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Home My WebLink About202-119Chevron • Francisco Castro Technical Assistant r~ Chevron North America Exploration and Production 909 W. 9th Avenue Anchorage, AK 99501 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com ]anuary 3, 2008 To: AOGCC ~~.~~~~ .1AN ~ ~ ZOGB Mahnken, Christine R 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 -- I - ~ - i ~ ~ NGTES - ~~ INTE ~..L 1rJELL LOS TYPE SCALE I LOG Dry I R A RUrJ ~ B- Fi~lv1 ~~ ~D LAS. ~~GED I, ~ LINE ~ PDT, ~_~._i_ _DLI; - - - - -- -~- ABANDONMENT RECORD SQUEEZE PERF AND TUBING KGSF 2 CUTTER 5" 19-Sep-07 200 - 400 1 1 1 PDS K~S~ ~~-- ~i5-~a3 Please acknowledge receipt by signing and returning one copy of this trans'~ittatt-+o~'FPr~~o~907 263 7828. ,°~ ~ } Received By: Date: r Page 1 of 1 • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, October 30, 2007 12:01 PM To: 'PORHOLA, STAN T' Cc: Larry Buster Subject: KGSF #2 (202-119) Stan, In mid September you submitted a 404 report for the deep plugging operations conducted through August 22. In mid October you submitted a 407 report covering the initial work as weft as subsequent work to P&A the weft. When a well is plugged and abandoned, the appropriate reporting form is the 407. A 404 is not required in this case. Cal! or message if you have any questions regarding this matter. Tom Maunder, PE AOGCC ~l~~~D AP R ~ 9 200 10/30/2007 - ~;~~'~~ ~/~ LOS I STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMMI ION $_ ~ sqi,~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ^ Gas ^ Plugged Q Abandoned ~ Suspended ^ 2oa,ac25.~os 20AAC25.110 GINJ ^ WINJ ^ WDSPL^ WAG ^ Other^ No. of Completions: 0 . 1b. Well Class: Development ^ Exploratory^ Service Q Stratigraphic Test^ 2. Operator Name: Union Oil Company of California 5. Date Comp., Susp., or Aband.: 9/27/2007 12. Permit to Drill Number: 202-119 3. Address: P.O. Box 196247, Anchorage, AK 99519 6. Date Spudded: 6!2912002 13. API Number: 50-133-10152-01-00 4a. Location of Well (Governmental Section): Surface: 1750' FNL & 1190' FWL Sec. 27, T8N, R9W, S.M. 7. Date TD Reached: 714!2002 14. Well Name and Number: Swanson River KGSF #2 Top of Productive Horizon: 1808' FNL & 1275' FEL Sec. 27, T8N, R9W, S.M. 8. KB (ft above MSL): 190 Ground {ft MSL): 175 15. Field/Pool(s): Total Depth: 2228' FNL & 806' FWL Sec. 27, T8N, R9W, S.M. 9. Plug Back Depth(MD+TVD) Surface : Swanson River Unit Tyonek 62-5 4b. Locati of Well (State Base Plane Coordinates, NAD 27): Surfa x- 348968 y- 2469986 Zone- 4 ' ~ 10. Total Depth (MD + TVD): 6915' 7 6248' i 16. Property Designation: FED (A-028406) TPI: x-.3?~9~ y-~.?!~e G''~. ~~ Zone- 4 Total Depth: x-,~~86~y~,3 y-o~~6 ~~yg, ~/ Zone- 4 11. SSSV Depth (MD + TVD): N/A 17. Land Use Permit: N/A 18. Directional Survey: Yes ~ No (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): N/A 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): N/A 22. CASING, LI NER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 13-3/8 54.5 K-55 0 2943 0 2943 18-5/8 0 9-5/8 40 N-80 2736 6046 2736 6046 12-1/4 0 5-1/2 20 & 17 N-80 0 6046 0 6046 8-1/2 0 2-718 6.4 L-80 5057 6665 5057 6247 4-5/8 44 sx 15.8 ppg 350 23. Open to production or injection? Yes ^ No0 If Yes, list each 24. TUBING RECORD interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8 5057 5026 ~~ANN~ APR 2 9 2D0~ 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 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 Q If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. COMPLETION ~, ~~ r ~_ ~ ~~ ~ ~s 2DD7 Form 10-407 Revised 2!2007 ~ ~ ~ ~ ~ ~ ~C~JNTINUED ON REVERSE ~~~ ` t~ • • 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ~ No If yes list intervals and formations tested , , briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Top needed, and submit detailed test information per 20 AAC 25.071. Permafrost -Base Formation at total depth: 30. List of Attachments: Daily Summary of Operations; Wellbore Schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Stan Porhola o.?~ y~~ O Printed Name: Tim Brandenburg Title: Drilling Manager Signature: Phone: 263-7640 Date: 10!3!2007 ~~'' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, 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 tnjei;tion, 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 212007 P' • • Chevron Swanson River Unit Kenai Gas Storage Facility #2 Actual Schematic 9-27-07 RKB = 191' AMSL CASING DETAIL ,: ~ ~~~ SIZE WT GRADE TOP BOTTOM .', ~.A:::::: 13 3/8" 54.5 J-55 0' 2943" '' B 9-5/8" 40 N-80 2736' 6046' window 1 5-1/2" 20 & 17 N-80 0' 6046' window TOC C ' 2080' M D ~ TUBING & LINER DETAIL SIZE WT GRADE CONN TOP BOTTOM 2-7/8" 6.4 L-80 IBTC SCC 0' 6665' (uncemented liner) w D COMPLETION EQUIPMENT DETAIL NO. Depth Item 1. 1992' Methanol injection mandrel (ID= 2.312") 2. 5026' Baker SAB-L3 hydraulic packer (not set) 3. 5057' Baker HMC liner hanger w/ 7' tieback PBR 4. 5928' Baker overshot w/high pressure pack-off 5. 6642' Baker landing collar & float collar 6. 6663' Baker float shoe TOC @ 7. 5034' Baker `X' nipple 2.31" ID 3688' MD E ABANDONMENT DETAIL s- F ....r • .. ' ~'~ ' "' NO. Depth Item f ~'~' ~: ~ ~ `~: ~'' A. 300'-305' Tubing punch holes (circulate cement to surface) B. 310' Bridge Plug set in 5-1/2" casing F C. 3110' Cement Retainer w/ poppet valve ' D. 3115'-3120' Squeeze holes TOC (a~ E. 4600' Balanced cement plug 4638'MD ~. 2 F. 4607'-4612' Squeeze holes ~ G. 6330' Cement Retainer (previously set in 2002) ' 3 ' ..~ -~~~, ''*, Calculated top of cement @ 5364' j!' ~g ~'~; "_`~ q ! Window @ 6046' MD / 6042' VD (LOT result: could not pump in w/ 2000 ' "' ` psi on top of 9.0 ppg OBM - 15.3 ppg E.M.W.) ~~~„ ~T7~~~" Top of 62-5 reservoir at 6330' MD / 6238' VD ,;~; ,~:,. ` ',~"4' Wiper plug fish pushed to 6391' (89° incl.) w/ CTU & hung up. .. .. Window ' Master ~ G ` 5 6 9.6 ppg OBM throughout wellbore EZSV TD = 6915' MD / 6248' VD 2-7/8" liner un-cemented at 6665' MD (top of float equipment at 6642' MD) WBD KGSF#2 Actual 9-27-07.doc DRAWN BY: STP ~C~tievron • • KGSF #2 Plug and Abandon Swanson River Field, Alaska Daily Summary of Operations PTD No. 202-119 8/07/07: PJSM w/ Peak crews. Layout liner and berms for coil tubing operations around wells KGSF #2 and KGSF #3. Move in water and returns tanks. SDFN. 8/08/07: PJSM w/ Peak and Schlumberger crews. Spot various coil and cementing equipment on pad and inside containment. Wait on delivery of coil tubing unit. Running single daylight tours (16 hour days). SDFN. 8/09/07: SIMOPS meeting w/ Production. PJSM w! Peak and Schlumberger crews. Chevron general orientation for crews. MIRU Coil tubing unit. Release cementing crews to Nabors rig #129. Continue rig up until crews released for rest. SDFN. 8/10/07: SIMOPS meeting w/ Production. PJSM w/ Peak and Schlumberger crews. Finalize rig up of coil tubing unit. Perform BOP test to 4000/250 psi. Test OK (witness waived by AOGCC). TIH w/ 1.75" cement nozzle on 1.5" coil cleaning out OBM in 2-718" tubing w/ fresh water. Set down at 3831'. Worked and washed through fill (cement?) to 3840'. Continue TIH and circ to 5038' and set 5000# down on X profile at 5034' RKB. Could not work past. POOH w/ coil. Consult w/ town and decide to add weight bar to stiffen BHA next run. Release crews for rest. SDFN. 8111107: SIMOPS meeting w/ Production. PJSM w/ Peak and Schlumberger crews. Haul return fluids w/ vac truck to disposal well. MIRU cement batch mixer. Add 10' of lubricator. Test lubricator to 3650/250 psi. Test OK. MU BHA w/ weight bar and TIH w/ 1.75" cement nozzle on 1.5" coil. Troubleshoot problem w/ electronic depth counter on injector head. RU man lift. PJSM w/ crews on operations w/ man lift. Change out encoder, still not operational. Continue w/ manual depth counter. Continue TIH and circ to 5059' and set 1130# down and circ at 1.5 bpm. Could not work past. POOH w/ coil. Found cement piece wedged in cement nozzle. Consult w/ town and decide to add motor and mill next run. Repair electronic depth counter. Release cement batch mixer to SCU 42-OSY. Release crews for rest. SDFN. 8/12/07: SIMOPS meeting w/ Production. PJSM w! Peak and Schlumberger crews. Chevron general orientation for new crews. MU BHA w/ 2.25" mill and mud motor. Test lubricator to 3500/250 psi. Test OK. TIH w/ coil to 5050' and set 2000# down. Washdown to 5430' and set down hard. Drill hard cement to 5448'. PU off bottom and pull 10,000# above UWT. Work coil and circulate clean. Consult w/ town. Drill hard cement to 5458'. Circ 2 bottoms up. POOH w/ coil. Pressure up 2-7/8" tubing to 2700 psi. Pressure bled to 1659 psi in 30 min. Pressure on 5-1/2" x 2-7/8" annulus has remained at zero psi. Consulst w/ town and decide to put coil on standby. SDFN. 8/13107: PJSM w/ Peak crews. RU test pump on 5-1/2" x 2-7/8" annulus. Pressure up to 640 psi. Bled to 630 psi in 20 min. Bleed off pressure and RD test pump. Consult w/ town and plan forward is to lay cement plug w/ coil when crews are available. SDFN. page 1 • KGSF #2 Plug and Abandon Swanson River Field, Alaska 8/14/07: SIMOPS w/ Production. PJSM w/ Peak and Schlumberger crews. RU injector and shell test to 4000 psi. Pressure up 2-7/8" x 5-1/2" annulus to 2490 psi and tubing to 2700 psi. Pressure dropped to 2390 on annulus and 2410 on tubing in 30 minutes. Bleed pressures to 0 psi. TIH w/ 1.75" cement nozzle on 1.5" coil cleaning, notice small communication between annulus and tubing. Wash down to 5460'. Circ bottoms up. Mix and pump 5 bbls LXT cement, follow by 10 bbl barazan vis pill. Lay cement from 5460' to 4596' and barazan vis pill from 4596' to 4400'. Follow barazan vis pill w/ fresh water and circulate out of hole. POOH w/ coil. RD coil and secure well. Tubing pressure 0 psi and casing pressure 0 psi. Prep coil for move to KGSF #3. SDFN. 8/15-8/21/07: No Operations at KGSF #2 8/22/07: SIMOPS w/ Production. RU Pollard slickline. Pressure test lubricator 2500/250 psi. RIH wJ 2"x5' drive down bailer and tag cement at 4638' RKB (SLM). Collect sample and POOH. Had contaminated cement in bailer. Pressure up tubing to 2500 psi and chart. Bled down to 2250 psi in 1 hour. Jeff Jones w/ AOGCC onsite for witness of tag and pressure test. RD slickline and move to KGSF #3. SDFN. 8/23/07: SIMOPS w/ Production. PJSM w/ Peak. Clean location. Prep location for E-line and cementing operations. SDFN. 8/24/07: SIMOPS w/ Production. PJSM w/ Peak. Mob choke skid, test pump, and water tank to well SCU 42-OSY. Suspend operations at KGSF #2. 8/25-8/28/07: No Operations at KGSF #2. 8/29/07: SIMOPS w/ Production. PJSM w/ Peak. Clean location. Mob Slb crews for E-line and cementing operations. SDFN. 8/30/07: SIMOPS w/ Production. PJSM w/ Peak and Schlumberger crews. RU water tank, test pump and choke skid that had been at SCU 42-SY. SDFN. 8/31/07: SIMOPS w/ Production. PJSM w/ Peak and Schlumberger crews. RU Slb lubricator. Test to 250/3000 psi. RIH w/ 5' of 1.56" HSD 60° 6spf perf guns. Tag plugback depth at 4625' RKB. Set guns on depth at 4607'-4612'. Pressure up tubing to 1500 psi. Fire guns. Lost 1000 psi in tubing, gained 25 psi on 2-7/8" x 5-1/2" annulus, 0 psi on 5-1/2" x 9-5/8" x 13-3/8" annulus. POOH w/ guns. All shots fired. Pressure up tbg to 2800 psi, 2500 psi on 2-7/8" x 5-1/2" annulus, 0 psi on 5-1/2" x 9-5/8" x 13-3/8" annulus. No circulation up 5- 1/2" x 9-5/8" x 13-3/8" annulus. Establish 5 bbls of circulation up 2-7/8" x 5-1/2" annulus. RIH w/ 5' of 1.56" HSD 60° 6spf perf guns. Set guns at same depth at 4607'- 4612'. Pressure up tubing to 1500 psi. Fire guns. No change in pressure. POOH w! guns. All shots fired. RD E-line. No circulation up 5-1/2" x 9-5/8" x 13-3/8" annulus. Establish 5 bbls of circulation up 2-7/8" x 5-1/2" annulus. Discuss plan forward w/ AOGCC and BLM. Proceed ahead w/ balanced cement plug in tbg and 2-7/8" x 5-1/2" annulus. Mix and pump 22 bbls of 9 ppg spacer ahead of 15 bbls of 15.9 ppg LXT cement followed by page 2 • CJ KGSF #2 Plug and Abandon Swanson River Field, Alaska 22 bbls of 9 ppg displacement. Pump rate 3 bpm and max pressure of 1400 psi. Close tbg and annulus valves. Calculated top of cement at 3855'. Shut-in pressure of 350 psi tbg, 350 psi 2-7/8" x 5-1/2" annulus, 0 psi on 5-1/2" x 9-5/8" x 13-3/8" annulus. RD cementers. Contact AOGCC and BLM inspectors. Plan to pressure test and tag cement 9/4/07. WOC. SDFN. 911-913!07: No Operations at KGSF #2 9/4/07: SIMOPS w/ Production. PJSM w/ Peak and Schlumberger crews. RU Slb lubricator. Test to 250/3000 psi. Bob Noble w/ AOGCC onsite. Pressure test tubing to 3067 psi. Lost 69 psi in 30 min. RIH w/ E-line. Tag cement top at 3688' RKB. POOH. Pressure was 0 psi on tbg and 2-7/8" x 5-1/2" annulus. RIH w/ 5' of 1.56" HSD 60° 6spf perf guns. Set guns on depth at 3115'-3120'. Pressure up tubing to 900 psi. Fire guns. Lost 450 psi in tubing, gained 450 psi on 2-7/8" x 5-1/2" annulus, 0 psi on 5-1/2" x 9-5/8" x 13-3/8" annulus. POOH w/ guns. All shots fired. Pressure up tbg to 2500 psi. Had 2500 psi on 2-7/8" x 5- 1/2" annulus. Attempt circulation into formation w/ no success. Attempt circulation of 5- 1/2" x 9-5/8" x 13-3/8" annulus with no success. RIH w/ 5' of 1.56" HSD 60° 6spf perf guns. Set guns at same depth at 3115'-3120'. Pressure up tubing to 900 psi. Fire guns. Gain 25 psi on 5-1/2" x 9-5/8" x 13-3/8" annulus. POOH w/ guns. All shots fired. Inject 10 bbls into formation at 0.8 bpm at 2000/1700/1200 (Tbg/IA/OA) psi. Circulate 10 bbls up 5-1/2" x 9-5/8" x 13-3/8" annulus at 3.2 bpm at 1700/1700/400 psi. Close OA valve. Circ up 2-7/8" x 5-1/2" annulus at 3 bpm at 500/200 psi. RIH w/ 2-7/8" cement retainer and set at 3110' RKB. Inject below retainer into formation at 1.5 bpm at 1294/2300/1700 psi. Increase rate to 2 bpm at 2500/2500/1900 psi and well jugged up. Bled tubing to 861 psi. Annular pressures remain at 2500/1900 psi. Attempt to inject into formation with no success. Close 2-7/8" x 5-1/2" annulus and open 5-1/2" x 9-5/8" x 13-3/8" annulus to returns tank. Mix and pump 18 bbls of 9 ppg spacer ahead of x bbls of 15.8 ppg LXT cement followed by 22 bbls of 9 ppg displacement. Pump rate 1 bpm at 1700/2000/430 psi. With 2.5 bbls cement inside 5-1/2" x 9-5/8" x 13-3/8" annulus, 2-7/8" x 5-1/2" annulus increased to 2500 psi (maximum pressure to not exceed). Shut down pumps. Pressure of 5-1/2" x 9-5/8" x 13-3/8" annulus at 0 psi. Tubing pressure at 1400 psi. Close 5-1/2" x 9-5/8" x 13-3/8" annulus. Open 2-7/8" x 5-1/2" annulus and bled to 500 psi. Pump 15.3 bbls cement in 2-7/8" x 5-1/2" annulus and 5.8 bbls cement in tubing on top of retainer. Shut-in well. Pressures at 0/0/0 psi. Calculated cement top at 2000' RKB in tbg and 2-7/8" x 5-1/2" annulus. Calculated cement top at 3065' RKB in 5-1/2" x 9-518" x 13- 3/8" annulus. RD cementers. Plan to pressure test and tag cement 9/6/07. WOC. SDFN. 9/5/07: SIMOPS w/ Production. PJSM w/ Peak. Continue to wait on cement. Empty returns tank and transport by vac truck to disposal well. 9/6/07: SIMOPS w/ Production. PJSM w/ Peak and Schlumberger crews. RU test skid. Shut-in wells pressures are 0/0/0 psi. Pressure test 5-1/2" x 9-5/8" x 13-3/8" annulus to 1290 psi. Had 0 psi loss in 30 min. Charted pressure. Tim Lawlor w/ BLM onsite. Pressure test tbg to 2623 psi. Lost 82 psi in 30 min. No pressure increase in either annulus. RIH w/ E-line and tag top of cement in tbg at 2080' RKB. Pressure test 2-7/8" x 5-1/2" annulus to 2509 page 3 • KGSF #2 Plug and Abandon Swanson River Field, Alaska and lost 179 psi in 30 min. Retest 2-7/8" x 5-1/2" annulus to 2504 psi and lost 37 psi. RD all crews. Secure well. Suspend operations at KGSF #2. SDFN. 9/7-9/12/07: No Operations at KGSF #2. 9/13-9/17/07: No Operations at KGSF #2. 9/18/07: SIMOPS w/ Production. PJSM w/ Peak, Schlumberger, and Vetco crews. RU E-line. RIH w/ 2-1/8" tubing jet cutter. Set cutter at 350'. Pressure up tubing to 700 psi. Fire jet cutter, pressure dropped to 0 psi. Jet cutter tools hanging up inside 2-718" tubing at tool joint at 322'. Work tool free at 1800 lbs pull. Tool hung up in next tool joint at 291'. Pull 2400 lbs and came out of rope socket. POOH leaving jet cutter inside tubing. RD E-line. Tubing pressure at 0 psi. 2-7/8" x 5-1l2" annulus at 0 psi. 5-1l2" x 9-5/8" x 13-3/8" annulus at 0 psi. ND wellhead to tubing hanger and NU 8' riser spool. NU swab valve on top of riser. Secure well. SDFN. 9/19107: SIMOPS w/ Production. PJSM w/ Peak crews. RU crane to pull tubing. ND tubing hanger spool. Pull and lay down 346.5' of 2-7/8" tubing and control line. Parted control line w/ 3400 lbs at 350'. RD crane. RU slickline. RIH w/ 4.55" GR and junk basket. Set down at 290'. Spang down to 325'. POOH w/ no recovery in junk basket. MU 5-1/2" bridge plug. Set bridge plug at 310'. POOH w/ slickline. RU E-line. RIH w/ 5' long, 4 spf, tubing punch and punch tubing from 300' to 305'. POOH w/ tubing punch. RIH w/ 2"d 5' long, 4 spf, tubing punch and punch tubing from 300' to 305'. POOH w/ tubing punch guns. RD E-line. Circulate down 5-1/2" casing and take returns up 5-1/2" x 13-3/8" annulus. Circulate 61 bbls (1.35 bottoms up) fresh water taking mud returns at surface. RU cementers. Mix and pump 65 bbls of 15.8 ppg cement w/ 21 bbls of cement returns to surface. RD cementers. Secure well. SDFN. Wait on cement. 9/20/07: No Operations at KGSF #2. Waiting on cement. 9/21/07: SIMOPS w/ Production. PJSM w/ Peak crews. Clean up around pad and in cellar. Notify AOGCC and BLM of expected casing cut and marker plate installation. SDFN. 9/22/07: SIMOPS w/ Production. PJSM w/ Peak crews. Build containment for soil removal. Pull tree. Mix and place 2' of cement inside 5-1/2" casing. Prep cellar for welding. SDFN. 9/23/07: No Operations at KGSF #2. 9124/07: SIMOPS w/ Production. PJSM wl Peak crews. Cut 13-3/8" and 5-1/2" casings. Cement top found 10' below cut-off depth inside 13-3/8" x 5-1/2" annulus. Top off w/ cement. Wait for agency witness for marker plate installation. SDFN. 9/25/07: SIMOPS w/ Production. PJSM w/ Peak crews. Clean out cellar. Tim Lawlor w/ BLM onsite. Cement tops at surface. Weld on abandonment marker plate. Took GPS reading of page 4 • • KGSF #2 Plug and Abandon Swanson River Field, Alaska well: Lat = 60.75751, Long = 150.84662. Begin demobe non-essential equipment. Waiting on excavator to bust cement in cellar. SDFN. 9/26/07: SIMOPS w/ Production. PJSM w/ Peak crews. Break out cement in cellar. Clean out and pull mouse hole pipe. Pull cellar culvert pipe. Back fill cellar. Continue demobe of non- essential equipment. 9/27/07: SIMOPS w/ Production. PJSM w/ Peak crews. Clean up location. Pick up pad liner and timbers. Complete final demobilization. Clean and clear location. Final Report. page 5 --:.~-rte ~. ,.. ~,,. ..,:~: ~~•._ .. ~. ~ ` ~e \~ ~ '~ r ,~, ~ "~. ~^ ~. ~'~,'.}'fig ~ ~ ~ .e. w ,yti. _ _ ~ ~.~~ " c `~ yy .. ka'.... Y ,' @ k .' ~` ! ~*a, ~ ~.~ r r n x ", ~.' ~`~ ~ ~1 ~,~_ s r = ;'{ •,~ ~ ~ ~ _ • • a ,~ _,,.r _ ~' ~ ~ ~ ~~ ~ ', ~ . ~:~~°,: '. ~" r ~~ a -'.~, kJ' ~` ~~ ~ :~ ~a~- ~j,. ~ ;. ~ ,` w r KGSF #2 Operations ~ Page 1 of 2 Maunder, Thomas E (DOA From: PORHOLA, STAN T [stan.porhola@chevron.com~ Sent: Tuesday, October 02, 2007 11:15 AM To: Maunder, Thomas E (DOA) ~3 - `~~ Subject: RE: KGSF #2 Operations Attachments: KGSF #2 Cement Top.jpg; KGSF #2 Plate.jpg Tom, Attached are photos of the cement top and plate for the abandonment of KGSF #2. They will be included in the sundry notice. ~~~"~~~ NUV ~~- ~ 2007 Stan Porhola Drilling Engineer MidContinent/Alaska Business Unit Chevron North America Exploration aryl Rroduetiorr 909 West 9th Avenue Anchorage, AK 99501-3322 Tel 907 263 7640 Fax 907 263 7884 Cell 907 229 1769 porhost@chevron.com Mail Confzderttial Footer Privileged/Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 263-7640. From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, October 02, 2007 8:14 AM To: PORHOLA, STAN T Cc: Harness, Evan; tzelenka@blm.gov; Tim Lawler Subject: RE: KGSF #2 Operations Stan, Thanks for the reports. When the cutoff occurred were any photos taken? If so, it would be appreciated if photos of the cutoff showing final cement height and the plate could be submitted. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC From: PORHOLA, STAN T [mailto:stan.porhola@chevron.com] Sent: Monday, October 01, 2007 2:40 PM To: Maunder, Thomas E (DOA); tzelenka@blm.gov 10/6/2007 KGSF #2 Operations • Page 2 of 2 Cc: Harness, Evan; Applewhite, Billy -APRs [contractor] Subject: KGSF #2 Operations Tom M. and Tom Z., For your review, attached are the daily operations summaries for KGSF #2 between 9/13 and 9/27. «Weekly Summary of Ops KGSF-2 Report #6.doc» «Weekiy Summary of Ops KGSF-2 Report #7.doc» Final surface abandonment was completed last week w/ Tim Lawlor of the BLM onsite. Abandonment sundry reports will follow shortly. Final location clearance is still required. Stan Porhoia Drilling Engineer MidContinentJAlaska Business Unit Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501-3322 Tef 907 263 7640 Fax 907 263 7884 Ce11 907 229 1769 porhost@chevron.com Mail Confidential Footer Privileged/Confidential information maybe contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message aRer notifying me immediately by replying to the message or contacting me at (907) 263-7640. 1016/2007 _. ~. :. ,~ , ;~ .. „. ;. i' . ~jra ~w r ~, ro M ~' '~n -'~~*1 +.r " ~- ~ ~ ~ `- ' ~ k- „i" -` y~.;-;.' 7, w""~. s ~ ^ A. ~~ 4 ~~. ~ ~ ~ • ~ .va ~~'T~7xY <'%~. ~ ~; t . ~ ~~r Chevron Weekly Summary of Operations 9/20/07: No Operations at KGSF #2. Waiting on cement. • KGSF #2 Plug and Abandonment Swanson River Field, Alaska 9/21/07: SIMOPS w/ Production. PJSM w/ Peak crews. Clean up around pad and in cellar. Notify AOGCC and BLM of expected casing cut and marker plate installation. SDFN. 9/22/07: SIMOPS w/ Production. PJSM w/ Peak crews. Build containment for soil removal. Pull tree, Mix and place 2' of cement inside 5-1/2" casing. Prep cellar for welding. SDFN. 9/23/07: No Operations at KGSF #2. 9/24/07: SIMOPS w/ Production. PJSM w/ Peak crews. Cut 13-3/8" and 5-1/2" casings. Cement top found 10' below cut-off depth inside 13-3i8" x 5-1/2" annulus. Tap off wl cement. Wait for agency witness for marker plate installation. SDFN. 9/25/07: SIMOPS w/ Production. PJSM w/ Peak crews. Clean out cellar. Tim Lawlor w/ BLM onsite. Cement tops at surface. Weld on abandonment marker plate. Took GPS reading of well: Lat = 60.75751, Long = 150.84662. Begin demote non-essential equipment. Waiting on excavator to bust cement in cellar. SDFN. 9/26/07: SiMOPS w/ Production. PJSM w/ Peak crews. Break out cement in cellar. Clean out and pull mouse hole pipe. Pull cellar culvert pipe. Back fill cellar. Continue demote of non- essential equipment. 9!27/07: SIMOPS w/ Production. PJSM w/ Peak crews. Clean up location. Pick up pad liner and timbers. Complete final demobilization. Clean and clear location. Final Report. Report #7 page 1 Che~rron • KGSF #2 Plug and Abandonment Swanson River Field, Alaska Weekly Summary of Operations 9113-9/17/0'1: No Operations at KGSF #2. 9/18/07: SIMOPS w/ Production. PJSM w/ Peak, Schlumberger, and Vetco crews. RU E-line. RIH w/ 2-1/8" tubing jet cutter. Set cutter at 350'. Pressure up tubing to '700 psi. Fire jet cutter, pressure dropped to 0 psi. Jet cutter tools hanging up inside 2-?