North Tradin9 Bay unit At Top Producing Interval 10. Well Number 185' FNL, 30' FEL, Sec. 34-10N-13W-SM S-8 ...... -- At Total Depth 1 1. Field and Pool 245' FNL, 467' FEL, Sec. 34-10N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 115' KB above MSLI ADL 17597 West Foreland 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions July 25, 1985J 60 ' feet MSLI One 17. lotal Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. lhickness of Permafrost 11,855'MD10,970' ll,360'MD 10,519' YES [] NO ~ 310' feetMD I 22. Type Electric or Other Logs Run Casing cal±per, GR, CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 7" 29# N-80 9,957' 10,775' 9-5/8"c~g. 200 sx cl "G" Tieback exten. 24. Perforations open to ProductiOn (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) West Fore land 2-7/8" 11,130' 10,998' MD TVD 11,198'-11,230' 10,370' -10,399'. 4SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. , 11,243'-11,300' 10,411'-10,464' 4SPF DEPTH INTERVAL (MD} AMOUNT & KIND OF MATERIAL USED (11,285'-11,287') 8SPF 11,198'-11,230' 1. 95 bbls 15% HC1 w/5 bbls. 11,310'-11,320' 10,473'-10,482' 4SPF 11,243'-11,300' diesel wash. 2. 24 bbls ~.' ' 11,310'-11,320' xylene. 60 bbls 15% HC1. 149 . bbls 6 1-1/2% Mud Acid, 60 27. PRODUCTION TEST bbls Clay Acid w/18 bbls Date First Production '~ I :Method of Operation(FloWing, gas lift, etc.) diesel wash. 6/10/85I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO 8/8/85 24 ' TESTPERIOD ~: 50 5 ] 39Ii ~308 Flow T~bing Casing'Pressure CALCULATED -~ O1L-BBL GAS-MCF WATER-BBL OIL GRAVITy-APl (corr) Press. 75 775 24-HouR RATE~ 5 0 '5 i 3 9 26.5 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. : . · : . · , RECEIVED · S EP 0 :[985 Alaska 0il & Gas Cons, Commission Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Anchorage Submit in duplicate 29. ' 3O. · ~ !~ "~ :.. · . . . : ,. ~ · ~.. . . ~.~ ~ - .... GEOLOGIC MARKERs . .. -~i · ' ' FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH · GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". STATE Or: ALASKA ALASK~L AND GAS CONSERVATION ¢~MISSION ~ ,.',ONTHLY R =PORTn- F _ORILLING AND WOFIKOVER OP .RATION . 1. Drilling well [] Workover operation [~ ~ 2. Name of operator · .. . . ~.. Address ~'. Location of Well at surface Marathon Oil Company 7. Permit No. P. O. Box 102380, Anchorage, AK 99510 Leg 3, Spark Platform 2572' FSL, 2559' F~TL, Sec 26, T10N, R13W SM 5. Elevation in feet (indicate KB, DF~ etc.) 115 ' KB above MSL 6. Lease Designation and Serial No. ADL- -17597 71-33 -~. APl Number 50-733-20233 ~. Unit or Lease Name North Tr~d~ nq Bay 10. Well No. S-8 11. Field and Pool Trading Bay NE Hemlock For the Month of May _, 19._85__ Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Pulled 3 1/2" tubing and completion equi_~ent. Recover packers in 9 5/8" casing at 10,415' and 10,549'. Successfully fished cut off 4 1/2" x 3 1/2" tubing string from packer in 7" liner. A total of 206' of tubing was recovered. Fished 7" packer from liner at 10,844'. Cleaned out junk and fill to 13,347'. .~ 13. Casing or liner run and quantities of cement, results of pressure tests Ran 19 joints of 7", 29# N-80 butt and ste_b_bed into 7" liner tie back extension at 10,775'. Cemented liner in'place with 200 sacks of Class "G". 9 5/8" casing pressure tested to 1500 psi prior to running 7" liner. i4. Coring resume and brief description 15. Logs run and depth where run Casing caliper log from 10,070' to surface. RECEIVED ,16. DST data, perforating data, shows of H2S, miscellaneous data JUN 2 6 Lq85 Alaska 0il & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 'SIGNED__ TITLE_ DATE. · NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Submit in dupli6ate Form 10~,04 ~-'"'~ STATE OF ALASKA ~'"-~, ALAS~-,~ OIL AND GAS CONSERVATION ~,,~MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Marathon Oil Oompany 71-33 3. Address 8. APl Number P.O. Box 102380 Anchorage, AK 99510 50- 733-20233 " 4. Location of Well Surface: Leq 3, Spark Platform 2572' FSL, 2559' FWL, Sec. 26-10N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 115' KB above MSL 12. I 6 . Lease Designation and Serial No. ADL- 17597 9. Unit or Lease Name North Tradinq Bay [nit 10. Well Number S-8 11. Field and Pool Tradinq BaV NB, Hemlock Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF. INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon I~ Stimulation [] Abandonment r-1 Repair Well [] Change Plans [] Repairs Made [] Other I-1 Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Well S-8 Workover Workover operations should begin in December, 1984' and be oompleted usinq the attached procedure. R E C :i V I? D nm-2 6 1,984-. Alaska 0JJ & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Com--~ission use Conditions of Approval, if any: Approved by .'-~pproved CoDy Ret, urns1 / / By Order of COMMISSIONER the Commission Da,e ~o / z4 / ad, Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 Rev. 7-1-80 -- AFE ~. 8054-4 NTB[] WELL S-8 WEST FORELAND REC, OMPL5~IO~ RECON~ED PROCEDURE 21. Kill well w/ 11.6 pD~ WO fluid. 22. Set BPV. ND tree. bP3 and test BOPE. 1. Skid ,rig over Well S-8. 2. Perf tbg above tod of fill @ 10,157'. 3. Kill well. Set BPV. ND tree. NU and test BOPE to 2500 psi. 4. POH and ID 3-1/2" tbg and Baker FH hydraulic packer. 5. PU DP. Retrieve Baker _Model D permanent packer at 10,406'. Repeat for Baker Model D permanent packer at 10,824'. 6. Recover 4-1/2" X 3-1/2" tubing fish located at 10,694'. 7. Retrieve Baker Model F permanent .packer at 10,824'. 8. CO to tod of EZ Drill Bridge Plug. at 11,360'. 9. RIH w/ tie-back mill and dress 7" liner tie-back extension. 10. RIH and cement 7" 29~. tie-back liner across open C~-Zone and Hemlock perforations w/ 150 sx class "G" cement. 11. RIH w/ 8-1/2" bit and CO to top of 7" tie-back liner. 12. RIH w/ 8-1/2" bit and 9-5/8" csg scraper to top of 7" tie-back liner. , 13. Run DST liner lap test. . 14. RIH w/ 6" bit. CO to top of EZ Drill Bridqe Plu~. at 11,360'. 15. LD DP. 16. CDmplete well w/ packer at 11,000' DIL, 2-7/8" tubing, ~as lift equipnent and subSurface, safety valve. 17. Set BPV. ~D BOPE. NU and test tree. 18. Perforate West Foreland 11,271'-11,303' DIL under dra~own. 19. Test !~st Foreland. 20. If rate is acceptable, ~.~erforate 11,250 '-11,270 ' DIL under dra~own and go to stero 33. If rate is unacceptable, go to steD 21. 23. POH and ID tbg. RECEIVED Alaska Oil & Gas Cons. CommJssior,, Anchora¢:~e 30. 3~. 32. 33. Drill Brid.qe plug., at 11,360'- CO to pBTD RI~{ w/ retainer on DP. Set retainer at ll,350'- · squeeze perforations at 11,375' RI}{ w/ 6" bit. Drill up. retainer at 11,350'- CO to pSTD. RI~ w/ 6" bit and 7" csg scraper to pB.~- Fracture stimulate %~st Foreland- DST West Foreland' Recomplete well as before- Turn well over to ,.production- jAB:caS 09-05-84 -2- RECEIVED OCi" 2 Alaska Oil & Form P -7 SUBMIT IN D~. .,CATE* - STATE OF ALASKA '~see other tn- si ructions on reverse side OIL AND GAS CONSERVATION COMMITTEE ii WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: b. TYPE OF COMPLETION: NEW ~[ wonK [--] WELL OVER W ELL W ELL DR v Other "O" & Hemlock DEEP- [] PLUG co-mingled £s nAC~ [~] ~r~'.nssva. [~] Other 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. 0. Box 360, Anchorage, Alaska 99710 4. LOC^TXON OF WELL (Report location clearly and in accordance with any State requirements)* ~t ~¢~ Note well drilled from conductor ~6~ Leg 1, Spark Platform 2577'N & 2566'W~fr SE cr Sec~u, T10N, RiBW, SM At top prod. interval reported below 47'S & 99'E of NW er Sec 35, T10N, R13W, SM At total depth ORIGINAL AP1 NUM. FA~CAL CODE 50-133-20233 LEASE DF_,SIGNA~IO~' AND SERIAL NO. 17597 7.IF INDIA. N, ALLOTTEE OR TRIBE NAiViE 8.UNIT,FA/{2/i OR LF~kSENAME North Trading Bay Unit 9. WE~L NO. S-8 (41-34) 10. FIELD A/qD POOL, OR WILDC&T Hemlock & "G" Zone 11. SEC., T., R., M., (BOTTOM HOT-w- , OBJECTIVE) Sec 34, T10N, R13W, SM 12. PERMIT NO. 245'S & 467'W of NE cr Sec 34, T10N, R13W, SM 71-33 1-17-72 ~ 3-6-72 [ 4-1-72 I ll5'KB ~ ~DUCING !N~VAL(fi)~ OF ~Ifi CO~P~TION--TOP ~O~OM, NA~E (~ ~~)* ~,~ ~23. WAS DIREC~ONKL ' ~ , SURVEY MADE .;, 0'70 , 10220-10396'~ G Zone 9480-9636'T~ ~ Yes 10418-10758'~ He~°ck 9657-9963'~D 24. ~ ~crmc ~o or~m noss au~ DIVISION ~? Oil ;:'2-~2, C.,:~.; DIL, FDC, Dipmeter, CBL, ~R Density ~d sonic calmpe~~" .... ~'' ' - ' "" ~AS~G RECORD (Report all strings set h~ wall) " ' ' ' HOLE SIZE sxclass w/10C g l .6o / 1T__1/2 ,, iL//? 0 0 C~%[LNTING RECOYI,D ~ A2c[OUNT PULLED 1'12-1/~" ~/750 SX ClassG w/O.2g 27. TUBING SCi-~E~ (MD) SIZE DEPTH SET (MD) ~PACKE~ SET (MD) }00 13-3/8" 61# /K-55 ] .2046' 9-5/8" 47# -80~P 10 10892' 26. LINER lq~C Olq~ , $I~Z~ 't TOP (A{D) [. IBO']TTO~/I (A~D)[SACKS CE2'I~T* ~" [ ~o~5' [ ~]829 ! 550 28. PERFORATIONS OP~ TO PROD~O ([n[erval, size and number) Fo~ 1/2" holes/fg as follows: 10220-102~5' 10~1~10~50' C 10295-10312' 10~92-10526' 10330-10365' 10583-10758' 10376-10396' ~ ' 30. PRODUCTION 29. ACID, SL'OT, ]Y;IAC'[ CrRE, CF2,~ENT SQUEEZE, ETC. . DF~P//i INTiSRVAL (MD) ] ABiOUNF ~'~D I~!ND OF M~IEP~AL US~ · _ , DATE FIRST PI%ODUCTION I I:rF~oDucTIO:N ME'i[{O,D (Flowh*g, ga,; lif[, pumping--size and type of pump) ]VJELL STATUS (Producing or 4-2-72 ~ : Gas Li~ ! ~,~-~m Producing DATE OF T~Sm, IHOURS TEST~ ']CI-1OS{E SiZE ~PROD'N FO,R~ OI~BEL. ~A~MCF. WATE~BBL. JGAS-OIL' ILkTIO I~SS. 1 : 12!-HOUR RA~ I :l 3' 9I soo I 37 ...... 31. DISPOSITION Or aas (Sold, used yor IueI, vented, etc.) TEST WITNESSED BY Fuel 32. LIST OF ATTACHMENTS Well History, Lo~s, ,Directional Survey 33. I herebY' certify thj~e foregol~g and attached information is complete and correct as determined from all-available records sm,,v ,]~! ,{]x_&~~v--~ T,?,~E Dist. Drilling Supervisor DATE *(See Instructions and Spaces [~or Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth' measure- ments given in ether spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separate production from more than one ~nterval zone (multiple completion), so state in item 20, and in item 22 show the p~c. Jucing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produce, J, show- ing the additional data pertinent to such interval. Item26: "Sacks Cement": Attached' supplemental records for this well should show the details of any mul- tiple stage cementing an5 the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUM. M.A. Ry Ol~ ~O~4~ATI0'~ TESTS I~CLUDIN(; INTERVAL T~TED, PH~URE DAT~ ~'~OV~I~ OF OIL. GAS. 35. G~GIC MAR~ WAT~ AND MUD Liner Lap Water Shut-off Test - R~ 9-5/8" DST tools w/4135' water cushion. Set 9-5/8" packer at 10741'. ~ened tool at 9:50 ~ 3-15-72 for 61 ~n test. Light blow decreasing to dead in 5 ~n. Recovered net Beluga~ 1475 1560 fled rise of 280 ~ of ~illing mud. Tyonek 3642 3348 MGS mbr 4966 4549 Liner Middle Water Shut-off Test - R~ 7" DST tools w/7000' water cushion. F marker 8226 7534 ~ Set 7" packer at 11306'. ~ened tools at 4:50 ~ 3-16-72 for 1-hr G marker 9556 8770 test. We~ blow thro~hout test. Net fled rise of 188' of mud. G prod 10193 9339 He~ock ~ 10418 9542 ~' West Forel~d 10758 9849 J~assic 11730 ' 10741 .... i,, ~'- ........ , .... ~.....~w- ..... i' ' i il' ' ]' i i iiii , i - i · j i i ' ' i I ~ i i i i ii - ii ~ shoe 30 ~eeo~e~e~ ~Z Z0~30-ZZ83~' . ........ ~ .... ,~, ~ ,1~ ,, . ,, - ,i, = , , Preptre end subei~ ~ho I~,ITIAL REPORT on ~ sd&y eft, o"si ~rkover re :~,~'~'~..tsr~ed. D. ily york prior ~o spuddinf should be su.,uerized on the for., fivinfF inclusive detes only. _~:..~.. DAILY Y/ELL HISTORY-INITIAL REPORT SOUTH ALASKA County or Parish COOK INLET _State ALASKA Field NORTH TRADING BAY UNIT Lease or Unit NTBU S-8 Well No Tit le Development Oil Well District Auth. or W.O. No. 19837l~ TARCO'S W. I, 61.28% Operator ATLANTIC RICHFIELD COMPANY Spudded or W.O. Begun SPUDDED ~ ~:r~:~' ~' '~' ' ,Prior. Status Date 1-17-7 2-' Hour- 9:00~if a W. O. . o ec r f Day Reported Date & Depth as of 8:00 A.M. 1-14-72 NTBU S-8 - COOK INLET -API 50-13.3-2.0182 10405'TD . 10405'TD 10235"PBD - Changed flow line, unbolted pipe rack. Skid rig to cen~er of le~ 2. Skidding rig tO leg 1, well S-8. 1-17-72 NTBU S-8 - COOK INLET.- ~I .50-133-20233 ~:,j:~. ;.'~i:.~_~:~:.~f~:::,~,~,.:;~~- GIH w 1 -1 2 - b~t - ~ 8.8~, · V~s. 43. - >..-.:~,~:~.~.~j::~. . . jacked rig't°' leg fl, condUctor ~3;tRig'in(place.'j~:l~5,~l~72- 772 (772) 772 (772')-~ GIH-w/eilli~'..set' ~Pt:-,,~'/.8):g/;:;.".~['[.:~ _ ' .. Spud 9:00 ~ 1-17-72. ~'Drilling 12-1/~ . ~.~e (..]~oeiH~'~[[;1 · . .. - South .to s15w, ~mlled from. 60p,772..,..~ ,t~.'~: ...... ' , o .... ~..:~:"::l~:~¢~"-~j~';?:'~.,.';~:~} 1-20-7~ - NTBU S-8 - COOK ~~ - ~I 50-133-20233-.>: ..-:-~'.z..:-.¢'~ 2100' . . ~00' (0') - Open 1221/2". hole .~o. 17-1'/2".hole ~1925' - ~9.~, . '"-' ' wistea, orr hoXs .[e 2100' '..- .2100' (~').-'CirC~ating'.13:3/8''' cs~ ~ 20~,. [-'.~ 9t, -:.. -'-'..:" i. :OPened h° e t°' to 2075', Lost- 300' 'gJ:'J' L,~ ' '~ ' ~L '' 'x- r ~"'L 1/2 trip in hole. 'Had 20' fill. '~e~ed':out't6 2075' ..]~. '. '- : -. '".L . POH."RU'to run 1BLB/8',.':cs~',:.R~'2049' .(5!its)1S~B~8- ~':- · /'. casing. ShoJ. ~" 20~6'~((~float~:::collar '~ i944,..fL~QB~ef :../.-' .. ' ..'~ Had mud ret~ns .to.,s~face~..;~lesr~n~.~:;~$,3~.sg,'. ...:/ '- ' ;. class G.' PD W/1800 pSi~)'CiP ~ ~:~0'::~"122i~722'Fi8at' hela~H ?.?./ -'' ~hile c~n{ing['('L°~tJ':~°mPletje reb~ns w/150 bbls'ais~~t to-,~.' ~?~<~i~/%%['::.] -'"[.-'?..-'::- .... .- t~ns. CIP'~ ~:30 '~ ~-22-72;:;'~ ~3.~/8".'BOp stack, ,.,Test[~'~i1 -~d/?~' :~" . '1961', arinea h~a cement. to 2020':. Tested cSg~'to '~-" ' ' - ' ' · ~'~' ~ ~ '"'~ ~ '".. ~t to 20~6 . Drilled shoe & ran ~n~~::, ,~,h~ ,,~', " bel~ shoe w/l~6 psi OK. Drilled 21~2~5~ ~E ~' 't~bodrill & drilled to 2~19'. [[~ ~'Oistribution: The Above .is Corr~ ~ :": r~.: Dr~ll~n~ Section- Dallas ,~ ~ ~ ./.,,, , .... - cc:- ~strict Office ,~~~~/~'.'./' En~ineerin~ Division - (~20). s~~ - - ~' .... . Co-~ner(s) - As Appropriate' ...-~ ..... .~. .... ~ .... :..L. " ' -:~-:~?:.::..'. Re,ion~l Office, Well Record File .' ':'._- :--; ',,~.~..2DISTRICT_DRILL~ :~:~E.-NO. !/u '(NUMBER ALL DAILY WELL HISTOBY FO~S CONSECUTIVELY AS ~. ABE PREPARED FOa ~ INSTRUCTIONS: This form is used durinf drilling or vorkover operations, If teotins, corinl, or perforstinf, sham formation n~me in desc'ribins york performed. Number all drill stem testa sequentially, Attach description o! all cores, Work per- formed by Producinf Section wil! be reported on "INTERIM** sheets until final completion. Report official or representative test on "FINAL** form, (1) Submit "INTERIM** sheets vhen filled out but not less frequently than every 30 days0 or (2) on Wednesday of the week in vhich oil-strins is set. Submit veekly for vorkovera and followinf settinf of oi~ strinf until completion, DALLY WELL HISTORY - INTERIM · District SOUTH ALASKA , County or Parish COOK INLET State ALASKA Field NORTH TRADING BAY UNIT Lease or Unit NTBU S-8 Well No. Date & Depth at 8:00 A.M. 1-25-72 2607' 1-26-72 · 2997' 1-27-72 4060' 1-28~72 4925' 1,31-72 6563' 2-1-72 6801 ' 2-2-72 7215 ' 2-3-72 7491 2-4-72 7778' 2-7-72 8621' · Complete Record for each Day While Drilling or Workover in Progress NTBU S-8 - COOKINLET -API 50-133-20233 (13-3/8" ~ 2046') 2607' (188') - Drilling - MW 9.2#, Vis 42, WL 12.4. Drilled 12-1/4" hole 2419-2607'. Simultaneously closed all BOPE in 26 sec. Final pressure on accumulator 1000 psi. Initial pressure 2600 psi. Increased standby pressure to 3000 psi on accumulator. Stmvey: 2548' 24-1/4° TVD2485 S59W S283 W410. NTBU S-8 - COOK INLET -API 50-133-20233 (13-3/8" ~ 2046') 2997' (390') - Drilling - MW 9.2#, Vis 40, WL 12.5. Drilled 12-1/4" hole 2607-2997. Survey: 2934' 26-1/4° TVD2836 S33W S389 W533. NTBU S-8 - COOK INLET -API 50-133-20233 (13-3/8" ~ 2046' ) 4060' (1063') - Drilling 12-1/4" hole - MW 9.4#, Vis 39, WL 11.4. Held blowout drill PM tour 1-26-72 while drilling closed in well in 2 min. Survey: 3453' 26-3/4" TVD3302 S33W S575 W642. NTBU S-8 - COOK INLET -API 50-133-20233 (13-3/8" ~ 2046') 4925' (865') - Drilling '- MW 9.5#, Vis 40, WL 11.2. Held blowout drill w/both crews: 1 crew SI well in 30 secs; 1 crew SI well in 2 min. Drilled 12-1/4" hole 4060-4925'. NTBU S-8 - COOK INLET -API 50-133-20233 (13-3/8" ~ '2046') 6563' (1638') - Drilling - MW 9.7#, Vis 41, WL 8. Drilled 12-1/4" hole 4925-6563'. Survey: 6115' 21-1/4° TVD 5726 S43W S1462 W1287. NTBU S-8 - COOK INLET -API 50-133-20233 (13-3/8" ~ 2046' ) 6801' (238') - Drilling - MW 9'.3#, Vis 42. WL 8.4. Drilled 12-1/4" hole 6563-6801'. Survey: 6770 25-1/2° TVD6326 S49W S1645 W1475. NTBU S-8 - COOK INLET -API 50-133-20233 (13-3/8" ~ 2046') 7215' (414') - Drilling - MW 9.3#, Vis 39, WL 8.2. Drilled 12-1/4" hole 6801-7215'. Survey: 7012' 25° TVD6545 S50W S1712 W1553. NTBU S-8 - COOK INLET - AP1 50-133-20233 (13-3/8" @ 2046' ) 7491 (276') - Drilling - MW 9.3#, Vis 38, WL 8.9.~ Drilled 12-1/4" hole 7215-7491'. Held 2 blowout drills & SI well in 1 min. Survey: 7296' .25° TVD6802 S49W S1790 W1645.' NTBU S'8 - COOK INLET -API 50-133-20233 (13-3/8" ~ 2046' ) 7778" (287') Drilling- MW 9.3#, Vis 38, WL 8.2. Drilled 12-1/4" hole 7491-7778'. Tested Hydril w/3000 psi. Tested 5" DP rams - CS0 & choke manifold to 5000 psi OK. Tested kellycock 5000 psi OK. · CONFIDENT NTBU S-8- COOK INLET -API 50-133-20233 (13-3/8" ~ 2046') 8621' (843') - Drilling - MW 9.3#, Vis 39, WL 7.9. Held safety meeting.7778_8621,. . - Held blowout drill~ Well SI in_l Survey: 8621' 23-3/4° TVD7801 S53W S20 7 W1992. .The Above, is Correct: . ' 1 '"~J'I~N ATU fie ' DATE PAGE NO. DISTRICT DRILLING SUPERVISOR 2 TITLE (NUMBER ALL DAILY WELL HISTORY FORMS CONSECUTIVELY AS THEY ARE PREPARED FOR EACH WELL. ) PRINTED IN U.S.A. 33-459-~ 12/67 INSI~UCTIONS: This form is used durinl~ drillinf or vorkover operdtions, If testinf, corinf, or perforstinf, show forBetion ~n-'e in desc'ribinf work performed, Number ell drill stem tests sequentislly, Attsch description of ell cores, Work per- formed by Producins Section will be reported on "INT£RIM** sheets until finsl completion, Report official or representstive test; on #FINAL** form, (1) Submit "INTERIM" sheets when filled out but not less frequently then every 30 days, or (2) on Wednesday of t;he week in which oil strinf is set. Submit weekly for vorkovers end followinf settinf of oil otrinf until completion. District Field DAILY WELL ItlSTORY - INTERIM SOUTH ALASKA County or Parish COOK INLET NORTH TRADING BAY UNIT Lease or Unit NTBU S-8 State ALASKA Well No. Date & Depth at 8:00 A.M. 2-8-72 8853' 2-9-72 9147' 2-10-72 9377' 2-11-72 9640' 2-14-72 10134 ' 2-15-72 10265 ' 2-16-72 10384 ' 2-17-72 10426 ' 2-18-72 10588' 2-22-72 10866' Complete Record for each Day While Drilling or Workover in Progress NTBU S-8- COOK INLET -API 50-133-20233 (13-3/8" ¢ 2046' ) 8853' (232') - Drilling - MW 9.4#, Vis 41, WL 8.3. Dir drilled 12-1/4" hole 8621-8853'. Survey:. 8665' 22-1/4° TVD8053 S55W S2139 W2077. NTBU S-8 - COOK INLET -API 50-133-20233 (13-3/8" ¢ 2046') 9147' (294') - Drilling- MW 9.4#, Vis 40, WL 8.0. Drilled 12-1/4" hole 8853-9147'. Survey: 8859' 21-1/4° TVD8233 S54W S2181 W2136. NTBU S-8 - COOK INLET -API 50-133-20233 (13-3/8" ~ 2046') 9377' (232') - POH - MW 9.5#, Vis 42, WL 8.5. Drilled 12-1/4" hole 9145-9377'. Survey: -9145' 20° TVD 8548 S57W S2249 W2233. NTBU S-8 - COOK INLET - AP1 50-133-20233 (13-3/8" ¢ 2046') 9640' (263') - POH MW 9.5#, Vis 40, WL 6.8. Drilled 12-1/4" hole 9377-9640'. Survey: 9377 '20-1/2° TVD8718 S58W S2283 W2286. NTBU S-8 - COOK INLET -API 50-133-20233 (13-3/8" ~ 2046') 10134' (494') - Drilling - MW 9.5#, Vis 40, ~L 5.2. Drilled 12-1/4" hole 9640-10134'. Tested pipe rams, CSO & choke manifold to 5000 psi OK. Hydril to 3000 psi OK. Bit 25 lost 3 cones ~ 10119'. RIH w/bit 26~ drilled from 10119-10134' in 1 hr OK. NTBU S-8 - COOK INLET -API 50-133-20233 (13-3/8" ¢ 2046') 10265' (131') - Drilling - MW. 9.5#, Vis 42, WL 5.3. Drilled 12-1/4" hole 10134-10265'. NTBU S-8 - COOK INLET -API 50-133-20233 (13-3/8" ¢ 2046') 10384' (119') - Tripping - MW 9.6#, Vis 42, WL 5.1. Drilled 12-1/4" hole 10265-10384'. Survey: 10384 26° TVD9628 S56W S2517 W2647. NTBU S-8 - COOK INLET -API 50-133'20233 (13-3/8" ~ 2046') 10426' (42') - Tripping- MW 9.6#, Vis 43, WL 5'.0. Held 2 blowout drills. Well SI in 1 min. Drilled 12-1/4" hole 10384-10426'. NTBU S-8 - COOK INLET -' AP1 50-133-20233 (13-3/8" ~ 2046') 10588 (162') - Drilling - MW 9.6#, Vis 43, WL 5.0. Drilled 12-1/4" hole 10426-10588'. NTBU S-8 - COOK INLET -API 50-133-20233 (13-3/8" ~ 2046') 10866' (278').