/8" tubing at tool joint at 322'. Work tool free at 1800 lbs pull. Tool hung up in next tool joint at 291'. Pull 2400 lbs and came out of rope socket. POOH leaving jet cutter inside tubing. RD E-line. Tubing pressure at 0 psi. 2-7/8" x 5-112" annulus at 0 psi. 5-112" x 9-5/$" x 13-3/8" annulus at 0 psi. ND wellhead to tubing hanger and NU 8' riser spool. NU swab valve on top of riser. Secure well. SDFN. 9/19/07: SIMOPS w/ Production. PJSM wi Peak crews. RU crane to pull tubing. ND tubing hanger spool. Pull and lay down 346.5' of 2-7/8" tubing and control line. Parted control line w/ 34001bs at 350'. RD crane. RU slickline. RIH wl 4.55" GR and junk basket. Set down at 290'. Spang down to 325'. POOH w! no recovery in junk basket. MU 5-1/2" bridge plug. Set bridge plug at 310'. POOH w/ slickline. RU E-line. RIH w/ S' long, 4 spf, tubing punch and punch tubing from 300' to 305'. POOH w/ tubing punch. RIH wi 2°d S' long, 4 spf, tubing punch and punch tubing from 300' to 305'. POOH w/ tubing punch guns. RD E-line. Circulate down S-1/2" casing and take returns up 5-112" x 13-318" annulus. Circulate 61 bbls (1.35 bottoms up) fresh water taking mud returns at surface. RU cementers. Mix and pump 65 bbls of 15.8 ppg cement w/ 21 bbls of cement returns to surface. RD cementers. Secure well. SDFN. Wait on cement. Report #6 page 1 Chevrca[t Weekly Summary of Operations • KGSF #2 Plug and Abandonment Swanson River Field, Alaska 8114/07: SIMOPS w/ Production. PJSM w/ Peak and Schlumberger crews. RU injector and shell test to 4000 psi. Pressure up 2-7/8" x 5-1/2" annulus to 2490 psi and tubing to 2700 psi. Pressure dropped to 2390 on annulus and 2410 on tubing in 30 minutes. Bleed pressures to 0 psi. TIH w/ 1.75" cement nozzle on 1.5" coil cleaning, notice small communication between annulus and tubing. Wash down to 5460'. Circ bottoms up. Mix and pump 5 bbls LXT cement, follow by 10 bbl bara~.an vis pill. Lay cement from 5460' to 4596' and barazan vis pill from 4596' to 4400'. Follow barazan vis pill w/ fresh water and circulate out of hole. POOH w/ coil. RD coil and secure well Tubing pressure 0 psi and casing pressure 0 psi. Prep coil for move to KGSF #3. SDFN. 8115-8/21/07: No Operations at KGSF #2 8/22107: SIMOPS w> Production. RU Pollard slickline. Pressure test lubricator 2500/250 psi. RIH w/ 2"x5' drive down bailer and tag cement at 4638' RKB (SLM). Collect sample and POOH. Had contaminated cement in bailer. Pressure up tubing to 2500 psi and chart. Bled down to 2250 psi in 1 hour. Jeff Jones wJ AOGCC onsite for witness of tag and pressure test. RD siickline and move to KGSF #3. SDFN. Report #2 page 1 KGSF #2 Tbg Pressure Test 907 Page 1 of 1 • Maunder, Thomas E (DOA) 1~rom: PORHOLA, STAN T [stan.porhola@chevron.com] Sent: Wednesday, September 05, 2007 9:08 AM To: Maunder, Thomas E (DOA); tzelenka@blm.gov Cc: Harness, Evan; Applewhite, Billy -APRs [contractor] Subject: KGSF #2 Tbg Pressure 3est 9-4-07 Attachments: KGSF-2 PT 9-4 (1).pdf KGSF-2 PT 9-4 (2).pdf Tom M. and Tom. Z, Attached is a copy of the Schlumberger chark pressures for the pressure test of the 2-7/8" tubing cement plug at +/- 36$8'. «KGSF-2 PT 9-4 (1).pdf» «KGSF 2 PT 9-4 (2}.pdf» Stan Porhoia Drilling Engineer MidContinent Business Unit Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501-3322 Tel 907 263 7640 Fax 907 263 7884 Cell 907 229 1769 porhost@chevron.com Mail Corrfidentia7 Footer Privileged/Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 263-7640. l 0/6/2007 ~menti n ~ Schlumber er g ob Rep~-t 9 - - _ Well KGSF 2 Client Chevron Field Swanson River SIR No. 2200941310 Engineer Shane Wills )ob Type PA i Country United States ]ob Date 09-04-2007 Time i -- -- -_ - - - - -- pg,a,z~,oes_~, Pressure -Rate -- Density - ~ - - -__ -- 08:46:21 08:51:00 _ 08:56:00 09:01:00 09:06:00 li 09:11:00 09:16:00 09:21:00 i 09:26:00! 09:31:00 09:36:00 09:41:00 09:46:00 09:51:00 10:00:56' I I I hh:mmas o.oo iooo zooo sooo aooo sooo o.oo z.o a.o e.o a.o io.o s.o io.o is.o zo.o zs.o osianaa~ io:oo:w PSI - LB/G - B/M CemCAT v1.0 Messages Fluid Packing iron and Tubing Racot Tntal Vnl = 19.$1 bbl .2 bbl to fluid pack PT Iron to 4000 Pressure Test Good Bleed preesure to 400 psi Start Tubing Test Monitor tubing for 30 min 20 Minute Mark 54 psi loss 30 minute Mark, 69 psi loss End Tubing Test - - -- - 1 09/04/2007 10:07:42 l~ STATE OF ALASKA ALA~IL AND GAS CONSERVATION COMM N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well Plug Perforations ~ Stimulate O Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ ~°`~~~ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ^ Exploratory ^ 202-119 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic ^ Service ^~ 6. API Number: 50-133-10152-01 _ 7. KB Elevation (ft): 9. Well Name and Number: 15.33' above GL ' Swanson River KGSF #2 8. Property Designation: 10. Field/Pool(s): FED (A-028406) Swanson River Unit - 11. Present Well Condition Summary: Total Depth measured 6915 feet Plugs (measured) 4638 true vertical 6248 - feet Junk (measured) Effective Depth measured 4638 feet true vertical 4638 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 30' 20" 30' 30' N/A N/A Surface 2943' 13-3/8" 2943' 2943' 2730 1130 Intermediate 3310' 9-5/8" 6046' 6046' 5750 3090 Production 6046' S-1/2" 6046' 6046' 7740 6290 Liner 1608' 2-7/8" 6665' 6247' 10570 11170 Perforation depth: Measured depth: nj/A ,-,~~~~~~ A~~ ~ ~ 2Q08 e~ . ~a~ True Vertical depth: N/A Tubing: (size, grade, and measured depth) 2-7/8" L-80 5057' Packers and SSSV (type and measured depth) SAB-L3 5026' 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service ^~ Daily Report of Well Operations x 16. Well Status after work: Oil ^ Gas ^ WAG ^ GINJ ^~ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C. O. Exempt: 307-241 Contact Stan Porhola Printed Name Tim Brandenbur Title Drilling Manager ~ Signature ~ Phone 263-7640 Date 9/6/2007 E P 2 b 2007 fission C~...,,' Form 10-404 Revised 04/2006 ~ ~ ~ ~ N ~ L Submit Original Only Chevran • Daily Summary of Operations • KGSF #2 Plug and Abandon Swanson River Field, Alaska 8/07/07: PJSM w/ Peak crews. Layout liner and berms for coil tubing operations around wells KGSF #2 and KGSF #3. Move in water and returns tanks. SDFN. 8/08/07: PJSM w/ Peak and Schlumberger crews. Spot various coil and cementing equipment on pad and inside containment. Wait on delivery of coil tubing unit. Running single daylight tours (16 hour days). SDFN. 8/09/07: SIMOPS meeting w/ Production. PJSM w/ Peak and Schlumberger crews. Chevron general orientation for crews. MIRU Coil tubing unit. Release cementing crews to Nabors rig #129. Continue rig up until crews released for rest. SDFN. 8/10/07: SIMOPS meeting w/ Production. PJSM w/ Peak and Schlumberger crews. Finalize rig up of coil tubing unit. Perform BOP test to 4000/250 psi. Test OK (witness waived by AOGCC). TIH w/ 1.75" cement nozzle on 1.5" coil cleaning out OBM in 2-7/8" tubing w/ fresh water. Set down at 3831'. Worked and washed through fill (cement?) to 3840'. Continue TIH and circ to 5038' and set 5000# down on X profile at 5034' RKB. Could not work past. POOH w/ coil. Consult w/ town and decide to add weight bar to stiffen BHA next run. Release crews for rest. SDFN. 8/11/07: SIMOPS meeting w/ Production. PJSM w/ Peak and Schlumberger crews. Haul return fluids w/ vac truck to disposal well. MIRU cement batch mixer. Add 10' of lubricator. Test lubricator to 3650/250 psi. Test OK. MU BHA w/ weight bar and TIH w/ 1.75" cement nozzle on 1.5" coil. Troubleshoot problem w/ electronic depth counter on injector head. RU man lift. PJSM w/ crews on operations w/ man lift. Change out encoder, still not operational. Continue w/ manual depth counter. Continue TIH and circ to 5059' and set 1130# down and circ at 1.5 bpm. Could not work past. POOH w/ coil. Found cement piece wedged in cement nozzle. Consult w/ town and decide to add motor and mill next run. Repair electronic depth counter. Release cement batch mixer to SCU 42-OSY. Release crews for rest. SDFN. 8/12/07: SIMOPS meeting w/ Production. PJSM w/ Peak and Schlumberger crews. Chevron general orientation for new crews. MU BHA w/ 2.25" mill and mud motor. Test lubricator to 3500/250 psi. Test OK. TIH w/ coil to 5050' and set 2000# down. Washdown to 5430' and set down hard. Drill hard cement to 5448'. PU off bottom and pull 10,000# above UWT. Work coil and circulate clean. Consult w/ town. Drill hard cement to 5458'. Circ 2 bottoms up. POOH w/ coil. Pressure up 2-7/8" tubing to 2700 psi. Pressure bled to 1659 psi in 30 min. Pressure on 5-1/2" x 2-7/8" annulus has remained at zero psi. Consulst w/ town and decide to put coil on standby. SDFN. 8/13/07: PJSM w/ Peak crews. RU test pump on 5-1/2" x 2-7/8" annulus. Pressure up to 640 psi. Bled to 630 psi in 20 min. Bleed off pressure and RD test pump. Consult w/ town and plan forward is to lay cement plug w/ coil when crews are available. SDFN. page 1 • • KGSF #2 Plug and Abandon Swanson River Field, Alaska 8/14/07: SIMOPS w/ Production. PJSM w/ Peak and Schlumberger crews. RU injector and shell test to 4000 psi. Pressure up 2-7/8" x 5-1/2" annulus to 2490 psi and tubing to 2700 psi. Pressure dropped to 2390 on annulus and 2410 on tubing in 30 minutes. Bleed pressures to 0 psi. TIH w/ 1.75" cement nozzle on 1.5" coil cleaning, notice small communication between annulus and tubing. Wash down to 5460'. Circ bottoms up. Mix and pump 5 bbls LXT cement, follow by 10 bbl barazan vis pill. Lay cement from 5460' to 4596' and barazan vis pill from 4596' to 4400'. Follow barazan vis pill w/ fresh water and circulate out of hole. POOH w/ coil. RD coil and secure well. Tubing pressure 0 psi and casing pressure 0 psi. Prep coil for move to KGSF #3. SDFN. 8/15-8/21/07: No Operations at KGSF #2 8/22/07: SIMOPS w/ Production. RU Pollard slickline. Pressure test lubricator 2500/250 psi. RIH w/ 2"x5' drive down bailer and tag cement at 4638' RKB (SLM). Collect sample and POOH. Had contaminated cement in bailer. Pressure up tubing to 2500 psi and chart. Bled down to 2250 psi in 1 hour. Jeff Jones w/ AOGCC onsite for witness of tag and pressure test. RD slickline and move to KGSF #3. SDFN. page 2 r Chevron ~ • Swanson River Unit Kenai Gas Storage Facility #2 Actual Schematic 8-22-07 RKB =191' AMSL CASING DETAIL C SIZE WT GRADE TOP BOTTOM 13 3/8" 54.5 J-55 0' 2943" 9-5/8" 40 N-80 2736' 6046' window 5-1/2" 20 & 17 N-80 0' 6046' window TUBING & LINER DETAIL SIZE WT GRADE CONN TOP BOTTOM 2-7/8" 6.4 L-80 IBTC SCC 0' 6665' (uncemented liner) COMPLETION EQUIPMENT DETAIL NO. Depth Item 1. 1992' Methanol injection mandrel (ID= 2.312") 2. 5026' Baker SAB-L3 hydraulic packer (not set) 3. 5057' Baker HMC liner hanger w/ 7' tieback PBR 4. 5928' Baker overshot w/high pressure pack-off 5. 6642' Baker landing collar & float collar 6. 6663' Baker float shoe 7. 5034' Baker `X' nipple 2.31" ID ABANDONMENT DETAIL NO. Depth Item A. 4638' Top of cement (Tagged 8/22/07) B. 5460' Cement top from 2002 (milled down to 5460') A B. 6330' Cement Retainer (previously set in 2002) TOC @ _ ,t , ~~ 3 B ~+ .: ~~ ~'tiYhy,1. ..~ 'v e ~ ,`. ' S•f r :' •,• '`+'t. ~~, t'~. i ,~ • <.~ ~, «: ,.. Calculated top of cement @ 5364' Window @ 6046' MD / 6042' VD (LOT result: could not pump in w/ 2000 psi on top of 9.0 ppg OBM - 15.3 ppg E.M.W.) Top of 62-5 reservoir at 6330' MD / 6238' VD Wiper plug fish pushed to 6391' (89° incl.) w/ CTU & hung up. 5 16 9.6 ppg OBM throughout wellbore EZSV ~~ 2-7/8" liner un-cemented at 6665' MD • (top of float equipment at 6642' MD) TD = 6915' MD / 6248' VD WBD KGSF#2 Actual 8-22-07.doc DRAWN BY: STP . . AOGCC Memorandum Date: September 17, 2007 0'( 11/ D 1 . <í<~1 To: KGSF #2 Well File PTD 202-119 From: Jim Regg, Petroleum Engineer ,0 2 1 Z007 5'G~~NEO SEr Subject: P&A Operations Mr. Stan Porhola (Chevron; 907-263-7640) provided information regarding P&A operations at KGSF #2 (Swanson River Unit). AOGCC approved abandonment operations at KGSF #2 under Sundry 307-279 on August 24,2007. Chevron was unable to place the approved volume of cement in the outer annulus plug located near 3100 ft. I spoke with Mr. Porhola today about what the Commission would require to move forward with the final phase of abandonment. Summarized below is my review as discussed with Commissioner Seamount and Mr. Porhola; refer to the attached schematic (markup) for details: Balanced plug set in lieu of cement retainer at 4600 feet; top of cement verified at 3688 feet (tag) and pressure tested to 3075 psi [witnessed by AOGCC Inspector]; top of cement in 2-7/8" x 5-1/2" inner annulus ("IA") and 5-1/2" x 9-5/8" outer annulus ("OA") is calculated to be 4345 feet [2-7/8" tubing plug from 4638 feet to 3688 feet is 5.5 barrels, leaving 16.5 barrels of total 22 barrels cement pumped for the IA and OA]; Cement retainer set at 3110 feet; unable to pump cement through retainer into the formation (holes punched in pipe); able to pump only 2.5 bbls of cement down OA due to a pressure increase to the maximum allowable (2500 psi) in the IA; top of cement in OA calculated to be 3066 feet (54 feet above hopes punched in pipe for circulation); top of cement in tubing tagged at 2080 feet (1030 feet above cement retainer); top of cement in IA calculated to be 2035 feet (1085 feet above holes punched for circulating cement). The integrity of each cement plug has been confirmed with successful pressure tests: tubing cement top at 2080 feet tested to 2600 psi; IA cement top (calculated) at 2035 feet tested to 2500 psi; OA cement top (calculated) at 4395 feet tested to 1290 psi. I contacted Mr. Porhola by phone and email confirming that nothing additional is required from Chevron to continue with the final phase of abandonment operations at KGSF #2 and to note any deviations from the approved sundry in the well completion report (Form 10-407). He was also reminded about providing notice for AOGCC inspection of casing cut and marker plate installation. Chevron indicates work may recommence at KGSF #2 as early as September 18. FW: KG SF #2 Operations . . Page 1 of2 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Monday, September 17, 2007 2:35 PM To: 'PORHOLA, STAN T' Cc: Maunder, Thomas E (DOA) Subject: RE: KGSF #2 Operations q\ \1 \D1 1-Q1 ({ Stan - Thank you for the information regarding P&A activities completed to date at KGSF have reviewed and discussed the status with Commissioner Seamount, specifically the inability to et the pec olumn of cement in the outer annulus of the plug at approximately 3100 ft. Pressure testing of the plugs set thus far and the lack of pressure buildup in the tubing and annuli indicate that deviations regarding the cement placement have not impacted the intent and integrity of abandonment operations. You may move to the next phase of abandonment of KGSF #2. Deviations from the approved sundry should be summarized in the Well Completion Report (10-407). Please contact me to arrange for Inspector witness of the casing cutoff and marker plate placement Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: PORHOLA, STAN T [mailto:stan.porhola@chevron.com] Sent: Monday, September 17, 20079:28 AM To: Regg, James B (DOA) Subject: FW: KGSF #2 Operations Jim, Per our conversation, below is the email sent to the Maunder requesting approval to move onto our next phase of abandonment. We were not able to put our planned volume of cement into the outer annulus per pressuring up. However, we were able to get a solid pressure test of that annulus to 1290 psi wi ° psi lost in 30 min. I am including a copy of the approved sundry to aid in your review. «KGSF-2 AOGCC_Approved_1 0-403_082407.pdf» We plan to continue wi operations as early as tomorrow. Stan Porhola Drilling Engineer MidContinent Business Unit Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501-3322 Tel 907 263 7640 9/17/2007 FW: KGSF #2 Operations Fax 907 263 7884 Cell 907 229 1769 porhost@chevron.com . . Page 2 of2 Mail Cot¡fìdential Footer Privileged/Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy tl¡is message after notifying me immediately by replying to the message or contacting me at (907) 263-7640. From: PORHOLA, STAN T Sent: Wednesday, September 12, 2007 1:23 AM To: 'Maunder, Thomas E (DOA)'; 'tzelenka@blm.gov' Cc: Hamess, Evan; Applewhite, Billy -APRS [contractor] Subject: KGSF #2 Operations Tom M. and Tom Z., For your review, attached are the daily operations summaries for KGSF #2 between 8/23 and 9/12. «Weekly Summary of Ops KGSF-2 Report #3.doc» «Weekly Summary of Ops KGSF-2 Report #4.doc» «Weekly Summary of Ops KGSF-2 Report #5.doc» Based on our results of our cement tag and pressure testing of the tubing on inner annulus and outer annulus (conducted 9/6/07), we plan to proceed with the next phase of our abandonment as outlined in the approved sundry notices by cutting and recovering tubing, setting a bridge plug in the 5-112" casing, punching circ holes in the casing and circulating a cement plug to surface. Stan Porhola Drilling Engineer MidContinent Business Unit Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501-3322 Tel 907 263 7640 Fax 907 263 7884 Cell 907 229 1769 porhost@chevron.com lvlail Confìdential Footer Privileged/Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 263-7640. 9/17/2007 . KGSF #2 Plug and Abandonment Swanson River Field, Alaska . Weeklv Summary of Operations 8/23/07: SIMOPS wI Production. PJSM wI Peak. Clean location. Prep location for E-line and cementing operations. SDFN. 8/24/07: SIMOPS wI Production. PJSM wI Peak. Mob choke skid, test pump, and water tank to well SCU 42-05Y. Suspend operations at KGSF #2. 8/25-8/28/07: No Operations at KGSF #2. 8/29/07: SIMOPS wI Production. PJSM wi Peak. Clean location. Mob Sib crews for E-line and cementing operations. SDFN. Report #3 page 1 . KGSF #2 Plug and Abandonment Swanson River Field, Alaska . Weekly Summary of Operations 8/30/07: SIMOPS wi Production. PJSM wI Peak and Schlumberger crews. RU water tank, test pump and choke skid that had been at SCU 42-5Y. SDFN. 8/31/07: SIMOPS wI Production. PJSM wI Peak and Schlumberger crews. RU Sib lubricator. Test to 250/3000 psi. RIH wI 5' of 1.56" HSD 60° 6spfperf guns. Tag plugback depth at 4625' RKB. Set guns on depth at 4607'-4612'. Pressure up tubing to 1500 psi. Fire guns. Lost 1000 psi in tubing, gained 25 psi on 2-7/8" x 5-1/2" annulus, 0 psi on 5-1/2" x 9-5/8" x 13-3/8" annulus. POOH wi guns. All shots fired. Pressure up tbg to 2800 psi, 2500 psi on 2-7/8" x 5-1/2" annulus, 0 psi on 5-1/2" x 9-5/8" x 13-3/8" annulus. No circulation up 5- 1/2" x 9-5/8" x 13-3/8" annulus. Establish 5 bbls of circulation up 2-7/8" x 5-1/2" annulus. RIH wI 5' of 1.56" HSD 60° 6spf perf guns. Set guns at same depth at 4607'- 4612'. Pressure up tubing to 1500 psi. Fire guns. No change in pressure. POOH wI guns. All shots fired. RD E-line. No circulation up 5-1/2" x 9-5/8" x 13-3/8" annulus. Establish 5 bbls of circulation up 2-7/8" x 5-1/2" annulus. Discuss plan forward wi AOGCC and BLM. Proceed ahead wI balanced cement plug in tbg and 2-7/8" x 5-1/2" annulus. Mix and pump 22 bbls of 9 ppg spacer ahead of 15 bbls of 15.9 ppg LXT cement followed by 22 bbls of9 ppg displacement. Pump rate 3 bpm and max pressure of 1400 psi. Close tbg and annulus valves. Calculated top of cement at 3855'. Shut-in pressure of 350 psi tbg, 350 psi 2-7/8" x 5-1/2" annulus, 0 psi on 5-1/2" x 9-5/8" x 13-3/8" annulus. RD cementers. Contact AOGCC and BLM inspectors. Plan to pressure test and tag cement 9/4/07. WOC. SDFN. 9/1-9/3/07: No Operations at KGSF #2 9/4/07: SIMOPS wI Production. PJSM wI Peak and Schlumberger crews. RU Sib lubricator. Test to 250/3000 psi. Bob Noble wi AOGCC onsite. Pressure test tubing to 3067 psi. Lost 69 psi in 30 min. RIH wI E-line. Tag cement top at 3688' RKB. POOH. Pressure was 0 psi on tbg and 2-7/8" x 5-1/2" annulus. RIH wI 5' of 1.56" HSD 60° 6spf perf guns. Set guns on depth at 3115'-3120'. Pressure up tubing to 900 psi. Fire guns. Lost 450 psi in tubing, gained 450 psi on 2-7/8" x 5-1/2" annulus, 0 psi on 5-1/2" x 9-5/8" x 13-3/8" annulus. POOH wI guns. All shots fired. Pressure up tbg to 2500 psi. Had 2500 psi on 2-7/8" x 5- 1/2" annulus. Attempt circulation into formation wI no success. Attempt circulation of 5- 1/2" x 9-5/8" x 13-3/8" annulus with no success. RIH wI 5' of 1.56" HSD 60° 6spf perf guns. Set guns at same depth at 3115' -3120'. Pressure up tubing to 900 psi. Fire guns. Gain 25 psi on 5-1/2" x 9-5/8" x 13-3/8" annulus. POOH wI guns. All shots fired. Inject 10 bbls into formation at 0.8 bpm at 2000/1700/1200 (Tbg/WOA) psi. Circulate 10 bbls up 5-1/2" x 9-5/8" x 13-3/8" annulus at 3.2 bpm at 1700/1700/400 psi. Close OA valve. Circ up 2-7/8" x 5-1/2" annulus at 3 bpm at 500/200 psi. RIH wI 2-7/8" cement retainer and set at 3110' RKB. Inject below retainer into formation at 1.5 bpm at 1294/2300/1700 psi. Increase rate to 2 bpm at 2500/2500/1900 psi and well jugged up. Bled tubing to 861 psi. Annular pressures remain at 2500/1900 psi. Attempt to inject into formation with no success. Close 2-7/8" x 5-1/2" annulus and open 5-1/2" x 9-5/8" x 13-3/8" annulus to Report #4 page 1 . . KGSF #2 Plug and Abandonment Swanson River Field, Alaska returns tank. Mix and pump 18 bbls of 9 ppg spacer ahead of x bbls of 15.8 ppg LXT cement followed by 22 bbls of 9 ppg displacement. Pump rate 1 bpm at 170012000/430 psi. With 2.5 bbls cement inside 5-112" x 9-5/8" x 13-3/8" annulus, 2-7/8" x 5-112" annulus increased to 2500 psi (maximum pressure to not exceed). Shut down pumps. Pressure of 5-1/2" x 9-5/8" x 13-3/8" annulus at 0 psi. Tubing pressure at 1400 psi. Close 5-1/2" x 9-5/8" x 13-3/8" annulus. Open 2-7/8" x 5-112" annulus and bled to 500 psi. Pump 15.3 bbls cement in 2-7/8" x 5-112" annulus and 5.8 bbls cement in tubing on top of retainer. Shut-in well. Pressures at 0/010 psi. Calculated cement top at 2000' RKB in tbg and 2-7/8" x 5-1/2" annulus. Calculated cement top at 3065' RKB in 5-112" x 9-5/8" x 13- 3/8" annulus. RD cementers. Plan to pressure test and tag cement 916107. WOC. SDFN. 9/5/07: SIMOPS wI Production. PJSM wi Peak. Continue to wait on cement. Empty returns tank and transport by vac truck to disposal well. Report #4 page 2 . KGSF #2 Plug and Abandonment Swanson River Field, Alaska . Weekly Summary of Operations 9/6/07: SIMOPS wI Production. PJSM wi Peak and Schlumberger crews. RU test skid. Shut-in wells pressures are 01010 psi. Pressure test 5-112" x 9-5/8" x 13-3/8" annulus to 1290 psi. Had 0 psi loss in 30 min. Charted pressure. Tim Lawlor wI BLM onsite. Pressure test tbg to 2623 psi. Lost 82 psi in 30 min. No pressure increase in either annulus. RIH wI E-line and tag top of cement in tbg at 2080' RKB. Pressure test 2-7/8" x 5-112" annulus to 2509 and lost 179 psi in 30 min. Retest 2-7/8" x 5-1/2" annulus to 2504 psi and lost 37 psi. RD all crews. Secure well. Suspend operations at KGSF #2. SDFN. 917-9/12/07: No Operations at KGSF #2. Report #5 page 1 • MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~ DATE: Sept 4, 2007 P. I. Supervisor '~-~~~~ ~d.J~-I~,-~ FROM: Bob Noble SUBJECT: Plug Tag and Test Petroleum Inspector Swanson River KGSF #2 Chevron PTD 202-119 Seat 4th, 2007: I traveled to Chevron's Swanson River, Well KGSF #2 to witness a pressure test and a tag of a cement plug for a P&A. Plug was set with the balance method. Summary: I met with Chevron's rep. Billy Applewhite. We did a pressure test on the tubing and it passed according to MIT standards. Pre. T/I/O = 0/500/300 Initial T/I/O = 3075/600/300 15 min T/I/O = 3050/590/300 30 min T/I/O = 3040/590/300 They then rigged up Schlumberger E-line to perform a tag. Hard cement was tagged at TOP 3688' RKB in the tubing. TOP in the Inter annulus was estimated at 3983" Attachments: none MEMORANDUM • To: Jim Regg '~ i. - P.I. Supervisor ? >.~~;~j ~ ~ ~ ~ ¢ FROM: Bob Noble Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, September O5, 2007 SUBJECT: Mechanical Integrity Tests U]VION OIL CO OF CALIFORNIA KGSF 2 SWAAISON RIVER KGSF 2 Src: Inspector NON-CONFIDENTIAL 1~~~ L ~~ Reviewed By: P.I. Suprv .u~~~..~ Comm Well Name: SWANSON RNER KGSF 2 API Well Number: 50-t33-10152-01-00 Inspector Name: Bob Noble Insp Num: mitRCN070904161851 Permit Number: 202-1 l9-o Inspection Date: 9/4/2007 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We j KGSFZ Type Inj. ~ N TVD ~ ,,,;~~} .i IA 500 600 ~ 590 ~ 590 ~ P.T. i 2021190 Type Set PT' eST t pSl 300 ~ 307 ~ DA 00 - - 300 300 ~ ~ Interval OTHER P~F P ' '~ Ttibing ~ 0 ~ 3075 ~ 3050 ~ 3040 Notes: Bob This is not an MIT. It is a pressure test on the tubing of a P&A. That's why no paker TVD. TOC was @ 3688. Wednesday, September 05, 2007 Page 1 of 1 . ~1r~1rŒ (ID~ ~~~~æ~ . A"lA~Ji.& OILAlQ) GAS CONSERVATION COMMISSION SARAH PALIN, GOVERNOR 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 99519 SCANNED AUG 2' B 2007 ~o:;;.- It 1 Re: Swanson River Field, 62-5 Gas Storage Pool, Swanson River KGSF #2 Sundry Number: 307 -279.~~__-... Dear Mr. Brandenburg: 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 fonn. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this v( day of August, 2007 Encl. brS ~4fííI.,> cP:¡- 9-lf'-o7 RECEIVEU ./ STATE OF ALASKA I L . ALASKAOILAND GAS CONSERVATION COM SION C'~AUG 242007 APPLICATION FOR SUNDRY APPROVALS 0', "\ iI. G Cons. Commission 20 MC 25 280 .Alaska '3 as 1, Type of Request: Abandon D Alter casing D Change approved program 0 . 2. Operator Name: Union Oil Company of California 3. Address: P,O. Box 196247, Anchorage, AK 99519 Suspend D Repair well D Pull Tubing D Operational shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Development D Stratigraphic D Perforate D Waiver I.:":], Stimulate D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory D 202-119 . Service 0, 6. API Number: 50-133-10152-01 . Other D 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? Yes D 9. Property Designation: FED (A-028406) 12. 8. Well Name and Number: Casing Structural Conductor Surface ..Intermediate Production Liner Total Depth TVD (ft): 6248' , Length No 0 . Swanson River KGSF #2 10. KB Elevation (ft): 11. Field/Pool(s): , /J ~ .,(1' 15.33' above GL Swanson River Unit '-¡;ø~ ~ 'ð'- i-=Z~i:. 7 PRESENT WELL CONDITION SUMMARY (/ Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 6330' 6238' 6330' Junk (measured): Total Depth MD (ft): 6915' . Size MD TVD Burst Collapse Perforation Depth MD (ft): N/A Packers and SSSV Type: 3020" 2140 13-3/8" 3310 9-5/8" 6046 5-1/2" 1608 2-7/8" Perforation Depth TVD (ft): N/A 30 2943 6046 6046 6,665 30 2943 6046 6046 6,247 Tubing Grade: L-80 2730 5750 7740 10,570 Tubing MD (ft): 5057' 1130 3090 6290 11,170 Tubing Size: 2-7/8" Baker SAB-L3 Hydraulic Packer (Not set) Packers and SSSV MD (ft): 5026' 13. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 15. Estimated Date for 8/25/2007 Commencing Operations: 14. Well Class after proposed work: Date: Exploratory D Development 16. Well Status after proposed work: Oil D Gas D WAG D GINJ D D Service 0 17. Verbal Approval: Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Stan Porhola Title Drilling Engineer Signature "~/J, /J /) ~tA..- 1/ c71~~t(4',.e\. Plugged WINJ o D Abandoned WDSPL o D Contact Stan Porhola - 263-7640 Phone Date g/21 (0 7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: êiJ'1" ~ 7 q Plug Integrity ~ BOP Test D Mechanical Integrity Test D Location Clearance D Oth," Cc,,\c.¿.. I "<;'P"'c-~~ p-\-'<o" "> \a w \ \-I'(¡,~ ~\..;:¡ ~,,>, ~ rC~Ç€ SV\\~~No.X-~~~~~\ - CCCð\,~~\<;O (~ 1 APPROVED BY ~, r/ ~ -Z- ~ Approved by: T ) MlþSIONER THE COMMISSION Date: 1) ,2 r- ,.. v-r ~ \~AL .¿~,¿~~ Form 10-403 Revised 06/2006 n R \ G ''4 ~ #. ~J'J~ in Duplicate Chevron === . . Swanson River Unit KGSF #2 Well Abandonment Revision #1 8/24/07 CHANGE TO ORIGINAL PLAN: · Following our coil tubing operations, the top of cement inside the 2-718" tubing is 4638' RKB. The plan forward will be to set cement retainers at +1- 4600' and +1-3100' RKB. From the surface, bullhead cement down the 2-7/8" tubing thru cement retainers into squeeze perforations below the retainers. The original plan called for setting of the plugs wi coil tubing. This was made in error since the retainers cannot receive a stinger assembly to stab into the retainer and establish circulation. These cement retainers will be set wi E-line and cement bullheaded from surface. The retainers are equipped wi a poppet (check) valve to prevent cement from U-tubing back up the tubing. Bullheading down the tubing provides the advantage of not have a separate coil tubing annulus that would further complicate the cementing procedure. REVISED PROCEDURE SUMMARY: · RIH wi E-line and fire squeeze perfs at 4610' RKB +1-. POOH wi E-line. Attempt to break circulation up 2-7/8" x 5-112" inner annulus (IA) and 5-112" x 9-5/8" x 13-3/8" outer annlus (OA). · RIH wi E-line and cement retainer wi poppet valve to 4600' RKB +1-. Set retainer and POOH wi E-line. · From surface, bullhead squeeze 15.8 ppg LXT abandonment cement below retainer and up OA then IA. Close both OA and IA valves and squeeze cement into formation. .~ d.tJ~~\s ~~\ ú"'> 'o~œ. ÇXl-\~\> · Displace cement to above retainer with 9.0 ppg weighted fluid and leave cement top at a minimum 4400' RKB +/-. WOC. I .. ~,,",,-r,~,>\:"" ~d" .~~/,ç-Tì · RIH wi E-line and tag new plugback depth wi dummy guns. POOH wi E-line. '-c"'~~ .¡:~~ t" "}-\WU "'" · RIH wi E-line and shoot squeeze perfs at 3120' RKB +1-. POOH wi E-line. Attempt to break circulation up 2-7/8" x 5-112" inner annulus (IA) and 5-112" x 9-5/8" x 13-3/8" outer annlus (OA). · RIH wi E-line and cement retainer wi poppet valve to 3110' RKB +1-. Set retainer and POOH wi E-line. · From surface, bullhead squeeze 15.8 ppg LXT abandonment cement below retainer and up OA then IA. Clo~e both OA and IA valves and squeeze cement into formation. ~<oç ~\:>\~ \O~ \.Ct~ ~<G~ttè ~\<; P · Displace cement to above retainer with 9.0 ppg weighted fluid and leave cement top at a minimum 2500' RKB +1-. WOC. ~ \)~S~~~\-~"?..\.-\o ,\,,~ 'i.. ,~S ~\ 14') RIH wi E-line and tag new plugback depth wi dummy guns. POOH wi E-line. \ _ \'^-\.~'\ ""--.)~ .. . c..ot'-.~cl- x:.~¡y;.c-\"O\ · RIH wi E-Ime and cut tubmg at 500' RKB +1-. POOH wi E-Ime. ,- RU Crane. Recover and laydown cut tubing. RIH wi E-line and set 5-112" BP at 310' RKB +1-. · RIH wi E-line and shoot punch holes in 5-112" casing at 300' RKB +1-. POOH wi E-line. · RU Cementers to pump 15.8 ppg G Neat abandonment cement down 5-1/2" casing. Circulate cement down 5-112" casing and up 13-3/8" annulus to surface. WOC. ND wellhead and perform top off cement if necessary. · Dig out cellar and cut 13-3/8" and 5-1/2" casings 3' below original ground level. ~~~~~~~: · Weld on 13-3/8" abandonment marker plate across 13-3/8" and 5-112" casing. Weld separate plate ring over 20" conductor. Inscribe well information, and acquire GPS coordinates of well. Backfill cellar. RDMO all equipment. Clean and clear location. KGSF #2 P+A Revised Procedure Summary. doc REVISED BY: STP 8/24/07 RKB = 191' AMSL WED KGSF#2 Proposed P+A Revised,doc 2. 3. 4. 5, 6, 7, 5026' 5057' 5928' 6642' 6663' 5034' Baker SAB-L3 hydraulic packer Baker HMC liner hanger wI 7' Baker overshot wI high pressure pack-off Baker landing collar & float collar Baker float shoe Baker 'X' nipple 2.31" ID 310' Bridge set in 5-1/2" casing 3110' Cement Retainer wI poppet valve 3120' Squeeze holes 4600' Cement Retainer wI poppet valve 4610' Squeeze holes 6330' Cement Retainer (previously Calculated top of cement @ 5364' Window @ 6046' MD I 6042' psi on top of9.0 ppg OBM- (LOT result: ppg E.M.W.) Top of 62-5 reservoir at 6330' MD I 6238' Wiper plug fish pushed to 6391 ' (890 inel.) wI 2-7/8" liner un-cemented at 6665' MD (top of float equipment at 6642' MD) 9.6 ppg throughout wellbore . . Chevron === Stan Porhola Drilling Engineer Union Oil Company of California P.O, Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7640 Fax 907 263 7884 Email porhost@chevron.com RECEIVED AUG 2 4 2007 August 24, 2007 Commissioner Alaska Oil & Gas Conservation Commission 333 W. th Avenue Anchorage, Alaska 99501 Re: Change of Approved Program Sundry Notice, KGSF #2, Sundry No. 307-241 Alaska Oil & Gas Cons. Commission Anchorag$ Dear Commissioner, Enclosed for your review and approval is form 10-403, Application for Sundry Approvals for a change of the approved program for the above referenced well. This change of program is in regard to the approved sundry notice no. 307-241, approved 7/27/07. .,/ In order to facilitate the plug and abandonment of this well, Union Oil Company request a variance to the following AOGCC regulation: 1. 20 AAC 25.120 (b): Union Oil Company seeks approval to cut the casings of this /' well above the conductor and place marker plates across the 13-3/8" and 5-1/2" casings. A separate ring-shaped marker plate would be placed over the 20" conductor and separately welded onto the conductor. The well was originally drilled in 1959 and access for cutting the casing strings to the top of the 20" conductor will be problematic. Placing separate marker plates will have little to no effect on the abandonment. The 20" conductor is only driven to 30' and a separate ring-shaped plate welded to the 20" should provide the same effect as a larger plate across all strings. We would like to begin wireline operations on August 25, 2007 and appreciate your timely review and approval of this Sundry notice. Please review the attached abandonment procedure and well bore diagrams and feel free to contact myself at 907-263-7640 if you have any questions. Sincerely, ß 1.1£ Stan Porhola Drilling Engineer Union Oil Company of California / A Chevron Company Page 1 of 2 . . Attachments: Form 10-403, Application for Sundry Approvals KGSF #2 Revised Planned P&A Schematic KGSF #2 Revised Abandonment Procedure Cc: File Union Oil Company of California / A Chevron Company http://www.chevron.com Summary of Operations KGW2 and #3 . Page 1 of2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, August 24, 2007 9:04 AM To: 'PORHOLA, STAN T; tzelenka@blm.gov Cc: Harness, Evan; Applewhite, Billy -APRS [contractor]; Jeff Jones Subject: RE: Summary of Operations KGSF #2 (202-119) and #3 (203-074) Gentlemen, I have received a report from the Inspector who witnessed pressure tests and plug tagging on these wells. It appears that tags were made, however it also appears that the samples were inconclusive. Following is my assessment of the information I have received. Also, it is requested that the permit to drill number for a well be included in your message titles. That helps with processing and filing. KGSF #3 (203-074) - Based on the pressure test witnessed by Inspector Jones it appears that the deep plugging on this well has been successful. Again, although wireline did reach 6281' md rkb, the sample returned was not conclusively determined to be cement. Given the volume of cement listed as placed above the retainer, an even shallower tag could be expected. However since the cement needed to displace a barazan pill as it was placed, it is not surprising that the sample determination is inconclusive. The work planned at this time has been completed. Recovery of portions of this well for sidetrack/red rill is planned in the future and the option remains to do additional work should it be determined necessary. A couple of observations, I find it interesting that the first fluid pumped into the well was a barazan pill. As I understand, fluids with barazan are used to contaminate cement preventing it from setting. It is routinely used after placing cement with coil as you have done here to cleanout to a desired cement top. 2nd observation is that the depth given for the 2nd set of perforations is the same as the first which would have been isolated below the 1st retainer set at 7300' ctm. ~ KGSF #2 (202-119) - Based on the operations information, it does not appear that the deep plug has achieved the intended isolation. The pressure test of 8/22 still shows a loss and the recovered sample determination was not conclusive. Based on the approved work plan to use coil tubing for additional plugs, I believed that running in deeper to make a solid tag would not have been a problem and potentially spotting additional cement could be done. However, when I spoke with Stan this morning he indicated that the further work would be accomplish with wirelineleline, If Chevron desires to make changes to the operational plan that has already been approved, it will be necessary to submit a revision. Since the objective is to plug and abandon this well, that revision should be submitted to the Commission as a new 403. One question with regard to this well, after the pressure test, were the pressures bled down? If so, has there been any pressure build up noticed? Please provide the current pressures on the well. Call or message with any questions. Tom Maunder, PE AOGCC ------ .---.,.-----"- From: PORHOLA, STAN T [mailto:stan.porhola@chevron.com) Sent: Friday, August 24, 2007 4:28 AM To: Maunder, Thomas E (DOA); tzelenka@blm.gov Cc: Harness, Evan; Applewhite, Billy -APRS [contractor] Subject: Summary of Operations KGSF #2 and #3 Tom M. and Tom Z., Attached are the weekly summary of operations for KGSF #2 and #3. 8/24/2007 Summary of Operations KGW2 and #3 . Page 2 of2 «Weekly Summary of Ops KGSF-2 Report #2,doc» «Weekly Summary of Ops KGSF-3 Report #1.doc» «Weekly Summary of Ops KGSF-3 Report #2.doc» Stan Porhola Drilling Engineer MidContinent Business Unit Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501-3322 Tel 907 263 7640 Fax 907 263 7884 Cell 907 229 1769 porhost@chevron.com Mail Confidential Footer Privileged/Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 263-7640. 8/24/2007 Page 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, August 24, 2007 4:16 PM `~~ To: aogcc_prudhoe_bay@admin.state.ak.us ~ "~ ~\\~ Subject: 202-119_KGS F#2_307-279. pdf Attachments: 202-119_KGSF#2_307-279. pdfi Alt, Here is the revision for KGSF #2. Jeff witnessed the attempted tag and pressure test on the CT place plug. The changes are due to equipement issues with the CT. Plugs should be cleaner bullheading. Several options to witness. As usual, call or message with questions. Tom 10/6/2007 i Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, August 23, 2007 4:37 PM To: PORHOLA, STAN T Cc: Jeff Jones r' Subject: KGSF Weiis ~©~~ ~~~ Page 1 of 1 Stan, Could you give me a summary of where in the abandonments) the operations are? Jeff is sending me a summary of his inspection. 1 have also received a fax from Billy Applewhite of two pressure test charts. It appears that the test for KGSF #3 lost only 30 psi during the observation period while the test for KGSF #2 showed a 250 psi foss during the observation period. We just spoke. You will be sending the further reports for the operations on both welts. Your next ptug in KGSF #2 will involve punching the tubing and cementing through a retainer. I will examine both sets of reports this evening and then get back with you in the morning. Tom Maunder, PE AOGCC 10/6/2007 . . Page 1 of 1 Maunder, Thomas E (DOA) From: Jones, Jeffery B (DOA) Sent: Thursday, August 23, 2007 5:24 PM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA) Subject: KGSF #2 & KGSF #3 abandonement plug tag & pressure test Hi Tom, Yesterday, 8/22/07, I witnessed slickline unit plug tag and pressure test operations on Chevron's Swanson River Field wells KGSF #2 & #3 with Chevron representative Bmy Applewhite. .". ê)C ò - , \ ~ KGSF #2: the Pollard W/L slickline unit was able to reach a depth of 4638' RKB (RKB=22ft,) utilizing a weight bar, 2 jars, guage ring and sample catcher assembly which returned a sample that appeared to be thick mud, possibly slightly contaminated with cement. I could not say if there is hard cement at this depth. The tubing was then pressured up to 2450 psi and the I noted the pressure dropped 100 psi in the first 15 min. and 50 psi in the second 15 min, The pressur dropped 25 psi each in the next two 15 min. intervals and continued at the same rate of loss, The IA and OA pressures remained constant throughout the test at 0 psi and 40 psi respectively. Mr. Applewhite indicated to me Chevron plans a permanent abandonement of this well and plans to bullhead cement downhole for the remaining plugs. Since it appeared this P&A procedure has changed significantly from what was approved previously by our office, I asked him to get approval from the AOGCC engineering staff prior to proceeding. àO~ -0'"1 ~ KGSF #3: the slickline unit was able to reach a depth of 6281' RKB (RKB=29ft.) and returned a sample that appeared to be very thick (barazan?) contaminated mud. There was no sample evidence of cement at this depth and Mr. Applewhite indicated an approximate wellbore deviation of 49 degrees. The tubing was then pressured up to 2480 psi and after a well head flange leak was repaired, I noted the pressure dropped 30 psi in the first 15 min. and 0 psi in the second 15 min. The IA pressure increased from 400 psi to 490 psi and stabilized and the OA remained at 0 psi throughout the test. In my opinion both of the slickline tags seem inconclusive and it may be necessary to clean out the contaminated mud above the plugs and use a procedure applying more weight if we want to effectively determine the plug location and competency. Thanks, and let me know if you need anything else. Jeff 8/24/2007 . . Chevron === KGSF #2 Plug and Abandonment Swanson River Field, Alaska OOd-\\~ Weeklv Summary of Operations 8/14/07: SIMOPS wi Production. PJSM wi Peak: and Schlumberger crews. RU injector and shell test to 4000 psi. Pressure up 2-7/8" x 5-112" annulus to 2490 psi and tubing to 2700 psi. Pressure dropped to 2390 on annulus and 2410 on tubing in 30 minutes. Bleed pressures to 0 psi. TIH wi 1.75" cement nozzle on 1.5" coil cleaning, notice small communication between annulus and tubing. Wash down to 5460'. Circ bottoms up. Mix and pump 5 bbls LXT cement, follow by 10 bbl barazan vis pill. Lay cement from 5460' to 4596' and ....barazan vis pill from 4596' to 4400'. Follow barazan vis pill wi fresh water and circulate out of hole. POOH wi coil. RD coil and secure well. Tubing pressure 0 psi and casing pressure 0 psi. Prep coil for move to KGSF #3. SDFN. 8/15-8/21/07: No Operations at KGSF #2 8/22/07: SIMOPS wi Production. RU Pollard slickJine. Pressure test lubricator 2500/250 psi. RIH wi 2"x5' drive down bailer and ,tag cement at 4638' RKB (SLM). Collect sample and POOH. Had contaminated cement in bailer. Pressure up tubing to 2500 psi and chart. Bled down to 2250 psi in 1 hour. Jeff Jones wi AOGCC onsite for witness of tag and pressure test. RD slickJine and move to KGSF #3. SDFN. ".-- ~--- --- Report #2 page 1 AUG-23-2007 THU 07:24 A~ FAX NO, .028 P. 03 2. 7t. - 75'f~ Chevron Swanson· RiVer Field .', Fax Cover Sheet Date: ~/:J.3 / ÇJ 7 . ( Time: '/ : IS 1fJV( To: .. -;;DM 11 If ¡}!AJ d..eœ..- , Location:. 46 C; c.. c- ,. . ~ ·R€CT::/VED . ' 4UG 2 3 ZOO? Alaska Oil & G . a, Con, c' .Anchora,.' .. omrnl..'øn From: g'L~f.,!JfR/éW~,-+~. ~ 1Jß-:1536 3 HM_' Cover +: Please corifirm receipt;· 907 ~283·2541 . Message: --1c~s ç d-- -d- 3 , p~ss UV-~· ~ST' . ", '., uJ~+,uGss'~ 'Lo'f~Æ ~.~~5 \ ' Tl. _ J>.... . T "I"'<7 ----.¡p-- I>.... AMP' AUG-23-2007 THU 07:22 AM "~ . r? :¡. A 10 i.' ~"".¡Jf'lce~~~'!-'f-~¿!; =;: :;:"C, , ., , AÁ'/" """.'f' cf--!Ê- ~--?'- - - ~: <0 ÆTÞ?¿/'>'f'''''\;V''':C':::;''' ~ '#''''~: "",j,ò,;8:~ t%+"";~'ßOO ..'< '1" ',,''fo.-,-,£~=<,,·' ''F-' - .:"" .'... · ' >-- :·;u~~;¿·-;¿i:1:;!!~~;~~~';/:>~":~"'· , ?(;_<.~ ;:%:,~?~~J~8~1I....:;...~:~f.];::~J~='!?::"'=~~:t.?~: ;~~'."i:~~S¿0-."o .. .. .' ' .. r"" .¡ .-" c.r. ,CF .£ ."£ ' " . 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I I: \ ,\\ \ ," \~,o~. ~ < Ii: '" %í, 'I"l! 1$,~r¡ 'm¡IiJJ f~¡ 'Ii \ 11111 ~ '. I~¡"~t~~\,~:t,\ \~ , A/;;ifl1 ' HI¡~#!~~~~lIf~H~I!I~A1j!~!I!!il! ~,,~ §¡ , :¡,,*~"": "'.; .,'," : .:o.P"" l' (,,0',-%,' ~%îJ ' , ~,W¡í 'II!I!/!)ij~ Jß II/WC, ~ .III , /11 ~,\,' ~~ , :\.~~",~~~.~"~:,<. ,~::' .~' ':"~7-C-- .~~:::=J::~:::'::-.: _,<""'ff¡' = %,' !1¡;,'j/1I./J, 1/1/; IW¡IIIII 111"1 . ,~",Yii"~ "", "..,.. ;>.,.',' ="'-1:'<'",....,,,-0 " , '" . /, ï ' r I, , ",,<'~';" ,,~" -" ,',.' .' ._. ,__~ 'I',.,~".,w /, /, " / I . '!I ~" ~ c ~~~,,~:~~~~:'.;;~:':'f~]i~~'~;~"~'§j~~~~~J;>' 0<' " , I/(/' %:r, ;1/[«% J~\~~~it~~~~:~~~';~t"~~~;~~ ,/ '0 I ! ~;J , " ",-,,, " ,'~ ",___ .~_~,o¡;."1""-2-<""ß" y/ " '~~ 0 r.: '%0 '.' ,,, ",'~ .,_ ._ . ,,' ._~"!:5:g_",__a¿~9~' ~êi< ~/I/ ,R'0~;,~~~:& j-lF~~~~f1?ß~f§~-rø::%~' '- ,,' "". ~', _~:~:§~iI~1~~~_Wd' '-" .."'.."-.... ~ NO, 4íiÞ028 ~, .', p, 02 , 5 / ".. ô 01 ...,,1 . MEMORANDUM . State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~I' / 0/-"'/"7 DATE: P. I. Supervisor ",eft u YJ,e FROM: Jeff Jones SUBJECT: Petroleum Inspector August 21, 2007 P&A KGSF #2 Chevron PTD 202-119 ./ Swanson River Unit ---_._---------~--~--- -----AŒgLisTTr;~007: I traveled to Chevron'S'Swanson River Unit KGSF #2 gas storage well site to witness the pressure test and wire line tag of a cement plug for abandonment of this well. Bill Applewhite was the Chevron representative for the tests today. The Pollard W /L slick line unit was able to reach a depth of 4638' RKB (RKB=22ft.) utilizing a weight bar, 2 jars, gauge ring and sample catcher assembly which returned a sample that appeared to be very thick mud. Mr. Applewhite indicated the sample was contaminated with a Barazan chemical mud additive. I could not determine / from the wire line tag or the sample returned if there was hard cement at this depth. The tubing was then pressured up to 2450 PSI and I noted the pressure dropped 100 PSI in the first 15 min. and 50 PSI in the second 15 min. The pressure dropped 25 PSI each in the next two 15 min. intervals and continued at the same rate of loss. The IA and OA pressures remained constant throughout the test at 0 PSI and 40 PSI respectively. In my opinion these tests were inconclusive and it may be necessary for the operator to clean out the contaminated mud above the plug and use a procedure applying more weight to effectively determine actual plug location and competency. Because the P&A procedures have changed from what was originally approved, I required Mr. Applewhite to get approval from the AOGCC engineering staff prior to proceeding. / Summary: I witnessed an inconclusive wire line tag and pressure test of a cement plug for abandonment of Chevron's gas storage well KGSF #2. Attachments: None Non-Confidential SCANNED S E P 1 1 2007 P-A SRU KG SF #2 8-21-07 Hdoc ,~L4,1Q)7,- r ,_ , ¡?.(! fÜß<:¡ r- +.n.:~ \0,1." A¡''<~$'V1C4:- , b- , tD c'&t{,'ES's IV\G,N..cll{.<ÇlI.Jtt17\Ç; ~ 1'\' ID C.t .] ¡AtS5v'V-ê.. 'JC. ~ ' .. ~\. e,$, íl.Y\ . , ) s<'\,bM. ç\\e ('{ (èÜl ,s~J j 0 -403 KGSF #2 Abandonment UPdl . Page 1 of 1 Maunder, Thomas E (DOA) From: PORHOLA, STAN T [stan.porhola@chevron.com] Sent: Wednesday, August 15, 2007 9:20 AM To: Maunder, Thomas E (DOA); tzelenka@blm.gov Subject: KGSF #2 Abandonment Update Attachments: Weekly Summary of Ops KGSF-2 Report #1.doc; KGSF-2 Cement Plug#1.doc; KGSF-2 Cement Plug#2.doc I. . ~ J-Od - \ \ '\ Gentlemen, The procedure for KGSF #2 will proceed as submitted, with a slight change due to tagging and milling cement inside the 2-7/8" tubing at 5458' RKB. The coil tubing layed plug originally planned to be layed from 6330' to 5000' will now be layed from the top of cement at 5458' to - 4600' RKB (- 5 bbls of cement). The squeeze perforations and cement retainer originally planned to be set near 5000' will now be moved uphole to - 4600'. Attached is a summary of the operations to date. «Weekly Summary of Ops KGSF-2 Report #1.doc» Also attached are the cement designs for the plug to be layed with coil (plug #1) and the squeeze cement at - 4600' (plug #2). «KGSF-2 Cement Plug#1.doc» «KGSF-2 Cement Plug#2.doc» Stan Porhola Drilling Engineer MidContinent Business Unit Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501-3322 Tel 907 263 7640 Fax 907 263 7884 Cell 907 229 1769 porhost@chevron.com SCANNED AUG 1 62007 Mail Confidential Footer Privileged/Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delívery of the message to such person), you may not copy, forward, disclose, delíver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 263-7640. 8/16/2007 . . Chevron III KGSF #2 Plug and Abandonment Swanson River Field, Alaska Weeklv Summary of Operations 8/07/07: PJSM wi Peak crews. Layout liner and berms for coil tubing operations around wells KGSF #2 and KGSF #3. Move in water and returns tanks. SDFN. 8/08/07: PJSM wI Peak and Schlumberger crews. Spot various coil and cementing equipment on pad and inside containment. Wait on delivery of coil tubing unit. Running single daylight tours (16 hour days). SDFN. 8/09/07: SIMOPS meeting wI Production. PJSM wi Peak and Schlumberger crews. Chevron general orientation for crews. MIRU Coil tubing unit. Release cementing crews to Nabors rig #129. Continue rig up until crews released for rest. SDFN. 8/10/07: SIMOPS meeting wI Production. PJSM wI Peak and Schlumberger crews. Finalize rig up of coil tubing unit. Perform BOP test to 4000/250 psi. Test OK (witness waived by AOGCC). TIH wI 1.75" cement nozzle on 1.5" coil cleaning out OBM in 2-7/8" tubing wi fresh water. Set down at 3831'. Worked and washed through fill (cement?) to 3840'. Continue TIH and circ to 5038' and set 5000# down on X profile at 5034' RKB. Could not work past. POOH wI coil. Consult wi town and decide to add weight bar to stiffen BRA next run. Release crews for rest. SDFN. 8/11/07: SIMOPS meeting wI Production. PJSM wi Peak and Schlumberger crews. Haul return fluids wI vac truck to disposal well. MIRU cement batch mixer. Add 10' of lubricator. Test lubricator to 3650/250 psi. Test OK. MU BRA wI weight bar and TIH wI 1.75" cement nozzle on 1.5" coil. Troubleshoot problem wI electronic depth counter on injector head. RU man lift. PJSM wI crews on operations wI man lift. Change out encoder, still not operational. Continue wI manual depth counter. Continue TIH and circ to 5059' and set 1130# down and circ at 1.5 bpm. Could not work past. POOH wI coil. Found cement piece wedged in cement nozzle. Consult wI town and decide to add motor and mill next run. Repair electronic depth counter. Release cement batch mixer to SCU 42-05Y. Release crews for rest. SDFN. 8/12/07: SIMOPS meeting wI Production. PJSM wI Peak and Schlumberger crews. Chevron general orientation for new crews. MU BRA wI 2.25" mill and mud motor. Test lubricator to 3500/250 psi. Test OK. TIH wI coil to 5050' and set 2000# down. Washdown to 5430' and set down hard. Drill hard cement to 5448'. PU off bottom and pull 10,000# above UWT. Work coil and circulate clean. Consult wI town. Drill hard cement to 5458'. Circ 2 bottoms up. POOH wI coil. Pressure up 2-7/8" tubing to 2700 psi. Pressure bled to 1659 psi in 30 min. Pressure on 5-112" x 2-7/8" annulus has remained at zero psi. Consulst wI town and decide to put coil on standby. SDFN. 8/13/07: PJSM wI Peak crews. RU test pump on 5-112" x 2-7/8" annulus. Pressure up to 640 psi. Bled to 630 psi in 20 min. Bleed off pressure and RD test pump. Consult wI town and plan forward is to lay cement plug wI coil when crews are available. SDFN. Report #1 page 1 Schlumberger Laboratory Cement Test Report-KGSF2 Plug 2 Swanson River Fluid No : PAK plug07115 Date : Au -06-2007 Client : Chevron Well Name : KGSF#2 Location I Rig Field : Swanson River Si natures Sam Sudderth 128 degF 80 degF 648 psi 15.801blgal 41.2% D053 D065 M045 D600G C359 D177 Rheolo 300 68.0 200 53.0 100 40.0 60 32.0 30 28.0 6 19.0 3 18.0 I Temperature 81 degF pv: 44.232 eP Ty: 23.791bf/100ft2 Th' k T" Depth BHCT Time to Temp. Time to Pressure Yield Porosit 94 Ib of BLEND 1"1 99.0 76.0 54.0 45.0 37.0 31.0 27.5 117 degF pv: 68.415 cp Ty: 30.69 Ibf/100ft2 IC enmg Ime . " 30 Be 02:15 hr:mn lOBe 03:40 hr:mn 100 Be 04:07 hr:mn Remark: Thickening time includes 1 :00 hr:mn batch time Fluid Loss API Fluid Loss 36 mL 18 mL in 30 min at 117 de F and 1000 Comments General Comment: 4990.0 ft 117 degF 00:11 hr:mn 00:11 hr:mn 1.19 ft3/sk 58.8 % . .. .. Blend Base Fluid thixotrop. dispersant antifoam GASBLOK biozan retarder TVD BHP Heating Rate Schedule Mix Fluid Slur t e ::. '" . ... 