- Trip- MW 9.6#, Vis 43, WL 4.9. Drilled 12-1/4" hole 10588-10650'. Ran DIL 10641-2044'. Tested 5" pipe rams CS0, choke manifold & Kelly cock to 5000 psi & ~r[~ ~o 3000 psi. Drilled 12-1/4" hole '10650-10866'. Survey: 10812' 25° TVD10014 S59W S2614 W2804. S[GNA~RE DATE ,/ DISTRICT DRILLING 9~ERVISOR TITLE PAGE NO. ~ (NUHBEB ALL DAILY WELL HISTORY FORMS CONSECUTIVELY AS THEY ARE PREPARED ~ E~CH WELL, ) PRINTED IN U.S,A. 3B-4sg-2 12/67 ~NSTRUCTIONS: Thia fora ia uaed dories drilling or vorkover operations. If terries, coring., or perforating, ahow foraatiou nape in describing york perforeed. Nueber all drill area trace aequenclally. Attach deacription of all coreR. Work per- foraed by Producing Section will be reported on "INTERIM" Jheeta until final coIpletion, Report official or repreaentative teat on "FINAL*' fora. (1) Subeit "INTF~tlM'* aheeta when filled out but not lear frequently then every 30 daya, or (2) on Wedneaday of the week in which oil erring ia art. Subeit weekly for vorkovera and following Retting of oil erring until colpletion. DALLY WELL HISTORY - INTERIM Dis t r i c t SOUTH ALASKA County or Parish COOK INLET State Field NORTH TRADING BAY U-NIT Lease or Unit Date & Depth at 8:00 A.M. 2-23-72 10905' 2-24-72 10905 ' 2-25-72 10898' 2-28-72 10930' 2-29-72 11065 ' 3-1-72 11154' 3-2-72 ' 11280' 3-3-72 11446' 3-6-72 11837 ' $-7-72 11855'TD NTBU S-8 Well No. , Complete Record for each Day While Drilling or Workover in Progress NTBU S-8 - COOK INLET -API 50-133-20233 (13-3/8" ~ 2046') 10905' (39') - Logging - MW 9.6#, Vis 42, WL 4.8. Drilled 12-1/4" hole 10866-10905'. Ran DIL 10876-8000'. FDC from 10876-2046'. NTBU S-8 - COOK INLET -API 50-133-20233 (13-3/8" ~ 2046') 10905' (0') - Running 9-5/8" csg - MW 9.6#, Vis 43, WL 5.0. Took sidewall samples. WIH &cond mud 3-1/2 hrs. POH & RU to run 9-5/8" csg. NTBU S-8 - COOK INLET -API 50-133-20233 (9-5/8" ¢ 10892') Corrected depth from 10905' to 10898' - NU. Ran 131 jts 9-5/8" 47# P-110 butt csg & 135 its 9-5/8" 47# N-80 butt esg. Shoe ~ 10892'. Baker differential float collar ~ 10808'. Baker baffle plate e 10769'. Cemented 9-5/8" csg w/750 sx Class G w/0.2% Hlq-7. Pumped 10 bbls wtr ahead of cement & 5 bbls behind. Displaced cement w/788 bbls drlg mud using Halli pumps, Bumped plug w/2000 psi. Bled off'pressure. Float equip held. CIP 12:00 M 2-24-72. Had good circ thru out cement operation. NTBU S-8 - COOK INLET -API 50-133-20233 (9-5/8" ¢ 10892') 10930' (32') - Drilling -MW12.7#, Vis 43, WL 4.9. Tested BOP rams & surface equip w/500 psi & Hydril to 3000 psi. Tested 9-5/8" csg to 1500 psi OK.'RIH w/8-1/2" bit. Installed DP rubbers on DP. Drilled out hard cement & shoe. Tested shoe w/71'psi OK. Raised mud wt from 9.6 to 12.7#. Drilled 8-1/2" hole 10898-10930'. NTBO S-8 - COOK INLET -API 50-133-20233 (9-5/8" ¢ 10892' ) 11065' (135') - Drilling - MW 12.7#, Vis 45, WL 4.8. Drilled 8-1/2" hole 10930-11065'. NTBU S-8 - COOK INLET -API 50'133-20233 (9-5/8" ~ 10892' ) 1154' (89') - Tripping - MW 12.7#, Vis 45, WL 4.8. Bit #36 made 256' in 43 hfs rotating. Tripping in w/bit #37. Survey: 11154' 22-1/4° TVD10328 S58W S2685 W2919. NTBU S-8 - COOK INLET -API 50-133-20233 (9-5/8" ~ 10892') 11280' (126') - Circ samples ~ 11280' - MW 12.7#, Vis 43, WL 4.5. Drilled 8-1/2" hole 11154-11280'. Drilling break 11210-11237'. NTBU S-8 - COOK INLET -API 50-133-20233 (9-5/8" ¢ 10892') 11446' (166') - Drilling - MW 12.7#, Vis 46, WL 4.4. Drilled 8-1/2" hole 11280-11446'. NTBU S-8 - COOK INLET -API 50-133-20233 (9,5/8" ~ 10892') 11837' (391') --Drilling - MW 12.7#, Vis 45, WL 4.1. Drilled 8-1/2" hole 11446-11837'. Survey: 11513'. 23° TVD10660 S56W. NTBU S-8 - COOK INLBT - API 50-155-20255 (9-5/8" @ 10892') ! , · . 11855 TD (18) - Loggzng - MW 12.7#, Vzs 44, WL 4.0. Drilled 8-1/2 hole 11837-.11855., Made wiper tripl:i~n:to~:9~.s/,S ~,@ ~0~8i5D; i Sent back to btm..,Encountered 1 bridge 11855-.11852~. RU Schl. Ran D~D,i FDC, ~ Dipmeter 11836-.10888'. Loggers TD 11856'. Prep to run~isidewal~)cd~q~. CONFIDENT DI\"!$!ON OF OiL ,:'..,.::_; The Above is Correct: IA .... ~NA~E ~ DATE ..;' , , _ . DI..$TRICT DRILLING SUPERVT,qO~ 4 TITLE PAGE NO.. .(NUMBER ALL DAILY WELL HISTORY FORMS CONSECUTIVELY AS THEY ABE PREPARED FOe EACH WELL, ) .- PRINTED IN U,S,A. 3B-459-2 INSTRUCTIONS: This fora is used during drilling or ,orkover operations. If testing, corinl. 0 or perforatinl, show foraation n,Ie ~n describing work performed. Number all drill stem tests sequentially· Attach description of all cores. Work per- formed by Producing Section will be reported on "INTERIM'· sheets until final completion. Report official or representative test on "FINAL*' form. (1)Sublit *'INTERIM'* sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. DALLY WELL HISTORY - INTERIM COOK INLET State ALASKA County or Parish District SOUTH ALASKA Field NORTH TRADING BAY UNIT Lease or Unit NTBU S- 8 Well No. Date & Depth at 8:00 A.M. 3-8-72 lldSS'TD 3.9-72 lldSS 'TD 3-10-72 lldS5'TD 3-13.-72 l1855'TD 3-14- 72 11855 'TD 3-15-72 l1855'TD PAGE NO. 5 PRINTED IN U.S.A. Complete Record for each Day While Drilling or Workover in Progress NTBU S-8 - COOK INLET - AP1 50-133-20233 (9-5/8" @ 10892') lldSS'TD - POH w/fish - MW 12.7#, Vis 45, WL 4.0- Took 30 sidewall samples; recovered 27, 2 empty, 1 lost. RD Schl. Tested pipe &.blind rams, choke manifold, upper & lower kelly cocks to S000 psi OK. Tested Hydril to 3000 psi OK. RIH to 11835'. Clean out 20' to bottom. · DP parted @ 4869'. POH. Found pin thread twisted off. PU 6-1/4" overshot. RIH to top. Latched onto fish. POH w/fish. Max pull 300,000#. NTBU S-8 - COOK INLET - AP1 S0-133-20233 (9-5/8" @ 10892') l1855'TD - GIH w/8-1/2" bit - MW 12.7#, Vis 45, WL 4.0. Finished POH. LD 152 jts corkscrew DP. RIH & replacing corkscrew DP. NTBU S-8 - COOK INLET - AP1 50-133-20233 (9-5/8" @ 10892') l1855'TD - Running 7" liner @ 6 AM - MW 12.7#, Vis 45, WL 4. PU DP. Went to bottom & circ 3-1/2 hrs. POH. RU to run 7" liner. NTBU S-8 - COOK INLET - AP1 50-133-20233 (7" liner @ 11829') l1855'TD l1740'PBD - Cleaning armature on drawworks - MW 12 S#, Vis 42, WL S.4 · Ran 7" liner to 7631' liner stopped Worked liner to 7775' could not work · lnr past 7775'. Pulled back to 7" lnr. LD 9-5/8" x 7" M.C. Brown hydraulic lnr hanger.. Made up new 9-5/8" x 7" Brown hydraulic lnr hanger Ran lnr to · 11829'; top of lnr @ 10775' Ran 25 its 7" 29# N-80 buttress csg, total of 1033'. Lnr equip w/Brown shoe & landing collar & 22 centralizers. Shoe @ 11829'. Landing collar @ 11740'. Top of lnr @ 10775'. Cemented 7" lnr w/ 350 sx Class G cmt w/0.2% HR-7; 10 bbls water ahead of cement & S bbls behind· Displace cmt w/233 bbls mud. Bumped plug w/2500 psi. CIP il:S0 PM 3-10-72. 1/2 trip out of hole. 19 hfs working on drawworks. 1/2 trip in hole w/8-1/2" bit. Found top of cmt @ 10217'. Drilled out hard cmt to top of lnr @ 10775'. Test lnr lap w/1S00 psi for iS min OK. POH. Made up 6" drilling set up. Started in hole. Blew fuses in SCR. Replaced fuses & cleaning armature on drawworks #2 motor· Down 8 hrs. NTBU S-8 - COOK INLET - AP1 50-133-20233 (7" lnr @ 11829') 11855'TD l1740'PBD - Logging - MW 12.5#, Vis 40, WL 6..0. Down total 16 hrs for SCR repairs. Finished in hole. Cleaned out 38' hard cement 10775-10813'. Tested liner lap w/1S00 psi. for 1S min OK. Circ & cond mud @ 11600'. Logging. NTBU S-8 - COOK INLET - AP1 50-133-20233 (7" lnr @ 11829') l1855'TD l1740'PBD - RIH w/DST tools to test liner lap - MW 12.S#, Vis 39, WL 6.4. Ran GR-CBL from 11605-8300'. Good'cement bond behind .9-5/8" w/top of cement @ 9375'. Poor cement bond behind 7". Ran DST tools w/4135' water cushion to te~t liner lap.-Tools leaked & DP flowed back mud. POH. Left top packer rubber in hole. Redressed tools. GIH. C.O I A L The SIGNA~RE DATE DISTRICT DRILLING SUPERVISOR TITLE (NUMBER ALL DAlLy WELL HISTORY FORMS CONSECUTIVELY AS THEY ARE PREPARED FOR EACH WELL. ) INSTRUCTIONS: This fore ia nsed during drilling or workGver operations, If testing0 coring., or perforatiug, ahoy for-arian name in describing work performed, Number all drill stem teats sequentially, Attach description of all cores, York per* forued by Producing Section viii be reported on "INTERIM" sheets until final completion, Report official or repreaentativw test on "FINAL" form. (1) Submit "INTERIM" sheets when filled out but not le,, frequently than every 30 days. or (2) on Wednesday of the week in which oil string ia set. Submit weekly for workovera and following setting of oil string until completion. DALLY WELL HISTORY - INTERIM District SOUTH ALASKA County or Parish '. COOK INLET State ALASKA Field NORTH TRADING BAY UNIT Lease or Unit NTBU S-8 Well No. Date & Depth at 8:00 A.M. 3-16-72 ll8S5'TD 3-17-72 l1855'TD 3,20-72 11855'TD 3-21-72 l1855'TD 3-22-72 11855'TD 3-23-72 11855'TD Complete Record £or each Day While Drilling or Workover in Progress NTBU S-8 - COOK INLET- AP1 50-133-20233 (7" liner @ 11829') 11855'TD l1740'PBD - Testing - taking final shut 'in @ 6 A~\! - btW 12.4#, Vis 39, WL 6.5. Ran Howco DST tools on 5" 19.5# Dp w/4135' wtr cushion. Set 9-5/8" Halli packer @ 10741'; 2-7/8" perf tail including 2 outside pressure recorders @ 10763'. Opened tool @ 9:50 AM 3-15'-72 for a 61 min test. Had a light blow · decreasing to dead in S min. Dead balance test. Pulled pkr free. POH. Recovered a net fluid rise of 280' drilling mud. Charts indicated tools operated properly. IHP 6486, IFP 1798, FFP 1798, FHP 6486 (outside pressure bond)' RU Schl. Jet shot 4 1/2"'holes @ 11372' DIL measure. Ran Howco 7" DST toolS on 752' x 3-1/2" 13.3# DP on S" 19.5# DP 7000' wtr cushion. 5/8" beam. Set 7" Halli pkr @ 11306', 2-7/8" perf tail including 2 outside recorders @ 11329'. Opened tools @ 4:50 AM 3-16-72 for a 1 hr test. Had a very weak blow thru out test. Closed tool in @ 5:50 AM for a 1 hr shut in; taking shut in @ 6 AM. NTBU S-8 - COOK INLET - AP1 50-133-'20233 (7" lnr @ 11829') 11855'TD l1360'PBD - Cleaning mud tanks, prep to displace water w/Invermul. 'Finished taking WSOshut in thru perfs @ 11372'. POH. Recovered net fluid rise of 188' mud. Pressures IHP 6868 psi, IFP 2826, FFP 2875, ISIP 6144, FHP 6868. Ran gauge ring on WL to 11358', stopped. Ran E-Z drill plug & set @ 11560'. Ran in w/DP & displaced mud with inlet water. NTBU S-8 - COOK INLET - AP1 50-133-20233 (7" lnr @ 11829') 11855'TD l1360'PBD - Running completion assembly - MW 9.2#, Vis 46. Dis. placed hole w/9.2# Invermul mud. Ran & set Baker Model F 7" x 4" packer @ 10824' on Schl line. With Schl 4" jet csg gun shoe 7 1/2" holes/ft 107580 10583', 10526-10492', 10450-10418', 10396-10376', 10365-10330' 10312-10295', 10275-10220' for a total of 368'. Made 13 runs w/no misruns. R~H w/8-1/2" bit & csg scraper to 10775'. Cond mud 2 hrs. LDDP. Installed 4-1/2" tbg rams. Running completion assembly. NTBU S-8 - COOK INLET - AP1 50-133-20233 (7" lnr @ 11829') 11855'TD l1360'PBD - Removing BOP - MW 9.2#, Vis 47. Ran 3-1/2" & 4-1/2" completion assembly, spaced out on Baker packer @ 10824'. Landed tbg hanger, tested ball valve control lines. NU BOP & riser. NTBU S-8 - COOK INLET - AP1 50-133-20233 (~" lnr @ 11829') 11855'TD l1360'PBD - Changing out hydraulic pump on Otis power unit. Removed BOPE. Installed wellhead. Tested to 5000 psi OK. PUMP 100 bbl unweighted Invermul. Displaced Invermul w/diesel. Pulled ball valve. Set "X" plug in nipple @ 10016'. Hydraulic pump failed on Otis power unit, unable to shear off plug. NTBU S-8 - COOK INLET - AP1 50-133-20233 (7" lnr @ 11829') 11855'TD l1360'PBD - Working to free plug. Set Otis XX Plug @ 10016'. Set Baker hydraulic packer @ 9975'. RIH w/Otis WL, unable to pull XX plug. PAGE NO. The Above is Correct: SIGNA~RE DA~ DISTRICT DRILLING ~UPERVI~OR T~TLE 6 ...