199.771b/ft3 4990.0 ft 2340 psi 2.59 degFlmin () 5.291 galfsk Conventional I" Page 1 Schlumberger Laboratory Cement Test Report- KGSF2 Plug 1 144 degF 80 degF 833 psi Sl natures Client : Chevron Location / Rig Well Name : KGSF#2 Field : Swanson River Sam Sudderth Depth 6238.0 ft lVD 6330.0 ft BHCT 140 degF BHP 3400 psi Time to Temp. 00:14 hr:mn Healing Rate (degF/min) Time to Pressure 00:14 hr:mn Schedule () Fluid No : PAK plug07114 Date : Au -05-2007 . . . .. . 15.80 Iblgal 41.4% Yield Porosít 1.20 ft3/sk 58.6% 94 Ib of BLEND Blend Base Fluid dispersant antifoam GASBLOK biozan retarder Thixotro a D065 M045 D600G C359 0177 D053 Rheolo 600 115.0 300 75.0 200 58.5 100 43.0 60 37.5 30 32.5 6 28.0 3 26.0 I Temperature 81 degF pv: 43.592 cp T y : 29.10 Ibf/100fl2 Th' k T" 85.0 57.0 44.0 32.0 27.5 24.0 21.0 19.0 140 degF pv: 32.591 cP T y : 21.48 Ibf/100fl2 IC emnQ .me . 30 Bc 03:57 hr:mn 70 Bc 04:46 hr:mn Remark : Thickening lime includes batch time Batch Mix Time: 01 :00 hr:mn at 80 degF Fluid Loss API Fluid Loss 20 mL in 30 min Comments I General Comment: Page 1 FW: KGSF #2 . . Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, August 13, 20072:53 PM To: 'Alexander, Steve [TWT]'; 'PORHOLA, STAN r Subject: RE: KGSF #2 (202~119) Steve and Stan, From my conversation with Stan, I understand that BLM did not agree with the proposed changes so cement will be placed in the tubing via coil to substantially meet the depths originally proposed. Call or message with any questions. Tom Maunder, PE AOGCC From: Alexander, Steve [TWT] [mailto:Steve.Alexander@chevron.com] Sent: Monday, August 13, 200711:43 AM To: Maunder, Thomas E (DOA) Subject: FW: KGSF #2 Tom thanks for your time on this. We began this P&A activity on KGSF no. 2 on Thursday the 8\9\07 with 1 1/2" coil tubing clean out operations on the attached Approved notice. Upon clean out operations however, we encountered hard at 5438' and drilled to 545S' to confirm that it was not just a stringer of cmt as found at 5034' . At this time we feel we have hard cmt from 545S' down to the cmt retainer at 6330' from a 2003 cmt opertion when Unocal attempted to cement in the 27/8" tubingless completion into place and the retainer failed. A pressure test on the cemented 2 7/S" tbg was performed to 2700 psi but slowly leaked off to 1600 psi in 30 minutes. This leak however could also have been within the chemical injection mandrel within the tbg string at 1992' as the leak path although no annular pressure was detected outside the 27/8" due to the slow leak off. Now that a hard clean out depth has been obtained at 545S' it would only require 2.6 bbls volume of cmt from 5458' to the planned 5000'. Therefore we would now like to propose a change by placing a greater amount of cement above the liner hang/packer both within the 27/8" tbg and the 2 7/S" x 5.5" liner annulus to 4500', or as directed. A revised proposed well bore sketch is attached for discussion witch illustrates a tbg punch gun hole rather than a squeeze gun at 5000' to maintain the outer casing string integrity and reduce the complexity of this cmt operation. Operations have been suspended but with the CT still over the well bore in the event the small cmt plug was still required from 545S' to 5000' within the 2 7/S" tbg so your attention is requested at your earliest convenience due to this new clean out depth. A revised Objective procedure is attached for consideration and will be amended and sent in after our discussions today. Regards Steve Alexander / Stan Porhola «KGSF~2 BLM_Approved_3160-5_072007.pdf» «WBD KGSF#2 Proposed revised.doc» «KGSF #2 P+A Objective and Procedure Summary Aug 13.doc» 8/16/2007 . ~V~VŒ (ID~ ~~~~~~ . AI,ASIiA. OIL AND GAS CONSBRVATlON COMMISSION SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 99519 aö~- ~lO( Re: Swanson River Field, 62-5 Gas Storage Pool, Swanson River KGSF #2 Sundry Number: 307-241 Dear Mr. Brandenburg: 5CANNED JUL 3 1 2007 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may me with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day Ü 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, DATED this f, ~y of July, 2007 Enc!. . . . Chevron === Timothy C Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com July 16, 2007 f'-"ECE'VEn t~:{ ::: . ~h,J ~f.I. JUL 1 W 2007 Commissioner Alaska Oil & Gas Conservation Commission 333 W. ih Avenue Anchorage, Alaska 99501 ,\ '1."..I'a Oil & Gas Cons. C"i!h\ìissiol1 /"'1. ",Q.:tr... ' Anchnrag8 Re: Sundry Notice of Intent to Plug and Abandon, KGSF #2, PTD No. 202-119 Dear Commissioner, Enclosed for your review and approval is form 10-403, Application for Sundry Approvals to plug and abandon the above referenced well. We would like to begin coil tubing operations on July 30, 2007 and appreciate your timely review and approval of this Sundry notice. Please review the attached abandonment procedure and well bore diagrams and feel free to contact myself or Stan Porhola at 907-263-7640 if you have any questions. Sincerely, 7~c Timothy C. Brandenburg Drilling Manager TCB: sk Attachments: Form 10-403, Application for Sundry Approvals KGSF #2 Actual Schematic KGSF #2 Planned P&A Schematic KGSF #2 Abandonment Procedure Cc: File Union Oil Company of California / A Chevron Company Page 1 of 1 · m 1~~1'o1 ~,., ~~ RECEIVED STATE OF ALASKA t~,1(I ALASKAOILANDGASCONSERVATIONCOMM SON Þ""IëJ-~ JUL 1 82007 APPLICATION FOR SUNDRY APPROVALS . ~ 'I'" 20 MC 25.280A1aò.lka 01. & lias Guns. Cammission 1. Type of Request: Abandon 0 Suspend 0 Operational shutdown 0 Perforate 0 Waiver 0 t\nCrW¡ôijOC>ther 0 Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development 0 Exploratory 0 202-119 '" 3. Address: Stratigraphic 0 Service 0 6. API Number: P.O. Box 196247, Anchorage, AK 99519 50-133-10152-01 ,- 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes 0 No 0 Swanson River KGSF #2 , 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool( s): FED (A-028406) . 15.33' above GL Swanson River Unit / 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): 6915' 6248' ,- 6330' 6238' - 6330' Casing Length Size MD TVD Burst Collapse Structural Conductor 30 20" 30 30 Surface 2140 13-3/8" 2943 2943 2730 1130 Intermediate 3310 9-518" 6046 6046 5750 3090 Production 6046 5-1/2" 6046 6046 7740 6290 Liner 1608 2-7/8" 6,665 6,247 10,570 11 ,170 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A 2-7/8" L-80 5057' Packers and SSSV Type: Baker SAB-L3 Hydraulic Packer (Not set) Packers and SSSV MD (ft): 5026' 13, Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 15. Estimated Date for 7/30/2007 16, Well Status after proposed work: Commencing Operations: Oil 0 Gas 0 Plugged 0 Abandoned 0 17. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola - 263-7640 Printed Name Timothy C. Brandenburg Title Drilling Manager , Signature ,~ '-~çA Phone~ Date '7- -I?- --0 ':J- ./ /" ~/C, ~ COMMISSION USE ONLY --- Conditions of approval: Notify Commission so that a representative may witness Sundry Number: L~' .. ól4/ Plug Integrity -Ø, BOP Test ~ Mechanical Integrity Test 0 Location Clearance ~ 0Ih." ~5DD \'.,;, ~'\ ~~" ,,"'.,\- or ~ \ "\ yo ~ soD"" \.-.'\ '-"'-<t."~ 0:-, ~~ ~~ , c.J c.(),,~ú..c-\- :C-~t>~c....\-\':),~ '"~~~'1tO~<> ~ ~~~'>~ ~\~~. S«.~ ~~ ' -...)1"t S,',"",.m Fonn ROO';'''' "i 0 ~' RBDMS BfL JUL 3 0 2001 ~ J l0/~ONER APPROVED BY Date: -1,Z':}-,.O 1- Approved by: THE COMMISSION J / / Form 10-403 Revised 06/2006 Q-RI~+',{AL ¡~ ~ ¥~7 Submit in Duplicate RKB = 191' AMSL 9-5/8" 40 5-1/2" 20 & 17 N-80 N-80 2736' 0' 6046' window 6046' window 7 2. 3. 4. 5. 6, 7. 5026' 5057' 5928' 6642' 6663' 5034' Baker SAB-U hydraulic Baker HMC liner hanger wi 7' Baker overshot wi high pressure pack-off Baker landing collar & float collar Baker float shoe Baker 'X' nipple 2.31" ID Calculated top of cement @ 5364' . . . ..... . . .. . . 4;' ::: :;: Window @ 6046' MD I 6042' VD (LOT result: ;> ::: ~v:~ psi on top of9,O ppg OBM -15.3 ppg .... ... ... / TOP::::~~:::p:,::::~::,6::9:':)W/cru 5 6 9.6 ppg throughout wellbore 2-7/8" liner un-cemented at 6665' MD (top of float equipment at 6642' MD) TD= WBD KGSF#2 Actual 7-16-02,doc RKB = 191' AMSL 9-5/8" 40 5-112" 20 & 17 N-80 N-80 2736' 0' 6046' <window 6046'wfudow 2, 3, 4. 5, 6. 7. 5026' 5057' 5928' 6642' 6663' 5034' Baker SAB-L3 hydraulic Baker HMC liner hanger wi 7' Baker overshot wi high pressure pack~off Baker landing collar & float collar Baker float shoe Baker 'X' nipple 2.31" ID WBD KGSF#2 Proposed P+A.doc B. e. D. E. F, G, 310' 3110' 3120' 4980' 4990' 6330' Bridge Plug set in 5-112" casing Cement Retainer wi poppet valve Squeeze holes Cement Retainer wi poppet valve Squeeze holes Cement Retainer (previously set in 2002) Calculated top of cement @ 5364' Window @ 6046' MD 16042' VD (LOT result: could psi on top of9.0 ppg OBM - 15.3 ppg E.M.W,) Top of62-5 reservoir at 6330' MD 16238' VD Wiper plug fish pushed to 6391' (890 incl.) 2-7/8" liner un-cemented at 6665' MD (top of float equipment at 6642' MD) 5 6 9,6 ppg throughoµt wellbore TD= Chevron ~~ IIììijíII . . Swanson River Unit KGSF #2 Well Abandonment Revision #0 7/16/07 OBJECTIVE: · Plug and abandonment ofthe KGSF #2 wellbore. PROCEDURE SUMMARY: · Mobilize coil tubing unit and ancillary equipment to KGSF #2. · RU and RIH with coil tubing to plugback depth of 6330' RKB +1-. · Circulate out OBM wI 9.0 ppg brine or abandonment mud. · Pump 15.8 ppg LXT abandonment cement while pulling out of hole from 6330' to 5000' RKB +1-. · POOH wI coil and WOC (wait on cement). · RIH wI E-line and tag new plugback depth wi dummy guns. POOH wi Eline. ~~~ \ · RIH wi E-line and fire squeeze perfs at 4990' RKB +1-. POOH wI Eline. Attempt to break circulation up 2-7/8" x 5-112" inner annulus (IA) and 5-112" x 9-5/8" x 13-3/8" outer annlus (OA). · RIH wI coil and cement retainer wI poppet valve to 4980' RKB +1-. Set and sting into retainer. · Squeeze 15.8 ppg LXT abandonment cement below retainer and up OA then IA. Close both OA and IA valves and squeeze cement into formation. · Unsting coil from retainer and lay cement on top to 4800' RKB +1-. POOH wI coil and WOC. · RIH wI E-line and tag new plugback depth wI dummy guns. POOH wI Eline. ro()~, ~ I:,,~t.\.o' · RIH wI E-line and shoot squeeze perfs at 3120' RKB +1-. POOH wi Eline. Attempt to break circulation up 2-7/8" x 5-1/2" inner annulus (IA) and 5-1/2" x 9-5/8" x 13-3/8" outer annlus (OA). · RIH wi coil and cement retainer wi poppet valve to 3110' RKB +1-. Set and sting into retainer. · Squeeze 15.8 ppg LXT abandonment cement below retainer and up OA then IA. Close both OA and IA valves and squeeze cement into formation. · PU coil above retainer and lay cement on top to 2500' RKB +1-. POOH wi coil and WOC. · RIH wi E-line and tag new plugback depth wi dummy guns. POOH wi Eline. .~~ r ~~r · RIH wi E-line and cut tubing at 500' RKB +/-. POOH wi E-line. · RU Crane. Recover and laydown cut tubing. RIH wi E-line and set 5-112" BP at 310' RKB +1-. · RIH wi E-line and shoot punch holes in 5-112" casing at 300' RKB +1-. POOH wi E-line. · RU Cementers to pump 15.8 ppg G Neat abandonment cement down 5-112" casing. Circulate cement down 5-112" casing and up 13-3/8" annulus to surface. WOC. ND wellhead and perform top off cement if necessary. · Dig out cellar and utilize Wach Saw to cut casings 3' below ground level. · Weld on abandonment marker plate, inscribe well information, and acquire GPS coordinates of well. · Backfill cellar. RDMO all equipment. Clean and clear location. KGSF #2 P+A Objective and Procedure Summary. doc REVISED BY: STP 7/16/07 Cement Volumes for ChevroWlls KGSF #2 and KGSF #3 . Page 1 o~ U'I'M Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, July 26,20073:21 PM To: 'PORHOLA, STAN T' Subject: RE: Cement Volumes for Chevron wells KGSF #2 and KGSF #3 Stan, Thanks for looking into my questions. Your plan looks appropriate. With regards to the displacement fluid, if available, mud would be preferable given the clabberedlviscous interface that could develop when mixed with the cement for the plugs. I will forward the sundry recommending approval. Call or message with any questions. Tom Maunder, PE AOGCC From: PORHOLA, STAN T [mailto:stan.porhola@chevron.com] Sent: Thursday, July 26,20079:37 AM To: Maunder, Thomas E (DOA) Subject: RE: Cement Volumes for Chevron wells KGSF #2 and KGSF #3 The well construction of the original well, SRU 12-27, is unusual. During drilling in 1959, surface casing has been set at 2943' MD. While drilling the intermediate hole, a kick was taken at approximately 7622' MD and the drillstring became stuck after picking up to 7601' MD. After 40+ days of fishing operations, a cement plug was set in the openhole and the well was sidetracked. A 9-5/8" casing string was run to 7228' MD (top setting the kick zone) and tied back to the surface casing with a liner. The 9-5/8" was not run to surface probably because of some wellhead/BOPE spacing concerns. This was the cause of the unusual well construction. The current configuration has oil-based mud from the drilling of KGSF #2 in the 2.875" tubing and the 5.5 x 2.875" annulus. The 9.625/13.375 x 5.5 annulus has 12.4 ppg (93 pet) water-based mud from the drilling of SRU 12-27 in 1959. The oil based mud in the tubing will be displaced out of the hole with coil tubing prior to setting the first plug from the cement retainer at 6330' MD to 5000' MD. After squeeze perforations are made at 4990' MD, circulation will be attempted on the 5.5 x 2.875" annulus and 9.625/13.375 x 5.5 annulus. The displacement fluid will be either lease water (8.5 ppg) or spud mud (9.0 ppg) with the spud mud being left in the hole between the plugs, The spud mud should have enough viscosity to hold the cement which will also have an increase viscosity over previous blends of our LXT cement. Schlumberger is still working on the cement blends for the KGSF wells. They were testing the latest blend in their lab in Prudhoe on July 25th to give us a report on thickening times, etc. I will forward this information as soon as it is available. The Schlumberger coil tubing unit is still on standby for heading out to the King Salmon platform for K-12RD. Once it becomes available, we will mobilize to the KGSF #2 and #3 upon AOGCC sundry approval. Stan Porhola Drilling Engineer MidContinent Business Unit Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501-3322 Tel 907 2637640 Fax 907 263 7884 7/26/2007 Cement Volumes for Chevrop ""ells KGSF #2 and KGSF #3 Page 2 ofð~ 1P-1'ff OF for (2 ~-~ ~<.)S Cyp1f';(' -"-/ì ~ :.SEe --, '. ..."-. 1//./1: .,.¡. 2. .....(lll L L -~I L) ì/l.4/.:-r i'(7~T ..H- f! Ivt;.f lfelolCr- ./Vcte$r"/~ <--'-_.__ wt.o' II (,vq..l i"//¡'qllþ dli1ll'c/ to r4l' fettr rJ.qr '/,f r.vel/ 4~.I /I~~ /" C ¥e¡JIf ~ /rocl(;'t.r¡()rl Aó l'eVt'cl1/ POfl''''''' q/ re5ervej Io$Je J ,'.$ /lecp§$i;? '(Á<:. l)r¥()~e~ I~ð-. æ 7//7/97 Cell 907 229 1769 porhost@chevron.com Alai! ('ol1(ìdenliol/;'ooler 1'e COl'1jJkft:cI ¡JI/ e Peey¡ Privileged/Confidential information may be ( message (or responsible for delivery of the use this message or any part of it in any for after notifying me immediately by replying I From: Maunder, Thomas E (DOA) [m Sent: Friday, July 20, 2007 1:29 PM To: PORHOLA, STAN T Subject: RE: Cement Volumes for Chevron wells KGSF #2 and KGSF #3 Stan, I am reviewing the P&A for KGSF #2. You plan to place abandonment mud or brine in the 2-7/8" string. What are the fluids in the 5.5 x 2.875" annulus as well as the 9.625 / 13.375 x 55 annulus? How will "flip-flop" of the cement in the annuli be minimized or prevented? The construction of this well is a little unusual, however since the original well was drilled in 1959 maybe not. 20 AAC 25.112 (c)(3) addresses plugging where fresh water is present. All aquifers are exempted below 1700' per 40 CFR 147.1 02(b)(1 )(i). Plug #3 will cover the liner top and the surface casing shoe, but the base of fresh water is still some 800' shallower. It appears that the regulation was written with the presumption that the surface casing shoe is set proximate to ttle base of fresh water. That is not the case here. I will have to clleck with my colleagues over here about this matter and get back to you. I'd look forward to any comments you might have. Tom Maunder, PE AOGCC ....-..-'..,---..-.- From: PORHOLA, STAN T [mailto:stan.porhola@chevron.com] Sent: Friday, July 20, 20079:53 AM To: tzelenka@blm.gov; Maunder, Thomas E (DOA) Cc: Alexander, Steve [1WT]; Tony Stafford Subject: Cement Volumes for Chevron wells KGSF #2 and KGSF #3 Tom Z. and Tom M., I am including information on cement volumes for the plug and abandonment of KGSF #2 and plugback of KGSF #3. The blend types will be similar to those used for the plug and abandonment of SCU 41-05 executed in October 2006. Details on the cement additives and mixing fluids is currently being worked with Schlumberger and will be provided to the BLM and AOGCC once available. «KGSF #2 and #3 Cement Planning v2.doc» Stan Porhola Drilling Engineer MidContinent Business Unit Chevron North America Exploration and Production 909 West 9th Avenue 7/26/2007 . . Chevron ... IìijííII KGSF #2 Cement Planning Data (Well P&A) 0.0 80.0 2000.0 7860.0 Geothermal Tem rature Profile TVD Temperature Gradient ft d F d F/10Oft 0.0 0,0 80.0 10.0 1928.9 1.6 6248.3 1.3 MD ft Plug #1 Blend: 15.8 ppg LXT Volume: 8 bbls Depth: 5000'-6330' MD (5000'-6238' TVD) BHT: 144°F ~Q~ CO \)o\~~ '"\J3-b'\-o\> Plug #2 Blend: 15,8 ppg LXT h Volume: 20 bbls S~CQ:. ~c\~'M..,Cè- l1 ~ \ \O~ \<;> Depth: 4800'-5000' MD (4800'-5000' TVD) J BHT: 128°F Plug #3 Blend: 15.8 ppg LXT Volume: 65 bbls Depth: 2500'-3120' MD (2500'-3120' TVD) BHT: 103°F c:;~~ \1~ù~ L.\~ _ \ b \0 \~ Plug #4 Blend: 15.8 ppg Class G Volume: 50 bbls Depth: 0'-300' MD (O'-300' TVD) BHT: 50°F ~~~(C \fJC)\~~ Li dJ.~ 'b\;)\5> MD ft F #3 Cement Planning Data (We 0.0 80.0 2000.0 7860.0 Plug #1 Blend: 15.8 p T Volume: bls (Below retainer) + 1.5 bbls {Above retainer Dept· 00'-7920' MD (6242'-6253' TVD) B : 144°F KGSF #2 and #3 Cement Planning v2.doc 7-20-07 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc 18 ~~ Àh~ DATA SUBMITTAL CbMPLIANCE 8/2/2004 ' REPORT Permit to Drill 2021190 Well Name/No. SWANSON RIVER KGSF 2 Operator UNION OIL CO OF CALIFORNIA )rJ~'~ '2 1 J(,~vv- ?¿~ L API No. 50-133-10152-01-00 MD 6915./ TVD 6248 ,/' Completion Date 7/18/2002 .../- Completion Status GSTOR Current Status GSTOR ...#w~"' ~;~ -Y¿! ">-~-- ""....~;u.-'" ---~-~---- -~-- REQUIRED INFORMATION Mud Log No Samples No " Directional Survey (fi;;i IV' \)}) " ) (f i _.~------ ----~-._--~--~~ DATA INFORMATION Types Electric or Other Logs Run: MWD/LWD-Directional/GR only Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Log/ Electr Data Digital Dataset Type Med/Frmt Number Name Log Log Run Scale Media No Interval OH / Start Stop CH .~~ -_.~--~~---~ Received Comments A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 6/14/2002. ~ÉD C eo.11136 Neutron c10g --- t.fiamma Ray ~ment Evaluation 25 Col 25 Col 25 Col 25 Blu field 5 Blu 5600 6340 Open 10/3/2002 5600 6340 Open 10/3/2002 5600 6340 Open 10/3/2002 5600 6340 Open 1 0/3/2002 6044 6912 Open 10/3/2002 5600 6220 Open 10/3/2002 CPST Setting Tool -'tog - Log V' Log ~og r"Neutron /' Gamma Ray _Casing collar locator Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments --- ADDITIONAL INFORM~TION yÁjj) Daily History Received? D/N ~ (~N Well Cored? Chips Received? . ~ Formation Tops Analysis Received? ~.. -" Comments: Permit to Drill 2021190 MD 6915 lVD 6248 ~---_.__._---------_._.~-- -~--------~_._~ --- ---~-- Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 8/2/2004 Well Name/No. SWANSON RIVER KGSF 2 Operator UNION OIL CO OF CALIFORNIA Completion Date 7/18/2002 Completion Status GSTOR Current Status GSTOR UIC Y ~ I Date: API No. 50-133-10152-01-00 / ç-,li! )ru ~. ~ ~ ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well SUSPENDED: OTHER: OIL: GAS: 2. Name of 0 perator Union Oil Company of California (UNOCAL) 3. Address P.O. BOX 196247 Anchorage, AK 99519-6247 4. Location of well at surface 1750'FNL,1190'FVVL, Sec. 27, T8N, R9VV, S.M. At Top Producing Interval ~ 1808' FNL, 1275' F~r. Sec. 27, T8N, R9W, S.M. At Total Depth 2228 FNL, 806' FWL, Sec. 27, T8N, R9W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB 15.33 above ground level ADL 028406 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. _,9[13/02 ~'2- Cf,(j¿')JÞ 7/4/02 7 !.rlr02 .,$1:> 17. Total Depth (MD+ TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 6915' MD /6248' TVD 6328' MD/6235' TVD Yes: X No: 22. Type Electric or Other Logs Run MWD/LWD - Directional/GR only Mud Log 23. ABANDONED: - ~ -. ~ ~t". '-... '. > ',~ , . \ .. ['J!.:.'rE .:Z. Ii' ,(;}-z, Classification of Service Well Shut-in 7. Permit Number 202-119 8. API Number 50- 133-10152-01 9. Unit or Lease Name Swanson River Unit 10. Well Number KGSF #2 (formerly SRU 12-27) 11. Field and Pool Swanson River Unit Tyonek 62.5 Sands 15. Water Depth, if offshore NA feet MSL 20. Depth where SSSV set NA feet MD Logs will be sent under separate cover by UNOCAL's Land Department. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM 0' 2943' CASING SIZE 1 3-3/8" 9-5/8" 5-1 /2" 2-7/8" VVT. PER FT. 54.5# 40.0# 20 & 17# 6.4# GRADE J-55 N-80 N-80 L-80 2736' 0' 6046' window 6046' window 6665' HOLE SIZE 18-5/8" 12-1/4" 8-1 /2" 4-5/8" 5057' 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) NONE 25. SIZE 2-7/8" 10,704' to 10,710 SQZD & Isolated to Abandon 6/02 10,726' to 10,750' 10,760' to 10,790' Isolated by closed SSD & Filled 6/02 10,810' to 10,823' Isolated by blanking plug, fill in tbg & abandon plugs 6,328' to 6,333' Cement Squeezed Annulus 7/18/02 16. No. of Completions Shut-In 21. Thickness of Permafrost " NA 7¡~.)f.-".d.o ¡.oJ ~o~~ ;nþ (;,.0'11 '" 'f'Y,þ CEMENTING RECORD AMOUNT PULLED 44 sx 15.8 ppg 'G' (12 bbls) TUBING RECORD DEPTH SET (MD) 5057' PACKER SET (MD) 5026' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED (All previous perfs in H2 to H5 abandoned) 27. Date First Production NA Date of Test PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) NA OIL-BBL PRODUCTION FOR TEST PERIOD => CALCULATED 24-HOUR RATE => GAS-MCF Hours Tested Flow Tubing Press. 