(NUMBER ALL DA~LY WELL ~]STOBY FOR~S CONSECUTIVELY AS T~EY ABE PREPABED PRINTED IN"I~. A. 3B-4S9-~ 12/67 INSTRUCTIONS: This fora is used during drilling or work@var operations. If testing, coring., or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores, Work per- formed by Producing Section viii be reported on "INTERIM" sheets until final completion. Report offieial or representative test on "FINAL'' fora. (1) Submit "INTERIM" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week ~n which oil string is set. Submit weekly for work@yarn and following settin$ of oil string until completion, DAILY ~/ELL HISTORY - INTERIM ALASKA District SOUTH ALASKA ......... County or Parish .... COOK TNT,ET State Field Date & Depth at 8:00 A.M. 3-24-72 11855'TD 3-27-72 11855'TD 3-28-72 11855 'TD 3- 29- 72 11855'TD 3-20-72 11855'TD NORTH TRADING BAY UNIT Lease or Unit NTBU S-8 Well No., I Complete Record for each Day While Drilling or Workover in Progress NTBU S-8 - COOK INLET - AP1 50-133-20233 (7" lnr @ 11829') 11855'TD l1360'PBD - Recovering 0.009 WL - Unable to pull Otis XX plug @ 10016'.. Put well on gas lift; unloaded diesel from tbg. Worked plug, unable to pull. Recovered 574 bbls of diesel, unable to pFll.plug. WL parted @ .counter, left 3' of WL above lubricator. Dropped WL cutter & cut line @ top of rope socket @ 10003'. Recovered WL, measured 10003'. NTBU S-8 - COOK INLET - AP1 50-133-20233 (7" lnr @ 11829') 11855'TD l1360'PBD - Testing BOP - MW 8.8#, Vis 40, WL 4.8. RD Otis .009 WL unit. RU Otis 1/4" WL unit. Recovered WL cutter. Ran 3-1/2" plug on WL to check fluid level, no fluid in tbg. Pumped 100 bbls diesel in tbg. Took hold of XX plug @ 10016', unable to pull. While GIH w/overshot, tools hung up @ 8886'. Left skirt & guide in hole. Tried to push junk down hole, unable to do. Filled 9-5/8" annulus w/diesel. Shot 4 1/4" hole @ 8660'. RU Halli to displace hole w/Invermul. Pumped 25 bbls.. Pressured up to 2800 psi. Reshot 4 1/2" holes. Displaced hole w/Invermul mud. Well dead. NU BOP. NTBU S-8 - COOK INLET - AP1 50-133-20233 (7" lnr @ 11829') 11855'TD l1360'PBD -'Dressing seal assembly - MW 8.8#, 45 sec, FL 4.2. NU & tested BOP. Pulled Baker hydraulic packer @ 9975' w/190,000#. Circ out & POH. Found barite in jt above X nipple. LD gas lift valves for retesting, dressed hydraulic packer, changed seals on seal assembly for lower packer. NTBU S-8 - COOK INLET - AP1 50-133-20233 (7" lnr @ 11829') 11855'TD l1360'PBD - Prep to set hydraulic packer - Ran completion assembly w/1 X@ sleeve open. Spaced out on Baker packer @ 10824'. NU. Tested ball valve liner. Pumped in tbg w/100 bbl unweighted Invermul followed with 798 bbl diesel thru XO sleeve @ 10704'. Circ clean diesel to surface. Ran WL. Pulled dummy ball valve. Closed XO sleeve @ 10704'. RU to set hydraulic packer @ 9975'. NTBU S-8 - COOK INLET - AP1 50-133-20233 (7" lnr @ 11829') 11855'TD l1360'PBD - Testing well on gas lift; cleaning, prep to RD - Set hydraulic packer @ 9975' w/2500 psi. Opened XO sleeves @ 10699' & 10704'. Pressured tbg w/1000 psi to check packer set OK. RU gas lift. Released well to Production @ 3:00 PM 3-29-72. Clean rig & mud pits. PAGE NO. PRINTED IN U,S. A. The Above is Correct: SIGNATURE DATE DISTRICT DRILLING SUPERVISOR TITLE 7__ ,(NUMBER ALL DAILY WELL HISTOIlY FOIlMS CONSECUTIVELY AS THEY AilE PIlEPAIlED FOil EACH WELL. } 3B-459-2 12/67 -~ !NSI~tUCTIONS: Prepsre snd subnit the FINAL REPORT on the first Wednesdsy after allowable has been ssaigned or ,ell i~ Plugged'~ -' Ab&ndone'd. 'o'r Sold. FINAL REPORT should be submitted ~1~o ~hen opera~ion~ ~re suspended for length of ti~e On ,orkovers when an official test is not required upon completion, repor~ co~ple~ion and representative ~est dace in blocks provided. The FINAL REPORT form ~ay be used for reportin~ the entire operation District DALLY WELL HISTORY - FINAL REPORT SOUTH ALASKA County or Parish COOK INLET State Lease or Unit NTBU S-8 Title Development Oil Well NORTH TRADING UNIT Field ALASKA Well No. Auth. or W.O. No.,, 198374 · Operator_ Spudded or W.O. Begun ATLANTIC RICHFIELD COMPANY TARCO' S W.I. 61.28~ 1-17-72 Spudded 'Date 1-17-72 Prior Status Hour 9:00 AM if a W.O. Date & Depth as of 8:00 A.M.' 4-3-72 11855'TD Complete Record for Each Day Reported NTBU S-8 - COOK INLET - AP1 50-133-20233 (7" lnr @ 11829') 11855'TD l1360'PBD - Production testing Hemlock - Cleaned up rig. RR & crews 12:01 AM 4-1-72. Will carry further testing on Production R~port. Old TD New TD 11855' PB Depth" 11360' Released Rig 12'01 AM Date 4-1-72 Kind of Rig Rotary_ Classifications Type Completion (Oil, Gas, etc.) OJ] (Single, Dual, etc.)- Sinfle . Producing Method Gas Lift Official Reservoir Name(s) G Producing & Hemlock Potential Test Data' OIL OB TEST TIME , PRODUCTION , WELL NO. DATE RESERVOIR PRODUCING INTERVAL GAS. ' OIL ON TEST GAS PER DAY __ ~/. : . 8-8 4-3-72 G .P. ro.due.i-ng & 10220-i0758' Oil' 25 hours 3749 800 mcr" lJem[o~ . .. -- PUMP SIZE, SPM X LENGTH CHOKE SIZE T, P.- C, P, WATER ~; GOR GRAVITY ALLOWABLE EFFECTIVE' DATE.~ CORRECTED -- ) ~ . · - .. Gas Lift 3" 145 1100 2.5 2_13 35 Capaei't:' 4-3-72 Distribution: The'Abov~ is Correct Orig., Drilling Section - Dallas cc:- District Office Engineering Division - (720) SIGNATUnE DATE Co-~ner(s) - As Appropriate DISTRICT DRILLING S~ERVISOR Begional Office~ Well Becord File 5-~PAGE NO, 8 (NUMBER ALL DAILY ~ELL HISTOBY FORMS CONSECUTIVELY AS THEY ABE PREPABED FOM EACH ~ELL. ) SYMBOL OF SERVICE REPORT of SUB-SURFACE DIRECTIONAL SURVEY ATLANTIC RICHFIELD COMPANY CO. SPARKS PLATFORM S-8',41 34) JOB NUIvlBER AMG2-172 SURYEY BY WELL NAME COOK INLET LOCATION TYPE OF SURVEY SINGLE SHOT DATE 3-7-72 KORII D.~Oal R 2.UTHO 8Y EASTCO IN U.S.A. ATLANTIC RICHFIELD CO, N,T,B,U, (41-34) S-8 LEG. I 5LOT o COMPLETION REPORT 3/8/72 SURVEY 1/17/72 TO 3/'J/72 MAGNETIC DECLINATIO!,', 25 DESREES EAST K.B. ELEV, 11.~ FT. TANGENTIAL METHOD GF COMP~jTATIONS BY F. ;¢. L!r4DSEY AND ASSr)C. SURVEY RY EASTMAN OIL WLLL SURVEY CO'~¢,PANY RECOi~.D OF SURVEY ALL CALCULATIONS PERFOF:~,v. EW BY I B :'.' ELECTROr..JIC .. _ . ...... TRUE MEAS, DRIFT.VERTICAL DEPTH ANGLE DEPTH SUB DRIFT TOTAL ~.Q,.,RD INA. T E S SEA D I REC DEG, .THE FOLLOWING DATA IS 0 0 0 0,00 63 O 0 63,00 88 0 20 8'7,99 ....... 113 0 25 1.12,99 1~8 0 15 137,99 163 0 30 162,99 . 188 0 30 187,99 .... 213 0 30 212,99 _. 238 0 30 237,99 263 0 30 262,99 .... 288 0 25 287,99 313 0 30 312,99 338 0 35 337,99 ._ 363 0 50 362,98 388 0 55 387,98 '._ 413 .... 432 0 25 ~31,98 500 0 10 499,98 ~. 600 0 30 599e97 " 700 2 25 ~99,88 .. . 800 4 10 799.62 - %000 4 15 999,10 FROM SPERRY-S UIN SURV£Y NO, $U-3-16725 -115,')0 N 0 E -51,99 N 0 E -27,00 N 82 W -2,00 S 69 W 22,9~ $ 80 W ~7.99 $ 85 W 72.q9 $ 67 W 97,99 5 60 W 122,99 $ 62 ~ 147,99 $ 61 W 172,99 $ 51 W 197,99 $ 21W 222,99 S 10 w 247.98 S ~ E 272,98 $ 6 E 297,98 $ 15 E 316,98 N 50 E 384,98 N 56 E 484,97 S 17 W 584,88 $ 22 W 684,62 $ 2g W 784,38 S 31 W 884,.10 S 35-w 33.49 S 75.05 33,49 S 75,05 39,4o S 7b,l~ 3~..57 S 75.69 33,69 S 75.g9 33,76 S 76.08 33,87 S 76,27 33.,97 ~ .... 76,~7 34,09 $ - 76.61 3~,29 $ 76.69 3~,55 S 76'.73 35,32 S 76,67 35,44 $ 76.51 35,32 S '76.34 36.16 S 76.59 40,09 S ~: 78,18 52,71 S 84,7~ 58'.78 S .... i:'8~.9~ .. .. X.~. ............... :.,.~ DEG/IOCF.T .... DI~TA,~CE w 0 · 000 ............ 7 ...~. ~5 w 0.5~0 ............... ~.0,~ 39 w 1. 186 _._ 59 w 0,~05 ........ 1~ w 1.772 ........ ~ ~...~: 40 W 0,6~1 : 6 W 1.9~2 ..... 3~ W 1,744 .......... ...... · , C (.;,'4 i'" LIT t., ~x {) I ST ANCt: A.",i,6 L u.. 5U3-10355 N2.1~ S 65 57 6 82.15 ~2,39 5 66 0 23 8£,b0 S ~b 1 ~3,67 63,85 5 66 0 84.01 g~.15 S 65 46 ~4.29 S 65 31 84.42 S 65 15 ~4.4b 5 8~.~2 S 56 8 5~,12 S 65 lO 8a.70 S 64 43 67.86 S 62 bl 93.64 S 50 3 99.7~ S 5~ 6 106.65 S b6 33 RECORD OF SURVEY _ .i~!~ .. ALL CALCULATIDN$ PERFORMED BY I B ;". ELECTRONIC CCi?PUTER .. TRUE .MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M 1100 5 50 1098,58 SUB DRIFT SEA DIREC DEG, 98~,~R $ 37 w 1200 5 40 1198,09 1083,09 S ~1 W 1300 6 40 1297,42 1182,42 $ 41 w .1~00 7.15 1396,62 1281,62 $ 42 w .1500 8 15 1495,58 1380,5u $ ~6 w .... laO0..lO 5 ..1594,03 1479,03 $ 49 W . 1700 12 O. 1691,85 t576,85 S 52 W 1800 14 15 1788,77 1673.77 S 53 W 1850. 15 10 1837,03 1722.03 $ 53 w · 1900 16 15 1885,03 1770.0B S 55 v~ 1950 17 20 1932,76 1817,76 $ 56 ~ TOTAL COCRDI?~ATE5 66.9£ S :.95.ii w 74.3& S 1!~1,59 W 83.13 S 109.21 w 92,51 5 lJ~7.65 W 102,4B S 12'7,9~ w 126.77 S 1.~7.56 W 1~1.58 S !.27.2¢ w i~9.~ S 187,69 W .... 2000.18..30 1~80,18 1865,1B S 5'7 w 17~,~O..S . 22,,81 .W 137,25 S b2 ~ 15 W 1~.57 S 51 ~9 20 W J02.25 S 51 1i 1 w 239.~B S D1 2U 9 W DOG Lr_G C L 0 S U .~, E S SEVERITY._ .... / r ~ "' , :).[STANCE A~\~LE DEb iOOF,[ .... D/S.IANC~ O M S :' : .":':~ 116.2~ ~ :.~ ~Z 22 W 1.~99 s w , . o. ............ 1.99~ ........ 2OZ, O1. 2,261 ............ 1,840 ..Zb~..2~ 15, 25.68.58 gu53.58 S 59 W 293U 26 15 2829.57 .271~.9'/ S 33 W ~120 27 0 2995,30 2880,~0 S 32 W 345~ 26 45 3292,66 3177,66 $ ~ w ~05 25 45 4060,05 3945,05 S ~4 ~ 5048 24 0 4738,82 4623,82 5 37 ~ 5~11 22 15 5167.34 5052,34 S 38 :.'; 6115 21 15 5730,28 5615.28 $ 43 W 6591 24 45 6162,55 60~7,55 $ 4~ ~ 6770 25 30 6324,12 6209,12 $ a9 W 7Q12 25 0 65~3,44 6428,4~ S 50 w 7296 25 0 6800,83 6685,83 5 49 w __7.902 24 45 ~987,91 6872,91 S 49 w 7802 24 15 7261,4~ 7146,44 S 50 W 8066 24 15 7502,14 7387,14 S 52 w THE FOLLOWING DATA IS FROM EAST~AN ~AG:';ETIC SI,NOLE SHOT SURVEY NO. A1-172 ' ~'~ 22Q5 22 45 2169,23 2054.23 S ~l w 212.89 S 294,1~ w ~,11 5 b4 25~8.2a 15 2481,96 2366,96 S 59 W 285,45 .S ~14,90 w b03,61S 55 2~ 20 ~' u,~95 ......... :.',': ', ' ~,844 ..... b~2,2~ p42.,_56 S 55 43 ~2_W 6~3,14 S 51 2D 32 W 743,~1 S 49 15 37 w 1252.08 $ 42 5d ~ W 15~,00 $ ,1 43 42 w 17g7,~9 S 4.~ 21 1 2144,95 S 42 U ~ W 2ZZl.~8 5 42 22 22 W ZB2Z,B~ S 42 42 27 W a19,49 '$ 518.49 485.10 ;..S 5~3.19 610,80.:5 ~4,~Z 917e67 S 851,8i 1497,27 ~S Ig90,91 1590,62 S 1439,01 16~1,17 .$ 1497,17 1706,91 ..~ 1575,5% 1842,24 .$ .!7B1,19 1921,4~ S 1825,~'? ~- Z650,gl S 43 32 ~ W 1~8,1~-S lVll,02 W Z7b/,7O $ 43 bi 5~ W .MEA$, DRIFT -DEPTH ANGLE RECORD OF ALL CALCULATIONS PERFORMED BY TRUE VERTICAL. SUB DEPTH SEA 7801,31 DRIFT D[REC ....... DEG. SURVEY I B :~ ELECTRONIC COMPUT£R .. TOTAL COORDINATES .... 8.665 22 15 ..... 8859 21 15 9195 2O 0 9377 20 30 ........ 9640..24 ..... 0 ..... 9921.27 10119 26 45 ..10.287 26 . 0 1038/+ 26 0 10650 25 30 .... 10812.25 . 0...1 1115/+ 22 15 1 11513 23 0 1 11855 25 0 1 8O 82 85 87 89 92 93 95 98 O0 O3 O6 09 ................... DOG..LEG ~- C L 0 S~U.R E _S ................ SEV.ERI.T..~ ......... SEC~i.~ DISTANCE ,. ANGLE ............ DEG./i:~O. EiT~ ..:. D,[.ST. AN.~! .......... D _M S ..7686,31- S 53 W 2064,62 S 2012,43 .W 288 54.91 7939.91 S 5 35.72 8120.72 S 5 51.~5 8435.~5 ..S 5 21,93 8606,93 S 5 62.19 .... 8847.19 ....... 5_5 10.87 9095.87 87.68 9272.68 38.88 .9423.68 25.86 9510.88 65.95 9750.95 12.77 9897,77_. 29.31 1021~.31 59.77 105~.77 69.72 1085~.72 5 W 2124.12 S 2097.~Z..w 298 ~ w 2165.~5 S ..... 215~.31 w 305 7 w 2228,0~..5 ...2250,68 w 316 B W 2251,82 S 230~,7~ w 322 8.W , 23i~.5.1_S .... 2395,~....W 33~ 6 W 2391.67 .S 2503.92 W 34~ 5 W 2441.50 S 2577.81W 355 7 W 2481.61S 2639.57 W 382 7 W 2504,77 S .2675,23 W 366 8 W 2565,45 S 2772,3~ W 377 ~ W _2600,72 S ....... 2~1,0~ .W .... ~8~ 8 w 266~,3~ S 29~0,85 w 397 9. W 274i~59 S 30~1.0~ W /~AO 6 ~ 2822,41S ~-3180.92 W ~ 425 R'(~-TTo'M HOLE 'CLOSURE ~252.~6 FEET .~T $ 48 25 3 W 3,15 S 44 16_. O..W ....... O.~.O~ ........... 5,15.._S ~..38 .... 15 .... W ......... 0,392_ 4,54 S 44 51 ..... 7_W ..........0..55.0: ...... ~,~8 5 .45.~7 22 W ........... 0,.48_7 ...... ~.19..5 ~5 32--.1~ w .......... 0,.33~ ........... ~.,72 S ~5_~ _,_~ .... N ......~.,..3.~1_.~~.~.~ 2.52 S ~5 18 ~8 W ....... 1,370 ......... 2.95 S ~ ~5 59 W 0,51~. 3621,~2~ ~.~0 S ~6 53 .... 5._W 0.000 ........... '~.£* S ,7 l~_lO.W ........... 0,2~9.~ ............. 3.7_?_.~,}.N~ 1,65.5 ~7 ~6_..l~..W ........... 0,813 ......... $g_7~.,,3~ w.~3..S ~_~9 __.5 .W ........ 0.23~ .... ~..0_~...,.2~ ~,. MARKER .... 36~2 3462,89 678,87 ............ . .................................................................. ........ I NTERPOI..ATED ..... T RUE--. ~ VER.T-.t CA L--..D E P T H$ * "'ii;~'" .-.iii ....... .ii ........ TRUE CODE ............ MEASURED VERTICA. L ..... TOTAL C.OORD~NAT.E5 ..... C. L O_$..U .R_.E .................... SUB --.:~ NA~E .... DEPTH _ DEPTH ........ D ~ STANCE A,NGLi,: .................... SEA ............ .............. O M 5 ........................... ....................... ......................... S 690,7~ W ~58,50 S MARKER ... 3804 ~ARKER ........... 4030 MARKER . _ 4456 ~RKE~ ............................ 4.951 MARKER ...... 4966 MARKER .... 5~6 MARKER ....................... 7~20 MARKER ...................... 8225 MARKER ....................... 9~]7 ........... 868~ .MARKER .......................... 95.5~ ...................88.85 HARKER _10193 9454 3608,80 737,22 S .. .730,10 .W 1037.55 5.4~ 4198,00 966,72 S 888,77 W .131~,19 5 ~2 35 ~0 W ~083,00 ...... ~650.20 ............. 1127,51 ~S ........... 1009,~._W ............ 1513,69 .... S .... ~563.91 1132.38 S ...10~3,6~ ..W 1519.77 5 ..~ 5107,18 1277.77 S .......... 1.~25.~5 .... W 170~,~2 ...... 5 6822.53 ~792.25 5 ......... ~573.68 W 2~52.22 5 ~3. 2.2b..W .... 5707,63. ......... 764.9,~3 ..... 2025,82_5 ............ ~950,.95 .... W ......... 28~9,~ ......... S ~ ..... ~ ........ ~_._W_ ........ 7.5~.~.,~ .b6 ..... 225~,~0 5 ........ 2292., 86.....W 32~5,.51 5 ,~9 2459,~7 5 2~05,0~...W_ . ~582,41 ,55 . 25~2,53 · 83 . 2568,97 .83 ......... ,70 MARKER 10418 9656 S . 2687,65 .W_. MARKER ................ 10758 9963 S 2811,47..W MARKER ..10907 10100.70 2619,78 S 2851,54 W MARKER .11175 103~9,55 2673.77 S 2948.22 W MARKER ................. ~13~5 ....... ~05~,25 ..... 2709,99 $ ............. ~O.O~,~__W. MARKER 11581 10721,40 2757,56 S 3084,92 W MARKER 11790 10856,44 2792.~7 S ~137.12 W .- 3679,17. S 45 _5.5._.43 ..W .... 9541 3821,9~ S 47 21 ~'3_W 98.~8 ~879,55 $ 47 31 31 W 9985 3980,09 S ~7 z~7 ~1 W 1023~ fi137.~0 ~ ~ 12 21.W 1060~ ~200o20 $ ~8 19 20 W 107z, l MEASURED.DEPTH..AND OTHER DATA FOR TRUE MEASURED VERTICAL SUB DEPTH DEPTH SEA 215 215. 100, ........... 315 315, 200, ..... ~15 415. 300. ......... 515 515. 400. ............................ 615 .............. 615, .. 500, 715 715. 600. .._ 815 815. 700. 915 915. 800. 1016 1015, 1115 1115, 1000, ........................ 1217 ............... 1215, 1100· · 1318 1315. 1200. 1~19 1~15, 1520 1515. lqO0 1621 1615, 1500 .. 172~ 1715. 1~00 ............. 1827 ................ 1815, . ..... 1931 1915. 1800 2038 2015, 1900 . .. 21~6 2115. 2000 ... 2255 2215. 2100 2365 2315. 2200 ....... 2~7~ ............. 2~15, 2300 258~ 2515, 2~00 .. 2695 2615, 2500 2805 271~, 2500 2918 28~5. 2700 3030 2915. 2800 ......... B~2 ...... 3015, 2900 3254 3115, 3000 3366 3215, 3100 _. 3478 3315, 3200 3589 3415, 3300 .. 9700 3515. 3~00 3811 3615, 3~00 · · · .. · · · · · · · · · · · · · · EVERY.. EVEN.. iOQ.._FEET gE ..SUB- SEA.-.DEPTH, N;D-TVD D I FFERE,'tC:E VERTICAL CORRECTION- 0 0 .0 _0 .......... 0 0 0 0 0 ............... _0 0 0 0 0 1 1 1 0 1 0 2 ......................... 1 TOTAL COORDI~;ATES 33·77 S 34.31 35·52 $ 35,45 S 36,75 $ ................... 76.53._.W ........ ~1·10 S 78o6B 53.5~ S 85,~0 W 60,08 68,14 $ 96.18 .W ........ 75.8.6...5 ......... 102.89_W 84.79 5 110.71 W 9~.3b $ 119.~7 76,10 W "~ . 76,59 .W .................................................................. 75 · ~0 .~ W .................................................... ~'?. 76,38 W ............................. '" 5 1 6 9 3 _12 .................................. ~ ............. 16 40 9 50 10 104.74 S 116.71 S 130.31 S ......... 145,86 .S ..... 162.72 S .206 181.54 S 237 201,87 S 274 223,51 S 311 246,71 S 3bO 14~.71 W ....................... 152.28 W · 92 W ............................ .91 · 58 W · 26 W ......................................... · 82.W ................................... · 43 ..W .................................... '~'. "' 50 69 80 91 103 115 127 139 151 163 174 185 195 .... 10 ............... Z69.91 S 9 29~.11 $ 11 324.7~ $ 11 ~56,10 S 12 407·4o S _.389,04__W ~27,66_W ~60.81W 487,67 w 514,93 W 12 ...... 12 12 12 12 11 450,40 S b41.51W ~93,4Z S ......... 568.o0__W 535.70 S 59b.05 W 577.97 S 523·50 W 619,73 S 650.85 W 659,72 S 677 · d2 W .................... 11 11 699.71 S 7~9,70 S 704·79 W 7~1,77.._W MEASURE,[') DEPTH... AND OTHER i)ATA TRUE MEASURED VERTICAL SUB DEPTH DEPTH SEA ,.- -- 3922 . . 371,,5, 3600, · .- 4'033 .. 3815, 3700', ...... 4.14, a 3915, 3800, ..... 4'255 4.015, 3900, ............. 4355 .............. 4.115, 4.000, ........... 4.~+ 75 ._ 4215, 4,100. 4584, 4.315, 4.200, /+694. 4.4.15, 4300, 4803 4.515o '+400, 4,912 4,615, 4.500, ....... .5022 ........ 4.715, /4,500, 5130 4815, 4.?00, 5238 4.915. 4,800, .53~+5 5015, 545~+ 5115. 5000. 5562 5215, 5100, ............. 5669 ........... 5315," 5200, .5777 5/'15. 5,300. 5884 5513, !5400, 9991 5615, 5900, 60Q9 5715, 5600, 6208 5815. 57O0, ........ 6318 ...... 5915, 5800, 6429 6015, 5900, 6539 6115, 6000. 6649 6215, 6100, . 6760 6315, 6200, 6870 64.15, 6300, ........... 6981 ......... 6515, .6400, 7091 6615, 6500, 7201 6715, 6600, 7312 6815, 6700, 7422 6915, 6800, 7532 7015. 6900. ~7641 _ 7115, 7000, FO~ EVERY EVEN MD-TVD DIFFERENCE 207 218 229 2~+0 250 260 269 279 2~S 297 3O7 . 315 323 331 362 37b 414 4~4 445 455 476 486 497 507 517 526 IO0-FEET OF.-&U8 SEA-DEPTH, ....... VERTICAL CORRECTION TDTAL COORDINATES il 11 11 11 ......... 10 9 10 9 9 8 8 8 8 8 7 7 9 819,67. 859,66 899,65 937,20 972,76 1U08,32 !0~3.87 1079,43 1114,99 1150,55 1183,58 1215.~1 12~8.05 1280,2W 1310,72 ........... 1~39,1~ 1367,60 1395,0~ la52,92 10 .................. lb14,2b 11 1545,10 10 i~7~,95 10 1607,0~ 11 1538,32 10 .. 1668e4i 10 1728.80 10 1759,39 11 1789.94 10 1~20.18 10 1~50,0~ 9 .. 181'~.0~ S 785 · 71.. W ................. S .. ~!.2,58 W ................... __...,_,,. S 839,66. W.. S ............. 866 , S 893,.32 W .................... S 920 · 12 . W ....................................... S 9Z~5,91 W S 973 , 71 W ....................... S 1000,50 w S ....... 10.27 · 3.0 .....W S 1052.87 w S 1078 , U5 W .... S 1103,24 W S 1128.a3 W ............................ S '115~+. 25 W '-- '--~' :; S .......... ll~O, 77 ...W .............. S lZ07,30 W S 1233.o2 W '- ~ 1260,3~ W S 1286,U6 W ."; S 1319,94, W S ....... 1354,,20_,W._ S 1388 .~6 W S 1422,71 W $ 1457,89 _W S i492,u8 W S 1529,63 W S ..... 156.5,2~ 5_W. S 1600,51; .W S 1535.89 W 5 1671.0Z W S 1705.82 W S 174C,53 W S _. 1775,04..W MEAS1JRED ,DEPTH A~gr'~,, OTHER TRUE v'E A SUR FD V F.'-. FR 'T'I C ZNL F)E:PT H 7751 7215. 7 8 a 1 7315 · ?970 7415, 8080 7515 · 8189 7615. 8297 7715, 8406 7815. 851a 7915. P, 622 8015, 8729 BllS. 8837 8215. 8943 8315. 9050 8415. 9156 8515. 9263 8615. 9370 8715. 9479 8815. 9588 8915. 9700 0015. 9813 9115. 9926 9215. 10038 9315. 10149 9415. 10261 9515. 10372 9615. loa83 9715. 10594 9815. 10704 9915. lOs]a 10015. 10922 10115. 110 30 10215. 111 39 103 15. 112a7 1041.5, 11356 10515. 11464 10615, DATA FOR , ~, ..... ?,1 lOU FEET SUP., F'"~-TV[3.:,.. VEiiTICAL .SFA D t ~F':.--' ;" "Ct.: CO''~ ' . ' ,,k'E.C T I ,.,', 7100. 536 7200. 546 10 73:30. 55b 9 7400. 565 75,2,0. 574 9 7600. 582 7700. 591 9 7,BOO. 5~9 8 7900 · 607 8 8000. 614 7 8100, 622 8 ~200. ~2~ 830'D. 635 7 8~00. 641 6 8500. 648 7 ~600. 655 7 qTC;O. 664 9 f~BO0, 573 8900 · 605 7,,')00 · 6'~ 9100. 711 92~0. 72~ i2 9300. 734 11 9403. 746 12 9500. 757 11 9600. 75a 9'79C. 77u 11 9900. 797 19 1000~. 8U7 8 10 100. 8 i 5 i0200. 824 9 10300. B32 8 104o0. 841 9 10503. 849 T C I A L C U :3 R 01 ,'.; .;~ I' E b 1907,R9 S i509,5:; 1'~'35 · 2') S 1544.;5 1964.02 S ~gUC.O6 lW~'l.4B S 1915.~7 2'J42,5'/ S 19~3.1'7 206'7.8~ b Z017.02 2U~1.29 S 205U.p3 211~,'7~ $ 2084.05 2137.86 S 21i6,~3 2160.72 ~ 21~7. F9 21~1.i7 S Z178.2i ZZOU,9~ S 2209.03 222~.82 S 223~.;~ 2Z~.0.63 5 2Z'/C.~3 2260.~ S 23U~.b~ 2Ze3, 78 S 233~.9~ S 24id .~:.Y 2~2.83 S 2DOb.05 2~2 i · rJ, z S 2D~7.g3 2~4~.'76 ~ 2475.32 S 2agg.b8 2P01.~9 S 267C.79 2527.30 S 2711.29 ZbJ2eSo S g-/Sle /~ 29/7,24 S 2791.95 2~Jl.Zu S 2~31,~1 204~.5~ S 2W01.20 2bUS. Oj, S Z972.~3 27C)9.¢~ E 3CU8.~2 2731..~0 S ~044, ~0 INTFRDOLATED VALU,.r~$ FC, P: ~.FASURED VE,RT I C DEPTH DEPT EV,-: F AL ~.4 1000 lO00 997, 88~, 2000 198U, 1855,. 3000 2888, 277~, 4000 3785. 3670, 5000 ~694, z+579. 6000 5625. 5510, 7000 6532. 6417. 8000 7z~41, 7326, 9000 g'56t. 8253. 100[)0 9281. 9166. 11000 10196. 