28. None OIL-BBL Casing Pressure GAS-MCF CORE DATA OCT '4 2002 ~9DMS 8Ft Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE WATER-BBL CHOKE SIZE GAS-OIL RATIO WATER-BBL OIL GRAVITY-API (corr) 'RECEIVED OCT 0 7 2002 Alaska on & Gas Cons. CommisSion - Anchorage r' Cy \; Submit in duplicate ') 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GaR, and time of each phase. Tyonek 62.5 Sands 6329' 6238' RECEIVED OCT 0 7 2002 ðtuka OU& G~A Con~. r.ommtsStlft 31. LIST OF AlTACHMENTS . Anchorage PERFORATION DATA SHEET, ABANDONDED WELL SCHEMATIC, SUMMARY REPORT OF OPEfMTIONS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Sign/); I~ tF. Title (bxy/¿, ~~ Date H/S /0 '2-- I NSTR UCTIONS 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 space 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 productin 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". Form 10-407 ) KGSF #2 formerly SRU 12-L7 /) Date 6/13/02 6/14/02 6/15/02 6/16/02 6/17/02 6/18/02 6/19/02 6/20/02 6/21/02 6/22/02 6/23/02 6/24/02 6/25/02 6/26/02 6/27/02 Daily Report of Abandonment Well Operations SRU 12-27 Abandonment APE #155462 Summary RU with SL unit for tbg clean out. Pressure test tbg to 3000 psi. RIH with WL assembly to 10,702'. Pressure test annulus line to 3000 psi. Pressure up to 3000 psi & shut well in. at 12:00 hrs. At 12:30 hrs. pressure = 500 psi. RIH with SL assembly. Operations secured until 6/15/02. Operations secured. RIH with 1.866 gauge ring to 1 0,617'. Attempt to pressure tbg to 1500 psi. Did not have direct communication with annulus. POOH with plug body. RIH with leak detector. No indication of fluid movement. POOH with leak detector. RD SL unit & secured well. Shut down operations. Pre rig SL work suspended. Operations secured. Operations secured. Operations secured. Began RU Nabors Rig 129. Completed RU Nabors Rig 129. RU Nabors Rig 129. Rig accepted @ 12:00 hrs. 6/21/02. Open csg & well to 600 psi. Circ & kill well with 11.0 ppg CaCI2. Bleed pressure to 0 psi & observed well 1/2 hr. Well dead. ND tree. Began NU BOP. Completed NU BOPs. Tested BOPs to 250/3000 psi. Prep for tbg cut. Prep to pull & LD 2-3/8". LD 2 3/8" tbg. 105 lts. Recovered. 3294' total recovery. RIH with 1- 13/16" jet cutter to TOF @3305'. Cut tbg in middle of It. @ 7,028'. Logged cut. POOH & RD WL unit. GIH with 27/8" DP to 1050'. Tagged TOF @ 3315'. No fish engaged. POOH. Fishing. POOH with fish. Recovered 117 lts. + cut It. + 6 GLM a total of 3717' 2-3/8" tbg today. Estimated TOF @ 7012'. GIH. RIH to 7000'. Spotted balanced abandonment plug. Pumped 12 bbls 15.8 ppg cement ETOC 6483'. POOH to 6346' & reversed clean. Ran GR/CNL/CCI correlation log from 6340' to 5600'. POOH. RIH & tagged cement @ 6631'. Set down 12k. POOH. RIH with WL & set bridge plug @ 6066. POOH. Pressure tested 5-1/2" csg. to 3000 psi for 10 min. 0 psi bleed off... Abandonment completed at midnight 6/27/02. Final report for abandonment operations. Well renamed KGSF #2. Switched to Redrill AFE No. 155539 @ midnight 6/27/02. .) KGSF #2 formerly SRU 12-Lf Date 6/28/02 6/29/02 6/30/02 7/1/02 7/2/02 7/3/02 7/4/02 7/5/02 7/6/02 7/7/02 7/8/02 7/9/02 7/10/02 7/11/02 7/12/02 7/13/02 Daily Report of Redrill Well Operations KGSF #2 formerly SRU 12-27 Redrill to convert to a Gas Storage Well AFE #155539 Summary PU stack. Changed tbg head spool. NU stack. Tested BOPs to 2500/3000 psi. RlH with whipstock to 6022'. RlH with gyro. Tagged bridge plug @ 6064'. Set whipstock. Added 11 pg CaC 12 brine to mud during whipstock operation. Changed over to OBM. Milled window through 5-1/2" csg & 9-5/8' csg from 6045' to 6057'. Milled open hole 6057' to 6070'. Performed FIT to 2000 psi. EMW = 15.3 ppg. Top of window 6045'. Bottom of window 6057' . POOH with window milling assembly. RlH with 4-5/8" bit & angle-build BHA. Orient TF & drilled with bit # 1 from 6070' to 6119'. Continue drilling build section with gyro from 6073' to 6159'. CBU & surveyed. Directionally drilled with MWD 6159' to 6290'. MWD surveyed @ 6069' 4.98 degrees. MWD surveyed @ 6081' 9.14 degrees/1 00' build rate. Bit # 1 from 6070' to 6290'. Continue drilling build section. Trip for bit #2. Drilled & surveyed to 6309' @ 24:00 hrs. Drilled & surveyed from 6309' to 6395'. Trip for bit #3. Bit #2 from 6290' to 6370'. Slide from 6395' to 6462'. Drill, slide & surveyed 6462' to 6866'. Drill & surveyed 6866 to 6915. Bit #3 6370' to 6915'. POOH. POOH. Ran 2-7/8" tbg through window & into open hole. Tbg stuck after coming off slips @ 6669'. Formation holding @ 1200 psi. Unable to circ. Regained ciTC with no loses. Pipe not free. RlH with 1-11/16" freepoint tool & take freepoint reading, RIH with SL unit. Ran freepoint to 6287'. POOH. RlH with chemical cutter & made cut @ 5888'. POOH with cut offtbg. Prep to fish. Multiple attempts with various overshots. Unsuccessful in engaging fish. Ran LIB. Noticed scaring on tool. Worked tools several times. Tagged at 5883'. Prep for back off. Ran string shoot. Recovered cut Jt. & full Jt. Pin up TOF @ 5945'. Tested BPOs & surface equip. to 2500/3000 psi. RlH with OS assembly & 9 Jts. 2-7/8" tbg to 882'. RIH with OS & 5- 1/2" liner hanger on 2-7/8" DP to 4494'. Cant with OS operations to TOF @ 5937'. POOH. RIH with 2-7/8" completion assembly. RIH with 2-7/8" production tbg to 4919' using bleeder plug. RlH tagged top of liner @ 5055'. Land tbg hanger. SET BPV & ND BOPs. NU tree & tested to 5000 psi. 2 ", ) KGSF #2 formerly SRU 12-L7 7/14/02 7/15/02 7/16/02 7/17/02 7/18/02 7/19/02 LD derrick & tie up lines. Finished RD & MO Nabors Rig #129. Prep for CTU to perforate & cement 2-7/8" pipe. RU CTU. RIH with OBM taking weight checks every 1000'. Light tagged wiper plug fish @ 5057' & started pumping @ .7BPM pushing plug downhole. Problems pushing plug downhole. Tagged @ 6391'. Unable to work past. POOH. Break offBHA & break down lubricator. Install night cap. RIH with perf gun assembly. Attempted to perforate 6328' to 6333' CTM. Gun would not fire. POOH. Made second attempt & perforated 6328' to 6333' CTM. RIH with 2-7/8" & set same at 6250' CTM. POOH. RIH with stinger & found retainer had fallen downhole to 6330'. Monitored pressure on 1-3/4" CT x 2-7/8" annulus & broke circulation up 2-7/8" x 5-1/2" annulus. Prep for cement job. Pumped 10 bbls 8.3 ppg chemwash + 10 bbll0.5 ppb mud push + 15 bbl cement + 2 bbl water. Began displacing cement with OBM. Circulated 14 bbls of cement into 2-7/8" x 5-1/2" annulus with full returns at surface. POOH. RIH with PX plus to set 2-7/8" packer. Set down in OBM @ 1281'. No further progress. POOH. Decision made to cease operations on 7/19/02. Well shut in. Final report for Well KGSF #2 until additional work authorized. 3 ) UNOCAL8 RKB=191' AMSL . . . . :¡¡¡Z ¿ ~¡~¡~ t . . . . . CIBP for Whipstock 6066' MD ) Swanson River Unit WeD SRU 12-27 Final Abandonment 6/28/02 CASING DETAIL SIZE WT 13 3/8" 54.5 9-518" 40 5-112" 20 & 17 GRADE J-55 N-80 N-80 TOP BOTTOM 0' 2943" 2736' 7228' 0' 11,492' TUBING & TAIL PIPE DETAIL: 2-3/8" 4.7 N-80 8rd EVE. 7036' Tested to 3000 psi ~>< r '~.'s Y:z" DV tool @ 8178' Balanced 500' 15.8 ppg cement pl~~:~k :::::::::: 7,000' to 6,50~\» ~~)) Tbg cut at 7,036' H2 SQZD & isolated (wet) H4 (below top of fill & isolated) . . . . . H5 (isolated) 13. TD = 11,500' MD, 5 ~" shoe @ 11,492' MD SRU 12-27 Final Abnd Schematic. doc NO. 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Interval H2 H3 H4 H5 Depth 6066 ' 10,617' 10,650' 10,717' 10,721 ' 10,750' 10,752' 10,757' 10,780' 10,803' 10,807' 10,821 ' 10,892' 10,820' JEWELRY DETAIL Item CIBP Otis 'XA' sleeve (open) Brown HS-16-1 packer Brown HS-16-1 packer Otis'S' nipple Otis 'XA' sleeve (open) Brown HS-16-1 packer Otis'S' nipple Otis' XA' sleeve (closed) Baker Model' F' packer Cameo 'D' nipple (wi 'CA' plug set onside) E.O.T. (WLEG) CIBP (Note: 57' fish (23/8" tbg) on top ofCIBP- not shown) PERFORATION DETAIL From To Comments 10,704' 10,710' Squeezed 10,726' 10,750' 10,760' 10,790' 10,810' 10,832' isolated by closed SSD & fill isolated by 'CA' plug & fill Note: DST & block squeeze perfs are not shown in order to simplify diagram. Drawn: 09/24/02 DRAWN BY: JFB UNOCAL8 L RKB = 191' AMSL 8: LC c= «. ':-:-:-,", . .. ... . . ,',',' ,',',',',' .:-:-: ,':-:-:-:-: . . . . '.. . ~'.'.'.'.'. ',',''''''M'''''''''' . . . .. . . . . . . . . . . ~ . . . . . . . . . . . . . . . . M . .. . . . . . KGSF #2 Schematic. doc ') Swanson River Unit Kenai Gas Storage Facility #2 Actual AO 7/16/02 I 1 CASING DETAIL TOP BOTTOM 0' 2943" 2736' 6046' window 0' 6046' window ~ SIZE WT 13 3/8" 54.5 9-5/8" 40 5-1/2" 20 & 17 GRADE J-55 N-80 N-80 TUBING & LINER DETAIL: 2-7/8" 6.4 L-80 IBTC SCC (LINER UN-CEMENTED) 0' 6665' NO. 1. 2. 3. 4. 5. 6. 7. COMPLETION EQUIPMENT DETAIL Depth Item 1992' Methanol injection mandrel (ID= 2.312") 5026' Baker SAB-L3 hydraulic packer (not set) 5057' Baker HMC liner hanger w/ 7' tieback PBR 5928' Baker overshot w/ high pressure pack-off 6642' Baker landing collar & float collar 6663' Baker float shoe 5034' Baker 'X' nipple 2.31" ID .2 7 . ~~+-- Calculated top of cement @ 5364' ]4:;r1¡1¡ .:Iv¡' W~ndow @6046'MD / 60~' VD (LOT result: could not pump in w/ 2000 ..................... pSi on top of9.0 ppg aBM 15.3 ppg E.M.W.) ')< :/) Top of 62-5 reservoir at 6330' MD / 6238' VD <L.// Wiper plug fish pushed to 6391' (890 incl.) w/ CTU & hung up. ..... " ...11, / \ / : H 2- 7 /8" liner un-cemented at 6665' MD < >: (top of float equipment at 6642' MD) TD = 6915' MD / 6248' VD Drawn: 09/24/02 DRAWN BY: JFB -, -, -, -: _! - ~ .-, -, ...., -¡ -, -; _I -, _I _I _I _I KG SF #2 SchlumlJel'gør UNOCALI> Survey Report - Geodetic Report Date: 19-Jul-2002 Survey / DLS Computation Method: Minimum Curvature I Lubinski Client: Unocal Vertical Section Azimuth: 68.300° Field: Swanson River Unit Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: Swanson River I SRU 12-27 TVD Reference Datum: KB Well: 12-27 TVD Reference Elevation: 192.500 ft relative to MSL Borehole: KGSF #2 Sea Bed I Ground Level Elevation: 170.000 ft relative to MSL UWI/API#: 501331015201 Magnetic Declination: +20.789° Survey Name I Date: KGSF #2/ July 8..2002 Total Field Strength: 55469.769 nT Tort I AHD I 0011 ERD ratio: 129.509° /890.61 ft /5.106/ 0.14~ Magnetic Dip: 73.587° Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: June 30, 2002 Location Lat/Long: N 60 4529.084, W 15050 40.04C Magnetic Declination Model: BGGM 2002 Location Grid N/E Y/X: N 2469986.400 ftUS, E 348967.600 ftUS North Reference: True North Grid Convergence Angle: -0.73685496° Total Corr Mag North -> True North: +20.789° Grid Scale Factor: 0.99992596 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station 10 MD Incl Azim TVD VSec N/-S E/-W I DLS Northing I Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (01100ft) (ftUS) (ftUS) Surface 0.00 0.00 0.00 0.00 0.00 0.00 0.00 2469986.40 348967.60 N 60 45 29.084 W 150 50 40.040 1.50 0.00 0.00 1.50 0.00 0.00 0.00 0.00 2469986.40 348967.60 N 60 45 29.084 W 150 50 40.040 121.50 0.50 92.00 121'.50 0.48 -0.02 .0.52 0.42 2469986.38 348968.12 N 60 45 29.084 W 150 50 40.029 225.50 0.17 250.00 225.50 0.74 -0.09 0.83 0.64 2469986.30 348968.43 N 60 45 29.084 W 150 50 40.023 341.50 0.25 260.00 341.50 0.32 -0.19 0.42 0.08 2469986.20 348968.02 N 60 45 29.083 W 150 50 40.031 467.50 0.25 252.00 467.50 -0.22 -0.32 -0.11 0.03 2469986.08 348967.48 N 60 45 29.081 W 150 50 40.042 601.50 0.33 272.00 601.49 -0.87 -0.40 -0.77 0.10 2469986.01 348966.82 N 604529.081 W 150 50 40.055 726.50 0.08 280.00 726.49 -1.27 -0.37 -1.22 0.20 2469986.04 348966.37 N 60 45 29.081 W 150 50 40.064 849.50 0.33 242.00 849.49 -1.70 -0.52 -1.62 0.22 2469985.90 348965.98 N 604529.079 W 150 50 40.072 971.50 0.08 110.00 971.49 -1.98 -0.72 -1.85 0.32 2469985.71 348965.74 N 604529.077 W 150 50 40.077 -~ 1091.50 0.08 270.00 1091.49 -2.00 -0.75 -1.85 0.13 2469985.68 348965.74 N 60 45 29.077 W 150 5040.077 1225.50 0.33 261.00 1225.49 -2.46 -0.81 -2.33 0.19 2469985.62 348965.26 N 604529.076 W 150 50 40.086 1345.50 0.25 162.00 1345.49 -2.81 -1.11 -2.59 0.37 2469985.32 348965.00 N 604529.074 W 1505040.092 1592.50 0.17 155.00 1592.49 -2.83 -1.95 -2.27 0.03 2469984.48 348965.31 N 604529.065 W 150 50 40.085 1715.50 0.25 236.00 1715.49 -3.08 -2.27 -2.41 0.23 2469984.16 348965.16 N 604529.062 W 150 50 40.088 1858.50 0.17 243.00 1858.49 -3.60 -2.54 -2.86 0.06 2469983.90 348964.71 N 60 45 29.059 W 150 50 40.097 1965.50 0.33 180.00 1965.49 -3.87 -2.92 -3.00 0.28 2469983.52 348964.56 N 604529.056 W 150 50 40.100 2090.50 0.08 68.00 2090.48 -3.91 -3.25 -2.92 0.29 2469983.19 348964.64 N 604529.052 W 150 50 40.098 KGSF #2 ASP Final Survey.xls Page 1 of 3 7/19/2002-11 :45 AM -. - -¡ -¡ _I ..! .-; ...' ...: ..., .. ~i ...: .., ..! "i ..! Grid Coordinates Geographic Coordinates Station ID MD I Incl Azim TVD VSec NI.S I E/.W I DLS Northing I ElIding latituda I !...ongitude (ft) (°) (°) (ft) (ft) (ft) (ft) (01100ft) (ftUS) (ftUS) 2245.50 0.33 0.00 2245.48 -3.64 -2.76 -2.82 0.20 2469983.68 348964.74 N 60 45 29.057 W 150 50 4C 2340.50 0.33 355.00 2340.48 -3.46 -2.21 -2.84 0.03 2469984.22 348964.73 N 604529.063 W 150 50 4C 2466.50 0.17 313.00 2466.48 -3.44 -1.73 -3.01 0.19 2469984.71 348964.57 N 60 45 29.067 W 150 50 4C 2586.50 0.25 140.00 2586.48 -3.43 -1.80 -2.97 0.35 2469984.63 348964.60 N 60 45 29.067 W 150504(, 2715.50 0.17 275.00 2715.48 -3.51 -2.00 -2.98 0.30 2469984.44 348964.59 N 60 45 29.065 W 150 50 40 2841.50 0.08 220.00 2841.48 -3.76 -2.05 -3.23 0.11 2469984.39 348964.35 N 60 45 29.064 W 150 5040 3001.50 0.25 110.00 3001.48 -3.60 -2.26 -2.97 0.18 2469984.18 348964.60 N 60 45 29.062 W 150 50 40 3151.50 0.00 0.00 3151.48 -3.35 -2.37 -2.66 0.17 2469984.06 348964.91 N 604529.061 W 150 50 40 3370.50 0.50 270.00 3370.48 -4.24 -2.37 -3.62 0.23 2469984.08 348963.95 N 60 45 29.061 W 150 50 40 3434.50 2.75 63.00 3434.45 -2.97 -1.67 -2.53 5.01 2469984.76 348965.05 N 60 45 29.068 W 150 50 40 3486.50 4.00 51.00 3486.36 0.00 0.03 -0.01 2.75 2469986.43 348967.59 N 60 45 29.085 W 150 50 40 3790.50 4.50 47.00 3789.53 21.24 14.84 16.95 0.19 2470001.02 348984.74 N 60 45 29.231 W 150 50 39 3982.50 4.25 53.00 3980.97 35.12 24.26 28.14 0.27 2470010.29 348996.05 N 60 4529.323 W 150 5039. 4108.50 4.25 52.00 4106.62 44.10 29.94 35.55 0.06 2470015.88 349003.53 N 60 45 29.379 W 150 50 39. 4181.50 4.25 52.00 4179.42 49.30 33.27 39.82 0.00 2470019.16 349007.84 N 60 45 29.412 W 150 5039. 4380.50 3.75 55.00 4377.94 62.71 41.55 50.96 0.27 2470027.28 349019.08 N 60 45 29.494 W 150 50 39. 4549.50 3.75 63.00 4546.58 73.59 47.22 60.41 0.31 2470032.84 349028.61 N 60 45 29.549 W 150 50 38. 4623.50 3.75 60.00 4620.42 78.39 49.53 64.66 0.27 2470035.09 349032.89 N 60 45 29.572 W 150 50 38. 4786.50 3.00 67.00 4783.13 87.93 53.86 73.20 0.52 2470039.32 349041.48 N 60 45 29.615 W 150 50 38. 5006.50 2.00 74.00 5002.92 97.51 57.17 82.19 0.47 2470042.51 349050.51 N 60 45 29.647 W 150 50 38. 5614.00 0.94 94.55 5610.22 112.52 59.70 97.35 0.19 2470044.84 349065.70 N 60 45 29.672 W 150 50 38.' 5969.00 0.89 83.77 5965.17 117.79 59.77 102.99 0.05 2470044.83 349071.35 N 604529.673 W 150 50 37.' 6013.00 0.87 95.60 6009.17 118.42 59.77 103.67 0.41 2470044.83 349072.02 N 604529.673 W 150 50 37.~ 6032.00 0.87 116.69 6028.17 118.64 59.69 103.94 1.68 2470044.75 349072.29 N 60 45 29.672 W 150 50 37.~ 6045.00 1.55 148.05 6041. 16 118.74 59.50 104.12 7.12 2470044.55 349072.47 N 60 45 29.670 W 150 50 37.~ 6051.00 1.86 162.53 6047.16 118.75 59.34 104.19 8.81 2470044.39 349072.54 N 6045 29.669W 150 50 37.~ 6057.00 2.80 168.61 6053.16 118.71 59.10 104.25 16.18 2470044.15 349072.59 N 604529.666 W 150 50 37.~ 6064.00 3.89 175.70 6060.14 118.61 58.70 104.30 16.63 2470043.75 349072.64 N 60 45 29.662 W 150 50 37.~ 6069.01 4.98 177.36 6065.14 118.49 58.31 104.32 21.91 2470043.36 349072.66 N 604529.659 W 150 50 37.£ 6081.53 9.14 181.50 6077.56 117.92 56.77 104.32 33.45 2470041.82 349072.64 N 60 45 29.643 W 150 50 37.~ 6090.00 11.95 184.30 6085.89 117.27 55.23 104.24 33.71 2470040.28 349072.53 N 60 45 29.628 W 150 50 37.~ 6100.21 15.31 187.67 6095.81 116.15 52.83 103.98 33.80 2470037.89 349072.24 N 60 4529.605 W 150 50 37.£ 6111.50 18.50 191.41 6106.61 114.44 49.60 103.43 29.84 2470034.66 349071.65 N 60 45 29.573 W 150 50 37.9 6120.39 21.66 194.35 6114.96 112.70 46.63 102.74 37.30 2470031.70 349070.92 N 60 45 29.544 W 150 50 37.9 6132.23 24.50 198.26 6125.85 109.84 42.18 101.43 27.25 2470027.27 349069.56 N 60 45 29.500 W 150 50 37.9 KGSF #2 ASP Final Survey.xls Page 2 of 3 7/19/2002-11:45 AM - - - -' - - - .. .. ... .. .. .. .. ...' .. .. .. .-. Grid Coordinates Geographic Coordinates Station ID MD I Incl 1 Azim.1 TVD 1 VSec I N/.S 1 EI-W I DLS Northing Easting latitude J Longitudê (ft) (°) (°) (It) (ft) (ft) (ft) r1100ft) (nus) (ftUS) 6143.70 27.67 201.35 6136.15 106.49 37.44 99.72 30.06 2470022.55 349067.78 N 60 45 29.453 W 150 50 38.033 6158.71 32.28 203.65 6149.15 101.26 30.52 96.84 31;65 2470015.67 349064.81 N 60 45 29.385 W 150 50 38.091 6168.00 34.94 204.37 6156.89 97.58 25.82 94.74 28.95 2470011.00 349062.66 N 60 45 29.339 W 150 5038.133 6177.09 37.75 205.78 6164.21 93.65 20.94 92.46 32.25 2470006.15 349060.31 N 60 45 29.291 W 150 50 38.179 6190.71 41.47 206.08 6174.70 87.23 13.14 88.66 27.35 2469998.39 349056.42 N 60 45 29.214 W 150 5038.255 6209.42 46.80 204.33 6188.12 77.73 1.35 83.12 29.22 2469986.68 349050.73 N 60 45 29.098 W 150 5038.367 6221.90 50.35 203.28 6196.38 71.06 -7.21 79.35 29.13 2469978.17 349046.84 N 60 45 29.013 W 150 50 38.443 6237.00 54.49 202.30 6205.59 62.68 -18.24 74.72 27.90 2469967.20 349042.07 N 60 45 28.905 W 150 50 38.536 6253.16 59.67 201.83 6214.36 53.30 -30.81 69.63 32.15 2469954.70 349036.82 N 60 45 28.781 W 150 50 38.638 6264.50 63.50 202.15 6219.76 46.41 -40.06 65.89 33.86 2469945.50 349032.97 N 60 4528.690 W 150 50 38.713 ~ 6272.36 66.28 202.48 6223.10 41.47 -46.64 63.19 35.57 2469938.95 349030.18 N 60 45 28.625 W 150 50 38.768 6290.00 71.27 204.00 6229.48 29.85 -61.74 56.70 29.40 2469923.94 349023.50 N 604528.476 W 150 50 38.898 6304.01 75.53 204.18 6233.48 20.23 -74.00 51.22 30.43 2469911.75 349017.86 N 604528.356 W 150 50 39.009 6333.62 83.12 208.40 6238.96 -1.38 -100.05 38.33 29.20 2469885.87 349004.64 N 60 45 28.099 W 150 50 39.268 6344.64 85.71 210.30 6240.04 -9.91 -109.61 32.96 29.10 2469876.38 348999.14 N 604528.005 W 150 50 39.376 6364.19 89.04 214.72 6240.93 -25.74 -126.08 22.47 28.29 2469860.06 348988.44 N 604527.843 W 150 50 39.587 6396.79 88.73 218.26 6241.57 -53.44 -152.28 3.09 10.90 2469834.11 348968.73 N 604527.585 W 150 50 39.977 6427.75 88.70 224.69 6242.26 -81.04 -175.45 -17.40 20.76 2469811.20 348947.94 N 60 45 27.357 W 150 5040.390 6458.59 89.14 225.03 6242.84 -109.33 -197.31 -39.15 1.80 2469789.62 348925.92 N 60 45 27.141 W 150 50 40.828 6489.67 89.04 225.70 6243.34 -137.95 -219.14 -61.27 2.18 2469768.08 348903.52 N 60 45 26.926 W 150 50 41.273 6520.96 88.90 225.89 6243.90 -166.86 -240.96 -83.69 0.75 2469746.56 348880.82 N 604526.712 W 150 50 41.724 6552.09 88.59 225.79 6244.58 -195.62 -262.64 -106.02 1.05 2469725.17 348858.22 N 604526.498 W 150 50 42.173 6583.51 88.66 225.62 6245.34 -224.62 -284.57 -128.50 0.59 2469703.52 348835.46 N 60 45 26.282 W 150 50 42.626 6615.19 88.45 225.43 6246.13 -253.82 -306.76 -151.10 0.89 2469681.63 348812.58 N 60 45 26.064 W 150 50 43.081 6645.88 88.66 224.68 6246.91 -282.01 -328.44 -172.82 2.54 2469660.24 348790.59 N 60 45 25.850 W 150 50 43.518 6676.92 90.31 224.69 6247.19 -31 0.45 -350.50 -194.64 5.32 2469638.46 348768.48 N 60 45 25.633 W 150 50 43.957 6707.78 90.27 224.52 6247.03 -338.70 -372.47 -216.31 0.57 2469616.77 348746.53 N 60 45 25.416 W 150 50 44.393 ~ 6739.26 89.85 224.36 6247.00 -367.49 -394.95 -238.35 1.43 2469594.58 348724.21 N 60 45 25.195 W 150 50 44.837 6770.16 90.07 224.24 6247.02 -395.72 -417.06 -259.93 0.81 2469572.74 348702.34 N 60 4524.977 W 150 50 45.271 6801.36 90.17 224.09 6246.95 -424.19 -439.45 -281.67 0.58 2469550.65 348680.32 N 60 45 24.757 W 150 50 45.708 6832.64 89.93 224.59 6246.93 -452.78 -461.82 -303.53 1.77 2469528.56 348658.18 N 60 45 24.537 W 150 50 46.148 6874.43 89.45 224.71 6247.15 -491. OS .. -491.55 -332..90 1.18 2469499.21 348628.43 N 60 45 24.244 W 150 50 46.739 6912.00 89.00 224.80 6247.66 -525.50 -518.22 -359.35 1.22 2469472.88 348601.64 N 604523.981 W 150 50 47.272 KGSF #2 ASP Final Survey.xls Page 3 of 3 7/19/2002-11:45 AM . 8; ~::ì ~U) o~ ~ ~ 6000- II ~ c ro ;~ .........0 .c~ ; 15. ~ ' . I - ~S =======Þ~=====t===========================~======~=== CC6150- i ~....--...-I . - I (ij ~ i ! , 0 ! I 1:: iri I KGSF #2: , ~~ ~~~~~~~~~~~==~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~3~~~ ~ Æ i ! 0 :) .= Wi; KGSF #2 (P6) 6300 -----___.__a____- --i.---- '--_u_---.-.-- - (--- -- - .- _u_------------ I 12-27 with GYR¿ whipstock survey ! I ¡ ! i I 0 . . . ..--~ ... . . . . .¡ ~.-~- - UNOCAL8 VERTICAL SECTION VIEW Client: Unocal Well: Field: KGSF #2 Swanson River Unit Structure: Swanson River Section At: 68.30 deg Date: July 19, 2002 5700 ---------.--- --------.1---- I i 5850 - ~ 6450 300 I -150 I -600 I -300 I -450 150 Vertical Section Departure at 68.30 deg from (0.0, 0.0). (1 in = 150 feet) .ì.i .¡'.: Schlumberuell ~ I -750 -.; _,I _:1 _if _I _1 _if - _ti -¡ -, -¡ _ü - PLAN VIEW Client: Well : Unocal KGSF #2 ~.~~ . UNOCALI> 200 ---. ^ ^ ^ I l- e::: 0 z -200- I I- -400-. ::> 0 C/) v v v 0- Field: Structure: Swanson River Unit Swanson River Scale: .Date:. 1 in = 200 ft 19-Jul:20~2 -800 , I I -400 -200 0 200 . -600 , i I True North Mag Dee ( E 20.79° ) ~I 400 I -., -'1 ..¡ -,,¡ .~; '. SchlumbDPoep 12-27 with GYRO whipstock survey i j In I I -600 -,-------,'.--.-.-______d___-_'----'--'----'---------'-------------.---------...-.---.--------.-"'--------""..------ KGSF #2 -800 -600 -400 -200 «< WEST I 0 I 200 EAST »> "-----._---_."-_U ----... ~.._._-- ~ I 400 ! - -_.__.._.~m_. - I I I j 600 600 , i I -200 .~ -0 - -200 - -400 ~' --600 Anchorage, AK 99501 Tele: (907) 263-7651 Fax: (907) 263-7828 E-mail: hamsonb@unoca1.com UNOCAL Beverly Harrison Business Ventures Assistant To: AOGCC Lisa Weerie , 333 W. 7t Ave. Ste#100 Anchorage, AK 99501 September 23, 2002 . A-29RD A-29RD A-29RD , A-29RD A-29RD A-29RD A-29RD ~ A-29RD B A-29RD \ A-29RD ~! A-29RD '{j I. A-29RD ! A-29RD ! A-29RD ¡ ¡ A-29RD ! l A-29RD ! A-29RD ¡ I A-29RD -- I A-29RD ~ irQ.oosl D-15RD2 -- ! D-15RD2 I DI-15 1_lp-Ot/5! DI-15 ~;os11 DI-16 \ 0\- ~ DI-16 c.f) I G-12RD3 r.n I G-12RD3 '» ¡ G-12RD3 'Õ 0 CO DATA TRANSMITTAL - . ADN DIP DATA v" ADNDIPDATA V ADN DIP DATA V ADN DIP DATA v CEMENT BOND LOG I GR I CCL V CEMENTBONDLOG/GR/CCL ~ CEMENT BOND lOG I GR / CCl v CEMENT RETAINER CASING PUNCHER V . CEMENT RETAINER CASING PUNCHER t/ EPOCH FINAL WEll REPORT WI FORMATION LOG ./ EPOCH FINAL WELL REPORT WI FORMATION LOG V EPOCH FINAL WELL REPORT WI FORMATION LOG ý MWD/GR MD COMPOSITE FIELD PRINT V PERFORATION DEPTH CONTROL MEMORY GR I CCL V PERFORATION DEPTH CONTROL MEMORY GR I CCL V PERFORATION RECORD 2 7/8" PJ HSD 6 SPFV PERFORATION RECORD 2 7/8" PJ HSD 6 SPF v SCHLUMBERGER FORMATION EVALUATION LOGS V VISION SERVICE MD COMPOSITE FIELD PRINT V PL ADVISOR I INJECTION PROFILE MEMORY PLT WIFLOVIEW v PL ADVISOR I INJECTION PROFILE MEMORY PL T W/FLOVIEW v COMPLETION RECORD 2" HSD, POWER JETS v COMPLETION RECORD 2" HSD, POWER JETS V' COMPLETION RECORD 2" HSD, POWER JETS ¡/ COMPLETION RECORD 2" HSD. POWER JETS v COMPLETION RECORD 10' CEMENT PLUG v COMPLETION RECORD 10' CEMENT PLUG v' COMPLETION RECORD 2.5" HSD PJ V 2/5 INCH 2/5 INCH 2/5 INCH 5 INCH 5 INCH 2 INCH 2 INCH 2 INCH 2 INCH 5 INCH 5 INCH 2 INCH 5 INCH SINCH 5 INCH 5 INCH 5 INCH 5 INCH 5 INCH 5 INCH 5 INCH 8/2/2002 8/2/2002 8/2/2002 8/2/2002 8/5/2002 8/5/2002 8/5/2002 6/30/2002 8/1/2002 8/1/2002 6/30/2002 8/10/2002 8/10/2002 8/28/2002 8/28/2002 8/212002 6/30/2002 3/17/2002 3/17/2002 5/11/2002 5/11/2002 5/912002 5/9/2002 6/29/2002 6/29/2002 6/21/2002 12606-13220 11950-12650 12606-13220 12029-12713 5000-13211 5000-13211 5000-13211 1680-1999 1680-1999 1786-13300 1824-12685 12720-13240 12720-13240 13100-13207 13100-13207 1824-13300 9150-10050 9150-10050 11950-12555 11950-12555 9800-1077 9800-1077 13150-13608 13150-13608 13100-13696 1 B-Line 1 B-Line 1 CD 1 CD 1 B-Line 1 CD 1 Film 1 . B-Line 1 Film 3 B-Line 1 CD 1 PAPER 1 B-Line 1 B-Line 1 Film 1 B-Line 1 Film 1 CD 1 B-Line 1 B-Line f ¥ I 1 CD 1 B-Line 1 Film 1 B-Line i ¡ 1 Film ! 1 B-Line ! 1 Film i 1 B..\.ine Please acknowledge receipt by signing and returning one copy of this transmittal or iAXm. ð~3~-t!?~.--. rl~ E~ '¿ . ~~- ~ ~ Received ~(~ Date: Ocr 0;) 2002 Alaska Oi: &. Gas Gor " t\- mmiH' 'J, v¡J i ~ ,.......iOil AnchoragfJ G-12RD3 G-12RD3 K-30RD K-30RD LRU C-1RD LRU C-1RD - .~D'O~ \ ~~ \0 NNA-1 ¡:; NNA-1 ~ NNA-1 Q ~ NNA-1 PEARL-1 PEARL-1 PEARL-1 PEARL-1 ::::: PEARL-1 0 PEARL-1 I (t) PEARL-1 CJ PEARL-1 '1S PEARL-1 PEARL-1 SRU 12-15 Od-do SRU 12-15 ,0Y' SRU 12-15 SRU 12-27 SRU 12-27 SRU 12-27 SRU 12-27 SRU 212- 27 SRU 212- 27 ~ SRU 213- 10 SRU 213- 10 SRU 213- 10 SRU 213- \)0 10 - SRU 213- ~ 10 rCJ S10RU 213- COMPENSATED NEUTRON LOG IN CASING v Q SRU213- ((j 1 0 SLlMPULSE / GR / MD / FIELD PRINT / SRU 213- 10 SLlMPULSE I GR I VD / FIELD PRINT v' SRU 23 33 111/16 ENERJET GUN COMPLETION REPORT V \ (01 ,0/9 - r() 0 ~ 1D~cP1 , - f\ /\ P '\)~ ~# \ -. \LJ , "-.>IVL..I I Lv", 1..1 VL..IVIL..I'II I ¡ b INCH COMPLETION RECORD POSISET PLUG 15' CEMENT ../ I 51NCH COMPLETION RECORD POSISET PLUG 15' CEMENT vi I 51NCH PERFORATING DEPTH CONTROL MEMORY GR / CCL v ! 5 INCH PERFORATING DEPTH CONTROL MEMORY GR / CCL v" ¡ 5 INCH COMPLETION REPORT 2" HSD POWER JETS v I 5 INCH COMPLETION REPORT 2" HSD POWER JETS v ! 