1()071, FFE'T OF' :',,'EASU~EO DEPTH, T ;5 T A L C 30 iq O I ;',~ 4 T F S 174,46 S a38,90 S ~ 534,32 807,81 S V 777,71 1144,70 S ].42 5,(35 S 17~3.65 S 1971,50 S 2191,72 S J-'K)RIZQNTAL" VIEW · . . ~CALE t"= 500' ATLANTIC RICHFIELD CO. WELL N.T.B.U. (4:]-34) $---6 LEG ! SLOT 6 TANGEN'F] AL -'METHOD ' OF 'COMPUTATI'-r~N ................ / / ./ TMD i1,~35~ I ! -; ..... ATLANTIC ~ICHFIE~D C : t' ' J '~~ .......... r : ~ ' --'~A'~G~E-METtlOD OF COMPUTATION ............ ~ ."I'",-'~"l~ ~ -; I I - ~ i ~ ' ',-., ' " ' ~ "1--; .... . .... ~ ................... . .. .... ~ ...... + ........ . . . : ~ ~" ~ ' ~ --- i ..... .... ~._. L.~.~.~ ~ ~. , t ~ , ~ ~.~-: : .~ . i :.;: .......................... :.-._:-.., :. ....... ........ , .. .... ~ .... ~ ............... , ........... j ........... ~ ....... J ......... , ........ ~ ....... :., i ~ ; I . ~ ; I" : ~ .... i - - L.J .L:_] l 1 , .... ,1'~'~- ~,, : .~ , ~-': ............. ~"' ..... : .................... ~ ........... i ......: ......... ~ ................... ! ............... , i i ~ i ~ ~' ~ ........ i ~ 1 i ..... ~..~..~ .; ~ . -. ~ _ ' t . · ~t;...' , '~:..~ .' , ." ~ .................... ~ ............................... , ! ; i~ ;-.I - ~ - - . ~ - , ' i I ' . --~ ...................., ~ ........... ~ .............; ....., ........ "~!.!'-', ?-i ti. ~_'"." i.. :: ' ~ ~ ~ ~ t ~ ~. , I ~ - · · i . ................ 4 .................. t ......................................... '' "~'; I .... ~ ; ~t, ~.;~ i.~ ~ '.. ,. . , , I :.~ i ........ , ..... ~.--i..:.:i..~:, : .~" ..... ; ...... ~ ,..; ~ : ~ l.i-.~ i ~ i ~" ': i _' ........................................................... 2 ............ , .......... · ......... ', .... :'---; - - I .... i,~.: :..~ ........... ~ ................ .................... .... ............ ~ .............. , I . i I i I ...... : ........................ t ......... ' ' ' i]es ....... .. T R A N S Il I T T A !. Transmitted herewitt~ are the following Fei' Well the subject well' Rtl n l'Jo. Scale Xerox Sepia Bt Line JUN 6 ~OF 01~ BHC Sonic/Caliper Log BHC Sonic/Caliper-Gamma Ray Log BHC Sonic-Gamma Ray Neutron Cement Bond Log Continuous Dipmeter (HRD) Continuous Dipmeter Polliwog Plo.~ Cont'inuous Dipmeter Printout ~ , Cor~. A'na l ys i s I nteI-\;a 1 ~_. Core No -Core description (SWC) Interval ...... i- Core description (Cony) Core 1,'o. Cores (\./et)(Pr'/) Interval Di Feet ional Log Dr-i 1 1 Stem T, eo.~ T, est No. Dual Induction Laterolog FD FS Formation Density LOg Gamma Ray-Neutron Hi crolog Hudlog ! nte rva 1_~_~_0_ Proximity-Hicrolog/Caliper Log Sample Log (ARCO) Interval · Sidewall i'.]eutron Porosity Samples (S\,IC) Interval No. Boxes Samples (Conv.)Core No. Boxes' Synerget i c Log Laterolog Recei pt Re t u r n acknowledged' receipt to' Atlantic Ricl~field Company District Gcoloflist P. O. Box 360 AI~cl~orage, Alaska 99501 Date' ,: :. '. .,. -. ! AUantic Richfield Com pa ny North American Producing Division North Ala/ ~\District Post Offic~ ~ox 360 Anchorage, Alaska 99501 Telephone 907 277 5637 May 8, 1972 State of Alaska Department of Natural Resources 0il & Gas Division 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Mr. Homer Burrell DIR J DRAFT CONFERs FII,.E: _ II_ll ........ Re: North Trading Bay Unit Well S-8 Permit 71-33 Gentlemen: Attached is a P-4 Monthly Report of Drilling Operations of the above mentioned well for the month of April, 1972. Very truly xours, B. T. Loudermilk Dist Drlg. Supvr. BTL: ll Att achment DIV!S!Ob] OF C)!L ;-",~ ID lV~r'r~ No. P~"V. ~- 1-70 STATE ,.(,. ,~d.A,SKA APl NUMERICAL CODE SUBMIT 1~ DUPLICATE OIL AND GAS CONSERVATION COMMITTEE MONTHLY RE!PORT OF :DRILLING AND WOR'KOVER OPERATIONS 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADb~ESS OF Oi~TOR P. O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL Conductor 6, Leg 1 Spark Platform 2572'N & 2559'W fr SE cr Sec 26, T10N, R13W, SM 50-133-20233 LEASE DESIGI~ATION AND SERIAL NO. ADL 17597 I'7. IF INDIA~, ALOTi~-.~. OR TRIBE NAME 8, L,~IT FARM OR LEASE NAME North Trading Bay 9 WELL NO S-8 (41-34) 10. F~ AND POOL, OR WILDCAT Hemlock & West Forelands 11. SEC., T., R., M.. (BOI~I'OM HOLE o~ Sec 26, T10N, R13W, SM 1~-. PER.MIT NO. 71-33 '"13. REPORT TOTAL DEPTH AT END OF MONTH, CHA~NGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PEI~ORATIONS. TESTS AND RESULTS, FISHING JOBG. JUNK IN HOLE A~ID SIDE-TR3LCKED HOLE A/~D A2CY OTHER SIGNIFICANT CHANG~ IN HOLI~ C~)NDITIONS. Continuing to test Hemlock & G zones. Plans for West Forelands still incomplete. C 0 N FI D E T IA Ii"il DIVi~ION OF OIL A~,i C.i-t O'.'.· ",~-t" .: hereby cattilY, that jh/f°reg°in~'lis true ~ ~ ~ T/ ~ [~ -// Dist Drlg. Supvr DA~ 5-8-72 SXG~ ~ ~,~~ ~ ~ ' ' NOY~--Regort off this f~m is required for .~ch calendar ~nt~ regardless of ~he stotus of operations, and must M flied in dupll~te wit~ oil an~ gas aonservat~on eommi~ee b~ the I~ of the succoring mon~, ~le~ otherwise directed. ,, ,~,~tla~CniChfieldC°mpany North Am~3n Producing " ~ '~, North Ala~ ,3rst~;t Post Offic~e BOx 3~0 Anchorage, Alaska 995011 Telephone 907 277 5637 DN1s~O~'4 OF O~L ~ND ~A$ State o£ Alaska Department o~ ~atu.ra_' Reso~L"aes Oil & Gas Division BOO1 Porcupine Drive Anchorage, Alaska 9~504 Attention- Mr. Homer Burrell Re: North Trading Bay Unit Well S-8 Permit 71-33 Gent lemen: Attached is a P-~ Monthly Report of Drilling Operations of the above mentioned well for the month of March, 1972. Very trAuly yours, B. T. Loudermilk Dist. Drlg. Supvr, BTL:ll Attachment '?. F~rm No. 1~. STATE O~,'~ ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICATE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. W~L~ 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF O~E~ATOR ' P. O. Box 360, Anchorage, Alaska 4. LOCATIOI~ OF WELL ,,, 99510 Conductor 6, Leg 1 Spark platform 2572'N & 2559'W fr SE cr Sec 26, T10N, R13W, SM ~7~A"' NU~EmCAn ~ODE 50--133--20233 6 LEASE DESIGNATION AND SEHIAL NO. ADL 17597 ~. IF INDIA~, ALOTTEE OR TRIBE NAME 8. L,~IT.FARM OR LEASE NAME North Trading Bay 9. WELL NO S-8 (41-34) lO. FI~IJI~ A_ND POOL. OR WILDCAT Hemlock & West Forelands 11. SEC., T., R., M.. (BO~I'OM HOLE OAJECTr~ Sec 26, T10N, R13W, SM 12. PEB,MIT NO. 71-33 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA~NGES IN HOLE SIZE, CASING AND CKNIENTING JOBS INCLUDING DEPTH SET AND VOLU1VIES USED. PEt{FORATIONS, TESTS A.ND 1RESULTS. FISHING JOBS. JUNK IAI HOLE A.ND SIDE-TRACKED HOLE A/~D ANY OTHiER SIGNIFICANT CHANGES IN HOLE CONDITIONS. See attached sheet ~. - ,, ,, .... sm~ ,~, Z/g-~¢'~ =~ Dist. Drlg. Supvr. nAE ~--/~- 7~ NOTE -- Rtpor't on this fo~ is require4 for each calendar ~nth% regardless of the status of operation, and mUSt ~ filed ~n duplicate with the oil and gas conservatbn commtflee bytbe 15~ of the succ~ding ~n~, ~le~ otherwiee directed. TBU S-8 (41-34) 3-1-72 Drilled 8-1/2" hole 11154-11855'TD. Ran DIL, FDC and Dipmeter 11836-10888'. Loggers TD 11836'. Recovered 27 of 30 sidewall samples. Tested rams, choke manifold, upper and lower kellycocks to 5000 psi OK. Tested Hydril to 3000 psi OK. Clean out 20' to bottom and drill pipe parted at 4869'. Recovered fish. Ran .7" liner w/9-5/8" x 7" hydraulic liner hanger. Liner tool hung. Pulled liner back out of hole. Reran liner to 11829' w/top at 10775'. Liner consisted of 25 jts 7" 29# N-80 buttress casing, total 1033' with 22 centralizers. Shoe at 11829'. Landing collar at 11740'. Cemented 7" liner w/350 sx Class "G" cement w/0.2% HR-7; l0 bbls of water ahead of cement and 5 bbls behind. CIP ll:50 PM 3-10-72. Drilled hard cement at 10217' to top of liner at 10775'. Tested liner lap w/1500 psi.for 15 rain OK. Cleaned out hard cement 10775-10813'. Tested liner lap w/1500 .psi OK. Ran GR-CBL from 11605-8300'. Good cement bond in lap and behind 9-5/8" w/top of cement at 9375'. Poor apparent cement bond on 7". Ran DST tools on 5" DP w/4135' water cushion. Packer set at 10741'; 2-7/8" perf. tail including 2 outside pressure recorders at 10763'. Opened tool at 9:50 AM 3-15-72. for 61 rain test. Had light blow ~ecreasing to dead in 5 min. Recovered net fluid rise of 280' drilling mud. Shot four 1/2" holes at 11372' DIL measure. Ran 7" DST tools w/7000' water cushion. Set 7" packer at 11306', 2-7/8" perf tail w/2 outside recorders at 11329'. Opened tools at 4:50 AM 3-16-72 for i hr test. Weak blow throughout test. Closed tool in at 5:50 AM. Taking shut in at 6:00 AM. Recovered net fluid rise of 188' mud. Ran and reset E-Z drill plug at 11360'. Displaced hole w/9.2# Invermul. Perforated 10758- 10583', 10526-10492', 10450-10418', 10396-10376', 10365-10330', 10312-10295', 10275-10220' w/4" casing guns at 4 spf. Ran and set .packer at 10824' on Schl line. Installed 4-1/2" rams. Ran 3-1/2" and 4-1/2" completion assembly, spaced out~~ landed tubing hanger, tested ball valve, control lines. Nippled down BOPE and installed wellhead. Tested to 5000 psi OK. Displaced Invermul w/diesel. Pulled ball valve. Set "XX" plug in nipple at 10016'. Could not shear off plug. Pressured up and set packer. Unable to pull "XX" plug at 10016'. Put well on gas lift; unloaded diesel from tubing recovering 574 bbls. Wireline parted while fishing for plug. Recovered WL measured 10003'-8,,Still/ unable to pull "XX" plug. Lost WL fishing tool~ in hole. Filled 9-5 annulus w/diesel. Shot four 1/2" holes in tubing. Killed well w/Invermul. NU and tested BOP. Pulled packer at 9975'. LD gas lift valves. Reran completion assembly w/1 XO sleeve open. Closed XO sleeve at 10704'. Set hydraulic packer at 9975' w/2500 psi. Opened XO sleeves at 10669' and 10704'. Pressured tubing w/1000 psi to check packer set OK. RU gas lift. Released well to production at 3:00 PM 3-29-72. Produg~_~ t~s~i~n~ H~mlock. RR and crews 12:01 AM 4-1-72. Proceeding with further testing on 4-1-72. AtlanticRichfieldCOmpany North Am?r: i/Producing Division South Ala~,j r~istrict Post Office BOx 360 Anchorage, Alaska 99501 Telephone 907 277 5637 March 9, 1972 State of Alaska Department of Natural Resources 0il & Gas Division 3001 Porcupine Drive Anchorage, Alaska 99504 .... CONFER: F1LF-: Attention: Mr. Homer Burrell Re: North Trading Bay Unit Well S-8 Permit 71-33 Gentlemen: Attached is a P-4 Monthly Report of Drilling Operations of the above mentioned well for the month of February, 1972. Very truly yours, BTL/WTJ/sw Attachment Mm No. ~,~ ,STATE O~'ALASKA 1R~V. B- 1-70 OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICA'I~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS AI~I~ NU'MER1cAL ~ODE' 50-133-20233 6 LE, ASE DESIGNATION AND SERIAL NO. ADL 1759T 1. T. IF INDIA)~, ALOTTEE OR TRIBE NAME OIL ~ GAB [] OT,Zl~ WILL WELL NA~m OF ATLANTIC RICHFIELD COMPANY ADDRESS 0X P. O. Box 360, Anchorage, Alaska 99510 4. IX)CATION Conductor 6, Leg 1 Spark Platform 2572'N & 2559'W fr SE cr Sec 26, T10N, R13W, SM 8. L~IT FARM OR LEASE N~J~E North Trading Bay g WELL NO 10. ~i~-.n ~SD POOL. OR WILDCA~ Hemlock & West Forlands i,. sec.. T., R., M.. OB,r~'TrV~ Sec 26, T10N, R13W, SM 1~-. PEP, MIT NO. 71-33 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA.NGES IN HOLE SIZE. CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLU1VIES USED. PERFORATIONS, TESTS A.ND HESULTS. FISHING JOl~. JUNK IN HOLE AND SIDE-TRACKED HOLE A.NTD ANY OTI-EER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 2-1-72 Drilled 12-1/4" hole 6801 - 7491'. Held 2 blowout drills & shut in well in 1 minute. Drilled 12-1/4" hole 7491 - 7778'. Tested Hydril w/3006 psi. Tested 5" DP rams - CS0 & choke manifold to 5000 psi OK. Tested Kellycock 5000 psi OK. Held blowout drill. Well shut in 1 minute. Drilled 12-1/4" hole 7778' - 10,134'. Tested pipe rams, CS0 & ohoke manifold to 5000 psi OK, Hydril to 3000 psi OK. Drilled 12-1/4" hole 10,134 - 10,384'. Held 2 blowout drills. Well shut in 1 minute. Drilled 12-1/4" hole ~10,384 - 10,650'. Ran DIL 10,641 - 2044'. Tested 5" pipe rams, CS0, choke manifold & Kellycock to 5000 psi. & Hydril to 3000 psi OK. Drilled 12-1/4" hole 10,650 - 10'905'. Ran DIL 10,876 - 8000'. FDC from 10,876 - 2046'. Took sidewall samples. 'Cond mud 3-1/2 hours. Ran 131 its 9-5/8" 47 #P.110 buttress casing. Shoe @ 10,8.~92'. Cemented 9-5/8" casing w/750 sx class "G" w/0.2% HR-7. Pumped 10 bbls of water &~ head & 5 bbls behind. Displaced cement w/778 bbls drlg mud using pumps. Bumped plug w/2000 psi. Float equipment held. CIP 12:00 Midnite 2-24-72. Had good circ throughout cement operation. Tested BOP rams & surface equipment w/5000 psi. & Hydril w/3000 psi. Tested 9-5/8" casing to 1500 psi OK. Ran in hole w/8-1/2" bit and drill pipe rubbers on drill pipe. Drilled out hard cement & shoe. Tested shoe ~~ ~ OK. Raised mud weight from 9.6 - 12.7ppg. Drilled 8-1/2" hole 10,898 - l~l~-r~. ' Drilling ahead ~ 11,154' on 3-1-72. 14. I hereby certify that t]~or~go~is t~ NOT~'Roport on thi~ fo~il r~quirod ~r~ colefld~r ~t~% regurdless of t~e mtolus of operotio~, ond must ~ filed ~n dupll~o/o ~it~ the -- oil ~d ~1 co~servolio~ commi~ee b~the 15~ of th~ muoc~din9 ~n~, ~le~ elherwimm directed, AtlanticRj~hfieldCompany North Americ~roducing Division Alaska Dist~ic~ Post Office BoX'~360 Anchorage, Alaska 99501 · Telephone 90,7 277 5637 February 8, 1972 State of Alaska Department of Natural Resources Oil & Gas Division 3001 Porcupine Drive Anchorage, Alaska 99504 ATTENTION: Mr. Homer Burrell Re: North Trading Bay Unit s-8 (~z-34) Permit 71-33 Gentlemen: Attached is Monthly Report of Drilling Operations of the above mentioned well for January, 1972. Very truly yours, B. T. Loudermilk Dist. Drlg. Supervisor ~TL/W~J/am Attachment ('., .:: x-',, ~ I ~ ~' ..... .._L~ , J s~cI 'CONFER: ¢-1L5: DIVISION OF OiL AND GAS i~orm No. P--4 lq, EV, $- I-?0 STATE OP/AJJ~KA OIL AND GAS CONSERVATION COMMITTEE: SUBMIT l~ ~"PLICAT~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS APl NL°.~fETL~CA-L CODE 50-133-20233 6 LE,A. SE DE$iGIqA'i'ION AND SEI~IAL NO ADL 17597 ATLANTIC RICHFIELD COMPANY P. O. Box 360, Anchorage, Alaska 99510 Conductor 6, Leg 1 Spark Platform 2572'N & 2559'W fr SE cr Sec 26, T10N, R13W, SM 8. L.~IT F.~! OH LEASE North Trading Bay .~O s-8 (~1-3~) Hemlock ~ West Forlands SEC., T., R.. M.. HOLE Sec 26, TION, R13W, SM pER.MIT NO. 71-33 - ' C~[ENTING JOBS I.~CLUDING DEPTH _ _: REPORT TOTAL DEI~'T'H AT ~g OF MON~. C}[~%'G~ IN HOLE SIZE, CASING SET ~ VOL~S USED. p~O~TIONS. ~T~ ~%~ ~SULTS FISHING OO~. JL~K LN HO~ ~D SIDE-~CKED ~O~ Spudded 9:00 ~ 1-17-72. bril~e~ ~_Y/g" ~o~ w/t~oari~ ~ ~00-~00'. 0pene~ ~a-~/~" ~o~e to ~-~/~" 600-~ 816'. ~isted off kelly sub. Top of fish at 35'. R~ in hole with overshot. Recovered fish. Opened 12-1/4" hole to 17-1/2" to 2075'. Clewed out to 2075'. Ran 2049' 13-3/8" 61~ K-55 buttress casing with shoe at 2046' ~d float coll~ at 1944'. Cemented 13-3/8" casing at 2046' with 900 sx Class "G" cement w/10% gel ~d 660 sx C%ass "G". CIP ~ 9:50 ~ 1-21-72. Lost ret~s with 150 bbl of ~sp!acement to go. R~ 1" pipe-t~o [2DO" ~d did top j~o with 275 sx Class "G" with f~l ret~ns. Nippled up 13-5/8" BOP stack. Tested Hy~il w/3000 psi; r~s ~d m~ifold 5000 psi. Tested cmsing to 1500 psi. Fo~d top of cement at 1961', ~illed h~d cement to , . ~ng to ~00 osi Clewed out cement to shoe. Clewed out to 2060' 2020 . Tested cas_ o 5~ ~ i ..... ~= ~==, ~ t~bo~ill ~d ~illed 2~02_~0~0~. ~$Ze ~$n~ heZ~ blowo~ ~$ZZ cZosin~ ~_~/~" hoZe ~050-580Z'~riZZin~ ~eaa 2-~-22 a~ gd0Z'. DIVISION OF Oli. A,~D GA'] NOTE --Report on this f~ ti required for eqCh coltn~at JJh~feJ~dMlt o~.Jhl iJot~ of operations, end : Atlan~cRichfieldCompany North American Producing Division Alaska Exp~tion & Producing Operations Post Office box 360 AnchoragefAlaska 99501 Telephone 907 277 5637 'C. © ~o~ ~ C. t': N'.~ ..... 1 ENG 2 [NG Howard A. Slack South Alaska District Manager February 4, 1972 .... I 1 Alaska Oil and Gas Conserva¢ion Co~iCtee 3001 rorcup~ne Dr~ve A~ebo~e, AZ~k~ ee~o~ ApplicationState of Alaskafor an Order Allowing the Co~ingling of Production -- from the Trading Bay Field "G" and Hemlock Northeast Oil Pools with Production from the Trading Bay Field West Forelands North- east Oil Pool in the Wellbore of Well S-8 and to Allow Required Separate Interval Testing to be Conducted by the Use of Subsurface Production ~gging ~vices; North Trading Bay. Unit, Cook Inlet, Alaska Gentlemen: Pursuant to the State of Alaska Oil and Gas Conservation Regulations and applicable statutes, Atlantic Richfield Company, as operator of the Trading Bay Field Northeast Oil Pools, for itself, Texaco Inc., and The Superior Oil Company, hereby petitions the Oil and Gas Conservation Committee for an order concerning the North Trading Bay Unit well S-8 which will allow: 1. The commingling of production from the Trading Bay Field "G" and Hemlock Northeast Oil Pools with production from the Trading Bay Field West Forelands Northeast Oil Pool in the wellbore of well S-8. 2. The required separate testing of the West Forelands interval and combined "G" and Hemlock interval to be con~ ducted by the use of subsurface production logging devices. The commingling of production from the Trading Bay Field "G" Northeast Oil Pool with production from the Trading Bay Field Hemlock Northeast Oil Pool is permitted by Rule 2 of State of Alaska Conservation Order No. 69, dated January 24, 1969. At the present time, well S-8 is being directionally drilled from Platform Spark to a bottom-hole location in the immediate vicinity of the northeast corner of Section 34, Township ION, Range 13W, Seward Meredian, in accordance with State of Alaska Permit #71-33. It is anticipated that well S-8 will develop the Trading Bay Field "G" and Hemlock Northeast Oil Pools and a deeper, undrained West Forelands oil sand. The entire producing area of the Trading Bay FEB 7 1972 DIVISION OF OIL AND Gz.\$ Alaska O~,and Gas Conservation Committee Page 2 February 4, 1972 Field "G" and Hemlock Northeast Oil Pools has been unitized by the North Trading Bay Unit as of an effective date of July 1, 1971, and all correlative rights and equities of the affected interest owners are adequately protected through this unitization and the applicable provisions thereof and of the Unit Operating Agreement. The entire West Forelands interval, and deeper horizons, are not included within the North Trading Bay unitized interval. As a consequence, the North Trading Bay Unit participants, Atlantic Richfield Company, Texaco Inc., and The Superior Oil Company have executed an appropriate joint linewell agreement that pro- vides for the protection of the correlative rights of the affected interest owners and establishes equities in all West Forelands formation production obtained from well S-8. A copy of this executed joint linewell agreement for the North Trading Bay Unit S-8 well is attached as Exhibit I. There are no affected operators other than the North Trading Bay Unit participants listed above, each of whom is receiving a copy of this application. With the approval of this commingling request from the Oil and Gas Conservation Committee, well S-8 will be completed with a single tubing string and two production packers, one packer separating the Hemlock pool from the West Forelands pool and one packer above the "G" and Hemlock pool. We believe that this completion will provide for a more efficient recovery of oil from the "G" and Hemlock and the West Forelands pools than an alternative non- commingled completion employing two tubing strings. The proposed single tubing string completion of well S-8 will permit the passage of subsurface-measuring production logging devices. These devices, in common use by the petroleum industry and locally available, can be used to determine the separate oil production rates of the West Forelands pool and the combined "G" and Hemlock pools. We propose to run such production logging devices at time intervals as required by the Committee, to deter- mine the amount of oil production from each of the West Forelands pool and the combined "G" and Hemlock pools. The anticipated completion of the proposed S-8 well in the "G" and Hemlock and the West Forelands intervals will produce from State of Alaska Leases ADL 35431, ADL 18776, and ADL 17597. Allocation of the production from the unitized "G" and Hemlock interval to each of these three leases will be in the same propor- tions as is the current North Trading Bay Unit production (ADL 35431 - 21.43 percent, ADL 18776 - 28,57 percent, and ADL 17597 - 50.00 percent). The State of Alaska, Division of Lands, is currently considering our proposal to allocate production from the West Forelands interval in well S-8 to these three immediately adjacent leases in the same proportions as the North Trading Bay Unit production but limited to the spacing unit where the 8-8 well will ~~ ~~b_~ c p ~I~]_ ~ .... :-..}I~.~.