5 INCH EPOCH MUD LOG V 2 INCH EPOCH MUD LOG ./ 2 INCH COMPLETION RECORD 2" HSD POWER JET V ' 5 INCH COMPLETION RECORD 2" HSD POWER JET V 5 INCH GR I CCL CORRELATION FLUID LEVEL DETERMINATION ¡/' 5 INCH GR / CCL CORRELATION FLUID LEVEL DETERMINATION /' 5 INCH COMPLETION RECORD 2" PJ HSD, 6 SPF V 5 INCH COMPLETION RECORD 2" PJ HSD, 6 SPF V" 5 INCH COMPLETION RECORD 2" PJ HSD, 6 SPF y/ 5 INCH COMPLETION RECORD 2" PJ HSD, 6 SPF V 5 INCH GR / CCL I PRESSURE / TEMPERATURE / TOP OF FLUID DETERMINATION V 5 INCH GR / CCL I PRESSURE I TEMPERATURE I TOP OF FLUID DETERMINATION ",.-' 5 INCH GR / CCl I TEMPERATURE / PRESSURE / TOP OF FLUID, SAMPLE.V"" 5 INCH GR / CCL I TEMPERATURE I PRESSURE / TOP OF FLUID, SAMPLE ~ 5 INCH GR / CCL TEMPERATURE, PRESSURE TOP OF FLUID, SAMPLE V 5 INCH GR / CCL TEMPERATURE, PRESSURE TOP OF FLUID, SAMPLE V ' 5 INCH COMPLETION RECORD 111/16" POWER PIVOT V' 5 INCH COMPLETION RECORD 111/16" POWER PIVOT v' 5 INCH COMPLETION RECORD POSISET PLUG 20' CEMENT PLUG / 5 INCH CEMENT RETAINER CPST SETTING TOOL ,./ 5 INCH MD FIELD PRINT""" 2/5 INCH NEUTRON / GR / CCL V" . 2/5 INCH NEUTRON/GR/CCL ~ ! 2/5 INCH 5.5" THRU-TUBING POSISET PLUG CEMENT DUMPT BAILER 25' CEMENT PLUG'" 5 INCH 5.5" THRU-TUBING POSISET PLUG CEMENT DUMPT BAILER 25' CEMENT PLUG .Y5INCH 2" HSD POWER JET 6 SPF COMPLETION RECORD v ¡ ì 51NCH I ¡ ¡ 51NCH 6/27/2002 I 13150-13670 ! 6/27/2002 i 13150-13670 6/27/2002 13150-13670 2/8/2002 I 9544-12045 2/8/2002 9544-12045 7/15/2002 5300-5975 7/15/2002 5300-5975 10/31/1999 . 1473-6430 10/31/1999 . 1473-6430 4/3/2002 8600-9750 4/3/2002 8600-9750 4/2/2002 8600-9790 4/2/2002 8600-9790 3/29/2002 5420-6066 3/29/2002 3690-4250 3/29/2002 5420-6066 3/29/2002 3690-4250 3/28/2002 3550-6954 3/28/2002 3550-6954 3/29/2002 3550-6607 3/29/2002 3550-6607 3/29/2002 100-6948 3/29/2002 100-6948 5/16/2002 5400-5600 5/16/2002 5400-5600 3/13/2002 4600-5642 6/27/2002 5600-6346 6/29/2002 6044-6912 6/26/2002 5600-6340 6/26/2002 5600-6340 8/20/2002 6025-6050 8/20/2002 6025-6050 8/4/2002 3800-4000 i 7/24/2002 I 1987-4105 7/24/2002 1987-4105 8/1/2002 I 0-4014 ¡ 8/1/2002 ! 0-4014 i 7/24/2002 ! 1987-4105 ! 7/18/2002 I 1952-4105 ! 7/18/2002 11952-4105 5/19/2002 110350-10625 1 B-Line 1 CD 1 Film 1 B-Line 1 Film 1 B-Line 1 Film 1 B-Line 1 Vellum 1 B-Line 1 Film 1 B-Line 1 Film 1 B-Line 1 B-Line 1 Film 1 Film 1 B-Line 1 Film 1 B-Line 1 Film 1 B-Line 1 Film 1 B-Line 1 Film 1 B-Line 1 B-Line 1 B-Line 1 B-Line 1 CD B-Line CD B-Line B-Line CD B-Line CD B-Line 2 B-Line 2 B-Line 1 B-Line Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. Rl-=;CEI \IE: ARRAY INDUCTION / DENSITY I CNL I GR / SP / CALIPER / PEX .,,-- ARRAY INDUCTION / DENSITY / CNL / GR / SP / CALIPER / PEX .,..,.- 5 INCH I I 5 INCH I i 51NCH ¡ ~ CEMENT BOND LOG/GR/CCL v CEMENT BOND LOG/GR/CCL v 5 INCH 2/5 INCH 2/5 INCH 5 INCH ReœiVedBY~(~_~ Date: 0, t' T (\ -:'. v ~ l) '¡..j ÞJ~t;;t\a ~.!<.; (!. vD{nr[Ú~ak;n Ancl!or8D{~ ..11.. . '-'I ~ ",UI LI.,. "". t".,UV ALb Abandon: - Suspend: - Operation shutdown: - Re-enter suspended well: - Alter casing: Repair well: Plugging: - Time extension: - Stimulate: - Change approved program: 'A Pull tubing: Variance: X Perforate: Other: 5. Type of well: 6. Datum elevation (OF or KB) Development: ~ 191' RT above MSL Exploratory: 7. Unit or Property name Stratigraphic: Service: 1. Type of Request: , 2. Name of Operator Union Oil COmpany of California (UNOCAL) 3. Address P.O. Box 196247 Anchorage, AK 99519-6247 4. Location of well at surface 1750' FNL & 1190' FWL SEC. 27, T8N, R9W, SM At top of productive interval 1750' FNL & 1190' FWL SEC. 27, T8N, R9W, SM At effective depth 1750' FNL & 1190' FWL SEC. 27, T8N, R9W, SM At tota I depth 2205' FNL & 893' FWL SEC. 27, T8N, R9W, SM 12. Present well condition summary Total depth: measured true vertical 6912' feet 6247' feet Effective depth: measured 5945' feet true vertical 5945' feet Casing Length Size Structural 30' 20" Conductor N/A N/A Surface 2943' 13-3/8" Intermediate 6045' 9-5/8" Production 6045' 5-1/2" Liner Perforation depth: measured Plugs (measured) feet Swanson River Unit 8. Well number Kenai Gas Storage Facility #2 9. Permit number ~~Ðd--\ '--~ 10. API number 50- 133-10152-01 11. Field/Pool Swanson River Field / Tyonek 62-5 Sand OR1(,~ f\L " .... I \.:1 I f-\ Junk (measured) Top of stuck 2-7/8" tubing string @ 5945' Cemented (Yes Details not recorded) N/A 2000 SX 500 SX 1350 SX No perforations true vertical No perforations Tubing (size, grade, and measured depth) 2-7/8" 6.4# N-80 BTC-IMP from' 6,669' to 5,945' (Tubing pin looking up) Packers and SSSV (type and measured depth) None 13. Attachments Description summary of proposal: x 14. Estimated date for commencing operation 7/15/02 Contact: Larry Buster @ 263-7804 16. If proposal well verbally approved: Measured depth 30' N/A 2943' 6045' (Window) 6045' (Window) True vertical depth 30' N/A 2943' 6045' 6045' RECEIVED JUL 1 2 2002 Detailed operations program: Araska OíJ & Gas Gons. Commission Anchoraae BOP sketch: Oil: 15. Status of well classification as: Gas: Suspended: - Approved by order of the Commissioner anginal SIgned By Cemmy 0ech8Ií T. Tom Maunder 7/10/02 Service: Gas Storage Injection Well 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed:.,%: f} ¡J -,;- -Ç.. \1.", /krl'IOV'" Title: Drilling Manager I~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity- BOP Test- Location clearance- Mechanical Integrity Test- Subsequent form required 10- \4 O~ Date: 7/JO/o 2.. Approval No. ~ C;~-. II ~)I't' 0" <:..C~y\~\-'\ ~~ Commissioner Date 'i/¡¥;), . Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE KGFS #2 Swanson River Field Revised Procedure July 10,2002 Current Well Status: (o~. \ d - Cdo~Ç;. ':- ~'-l1> \ $ \:O~~ ~b(o~ -~~4S ~ ~d~' 'oiZ-\t)~ ~\."ù~~ Horizontal Well TD'd with 4-5/8" bit and 9.2 ppt:; vu Jasemud at 6,912' md. While running a 2-7/8" tubing string, the string became stuck at 6,669'. Attempts to free the string were unsuccessful and the tubing was chemically cut at 5,882'. Attempt to recover the tubing with a grapple and overshot were unsuccessful and the tubing top was damaged during the fishing process. The tubing was backed off with a string shot and overshot at 5,945' to give a clean fishing neck lookin~~\ ~Q~S - S~4 ~ ': \00' o.~~ \u' Note: 5-1/2" Casing window at 6,045'. Plan Forward: 1. RIH with 2-7/8" high pressure pack-off overshot assembly and HMC liner hanger. Engage tubing stub at 5,945' with high pressure overshot and grapple assembly. Establish circulation and cement ~ tubing in place and then set HMC liner hange~t +1- 5,000'. '>-..)c...~~~~\,,)\ \~ $:).~.ç- <è.~~,~cl \ ~~ ~'\-'~CL\ 'ð--k~ r~~~:r&i~¡;:;:-~g~~~~k~~~I~~~~lowcheckandPOOH. I <...b-.:.tb "'O~c:.\~",~:" ~~~'tJ ~ Q\\D""-' ">~\. C\<L~ '" 'S 3. Clean-out casing and liner tie-back assembly if required. ~<LC"\ -\- -\0 ~ ~ '<.J;4-\- C'. . RIH with tie-back seals and ~AB Produc!~o~ Pack~~ assembly on 2-7/8" BTC-IMP tubing. Ck~~(L ~\~~~ ..\:-1:> ' ~~C)"''-~\3..\ë o...~f 5. \û%<èS~ M/U and run 2-7/,8" chemical injection mandrel and 2-7/8" tubing retrievable safety valve spacing ~ them at +1- 2,000 . \.....,. ~\. \è:::. ~ ~ ~ \. \ L ~1 ~"-J \""- ""= ~\o...~ ~~~ c:....'v,t\.~~- c:.~~\J ~~'('\~~ ~ ~~ os: ",--<;:.: ~ ~$~~ 6. Land seals into liner tie-back receptacle and calculate required space-out. ~~~~,<è.. ~-\--\"'~ \~ \ ~ 7. Set SAB Production packer. Test tubing and tie-back seals to 3,000 psi. -\,~ "'\-.c. ~~~-:I ~ ~ 8. N/Utree. ~ ~~-\-~~~"~~~ ~~, ~~~-\-~,.. ~~<;.\j wCì> \~~\~~ ~O ~\'-O~ ~~, Q..~~'\ ~ ~~~ ~ -\a ~ ~f\ b'f '-.:) ':> \ ~ Ç.~,-> ~ C>..> \~~ ,\ \~ ~ c:....O-~~t. \-J....~~\~\(C 5°~~"~ ~\\\ ~~' h<1:-JJ~~ ~c;t1'vvJ RECEIVED 9. Release Rig. ,.. \:'\ 'N~\\ w\\\ ~ ~~~ G,:\~It.'\ ~ ~ ~ \\è<J.. SQ::., JUL 1 2 2002 Alaska Oil & Gas Cons. CommiSSion Anchorage ...rom: I::;j~uster, Larry W -Alaska" <Ibuster@unocal.com> To: "Tom Maunder (tom_maunder@admin.state.ak.us)" <tom_maunder@admin.state.ak.us> CC: "Bowen, Jerry -Alaska" <jbowen@unocal.com> Tom. Attached please find a 403 and summary' of proposed plan forward for the KGFS #2 Gas Storage Well. I will be sending a signed copy of the same today. «KGFS2 AGOCC Rev Prog.doc» «403KGFS_2.xls» Regards, Larry W. Buster Drilling Engineer Unoca Alaska (907) 263-7804 - Office (907) 263-78a4 - Fax (907) 351-6730 - Mob. ... I Name: KGFS2 AGOCC Rev Prog.doc ~ KGFS2 AGOCC Rev Prog.doc Type: WINWORD File (application/msword)¡ Encoding: base64 I Name: 403KGFS .2.xls ~403KGFS 2.xls Type: Microsoft Ëxcel Worksheet (application/vnd.ms-exceJ) Encoding: base64 1 of 1 7/12/2002 10:51 AM TONY KNOWLES, GOVERNOR AI4ASIiA OIL AlWD GAS CONSERVATION COMMISSION 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Jim Harrison Drilling Manager U I10cal P.O. Box 196247 Anchorage, AK 99519 Re: Kenai Gas Storage Facility (KGSF) #2 U nocal Permit No: 202-119 Surface Location: 1750' FNL, 1190' FWL, Sec 27, T8N, R9W, SM Bottomhole Location: 2205' FNL, 893' FWL, Sec 27, T8N, R9W, SM Dear Mr. Harrison: Enclosed is the approved application for permit to redrill the above referenced gas storage well. The permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. The Commission must approve and issue a storage injection order prior to start of injection operations. Unocal's request for a variance from the packer requirements of 20 AAC 25.412 (b) is granted on the condition the well achieves a successful MIT, witnessed by a representative of the Commission, and Commission review of the cement records. Please provide a cement quality log and any other relevant cementing operational records for Commission review. In order to insure that a representative of the Commission is available to witness the MIT, please provide sufficient notice to the petroleum field inspector pager number at 659-3607, or coordinate arrangements with Tom Maunder at 793-1250. The Commission will not waive the witnessing of this MIT. .L o~ ¿.. VI ¿... The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of this injection well must be demonstrated under 20 AAC 25.412 and 20AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the BOPE test prior to drilling new hole must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~~}~~) Cammy O~hsli Taylor f)' Chair BY ORDER OF THE COMMISSION DATED this~ day of June, 2002 cc: Department of Fish & Game, Habitat Section w/o encL Department of Environmental Conservation w/o encl. ~(? ') STATE OF ALASKA ) ALASKA OIL AI"l/D GAS CONSERVATION Cvt.JIIVlISSION PERMIT TO DRILL 20 AAC 25.005 1a. Type of work Drill: Re-Entry: 2. Name of Operator Union Oil of Califomia (Unocal) 3. Address P.O. Bo)( 196247 Anchorage, AK 99519 4. Location of well at surface 1750' FNL, 1190' FWL, Sec. 27, T8N, R9W, S.M. At top of productive interval 1821' FNL, 1260' FWL, Sec. 27, T8N, R9W, S.M. At total depth 2205'FNL,893'FVVL,Sec.27,T8N,R9W,S.M. 12. Distance to nearest 13. Distance to nearest well property line I 660 feet 188 16. To be completed for deviated wells Kickoff depth: 6016 ! feet 90° Maximum hole angle: 18. Casing program size Specifications Hole Casing Weight Grade Coupling Length ~~ W æ exist 133/8" 54.5 J-55 ST&C 2943' exist 95/8" 40.0 N-80 L T&C 3269' exist 5 1/2" 23.0 N-80 L T&C 6005' 4 5/8" 2 7/8" 6.4 N-80 IBTC 6859' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical measured true vertical Redrill: X 1 b. Type of well Deepen: Service: X Effective depth: 11,500' 11,492' 10,751' 10,744' Stratigraphic Test: Single Zone: X 10. Field and Pool Tyonek 62-5 Sand Exploratory: Developement Gas: 5. Datum Elevation (DF or KB) 191' KB to MSL feet 6. Property Designation A-028406 7. Unit or property Name Swanson River Unit 8. Well number Kenai Gas Storage Facility #2 - 9. Approxima~ spud date 06/20/02 14. Number of acres in property Development Oil: Multiple Zone: 11. Type Bond (see 20 AAC 25.025) Number U 62-9269 Amount $200,000 15. Proposed depth (MD and TVD) feet 800 6859 I 6250 17. Anticipated pre~sur/see 20AAC 25.035 (e)(2» Maximum surface 2544 psig At total depth (TVD) Setting Depth feet 2794 psig Top Bottom Quantity of cement MD TVD (include stage data) 30' 30' (details not recorded) 2943' 2943' 1000sx + 1000sx DV @ 1018' 6016' KOP 6016' KOP 500 sx 6016' KOP 6016' KOP 600sx + 750sx DV @ 8178' 6859' 6250' +/-22 bbls MD 0' 0' TVD 0' 0' 2736' 0' 0' 2734' 0' 0' feet feet feet feet Pluas:Blanking plug in tbg @ 10,809', definite fill in tbg below 10,751', possiblE fill in tbg above 1 0,751' Junk: Tbg stub on top of CIBP at 10,835 Casing Length Size Cemented Measured depth True vertical deptt Structural 30' 20" (yes - details not recorded) 30' 30' Conductor N/A N/A N/A N/A N/A Surface 2943' 133/8" 1000 sx + 1000 sx thru DV @ 1018' 2943' 2943' Intermediate 3,269' 95/8" 500 sx 7228' 7228' Production 11,492' 51/2" 600sx + 750 sx thru DV @ 8178' 11,492' 11,492' Liner N/A N/A N/A N/A N/A Measured: H-3: 10,726-10,750', H-4: 10,770 - 10,790', H-5: 10,810 - 10,832', H-2 (SQZD): 10,704' - 10,710 True Vertical: H-3: 10,726-10,750', H-4: 10,770 - 10,790', H-5: 10,810 - 10,832', H-2 (SOZD): 10,704' - 10,710 Tubing (size, grade, and measured depth) 23/8" 4.7#/ft N-80 EUE 8rd @ 10,820' Packers and SSSV (type and measured depth) Three (3) Brown HS-16-1 perm pkrs @ 10,650', 10,717' & 10,753' MD, Baker 'F' pkr @ 10,803'. 20. Attachments: Filing fee: X Property Plat: X BOP Sketch: X Diverter Sketch: N/A Drilling program: X Drilling fluid program: X Time vs. depth plot: Refraction analysis: Seabed report: 20 AAC 25.050 requirements: 21. 1 herby ce~~foregOing is true and correct to the best of my knowledge: Signefþ:.. /. ~ ~t ;f/f Jim Harrison Title: Drilling Manager Commission Use Only Permit Number a API number Approval date ( \t , (. I\J I See cover letter 202- - /1, 5ð -/33 -/0/52--ð/ { _J)I forotherrequirements Conditions of approval Samples ~equired: [] Yes..pq1-Jo Mud log required: :] Y.as 0 Hydrogen sulfide measures [] Yes tfNO Directional survey required ~es [] No ~~~;;e~~~¡;;~~VE J..~~'~~~t1:ï \(:)~ $ ~ \\ K r: L .. I ~ U Carom Oechsli T avtof by order of Approved by -... Y Uommissioner the Commission Date: Perforation depth: JUN 0 3 2002 For~is1ai Öff't ~ã~t%ns. COmín1sskm Anchorage Date: 5/28/2002 (J IlY þÅ 0 L Submit in triplicate NOTE TO FilE Unocal Swanson River Field Kenai Gas Storage Facility #2 (KGSF #2) PTD 202-119 Unocal has applied to sidetrack a well with Swanson River Field and re-complete it as a storage injection welf. What is different regarding their proposal is that they propose to run a continuous 2-7/8" string as the casing and tubing. They further propose not to employ a packer but to cement the lower portion of the string as a one would a casing and raise cement a minimum of 500' md above the top of their proposed window. Construction of injection wells must be according to 20 AAC 25.412 (b) that states: A well used for injection must be equipped with tubing and a packer, or with other equipment that isolates pressure to the injection interval, unless the commission approves the operator's use of alternate means to ensure that injection of fluid is limited to the injection zone. The minimum burst pressure of the tubing must exceed the maximum surface injection pressure by at least 25 percent. The packer must be placed within 200 feet measured depth above the top of the perforations, unless the Commission approves a different placement depth, as the commission considers appropriate given the thickness and depth of the confining zone. Unocal has provided further information to support their proposal. They agree that achieving the necessary isolation to confine the stored gas to the intended sand is paramount and that their design and operational plans will allow them to achieve that goal. The cementing operation proposed is not different from what would be employed if some sort of mechanical sealing device (packer) were to be subsequently employed. Isolation of the pipe to the formation would be achieved by cement regardless. Intending to lift the cement about 500' above the window is 5 times the height as specified for liner laps at 20 AAC 25.030 (c) (6). It is reasonable to expect that when set, such a column of cement will seal the 2-7/8 " tubular within the 5-1/2" casing and through the window. In the latest document, Unocal has indicated that it is their intent to complete the well operations, rig down and move the rig and allow several days to pass to provide 'WOC" (wait on cement) time for the placed cement to cure. Following the waiting time, Unocal will run a cement evaluation log {per 25.412 (d» and perform a MIT of the 2-7/8' x 5..1/2" annulus (per 25.412 (c». ) ') If the interpretation of the cement evaluation log is positive and the well successfully passes the MIT, the regulatory requirements of 25.412 should be satisfied. I recommend that the permit to drill be approved. As a condition of the approval, a cement quality log and witnessed MIT will be required. t~d?1~ AOGCC ) . ,\,.,...., 'v JV JUN U'Q ¿UUl ~, AlaSka Oil & Gas COns. Comrmsslon Anchorage UNOCAL8 Jim Harrison Drilling Manager 06/07/02 Alaska Oil and Gas Conservation Commission 333 West ¡th Avenue Anchorage, Alaska 99501 Attn: Tom Maunder, Sr. Petroleum Engineer Re: Permit To Drill Application (Form 10-401) Kenai Gas Storage Facility Well #2 Swanson River Field, Kenai Peninsula, Alaska Dear Tom; The following discussion is intended to demonstrate that Unocal has correctly evaluated the pertinent safety and environmental risks associated with the subject well design as outlined in the Application (form 10-401) for a Permit to Drill. Specifically, AOGCC Regulation 20 AAC 25.412 Section (b) requires "a packer, or with other equipment that isolates pressure to the injection interval, unless the commission approves the operator's use of alternate means to ensure that injection of fluid is limited to the injection zone". Unocal is in full agreement that injection conformance to the intended 62-5 Sand completion interval is essential to store gas without environment risk. Essentially, we envision the following two potential leak paths; (1) via a leak in the 2 7/8" casing above the cement top (or above a packer if that were planned), and/or (2) uphole from the completion interval outside the 2 7/8" casing due to poor cement bond. The 5 Y2" casing is viewed as the primary containment vessel in the event of a leak in the 2 7/8" cemented tubing. We intend to pressure test the 5 Y2" casing to 3000 psi (i.e. the maximum gas injection pressure) to make certain a shallow leak in the 2 7/8" casing will not result in pressure transmitted to the 13 3/8" surface casing and/or an uncontrolled release to the atmosphere. Unocal will conduct the initial pressure test immediately after setting the cement retainer and pumping the abandonment squeeze, before any drilling takes place. Unocal also intends to pressure test the 2 7/8" x 5 Y2" annulus to 3000 psi several days after cementing the 2 7/8" long string, once the cement has cured. Having already been tested earlier in the program, this final test will verify a cement bond exists in the 2 7/8" x 5 Y2" annulus above the window. For your information, we strongly considered the option of running a conventional packer or an inflatable packer above the window. Both packer types would increase the risk of lost returns during cement displacement, especially the larger 00 production packer. Additionally, we do not have a high level of confidence in an ECP as a long term solution. Since the distance from the completion interval to the window is short (+/-300') the likelihood of getting good cement bond above the window is high, provided we design and execute the job correctly. It is our view that setting a packer inside the 5 Y2" casing offers no greater protection than does a pressure tested column of cement. AOGCC variance letter.doc JFB ) ) We agree that running a bond log can potentially provide additional evidence of cement quality above and below the window. Per your recommendation, Unocal will run Schlumberger's 1 11/16" SCMT (slim cement mapping tool) and will provide evidence of cement between the completion interval and the casing window to the AOGCC prior to perforating. However, please note that the SCMT tool will provide qualitative rather than quantitative measurements of cement bond quality, especially when ~ low-density slurries are used and when multiple strings of pipe are involved. In order to ensure a quality cement job, Unocal and Dowell-Schlumberger are investigating ways to minimize the ECD while displacing cement above the 2 7/8" casing shoe. In addition to the basic slurry properties, the rheological properties of various slurries are being measured, and are being used to simulate the displacement process to predict ECD using Dowell's CemCade software. We are tentatively planning to utilize a 12.0 ppg LiteCrete Gas- Block slurry, but are also investigating an 11.0 ppg LiteCrete Gas-Block design to determine if it offers advantages from an ECD standpoint. At this point, we believe that we can keep the cementing ECD at or below the drilling ECD and bring cement up to a height of 500' above the window. Therfore, if we can drill the well, we should be able to cement it. We are also planning to utilize centralizers in key positions near the landing point and above the window, and will reciprocate the 2 7/8" string during displacement. Considering the above points, Unocal respectfully requests the AOGCC to consider our plan to circulate and pressure test cement in the 2 7/8" x 5 }2" annulus as a valid means to satisfy the requirements of 20 AAC 25.412. If additional information is required, or if we can be of service in any other way, please contact Jerry Bowen at 263-7640. SinCr~IY' .' L...-j ~~ ~ .:Tí/IJ(. ~Jim Harnson Drilling Manager UNOCAL8 Draft: Wellbore Schematic for Side-Track ) ~}nson River Unit Kenai Gas Storage Facility #2 Proposed 5/16/02 RKB = 191' AMSL SIZE WT 13 3/8" 54.5 9-5/8" 40 5-1/2" 20 & 17 CASING DETAIL GRADE TOP BOTTOM I-55 0' 2943" N-80 2736' 7228' N-80 0' 6000' (windo\\ I I 1 2 I 2 .'.' :¡¡¡ TUBING~ TAIL PIPE~ and SCREEN DETAIL: 2-7/8" 6.4 L-80 IBTC S.C.C.O' 6859' . . . PROPOSED JEWELRY DETAIL NO. Depth Item 1. +/-500' Methanol injection port (ID= 2.312") 2. +/-530' TE-5 TRSV (ID= 2.312) ~ Pressure tested TOL to 2000 psi after squeeze Maximum depth of200 sx liner top squeeze = 3499' MDND II Minimum leak paths due to no seal assembly & no tbg movement issues. Maximum tbg tension during injection cycle = 34,000 lbs below surface. ,',",' '"0""'" . " .. . . . . . . . . . . . . ~. . . . . . . . . . . . . . ,',-,' ,',',',',' . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . ::::::;::::::::::::: ,",'.",',',',",',',' . . .. . . . . . . . :-:-: ..;.:- :-:-:.:-:- ,','.".',',',',','.' ,',',".',',',",',',' -:.:- ~-:-: -:-:-:-:-: . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . ,','.",',',',',',',' . . .. . . . . . . . . . . . . . . . . . ,'.'.",',',',",','.' ,','.",',',',',',',' . . .. . . . . . . . . . . . . . . . . . . . ~ . . . . . . . . . . , , . - , - ., , . .. . , . . . . . , , . ., .", . . - . . . . . . . . , , ., .." ,'.',OO,',' ",'.'.' , " .. ,. ...... , . , . , . ~ . . , . .. ' . . " . . . . , , . . " ,'.".oo.'.' ".'.', . " . ' , . . , " " , . " .. , . ~ ' , . , . . . , . . . " . . ' . ~ " . . . , , . . . . . . " . . " . , . . . . . . . . . . , . ' , . . , . ' . , . " . , . , , . , .. . . , , , .. . . . . . . . , . . . " . ~ .' " .'.'.oo.',' ,'.',",',' " . " . ' . . . . . , , . . . . . . . . . . . ., . . ,'.',OO,',' '.' . . .. ' . . . . . . . . . . . . .. ' . . " . . . . . , . , . . . . .. . . . . . . . . " . " " , . , , , " . . . - .. . . .. ' . . , . . . . . . . . " . . , , , . , , . . . . " . . .. . , . . , , . . . . . , . . . . . . . . . " . . . . , . . . . . . . , . . , . . . . . . .. . , " . . , , , . , . . - ....., .... .....<:., n. .......... ..111 ~ t I 11111 IIII ~ 1/1111 1 I IIIII III1 M j IIIHI I~~ mmPiPe to be centralized in critical areas and reciprocated. TD = ~859' MD/6250'TVD .. ,'.'.'.' -:. :-:-:-:-: -: -: -: -: -: -:.:-: -: -: -:. :-:-:-:-:-:-:--. " . ,'.' SCMT log to be run between -6270' (65° inclination) & 5500' to verify presence of cemnt. ..~ Calculate TOC @ 5318' (probably higher with inefficient j~l¡ ¡¡¡¡ ~ mud displacement, had full returns while cementing) ¡¡'¡II!!¡¡!!I!I ¡!I¡ TOC at 5410' per temp log & stated in daily reports. <><) < 45/8" window milled in 5-1/2" & 9 5/8" casing at +/-6000' \k¡¡r¡¡¡¡ :¡¡: volume and low probabtlIty oflost returns early ffiJob .::( ~ ( ) 2- 7 /8" tubingless completion . '~HHH...........:..............~..