~'~' F E. 6 7 i972 DIVISION OF OIL /:,iqD CAS Alaska 0~.,,. and Gas Conservation Committee Page 3 February 4, 1972 Applicant requests that this application for the issuance of an order allowing commingling and downhole measurement of West Fore- lands and combined "G" and Hemlock production in well S-8 be set for hearing at the earliest possible date. This application is for well S-8 only. Very truly yours, ATLiNTIC RICHFIELD COMPANY OPERATOR BY Howard A. Slack HAS/RI/RAW: sr Attachment cc Mr. Pedro Denton, State of Alaska, Division of Lands DISTRIBUTION LIST Mr. M. U. Broussard The Superior Oil Company Box 1521 Houston, Texas 77001 Mr. Leo McCann Texaco Inc. P. O. Box 4-1579 Anchorage, Alaska 99509 Mr. D. S. Pierson Texaco Inc. 3350 Wilshire Boulevard Los Angeles, California 90005 DIVISION Oi: OIL Atlan}icRichl'ieldCOmpany North American Producing Division Alaska Exl:'~'~liOn & Producing Operations Post Office box 360 Anchorage, Alaska 99501 Telephone 907 277 5637 HOward A. Slack South Alaska District Manager October 20, 1971 The sUPerior Oil Company P. O. Box 1521 Houston, Texas 77001 Texaco Inc. 3550 Wilshire Boulevard Los Angeles, California 90005 Re' North Trading Bay unit-S_8 ICell Cook Inlet, Alaska Gentlemen: Texaco Inc., The Superior Oil Company and Atlantic Richfield Company have agreed to drill the S-8 well which is intended to bottom near the northeast corner of Section 34, T1 N-R13I,, Seward ~Ieridian, ? ~ which point is common to the boundaries of State of Alaska leases ADL-17597, ADL-l$776, and AOL- 354Sl. The primary purpose for this drilling will be to serve as a Unit well for ~he North Trading Bay Unit. The well, however, will be drilled below the base of the formation covered by the North Trading Bay Unit and will test the IVest Foreland formation. Since the equities in the North Trading Bay Unit are approximately the same as :~ t~,e estimated equities of the parties in the 5'est Foreland reservoir to be tested by this well, the parties agree as follows: 1. The entire cost, risk and expense of drilling, testing, completing and equipping for production of said S-8 well will be borne by the parties in the sa.ne percentages as the ~asic Participating Interest of the parties in the North Trading B~y Unit, it being understood that the-entire cost of the well including that portion below the unitized formation of the North Trading Bay Unit will be treated for all purposes just as though the well were entirely a · Unit well. DIVISION OF OIL AND GA'3 The Superior Oil C6mpa'ny Texaco Inc.-' ' ~ October 20, '1971 · 2. It is further agreed that all West Foreland formation production obtained from the S-8 well will be shared by the. parties 'in the same propor- tions as used for the" sharing of North Trading Bay Unit produCtion: 5. OPerating costs attributable to the West Foreland Production will be treated, the same as the cost of Unit operations and .will be borne in the same proportion. _ 4. Except as herein provided to the contrary, all operations contemplated hereby shall be subject to the te~s and provisions of the North Trading Bay Unit Operating Agreement. If the foregOing is acceptable, please sigmify your company's approval .by signing in the space below. ' .Very truly yours, ATLANTIC RICHFIELD ./ ,- / /' '.~ ~ ./ / ./ -~-' /',.. -- . / / :7 -o ,- ..,.. · " Howard A. Slack At t qrney- in- Fact AGREED TO AND ACCEPTED THIS ? {/f'// DAY OF OCTOBER, TEXACO 'INC. -~t t Oi~ e'y', in- F ac t Attest XFEtSta~i FEB 7 i97g THE SUPERIOR OIL COMPANY -'ff~~~ ~-~ -- ~"- Assistant Secretary DIVISION OF OI/ AF~D GAS" AtlanticRichfieidCompany North American Producing Division South ~"~X~a District Post Off, : Box 360 Anchorage, Alaska 99501 Telephone 907 277 5637 January 14, 1972 Division of Lands Department of Natural Resources State of Alaska 323 East, Fourth Avenue Anchorage, Alaska 99501 Attention- Mr. Pedro Denton Re- FJorth Trading Bay Unit Well S-8 Gentlemen- Reference is made to your letter of December 10, 1971 and our letter of October 28, 1971, proposing a method of handling State royalty oil from a possible West Foreland completion in the S-8 well.- ENG ~ ..... i- 1' ENG ._.' _1. 'a ~:-:~'s' 1 .~ ENG :. I 1 GEOL '"q- ,, CONFER: ._ FI,LE: Based on a thorough evaluation of the geological and engineering information available for the West Foreland formation, Atlantic Richfield Company, Texaco and Superior agreed that the equities in this formation are virtually the same as those in the North Trading Bay Unit. In recognition of this evaluation, Atlantic Richfield Company, Texaco and Superior have entered into a Letter Agreement dated October 20, 1971, a fully executed copy of which is attached for your files. This Agreement provides that Atlantic Richfield Company, Texaco and Superior will bear all costs, risks and expenses and will share all production from a possible West Foreland completion on the same basis provided for the Hemlock and "G" in the North Trading Bay Unit Agreement and Unit Operating Agreement. I trust this Letter Agreement will satisfy the requirements set out in your letter of December 10. If the Division of Lands or the Oil & Gas Division would like to review the maps on which this is based, please let us know and we will arrange a meeting at your earliest convenience. .Very truly yours , ~ohn D. Carr FEB 2 19/2 ~-- ~- ' Senior Landman DIVISION OF OIL AND GAS JDC' kg ,~c',-~c~':, '" Attachment ~ppticafton for p~r;lf fo drll I the abcwe r~ferem~d t971, at a location in Section 26, Township I0 N., Well saaples a~ c~re c~ll~s are ~T required, t~ever, a directional survey Thls I~rait Is sa,jet to r~lut.atlons as specified I. Consarvatlon Order No.I I0. l~a~. Hve~ t. AI~ and their drainage sWfeas have bee. classified as ~aat ~ the ~.lng or mi :~rafl .on of aaad~s fish. 01~era?lons tn these areas, are s. bjec? to AS 16.05.870 and the regulations promulgated thereunder (Tltle 5. AlaSka Admtatstr~flve Code). Prt~r to com.~nclng o~eratl~s you may be con~ by ~ Habitat Coordl,ator~s office, De~'aa~'t of Fish and Game. the event of session or abaado~t please glve this office adequafe adYa~ce no~lce so that ~e may haYe a wl~s p~®sent. Very truly ~rs, ALASF~ OIL AI~ ~ ~ERYATIO{~ ~iTTEE ,cc: Department of Fish and ~, iiabltat Section ~/o mt. ~rfa~t of Envtraaental Conservation w/o mt. AtlanticRiChfieldCompany · North Am.~an Producing Division North Ala District Post Office :3ox 360 Anchorage, Alaska 99501 Telephone 907 277 5637 November 23,' 1971 State of Alaska Department of Natural Resources 0il & Gas Division 30'01 Porcupine Drive Anchorage, Alaska 99504 ATTENTION:'Mr. Homer L. Burrell RE: North Trading Bay Well No. S-8 (41-34) Gent lemen: Enclosed please find Application for Permit to Drill and the $100 filing fee for the above subject well. Very truly yours, C. R. Knowles Sr Drilling Engineer Enclosures: 60 Fl b E T ! A L NOV ~ ~'.~ 1971 AN~HO~A~ form P~I RE~. 9-30-~'~ STATE O,F ALASKA (Other instruction. reverse stde) OIL AND GAS CONSERVATION ,COMMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK 18. TYPE 0~' WORK DRILL ~ DEEPEN [] PLUG BACK [] b. TYP~ Or WELL 0I~ ~] OAS ~ ~I~OL, ~ MUI,TIPI,E~ WELL WELL OTHER ZONE ZONE 2. NAME OF OPEH~TOR Atlantic Richfield Company 3. ADDRESS O~ OPERATOR P. O. Box 360, Anchorage, Alaska 99510 4. LOCATION O'F WELL At surface 2572'N & 2559'W fr SE er Sec 26, T10N, R13W, SM At proposed prod. zone ' · 100' due E of SW cr of Sec 26, T10N, R1BW, SM APl //50- 133-20233 $. 6. LEASE D~IGNATION A2TD S~.AL NO. ?. IF INDIAN, ALLOTTEE OR TI~J~E NAME 8. UNIT, FARM OR LEASE NA2dE North Trading Bay 9. WELL NO. S-8 41-34 10, FIELD AND POOL, OR WILDCAT Hemlock, West Forelands 11. SEC., T.. R., M., (BOTTOI~[ HOLE OBJECTIVE) Sec 26, T10N, R13W, SM 13. DISTANCE IN MILES AND DIRECT!ON F2oM NEAREST TOwN OR-POST OFFICE* 12. 28 miles NW of Kenai, Alaska 14. BOND INFORAVIATION: TYPE Statewidesuretyand/orNo. Federal Insurance Company #8011-38-40 A~o,,. 100,000 (Also to nearest drig, unit, if any) on the lease, line · I 175g7 5120 i8. DISTANCE FROM PROPOSED LOCATION* J 19. PROPOSED DEPT~ TO NEARES? WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 730' 11,870' MD /,_.,,~- vo 21. ELEVATIONS (Show whether DF, RT, C-R, etc.) 115 ' KB 23. PROPOSED CASING AND CEMENTING PROGHAM 117, NO. ACRES ASSIGNED TO THiS WELL , 40 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START* 12-71 SIZE OF HOLE SIZE OF CASING} WEIGHT PER FOOT GRADE r SETTING DEPTH Qt'ANTIT! OF 26" ~20" ' 94# ~-40 432' Circulated to surface 17-1/2" 13-3/8" ~, 61# , K-55 2100' 875 12-1/4" 9-~/8" 47# , N-80 10850'/0,--~ 1000 sx 8-m/2" 7" 29t N-80 n87o' ~,~ 4o0 sx , , , , , Total depth will be 11,870' measured and 10,965' vertical £~]'~;' ; '''~'~ ~:/ 'fF:~ ~'~ Bottom hole location will be 546'S & 564'W fr NE cr of Sec 34, T10N, R13W, SW 20" Hydril while drilling 17-1/2" hole 13-5/8", 5000 psi Cameron preventers with drill pipe & blind rams w/3000 psi Hydril while drilling 12-1/4" holeC 0 ~~ F D E l~"~ T~~~~L~ ~1 ~ ~ * Spacing exception applied for by true vertical depths. Give blowout preventer program. 24. I hereby certify th~he Forego~ is True an($ Correct '//- zs-7/ (This space'for State office use) CONDITIONS OF APPHOVAL, IF ANY: jSAMPLES AND CORE CHIPS [] YES ~NO [ DIRECTIONAL SURVEY ~YES I-1 NO AP.I, N~Y~ERICAL CODE December 7. 1971 nAr~ December 7t 1971 /// / /// ! / / / / / /1 / / / / 34 ! ! / ! / ! ! ! ! -[-TIO N - R 13W 22 25 SUPERIOR- TEXACO ARCO ARCO ' Is ~s .// , i /// / / '-.. ,,, S_~,,~l / / / '~7~x~c°-~,~.~, ~ *' s,~ ,,/ // / Xx xx /1 / X $ / , / ~ // X ~8-7 ~ ~ S-7 R/D ION-RI2W AR~SO - SeC~L 24 TRADING BAY UNIT UN ION - MARATHON 19 25 3O ATL ANTICRICHFIE L DCOMPANY ALASKA DISTRICT WELL LOCATION NORTH TRADING S-8 MAP BAY SCALE I II- 22-71 ,z O~ lO(X) 2000 · ,, · Lease & We11'No. /t~o. ~d;~ 'l~.~ 5-? CHECK LIST FOR NEW WELL PERMITS . · I s we11 to be located i n a defi ned pool ................. ~,,~-. . Do statewide rules apply ........................ __ . Is a registered survey plat attached .................. ~. Is well located proper distance from property line ...... , ..... ;'. Is well located proper distance from other wells ...... . ....... ;. Is sufficient undedicated acreage available in this pool ........ t. Is operator the only affected party ................... ). Can permit be approved before ten-day wait . . .- ............ O. Does operator have a bond in force .................... ~ 1. Is conductor string provided ...................... /~/, 2. Is enough cement use~ to circulate on conductor and surface ...... 3. Will cement tie in surface and intermediate or production strings . . . 14. '.4ill cement cover all possible productive horizons ........... - 15. Will surface casing cover all fresh water zones ............ , 16. Will surface csg. in~ernal burst equal .5 psi/ft, to next string .... 17. Will all casing give adequate safety in collapse and tensi'on ...... 18. Does BOPE have sufficient pressure ,ating ........... Additional Requirements: ~ ~ CO. ]/0,,.~.,