~e~o,:~~~:~~~u,t~~:~~~: section) 2-7/8" tubing to be cemented to 500' above window (5500' MDND) & pressure tested to 3000 psi prior to completion KGSF #2 Draft Schematic. doc Drawn: 06/07/02 DRAWN BY: JFB during actual injection. The monitored data must be reported monthly on the Monthly Injection Report (Form 10-406). (f) If an injection rate, operating pressure observation, or pressure test indicates pressure communication or leakage in any casing" tubing, or packer, the operator shall notify the commission by the next working day and shall implement corrective action or increased surveillance as the commission requires to ensure protection of freshwater. (g) The commission will require additional mechanical integrity tests, if the commission considers them prudent for conservation purposes or protection of freshwater. (h) The commission will, in its discretion, approve a modification to an existing or pending injection operation under 20 AAC 25.507, if the applicant proves to the commission, upon application containing sufficient detail for the commission to evaluate' the proposed modification, that the modification will not allow the movement of fluids into sources of freshwater. . (i) If injection operations are not begun within 24 months after the date of the order authorizing enhanced recovery, that order expires unless a letter of application for extension is approved by the commission. History - Eff. 4/2/86, Register 97; am 11/7/99, Register 152 Authority - AS 31.05.030 20 AAC 25.410 INJECTION WELLS Repealed or Renumbered Repealed 4/2/86. 20 AAC 25.412 CASING, CEMENTING, AND TUBING OF INJECTION WELLS FOR ENHANCED RECOVERY, DISPOSAL, AND STORAGE. (a) A well used for injection must be cased and cemented in accordance with 20 AAC 25.030 to prevent leakage into oil, gas, or fteshwater sources. (b) A well used for injection must be equipped with tubing and a packer, or with other equipment that isolates pressure to the injection interval, unless the commission approves the operator's use of alternate means to ensure that injection of :(1.uid is limited to the injection zone. The minimum burst pressure of the tubing must exceed the maximum surface injection pressure by at least 25 percent. The packer must be placed within 200 feet measured depth above the top of the perforations, unless the commission approves a different placement depth as the commission considers appropriate given the thickness and depth of the confming zone. 74 (c) Before injection begins, a well must be pressure-tested to mechanical integrity of the tubing and packer and of the casing in1mediately surrounding injection tubing string, The casing must at a 1 or at a surface pressure of 0.25 psi/ft multiplied the true vertical casing shoe, whichever is greater, but the casing may not be subjected to a stress that \vill exceed 70 percent of the minimum yield strength of the casing. The test pressure must show, stabilizing pressure and may not decline more than 10 percent within 30 minutes, (d) The operator shall provide a cement quality log or other well data approved the commission to demonstrate isolation of the injected fluids to the approved interval. ( e) At least 24 hours notice of a pressure test required by (c) of this section must be given so that a representative of the commission can witness the test. History - Eff. 4/2/86, Register 97; am 11/7/99, Register 152 Authority - AS 31.05.030 20 AAC 25.420 NOTICE OF COMMENCEMENT AND DISCONTINUANCE OPERATIONS. (a) At least 10 days before beginning an injection operation or program, the operator shall notify the commission of the intended injection date. (b) Within 10 days after discontinuing an injection operation or program, the operator shall notify the commission of the date of discontinuance and the reasons for it. History - Eff. 4/2/86, Register 97 Authority - AS 31.05.030 20 AAC 25.430 ENHANCED RECOVERY RECORDS. Each operator shall keep accurate records showing volumes of fluids produced, injected volumes, reservoir pressures, and injection pressures, by well and pool. Each operator shall retain these records for five years. The commission will, in its discretion, specify retention of these records for a longer time period. Upon reasonable notice, the commission must be given fun access during normal business hours all records. History - am am 1 1 Authority - AS 31 L__~__.t_L~~O~ I\. I r: I\. I I 14-2 I ., I 41- I fJ.-A (0°1 N '\11/v~ ~ I i~!' f q¡ ~I I PROPOSED GAS \ UNIT STORAGE LEASE \ ---------- -- ,------ 8 I I I I I I __~_~-2J 21-33~ 10 32-3~ 3~33 0' 1,000' 32-33 : i I i I SCALE , jíÞ r¡J , ~ 23-22 ",,'?/o 81 1 t /¿tJ-Þ/7 + ~.;~f 00 /1r1 JI -1, ' z-ó) i~ \§ \ {,} 1-ð --K- \1 .,/0 I Î 7¿JóD le."fU4<t 21-27 . ,í{y¿ Proposed KGSF #2 Completion ¿jr""- I' $'1/0 ; Ga"~j ~o\.. V& ,I I' 11Z/ó6 ?ð,;"J f/;;)! -f)/L + v//(!w' .sT ~r$ '-2.-37-" ?-ç? Î'1Z~DC>". 32-27 -ro<- >íil>l> 2 7 '-f- 23-2781 , 77Z lðö (ll\ 1~-o:J-¿' . cOil .1 (}t ((\.1 V ~rVJ ¡ 314-27RD ~ ) 31i-27RD-2~ ~ .,' , r(' m-27-<>1lI'J -0, ) :t¡rU e + ~ '172./DO 1 ~ ------------- 21~ ~ UROCAL. I SWANSON RIVER FIELD I KENAI GAS STORAGE FACILITY ¡ 800 ACRE LEASE ! I . . ., Jr.t¡....4Ca1l& -= - Date: SEPT. 1996 J! .. SHOWN IIInfted 'To COrlOl'l I8IIIM: MAY 2002 ¡¡¡: 21A-34. ~ 150'54'1f 340000 SWANSON RIVER UNIT #212.21 @ 24 6000C ~ 0.1 cxw. GO'4Î'N < t -- < - ~ f~~f } \ 2475000 . 81ao ? - 60' 46'N -- +----,~- CONTOURED HORIZON 1 8300 24 70000 - 1 \ 60' 45'N 2465000. 32 ,------- ~ 0 :z ""!/;::::O~~ ('=~114~,.. UH ~1 14-~;~ ~ ,. ~~~~ U~ ~. "0.- "~\ I.r 2.~ SCALE IN fEET 3,000 I /50' 52'1f 345000 150'50'/1' 350000 355000 . . . I : I I ,~1)..'" I ----¡---~--:.~.~- .-.))--~;;r----- : ! 31-15 411-15../ I : I . I I I ~;.~ò I + : _I'~ I It-:t~1 ,~ W-15 I ~ 6 I 1 ~ QZ-IS I : I ~.¡i> .' I ", ,¥ - II Ø-If'"'' : I D-1Sj- Ø-I~ I : I I 'I I ~i' I D4-I~'" : ~ ~ I I : U-I"~" I ' I I~S I ----...l- - - - - - + - - - - - - - - - -.---+ - - -- -- I I : I ,~-:-': I : I ZI-U+ : I : I ~------J : I I :112-11 I :"Hn Fault 2 1 , I I , I , '- -- ---.i --- --- \ \ \ I I I PROPOSED GAS", J ~TQ..RA.G~AB.EA - ~ -1- - I I Z2-Zl~ -- - m-4" 1ø-4:f4H 4»-~F Exhib~ -A- I . I ¡ f ï UNOCALC> U-4 rf SWANSON RNER FIELD KENAI GAS STORAGE FACILITY STRUCTURE CONTOURS TOP 62-5 SAND TYONEK FORMATION m PRODUCTIVE LIMIT ........- ." ERIK P. GRAII£N ... SHOWN 1..-." <",.on I Dole: SEPT. 1996 -= APR. 2002 ( SIDETRACK, RE-DRILL & COMPLETION PROCEDURE Kenai Gas Storage Facility Well #2 Swanson River Field, Kenai Peninsula, Alaska Rig Procedure: Note: This procedure is a continuation of the SRU 12-27 abandonment procedure. / 1. PU stack, change tbg spool, re-test stack to 3000 psi. '2. RllI wI Window-Master (single-trip) whipstock. 3. Orient whipstock (in vertical well) w/ E-line gyro, set whipstock & POH wI E-line. . 4. Mill window thru 5 Y2" & 9 5/8" casing from ::1:6016 to 6057' & ./ POH w/ DP. Note: Information in the well file indicates that both the 5 Y2" and ./ the 9 5/8" casing strings are cemented at the planned sidetrack depth. / 5. Close pipe rams and perform F.lT. to 11.0 ppg E.M.W. (e.g. apply 625 psi on top of 9.0 ppg MW). 6. RllI, dress window & POH (only if necessary). Note: A second trip to dress the window might be necessary due to milling through two strings with small diameter 4 5/8" mills. This would be necessary if the first set of mills are worn under- gauge, or if significant drag remains after milling the window. 7. MU angle-build BHA & RIH to 20' above top of window. 8. RllI wI E-line SRO gyro (via side-entry sub) to orient BRA & drill angle-build section until accurate MWD signals are obtained. POH & RD E-line. 9. Drill 4 5/8" hole building angle to :1:900 to land in the 62-5 Sand J at :I:~ MD / 6250' VD & POH. b <65~c !ß?-¡ýJ Note: Maintain minimum weight OBM needed to control well with minimum solids. Maintain pump rate between 110 & 150 ( ( GPM, if possible. Reduce pump rate if necessary to maintain returns. 10. MU angle-hold BRA, RIH & drill 4 5/8" horizontal hole to 6859'. 11. Circ hole clean & POH laying down 2 7/8" DP & BRA: 12. Rill w/2 7/8" long string wI TRSV & methanol injection port positioned between 550' & 600' MD. 13. Space out & cement long string from TD to 500' above window with 12.0 ppg LiteCrete. / Note: It is essential to maintain returns while cementing to provide zonal isolation and to seal off the openhole from the 5 1/2" casing. 14. Pressure test 2 7/8" long string & 5 W' casing to 3000 psi. / Note: Both strings must test to 3000 psi or remedial action will be required. WOC until samples are hard before conducting test. If necessary, proceed with NDINU prior to conducting test. 15. ND BOPE & NU X-mas tree. 16. Clean tanks & release rig. Coil Tubing Perforating Procedure: 17. MI & RU CTU, pump, tank & N2unit. 18. Rlli to PBID w/2 3/4" wash tip, jet well dry & POH. I 19. M/U 2" x 500' TCP gun & real time GRIN logging tool. 20. Rill, Perf horizontal section & POH. Note: TRSV must be verified closed to lay down 500' gun without loading well. 21. LID guns. 22. RD CTU. Maximum Anticipated Surface Pressure Calculation & Verification of Casing Design K. G. S. F. Well #2 Kenai Gas Storage Facility, Kenai Peninsula, Alaska Assumptions: 1. The 62-5 Sand is known to be depleted to a 0.12 psi/ft (2.3 ppg E.M.W.) pore pressure gradient. However, for safety purposes, it is assumed that the 62-5 Sand is normally pressured (i.e. 0.447 psi/ft x 6250' = 2794 psi.). Some of the formations penetrated above (or possibly below) the objective should be normally pressured, based on all available reservoir data, and there is no known data indicating that any of the sandstone formations that will be penetrated will be over-pressured. - - --- -- 2. For the purpose of this calculation, it is assumed that the frac gradient at the planned window depth of 6005' is sufficiently high that a full column of normally pressured gas could exist inside the 5 1/2" casing in the worst case scenario In other words, 'the M.A.S.P. has been calculated assuming the theoretical worst case scenario; i.e.full replacement of drilling fluid wI gas, which results in the maximum surface pressure of approximately 2544 psi. M.A.S.P. Calculation: Max. pore pressure at T.D. = 6250' VD x 0.447 psi/ft = 2794 psi 2544 psi 3000 psi M.A.S.P. during drilling = 2794 psi - (0.04 psi/ft * 6250 psi) = M.A.S.P. during production/injection (*see note below) = Design Considerations: 1) *There are no known problems with the 51/2" production casing or the 133/811 surface casing in the subject well. The / well produced hydrocarbons and water with no significant quantities of H2S or CO2 since 1959. The maximum anticipated gas injection pressure ( limited by compressor discharge pressure) is 3000 psi. Therefore, the5 1/2" casing must test to 3000 psi in case a tubing leak were to occur when the reservoir was fully charged aVnear the end of an injection cycle. 2) The tubing head spool will be replaced prior to milling the window due to a sow leak in the packing on the outside of the 51/2" casing stub. The existing void area between the seals of the 5 1/2" casing pack-off have been packed with plastic, / but will still bleed off from 3000 to 2000 psi over approximately 15 minutes, but will then hold 2000 psi. This item will be pressure tested carefully to ensure no leakage prior to proceeding with drilling operations. 3) There is only 234' vertical separation between the window and the 62-5 Tyonek objective reservoir. It is highly unlikely that any pore pressure encountered while drilling between the window and the objective reservoir would have the potential to breakdown the formation at the window. Therefore, in this particular case, the pressure integrity of the 51/211 casing is the over-riding design consideration. The procedure will call for testing the 5 1/2' casing early in the process of abandoning the current Hemlock completion, if not sooner. 4) Utilize triple (5m) stack design. although testing above 3000 psi is not required / 5 1/211 Casing Strength Calculation: Original casing burst rating: 9190 psi (5 1/2" 20 ppf N-80 L T&C) Required strength vs. original strength (to be confirmed wI test) = (3000 psi / 9190 psi) * 100% = 32.6% ( BOP Stack for SRU 12-27 Abandonment & KGSF #2 Re-Drill Top of Rotary Table ( .. &~ ~ .& r , - 11" Hydril 5M .. 41.5" \. .) I I I .. - .. / 33" .. - 7 1/16"5M X 11". 5M adapter spool Top of Shaffertbg head spool (71/16" 5m flange) A 31116" 5M Foster HCR Valve B 31/16" 5M Manual gate valve C 31/16" 5M Manual gate Kill line D 31/16" 5M Manual gate Kill line .. - 24" .. - 19.5" .. - 18" .. I;"'~~~ . ~t~I¡1ii1~~1 ~. {.';''$~~~;'~;~;;::~~'.''{~:1::;.J.~1 ;'Wf.1. J} ~ ~ I P :¡ f i} I/t. :r ~.~ U..n l~ ~> ~ :~¡~ ,~.:m1f;1l~~~1~~~ ( ( ~ ~ May 29, 2002 UNOCAL 909 West 9th Avenue Anchorage, Alaska 99501 A TTN: Jerry Bowen Jerry Enclosed is the mud program for your upcoming Swanson River Gas Storage Well. Included is a well summary, economic summary, interval summary, and the project team. This well will be drilled with an Oil Base Mud. Please see attached Virtual Hydraulics. This will be a difficult well to drill. The hole cleaning properties in the build section will be poor because of lack of rotation. We recommend frequent wiper trips to make ensure a cuttings bed is not be- ing created. The necessity to keep solids to less will be difficult to achieve. This will be very dif- ficult with mud weights in excess of 8.85 ppg. The internal brine phase of this mud will be up to 34% calcium chloride. Since we will have not many solids in the mud we will need to use Ver- satrol and Ecotrol to reduce the HPHT fluid loss values. Please call me if you have any questions regarding the mud program. Lee Dewees Project Engineer M-I Drilling Fluids 907274-5533 M-I. L.L.e. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax ~ Economics Summary Well Target Cumula- Pretty Creek #4 Days tive Days Product Costs ($) De-complete 4 4 3500 Drilling 4 60000 8 Completion 4 12 $6000 . Engineering Costs are for M - I Engineer only . Costs assumes new mud. Swanson River Gas Storage 2 Engineering Costs ($) 2500 2500 $2500 . No cost allowance is made for lost circulation or stuck pipe. . Costs include 6% KCL completion fluid. M-I. L.L.G. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax Cumulative Cost ($) 6000 68500 77000 ~ Interval Summary Swanson River Gas Storage 2 6015' - 6889' MD 3 1/2" Tubing 4 5/8" Hole Drilling Fluid System Versa- Drill Oil Mud Key Products Mapco 200/ Versawet / Versacoat / Versa HRP / VG-69 / Versa- mod / Lime / Calcium Chloride / Safe Carb / Ventrol 401/Ecotrol Solids Control Shale Shakers / Desilter / Centrifuge , Potential Problems Coal sloughing, hole cleaning, drill solids buildup hI ---. ,"_h__- -- -- . ---'---.. ------ - h '-- h_____' 111 - r hOOT ,_h- . - - .- ..- --.- ..rr- - - --.. Interval Drilling Fluid Properties Depth Mud Plastic Interval Weight Viscosity (ft)(ppg) I' (cp.) 6015' -6889' 8.6-9.2 20 - 25 ""'-h_h 'h]-I----W-W-' 11--.-------'-.-.- ,_Jo- -"----.-'W-_h-"---'--- Yield HTHP Point Fluid Loss OIW (lb/100ft2) (ml/30min) Ratio 12 - 20 3- 5 cc's 65/35 . -,....--.- --_._~.._.--.---.._'---..,w..- h-"f''mrl-r-h''--T''.--'''' Gels (lb/100ft2) 15 - 30 - -'.'-1"----.- . Displace 5 1/2" casing to oil based mud. . Drill ahead, maintain low shear rate values with VG-69, Versamod, and Versa HRP. . Run centrifuge as continuously to minimize solids buildup. . Pump sweeps to aid in hole cleaning. Use Verstrol and Ecotrol for fluid loss control. . If sloughing coal becomes a problem, add 2 - 4 ppb of Ventrol 401 to mud system or spot a concentrated pill of 20 - 25 ppb V entrol40 1 across coal zone prior to trips. For severe coal sloughing consider raising mud weight. . Run~..JjDer. ~"'(i ¡¡ fö')-') Sfv'~5 . Displace well to 6 % KCl. . Estimated volume usage is 500 barrels. M-I. L.L.c. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax rm Project Team Jim Brown Field Engineer 1"'- J ~.m::.....'mwø'. .. ...,.. ~~~~;;:~~r. J w:::~~;~.J t .. ~ì~;~~~#f~~] Swanson River Gas Storage 2 Forest Slater J ..... --=d :~~e;_., . f ~~~~s~~e_J . MI Project Engineer and Engineering Manager will coordinate between the Anadarko office, rig, warehouse, and the M-I field engineers. . Well progress will be monitored to look for any changes which will improve the effi- ciency of the operation or avert trouble.. Project Team Title Work Cellular Craig Bieber District Manager 907 274-5051 907229-1196 Deen Bryan Tech Service 907-274-5003 Lee Dewees Project Engineer 907-274-5533 907-230-6653 GusWik Warehouse Manager 907 776-8680 907 252-4218 M-I. L.L.c. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax ~ Frac - 10.6 pp,g VIRTUAl HYDRAUI..ICN SnapShot 0fiIIIHIII1 u-tL.L.c.-AlIR~'. RtItIUtd MAPCO VERSADRll Option. PV=21, VP=16 >{: "I.cil~ MD: 6859 ft Operator: UNOCAL TVD: 6254 ft Well Name: Gas Storage #2 Bit Size: 4.625 in. location: Date: 512812002 Country: AnØe Density (lblgal) [ ;'!J. ~ s:J 8~- U i2 iU if ..5 t: Ø1t,:21U [ PV, VP, LSYP Temp (Of) AV (RinIn) Hole Clean Ind 1J 2J 3:J Q 11 fIJ ~ 111 ~ [ 2:1 I:J va G F P ~- Gutflsby DepOt HDflVD (Iþ Clg/H Dill (It) (ft) PI Eœ.. - -. ..YJ! '".4000 ..Em I500CI . ..Lm. &-fQ eooo 1.118 - too.. ...... .... 7000 ... eooo - -- All ""'--- .- -""'-;--- 2M.. ---. Pressure Loss (1M!) . JI .. 78 ~ DrllSIrInII 1 ~ t".~~- A....,. DRILLING R.UID VERSADRIL (MAPCO 200) Mud "MtIght 8.eSlb/g81 rut Temp 120 8F SYSTEM DATA Flow Rat8 110 gal/mln ROP RPM WOB TFA ðOftlhr Orpm 20Klb .ð04 In' / PREsSURË LOSS ..... ModIfied PoW8f' L8W(OR81R3) DrIll 9trfng 87.. Metar/MWO 150 1200 Bit 38 Bit On/Off 0 Annufu. 454 Surfao8 EquIp 3 U.Tube Pre.. 31 Tot. System 18S2 ESD ECD +Cut C.g Shoe 8.96 10.23 10.33 1D 8.88 10.38 10"'8 VlfDH -'NIIOn 1.1 ....-onœ..œ '" 10Ø .~. ,.~" 2 7/811 Long String Cement Volume Calculation K. G. S. F. Well #2 Kenai Gas Storage Facility, Kenai Peninsula, Alaska Assumptions: 1. 62-5 Sand frac gradient +/- 0.55 psi/ft due to low pore pressure 2. 2 3/8" x 5/1/2" annulus must pass pressure test to 3000 psi after cementing* 3. 300/0 excess in open hole will be sufficient to account for washout volume Notes: #1) *It is essential that the 5 1/2" casing pressure test to 3000 psi after the cemnt job is completed. However, considering the relatively short distance between the window and the horizontal sec~ion (359' MD, 250' VD), and the volume of cement to be pumped, the odds or obtaining a good pressure isolation in the 27/8" x 5 1/2" annulus are considered very high. #2) The 2 7/8" long string wi! be centralized at key positions in order to effect a good pressure seal between the horizontal objective formation and all formations in the angle-build portion of the well, as well as a good pressure seal (cement bond) between the openhole formation and the 2 3/811 x 5 1/2" annulus. Volume Calculation: Openhole volume = ((4.625)^2-(2.875)^2)*3.1417/4/144/5.61 *859*1.3 = 14.25 bbls 7.61 bbls 21.86 bbls / Cased hole volume= ((4.89)^2-(2.875)^2)*3.1417/4/144/5.61 *500 = Total planned cement volume Cement Type: 12.0 ppg, very low FL, LiteCrete (w.o. Dowell design) Contingency: In the worst case scenario, returns would be lost early during the primary cement displacement process, thus preventing displacement of cement above the 5 1/2" casing window. In this case, the only remedial option would be to perforate the 27/8" casing and squeeze the 27/811 x 5 1/2" casing annulus to create a reliable pressure seal. This could be done rig less using coil tubing, or with the rig and 1 1/4" C.S. Hydril tubing. (' Schlumbf Jel' * CemCADE well cementing recommendation for 27/8" Liner Operator Country State : Unocal : USA : Alaska Well Field : KGSF#2 . Swanson River Prepared for: Jerry B Proposal No. : Pre Permit # 1 Date Prepared: 05-31-2002 Location : Kenai Service Point. Anchorage Business Phone: 263-7800 FAX No. Prepared by . Paul Perius Phone' . 907-351-4373 E-Mail Address:perius12@prudhoe-bay.oilfield.slb.com ;';e:,\GN ~ Q«) 0 c: ~~ ;;f ~(,lIATe ~ Disclaimer Notice; This information is presented in good faith, but no warranty is given by and Dowell assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Dowell's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Dowell can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Dowell or others is not to be inferred. * Mark of Schlumberger Client : Unocal Well: KGSF#2 String : # 1 District: Anchorage Country: USA Loadcase : Section 1: well description Configuration Stage Rig Type Mud Line Total MD BHST Bit Size ft 0- 0 c::i 0- I£) N 0 c::i 0- 0 I£) 0 d- o It) ,,- : Liner : Single : Land : 0.0 ft : 6859.0 ft : 142 degF : 4 5/8 in ... Well ) .......... ......... I......... ......... I......... ......... I......... ......... .......... ......... I......... ......... .......... ......... ........... ......... I......... ......... .......... ......... I........" :Sandstone' . ......... I......... ......... .......... ......... I......... ......... .......... ......... I......... ......... I......... ......... I......... ......... I......... ......... I......... ......... t......... Lithology KGSF pre permit.cfw; 05-31.2002 ; Version wcs-cem43_99 Schlu_. -'ger (x 1000) psi ? Fl3c I . - - . Pore " . . -. 4 I 0 I ., Formation Press. Page 2 f-com~;;; @G;;hi-~;;.:wcli~S;~;-'¡ ¡ If: 1 li:Depth Scale + WelI Schematic ; t-:Lithology + F~~!.~on Pressure~~_---_.; Client : Unocal Well: KGSF#2 String : # 1 District: Anchorage Country: USA Loadcase : MD (ft) 6000.0 MD (ft) 5800.0 Previous String OD Weight (in) (lbltt) 5 112 '17.0 ID (in) 4.892 OD (in) 31/2 Weight ((bitt) 9.5 Drill Pipe ID (in) 2.992 Liner Hanger : 5800.0 ft Landing Collar MD : 6779.0 ft Casinglliner Shoe MD : 6859.0 ft MD OD (ft) (in) 6859.0 I 27/8 Joint (ft) 40.0 Casing/Liner Weight ID Grade (I bitt) (in) 6.4 2.441 Grade J55 Mean OH Diameter : 4.625 in. Mean Annular Excess : 30.0 % Mean OH Equivalent Diameter: 5.033 in Total OH Volume : 21.1 bbl (including excess) Max. Deviation Angle : 90 deg Max. DLS : 33.498 deg/100ft MD (ft) 0.0 6015.0 6027.0 6058.0 6060.0 6080.0 6100.0 6120.0 6140.0 6160.0 6180.0 6200.0 6220.0 6240.0 6260.0 6280.0 6300.0 6320.0 6340.0 6359.0 6859.0 Directional Survey Data TVD Deviation Azimuth (ft) (deg) (deg) Oß Oß Oß 6013.8 2.0 74.0 6025.8 2.8 117.0 6056.7 2.8 118.0 6058.7 2.7 132.0 6078.7 6.4 201.0 6098.4 12.2 213.0 6117.7 18.0 217.0 6136.4 24.0 219.0 6154.2 30.0 220.0 6170.9 36.0 221.0 6186.5 42.0 222.0 6200.6 48.0 223.0 6213.2 54.0 223.0 6224.1 60.0 224.0 6233.1 66.0 224.0 6240.3 72.0 224.0 6245.5 78.0 225.0 6248.6 84.0 225.0 6249.6 90.0 225.0 6249.6 90.0 225.0 Dogleg Sev. (deg/10Oft) 0.000 0.033 15.741 0.156 -33.498 29.933 30.424 29.448 30.209 30.085 30.123 30.163 30.207 30.000 30.291 30.000 30.000 30.385 30.000 31.579 0.000 KGSF pre pennit.cfw; 05.31.2002 ; Version wcs-cem43_99 E-75 Collapse (psi) 7676 Scblu( ~ger Collapse (psi) 5544 Burst (psi) 7620 Burst (psi) 7264 Thread N/A Page 3 Client : Unocal Well: KGSF#2 String : # 1 District: Anchorage Country: USA Loadcase : MD (ft) 6859.0 Frac. (psi/ft) 0.550 Formation Data Pore Name (psi/ft ) 0.120 Schlul .lger Lithology Sandstone MD (ft) Geothermal Temperature Profile TVD Temperature Gradient (ft) (degF) (degF/10OO) 0.0 80 0.0 6249.6 142 1.0 0- 0 c:i 0- 1,0 N 0 0 0- 0 I,C) 0 c:i- 0 1,0 .......- 0.0 6859.0 ft degF 7Ft 1 nn 125 ~- Geoth.Profile I I 150 I ft n ?nn 1- Hori. Dep311. 400 I Temperature g 0 ('1)- ~ s- o ~ ~ ð. I.C) U) t'- Hori. Departure Section 2: fluid sequence Original fluid Mud 9.00 Ib/gal Pv : 20.000 cP 56.1 bbl 50.4 bbl 113.8 bbl Displacement Volume Drill Pipe Volume Total Volume Ty : 20.00 Ibf/100ft2 KGSF pre pennit.cfw; 05-31-2002 ; Version wcs-cem43_99 600 I r------'-"-------------------'"'' -"---""---"-", ¡ Comment: @Graphic:</tWelI Temper; 1 ature If: I li:Depth Scale + - i -l~~_~~:_!.~~~~~-~o_~~~_._--_._---_._-_._.. "i (------------..---.....-------..--..'-....---'.--...----'------. .....-------- , j Comment: @Graphic:</tWelI_HDepa ¡ ..1 rture If: I li:Hori. Departure> -_____.1 Page 4 Client : Unocal Well: KGSF#2 String : # 1 District: Anchorage Country: USA Loadcase : I TOC 5800.0 ft Name Volume Ann. Len (bbl) (ft) CW100 20.0 1762.4 MUDPUSH XlO 20.0 1762.4 Tail Slurry 17.7 1059.0 Mud 56.1 Fluid Sequence Density (lb/gal) 9.09 10.00 12.00 9.00 Top (ft) 2275.1 4037.6 5800.0 0.0 Static Security Checks: Frac 345 psi Pore 2216 psi Collapse 7506 psi Burst 7264 psi Csg.Pump out 25 ton ft 0- 0 - 0 0- 1,,0 N - 0 - 0 0- 0 1,,0 - 0 - ci 0 - 1,,0 1'-- Fluid Sequence Schlu_'. ~g8r Rheology viscosity:5.000 cP Pv:24.000 cP Pv:80.000 cP Pv:20.000 cP at 6359.0 ft at 6000.0 ft at 6359.0 ft at 6779.0 ft (x 1000) psi ) 0 ? .... - Hydrostatic \ - - . Fl3c . Pore 4 I Static Well Security KGSF pre permit.cfw; 05.31.2002 ; Version wcs-cem43_99 Ty:24.00 Ibf/100ft2 Ty:10.00 Ibf/100ft2 Ty:20.00 Ibf/100ft2 r-ë¡;;-;e~t~-'@Gra~h~~~~Fluid- Sequ;-l ¡ ce If: 1 /i:Depth Scale + Fluid Sequence + ¡ L Static Well Security> ! Page 5 Client : Unocal Well: KGSF#2 String : # 1 District : Anchorage Country: USA Loadcase : Schlul' ~ger Section3:PlJrTlping schedule Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbVmin) (bbl) (min) (bbl). Temp. (degF) Pause 0.0 0.0 5.0 0.0 80 3-Pressure Test Lines CW100 1.0 20.0 20.0 20.0 80 5-Start Pumping Wash MUDPUSH 1.0 20.0 20.0 20.0 80 7-Start Pumping Spacer XLO Tail Slurry 1.0 17.7 17.7 17.7 80 9-Start Cement Slurry Pause 0.0 0.0 5.0 0.0 80 36-Drop Dart Mud 1.0 50.0 50.0 50.0 80 19-5tart Displacement Mud 0.5 6.1 12.2 56.1 80 19-5tart Displacement Total 02:09 113.8 bbl hr:mn Dynamic Security Checks : Frac 17 psi Pore 2085 psi Collapse 7506 psi Burst 7125 psi at 6859.0 ft at 6000.0 ft at 6359.0 ft at 5800.0 ft BHCT 115 degF Simulated BHCT (degF) CT at TOC (degF) Static temperatures: At Time (hr:mn) Top of Cement (degF) Bottom Hole (degF) Temperature Results Simulated Max HCT Max HCT Depth Max HCT Time (degF) (ft) (hr:mn:sc) (hr:mn) (degF) (degF) Geo. Temp. (degF) (degF) Page 6 KGSF pre permit.cfw; 05.31-2002 ; Version wcs-cem43_99 [ Comment: Client : Unocal Well: KGSF#2 String : # 1 District: Anchorage Country: USA Loadcase : Scblur ~ger Section 4: fluid description Fluid No: 1 Rhea. Model At temp. : BINGHAM : 80 degF MUD Mud Type: OBM Water Type: Fresh Fluid No: 2 Rheo. Model At temp. : NEWTONIAN : 80 degF Fluid No: 3 Rheo. Model At temp. : BINGHAM : 80 degF Fluid No: 5 Rheo. Model At temp. .: BINGHAM : 80 degF DESIGN BLEND Name : 12 Ib LiteCR Dry Density: 112.73 Iblft3 Sack Weight: 1461b BASE FLUID Type : Fresh water Additives Code D167 D047 D065 Cone. 0.350 %BWOC 0.020 gal/sk blend 0.350 %BWOC Mud DESIGN CW100 DESIGN Density: 9.00 Ib/gal Pv : 20.000 cP Ty : 20.00 Ibf/100ft2 Gel Strength: Job volume: 56.1 bbl Density : 9.09Ib/gal Viscosity : 5.000 cP Gel Strength: Job volume: 20.0 bbl MUDPUSH XLO DESIGN Density: 10.00 Ib/gal Pv : 24.000 cP Ty : 24.00 Ibf/100ft2 Gel Strength: Job volume: 20.0 bbl Tail Slurry DESIGN Density : 12.00 Ib/gal Pv : 80.000 cP T y : 10.00 Ibf/100ft2 Gel Strength: Job volume: 17.7 bbl Quantity: 41.87 sk Solid Fraction: 54.8 % Base Fluid: 8.025 gal/sk KGSF pre pennit.cfw; 05-31-2002 ; Version wœ-cem43_99 Page 8 SLURRY Mix Fluid: 8.045 gal/sk Yield: 2.38 ft3/sk Porosity: 45.2 % Density: 8.32 Ib/gal Function FLUID LOSS ANTI FOAM DISPERSANT Client: Unocal Well: KGSF#2 String: # 1 District : Anchorage Country: USA Loadcase : Code D800 Cone. 0.350 %BWOC Thickening Time Compressive Strength ( Additives Function RETARDER Schedule Schedule KGSF pre permit.cfw; 05-31-2002 ; Version wœ-cem43_99 SchlOI", ~g8r at at Page 9 I fluid No : pak KGSf # 2 Company: Unocal Well Data Job Type Casing BHST 142 degF Starting Temperature 80 degf Starting Pressure Composition Code Dry phase contents LiteCRETE D167 D065 D 800 Wet phase contents Fresh water D047 I Slurry Density Base Fluid Cone. Rheology Fann Readings (rpm) 300 200 100 60 30 6 3 10 see 1 min 10 min Fluid Loss I mLin API Fluid Loss Thickening Time Consistency 70 Be POD: Batch Mix Time: \'~hlumbepgep Cement Test Report Requested by : Peri us Well Name KGSF # 2 .? I : Swanson River I 05/31/02 LAB BLEND Location Field Depth BHCT Time to Temperature 6859.0 ft 131 degF 00:05 hr:mn TVD BHP Heating Rate 6249 ft 2989 psi + 1.92 degF/min 108 psi Time to Pressure 00:05 hr:mn Lot Number Cone. 0.35 %BWOC 0.35 %BWOC 0.35 %BWOC 0.02 gal/sk blend 12.001b/gal 8.025 gal/sk Porosity Mix Fluid 45.4 % 8.045 gal/sk Yield 2.39 ft3/sk At 80 degF I (deg) 103 74 42 30 19 12 11 At 70 degF I (deg) 108 76 44 31 21 12 11 Pv : 93.459 eP Ty:10.56Ibf/100ft2 Pv : 97.355 eP Ty: 11.05 Ibf/100ft2 30min at mL and Time 03:30 hr:mn at SCHLUMBERGER DOWELL CONFIDENTIAL (, Kenai Gas Storage Facility Well #2 Hazard Analysis for APD 20AAC 25.005 @ 4 Risk of Abnormal Pressure: The objective 62-5 Tyonek Sand is known to be depleted to a ).12 psi/ft (2.3 ppg E.M.W.), based on P/Z data from offset well SRU 212-27 (located on the same pad). However, a short interval above the objective sand which is not depleted will be penetrated (refer to attached log section). It is also assumed, for general safety and well design purposes, that the objective sand could be fully charged to the original normal seawater gradient of 0.447 psi/ft. I Although abnormally pressured water flows have been experienced at various depths in other wells in Swanson River Field, the risk of encountering an abnormally pressured water flow in this well is viewed as low due to the , relatively short 243' of vertical thickness will be penetrated according to the plan. Additionally, the risk of an abnormally pressured hydrocarbon (gas) interval is viewed as extremely low.' -----,,-- Regardless of the pore pressures encountered, due to the planned window depth of approximately 6016' MONO, and "the evidence which indicates good cement exists outside both casing strings through which the window will be milled, the risk of breaching to surface during a well control incident is essentially nil. Based on known petroleum engineering principles, a downhole blowout from 6250' VO to 6016' VO is practically impossible. The only risk associated with any conceivable well control situation, whether related to abnormal pressure or not, in this particular case, would be the risk of (1) human error. in handling the situation, or (2)105S Qfmechanical integrity of well control equipment, casing or wellhead equipment. In order to mitigate these risks; (1) every effort has been and will continue to be made to educate and train key personnel to recognize warning signs and take appropriate actions in the event of a well control situation, and (2) the casing, wellhead and BOPE integrity will be carefully tested to 3000 psi prior to drilling. Additionally, a triple ram 5m BOP configuration will be employed for added safety, althought there appears to be no reason to exceed the planned 3000 psi test pressure. The 3000 psi pressure test of the -casing will be 32.6% of the original burst strength (9190 psi) of the 5 %" 20 ppf N-80 L T&C casing, and this will occur as early as possible before significant expenditures have occu rred. APD Procedure & Hazard.doc 5/30/02 Risk of Lost Circulation: Lost circulation problems are li<~ to be encountered due to; (1) high ECDs associated with slimhole drilling and (2) the expected low frac gradient in the depleted objective formation (estimated to be :1:0.55 psi/ft). However, considering the close vertical proximity of the casing window to the objective formation, lost returns is not likely to result in a well control incident. Lost returns could cause delays and difficulties which, in turn, could potentially lead to significant problems such as; (1) stuck pipe, (2) an inability to complete the drilling due to total lost returns, or (3) problems circulating the primary cement into the required position could lead to a lack of pressure integrity in the 2 7/8" x 5 Vi" annulus. The risks associated with lost circulation have been considered in the process of making the decision to conduct the planned operations, and it is understood that there is a chance that the-project could potentially ,be unsuccessful due to lost circulation problems. In the case where returns are lost during the primary cementing of the 2 7/8" long string, resulting in a 2 7/8" x 5 Y2" annulus which fails to pressure test, certain remedial repair options would exist. One option would be to utilize coil tubing to circulate/squeeze cement and drill out until a successful pressure test is obtained. Waste Disposal: Leftover OBM will be transferred and used to drill the well immediately following the subject well. Contaminated liquid mud and/or waste water wil be transported to and disposed of in the approved class II disposal well, SCU 243-4. Cuttings will be placed in the Swanson River Solid Waste cell. Shallow Gas: Due to the depth of the window, there is no significant risk exposure / associated with shallow gas. -- Proximity: Due to the depth of the window, and the relatively short section to be drilled, the risk of a collision with another well is extremely low. However, the proximity to well 212-27 will be closely monitored at all times while drilling to make certain that the ellipses of uncertainty do not overlap. (, Surface Use Program for Kenai Gas Storage Facility Well #2 43 CFR Part 3162.3 - 1 1) Existing Roads See Map 2) Access Roads to be Constructed and Reconstructed Roads and Pad are already in place. 3) Location of Existing Wells See attached maps 4) Location of Existing and/or Proposed Facilities An existing gas flow line which extends from the existing Swanson River Field Facilities to the subject well will serve as the conduit to bring gas to the well to be stored during periods of low gas demand, and to produce gas from the storage well during periods of high gas demand. No additional surface facilities will be required at the well site to initiate gas storage, or to produce stored gas at a later date. 5) Location and Type of Water Supply Fresh water is available from the adjacent facilities. Minimal water will be required to sidetrack and drill the horizontal hole in the Kenai Gas Storage Facility Well #2 due to the use of oil based mud. 6) ConstructionMaterials N/A 7) Methods of Handling Waste Disposal Solid waste in the form of drill cuttings will be hauled in cutting boxes to the SRF Central Waste Facility. Liquid drilling mud will be recirculated while drilling the well. At the end of the well, the liquid mud will be hauled by vacuum truck to the location of the next planned drilling well, SRU #213-10. Liquid wastes such as water with high oil/grease content will be hauled to and disposed of in the field class II disposal well. Garbage will be burnArl pt thø in,...in"'r'" tnr "'t +h nn n I in' nnr- 9) Well Site layout See attached pad layout diagram 10) Plans for Reclamation The road and pad for the proposed well will not be able to be reclaimed because they will be in use. There is a high probability that the storage well can be successfully completed and placed in service, so there is only a low probability that the location will no longer be needed. In addition, well 212-27 is located on the same pad, but is currently shut-in awaiting clean-out with coil tubing to be returned to production. 11) Surface Ownership , BlM, Federal Government 12) Other Information None 13) leassee's Representative and Certification Jim Harrison, Drilling Manager, Unocal Alaska 907-263-7677 I hereby certify that " or persons under my direct supervision, have inspected the proposed drill site and access route; that I am familiar with the conditions which currently exist; that the statements made in this plan are to the best of my knowledge, true and correct; and that the work associated with operations proposed herein will be performed by Unocal and its contractors and subcontractors in conformity with this plan and the terms and conditions under which it is approved. This statement is subject to the provisions of 19 U.S.C.1 001 for the filing of false statement. Date: 3/- 5 -0:2- /Î ~ Name and Title: G ~ ~.J:--JII Jim Harrisor( Drilling Manager ( _£NAI GAS STORAGE FACILITY WELJ ~ SWANSON RIVER FIELD, KENAI PENINSULA, ALASKA GENERAL RIG LAYOUT DIAGRAM NABORS RIG #129 500 BBL Tiger Tank (Slops) :'...... .......... ....... ..... ........... ...~ æ Choke House æ : D : ¡ ! : ,:,¿ : : (ij : : 1; : : cø : æ C,) æ Top Drive Conex I I ~ ~ -~- ~ - æ Cuttings Tank ~ Õ --.-$.-.-. ~ ~ : (1)- ! :::J : -æ æ ~ æ { 0 æ (¡) Sub 001 : . ..\c: . 0: cø 0: Diamond Tanks 0 ~ 65 - ~ 0 : - æ 75 Hp Vac Unit ~ ~ === ~ Cuttings Tank ~D : II) II) ~ æ : 0.. c.. ...... : 500 BBL Tiger Tank ) - æ ~ ~ ~ æ -::ê c.. c.. ~ : Ë ~ C!J æ ~ ~ æ ~ ~ -: - : 130 BBL - ~ æ æ Trailer-Mounted ~ - ---ZiN : I . I : Iso-Tanks ~ ~ - ~ æ - Baller æ ~ = - - Do EJ! I Lockers/Shop d.t "-t--J ~ :..........................................; "- Storace Conexes . t CharQe and Transfer Pumps r- - - Pre-Mix CJ MI Shack XXX BBL Vertical Storage Tanks (Replaced w/ Tiger Tank on Griner #1) Bermed Area SUBJECT Lv~ 11 Y' <~ .., ~~' ,\Ì . ~2J ~ .~~' -.. -"-.._11 UNOCAL8 i ¿D8'1 1"A-2.., PREPARED IJV , RÐ~ Á. þ,. . ~"òa"- (' RDI.tJik. (~y QJ ) . --. ;;z.þ' .1- . . ..- - . . E A to\., )Own t~:t ~ I) ~ 'ft.t. i Þ'\ "It'~~"" R re.w. . DA1'£ PAGe . ~ J.'1-()~, W.O/Ä.H. ~O. OF . . -...,-- .. "'-,..,.. '-"..-.' ~- . ......~...... -..-.. -_...-- 'ÛJI 2.)t-J.7 G) lIøJ "f." Q l'. "l't.-; '" ~ ~ t\ oJ- CÞ'..r I Š,.H' f6"4I1t\' 101:>' \, . . \ .' , \~'\ \ \ . J 'Iø~ 'f' V ~~' ,'. . \ ... .. ,. "'...... ~... ~ ~of~~~~çv(þ. jo/~-' ,--/. '. '. , . :nr. " .AhA-" )'\ . . .. --... --...- t}" "...,. .,~,....."" ~. . RoaJ. V1\\~\)Ø)()'þO '/.~ . ;;? ... - p"(lf-.. .. - . .. ,"- FORM '.2C60 (REV. 2.&7) PRINTED IN U.S.A. _..n '~'..n_..- -".-'-'- . -... A .. ".-. .-."","'--. ~ , 'J\\. "'... . .. ~':. '.,. t .~ it~ r.. . .... i . r i j , II u :) I. " . 01 i ..\0 01 ..~ \ :t \': 0 ¡ ..... J , ~o { , \=: ~._""'I'. """,",~'''''-I- '-.. -. ~\---..'.........~. rlt, ---- '....:" . . ...:~" ..t:- . . ~ '. ~ ..~: '."' ~ .. ... " '11' ..,... "'YI''''''''~ .....,.7 . .....'... ... . '. - < . ,. - ~ I UNOCAL VERTICAL SECTION VIEW Client: Unocal Well: KGSF #2 (P4) Field: Swanson River Unit Structure: Swanson River section At: 224.11 deg Date: April 29, 2002 Schlumberger 5700 - -~~--_._- 5850 _n.............-...-..-......-.......''''-",,,,,,,,,,,,, ..........., "''''''''''''''''''''''''''''''''''................-...........................--'"'''''''''' ""M"""""""""'''''''-''''-'''''''''''''"""",,,,..-........"..,......"......"......-...,....."..,..""...........-.....--........................;-.--........-........"""--"'."""""""'"''''''''''''-'''''''''''''''''''''''''''_...............~................_...._.................,.............".. ~ ---;- Top of WhIpstock Q) ;;:: L 6016 M) 6012 TVD Q) VJ 2.00' 74.00' az ~ i 6000-------------------~~-~æ~- .- 4:: ! KOP Cry 30/100 ~ 0 6058 MD 6053 TVD - L() 2.17" 117.85' az :5 N .1¡9 departure 0..0) Q)~ O- m 6150 -..........................-.......-........................... ......, ~ ..................--...........-.....--.........,... ........................-..........-.....-..............-."'--"""'--'''''''''''''''''''''''''''''''''-''''''-''''''''''''''....-......-..-.....''''''''''''-'''' ......-..............................................................,.......-................................... rn u t.t-: Q) Q) > a': Q) > :::J Q) .=W ~ EndCrv ""'.----.-------------------7----- -:i"~~~~-~:;~::::~~:S~--------------~~~~;--------------------- 560 departure 0 -~ 0 6300 12-27 6450 -300 -150 150 300 450 600 Vertical Section Departure at 224.11 deg from (0.0, 0.0). (1 in = 150 feet) 0 750 ~ UNOCAL PLAN VIEW Client: Unocal Well: KGSF #2 (P4) Field: Swanson River Unit Structure: Swanson River Scale: 1 in = 200 ft Date: 29-Apr-2002 Schlumbepgep -600 -400 -200 0 200 400 , 600 , True North Mag Dec ( E 20.90° ) 200 _.......................................... -Proposal -Survey Top ofWhfp.tock Ea.. WIndow 6016 MD 6012 TVD 6028 MD 6024 TVD ....-.....-.............."""m""""--"''''''''''''''''''''''''''''"""'-'''''''-'''''''''''-'''''''''''''''''''''-'''''~711ß:-'I16~~''~1,_...,,,"'m',', "-¥'~'-1W.~.?:_~~_....""""""-'"'''''-'''''''''''-'''''''''''''''''""''''''''''-''''''''''''-'''''''''''''.....''''''''''''''''''''''''''.............. - 200 \ ~, 12-27 ^ ^ ^ :r: J- œ: 0 z 0 -..................-...........-...........-....-......-.....-.........-............--..........--...................................-......"......................--................--.-.......-.....-........""-...............................,. ...-.... ~~ ~. ~"C; $ .~ -200-..............-..........................................-.-"""""'-""''''''''''''''''''''''''''-''''''''''''''''''''-''"""""'''"""ð.6~'''''''''''''-'-'''''''''-'''''''-''''''''''''''... ~ KOP Cry '01100 6058 MD 6053 TVO 2.17' 1P.85' az 66 N 111 E End Cry 6359 MD 6247 TVD 89.66' 225.00' az ""-''''-''''''''''''''''''''''''''''''''''''''-''''''''''''''''''''''''14S-..10.W...........................-......-.--..............,,,-,,,,,,,-,,,,,,,,,,,,,,-,-,-,,,-,,,,,,''''''''-''''''-'''''''-'''................-...-"...."..............."..",...--200 :r: J- :J 0 en -400 V V V - - -400 TD 6859 MD 6250 TVO 89.66" 225.00' az 4285 364 W -600 --600 -600 -400 -200 «< WEST 0 200 EAST »> 400 600 ~ UNOCAL Report Date: Client: Field: Structure I Slot: Well: Borehole: UWI/API#: Survey Name I Date: Tort I AHD I DDII ERD ratio: Grid Coordinate System: Location Lat/Long: Location Grid N/E YIX: Grid Convergence Angle: Grid Scale Factor: KG SF #2 Proposed Well Profile - Geodetic Report April 29, 2002 Unocal Swanson River Unit Swanson River / SRU 12-27 II I lit)' 12-27 SlIlbl I KGSF#2 Fea 501331015201 KGSF #2 (P4) / April 29, 2002 108.203° 1844.62 ft /5.001 10.13E NAD27 Alaska State Planes, Zone 4, US Feel N 60 45 29.084, W 150 50 40.04C N 2469986.400 ftUS, E 348967.~00 ftUS -0.73685496° 0.99992596 Schlumberger Survey I DLS Computation Method: Vertical Section Azimuth: dy Vertical Section Origin: U . TVD Reference Datum: st TVD Reference Elevation: Sea Bed I Ground Level Elevation: Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North.> True North: Local Coordinates Referenced To: Minimum Curvature I Lubinski 224.110° N 0.000 ft, E 0.000 ft KB 192.5 ft relative to MSL 170.000 ft relative to MSL 20.898° 55451.654 nT 73.583° May 30, 2002 BGGM 2001 True North +20.898° Well Head i~~"-. Grid Coordinates Geographic Coordinates Station ID I MD I Incl I Azim I TVD I VSec I NI-S I EI.W I DLS Northing I Easting latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) Top of Whipstock 6015.73 2.00 74.00 6011.54 -128.80 66.88 116.05 0.00 2470051.78 349084.49 N 604529.743 W 1505037.704 Base Window 6027.73 2.77 117.85 6023.53 -129.06 66.80 116.51 16.00 2470051.69 349084.95 N 604529.742 W 150 50 37.695 KOP Crv 30/100 6057.73 2.77 117.85 6053.49 -129.46 66.13 117.79 0.00 2470051.00 349086.22 N 604529.736 W 1505037.669 6060.00 2.65 132.05 6055.76 -129.48 66.06 117.88 30.00 2470050.93 349086.31 N 604529.735 W 150 50 37.667 6080.00 6.43 200.79 6075.71 -128.47 64.71 117.82 --30.00 2470049.58 349086.23 N 604529.722 W 1505037.668 6100.00 12.15 212.61 6095.44 -125.38 61.88 116.29 30.00 2470046.77 349084.67 N 60 45 29.694 W 1505037.699 6120.00 18.05 216.86 6114.74 -120.23 57.63 113.29 30.00 2470042.56 349081.61 N 604529.652 W 150 50 37.759 6140.00 24.00 219.05 6133.40 -113.10 51.98 108.87 30.00 2470036.97 349077.12 N 604529.596 W 150 50 37.84~ 6160.00 29.97 220.41 6151.21 -104.06 45.01 103.06 30.00 2470030.08 349071.22 N 604529.528 W 1505037.96 6180.00 35.95 221.36 6167.99 -93.20 36.80 95.94 30.00 2470021.96 349064.00 N 604529.447 W 150 50 38.109 6200.00 41.93 222.06 6183.54 -80.64 27.42 87.58 30.00 2470012.69 349055.52 N 6045 29.354 W 150 50 38.277 6220.00 47.92 222.62 6197.69 -66.53 16.99 78.06 30.00 2470002.38 349045.87 N 604529.252 W 1505038.469 6240.00 53.91 223.08 6210.29 -51.02 5.62 67.51 30.00 2469991.15 349035.17 N 604529.140 W 1505038.681 6260.00 59.90 223.48 6221.21 -34.28 -6.57 56.03 30.00 2469979.11 349023.54 N 604529.020 W 150 50 38.912 6280.00 65.89 223.83 6230.32 -16.48 -19.45 43.74 30.00 2469966.39 349011.08 N 6045 28.893 W 150 50 39.159 6300.00 71.88 224.15 6237.52 2.17 -32.87 30.79 30.00 2469953.14 348997.96 N 604528.761 W 1505039.420 6320.00 77.88 224.45 6242.73 21.47 -46.68 17.31 30.00 2469939.50 348984.31 N 604528.625 W 150 50 39.691 6340.00 83.87 224.73 6245.91 41.20 -60.73 3.45 30.00 2469925.64 348970.27 N 604528.486 W 150 50 39.970 KGSF #2 (P4) report.xls Page 1 of 2 4/29/2002-4:25 PM Grid Coordinates Geographic Coordinates Station ID I MD I Incl I Azim I TVD I VSec I Nt-S I EI-W I DLS Northing I Eastlng Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (ot100ft) (ftUS) (ftUS) End Cry 6359.31 89.66 225.00 6247.00 60.47 -74.39 -10.14 30.00 2469912.15 348956.51 N 60 45 28.352 W 150 50 40.244 TD 6859.31 89.66 225.00 6250.00 560.40 -427.94 -363.69 0.00 2469563.20 348598.46 N 604524.870 W 1505047.359 Leaal Description: Surface: 3681 FSL 4247 FEL S27 T8N R9W SM Tie-In: 3747 FSL 4131 FEL S27 T8N R9W SM BHL: 3253 FSL 4611 FEL S27 T8N R9W SM Northina (Y) rftUSl Eastina eX) rftUSl 2469986.40 348967.60 2470051.78 349084.49 2469563.21 348598.47 -'> KGSF #2 (P4) report. xis Page 2 of2 4/29/2002-4:25 PM UNOCAL8 ~ nson River Unit Kenai Gas Storage Facility #2 Proposed Completion 5/16/02 RKB= 191' AMSL ¿ 11 I 2 ~ SIZE WT GRADE 13 3/8" 54.5 J-55 9-5/8" 40 N-80 5-1/2" 20 & 17 N-80 CASING DETAIL TOP BOTTOM 0' 2943" 2736' 7228' 0' 11,492' (original hole) (window @ 6000') TUBING~ TAIL PIPE~ and SCREEN DETAIL: 2-7/8" 6.4 L-80 IBTC S.C.C. Tbg (cemented) 0' 6859' PROPOSED JEWELRY DETAIL NO. Depth Item 1. +/-500' Methanol injection port (ID= 2.312") 2. +/-530' TE-5 TRSV (ID= 2.312) ."0" ;.:-:.:.:- '"0" "'"0""" "0" ,',".',".' . . . . . . . . .. . . . . . ,'.°, ,",'.°,'." 0"" ".'0°,0," ,'.°,- ,",',','." .'0°, ,',',',',' . . . . . . . . .. . . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .' . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ".'," ',','.".', . . . . . . . . ,',', .",'.'.'," . . . . . . . : . :.; . . . . . :- ;. ;. : -: . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .:-:. ~<-:.:-:-:-:-: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . , . . , , , :::::::::::::::::::: ::::::::;:;:::::::;: ~H~~ ~~~H ~~,~~~~~~~~ ,',',",'.',','.',',' ,',','.'.','.'.',"." .'.'.".",' '.",',",' :~:~:~:~:; "::~:~:~ . . . . , " . . . . , , ., . . . . . . . . , . ' , , . . , . . , , . . . . . . . . '.','.'.'. ". . , . , . , ',','.','. '.','.','. :::::::::: :::::::::: '.'.'.'.', ':-:-: -:.: '. '. ~::" "::1 :,"1 /' 2-7/8" tubmwess completion ,,""""'"" (perforated throughout horizontal section) ""IHHIHm~IITnmllmIHmIIlHHI'miiT !!i!!!"\""",,,'JIH(HlIHHIIHIIUWJIIHII~UIIJIH~~ :Ii! ilii" 2-7/8" tubmg cemented to 500' above window TD = :t6859' MD/6250'TVD KGSF #2 Prop Schematic.doc Drawn: OS/26/02 DRAWN BY: JFB UNOCALe HZ L: ~~~S:~~k ~¡¡¡: ¡¡¡¡¡¡¡¡¡ :i6000' MD »<:~ (:iIOO' abov~> <~:~: tbg cut) : . . . . . . RKB = 191' AMSL . . . . °.'.'.°0°. ,°, 1 :::::::::: ::: í><¡:;:] L.:.'.:~ Proposed log ~ cut @ +!-(. IIII_~' : .:.:. : Proposed Cement Squeeze . .~' OP'"!¡~ ():o ~J 13. . '. '\..::::::: ~¡¡¡~ :r ~ 'DV tool @ 8178' H2 SQZD & isolated (wet) H3 (open - to be squeezed) H4 (below top of fill & isolated) H5 (isolated) TD = 11,500' MD, 5 ~" shoe @ 11,492' MD SRU 12-27 Prop Abnd Schematic.doc ~. nson River Unit \Veil SRU 12-27 Proposed Abandonment 5/16/02 CASING DETAIL SIZE WT 13 3/8" 54,5 9-5/8" 40 5-1/2" 20 & 17 GRADE J-55 N-80 N-80 TOP BOTTOM 0' 2943" 2736' 7228' 0' 11,492' TUBING & TAIL PIPE DETAIL: 2-3/8" 4.7 N-80 8rd EVE. +/-6100' NO. 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Interval H2 H3 H4 H5 10,820' JEWELRY DETAIL Depth Item +/-6000' EZSV cement retainer - proposed 10,617' Otis 'XA' sleeve (open) 10,650' Brown HS-16-1 packer 10,717' Brown HS-16-1 packer 10,721' Otis '8' nipple 10,750' Otis 'XA' sleeve (open) 10,752' Brown HS-16-1 packer 10,757' Otis'S' nipple 10,780' Otis 'XA' sleeve (closed) 10,803' Baker Model 'F' packer 10,807' Cameo 'D' nipple (w/ 'CA' plug set onside) 10,821' E.O. T. (WLEG) . 10,892' CIBP (Note: 57' fish (23/8" tbg) on top ofCIBP- not shown) PERFORATION DETAIL From To Comments 10,704' 10,710' Squeezed 10,726' 10,750' currently open 10,760' 10,790' isolated by closed SSD & fill 10,810' 10,832' isolated by 'CA' plug & fill Note: DST & block squeeze perfs are not shown in order to simplify diagram. Drawn: 05/30/02 DRAWN BY: JFB '..;',1'" i/!'¥'" .,ii~.~ ;., ~t:::1 ~ ~..l ." "'. .. , ,. I'" .. - ... , ~ -,,'>Y K.B. 19r '" , " i .. 176 K".B., '!'O TUBInG HANGEn 21.G:1 ¡ ~U';~Tr',. 11--.'GER t," : .i 0.1_'...1 ~U1. .....1..11 X-eVER. ' 1 . 1.3 p PUP JT. (10.18'~ 6 JTS. 2%" EUE TOO. 198.~1.;;1 - 221.J5'-;- GrlS BALL VALVE ' , " ' 5.2'/; .~ , t ~ D.V. 10 IS' . ' , ~3 . .ITS. '2%" EUE 8rd TDG. ' 1 G'j7. '4'ì; q i - 1864.09'""")- CAI.%:O }~1 MA.tIDP~L . . .' .'. .' ..' 13.06, ~:l " , !. fTC' 8 d. . 00. , . .. .' '46 J'l'S. 2~ Ew:. r T ..' . .,' . '424.~.9~ . '\ 2943 , .' .. '~ . ~ 0 :~- 3301.64'->- CA!':CO 1.:~ JI.A}IDREL ,." '. '. . ". . '. .'. . 13.15!: . ':. . . . ,,' o' 32 JTS. 2.~.t1 EuE ~rd TBG.' '. .. 992.29 ' .. ... '.. .. . D .. -4307.08J"")-~A.~0 MM MANDŒÚ " .'. : .' .' ,. :..:".~ :'i.:. 13.07 .. : ~ : " ," . .,. . . '.' , ' 3". .' .' ,Þ' >.: . t.. t ~ " ".., ." ," ", '. ': 20 JTS,.2~ E~ .8rd! TEG. " '. .' 6,19.1;1 C\.J ..... .. .. :..... ... .. . ... . ...... 0::. ... 'ft ..... ... ....: p - 4939.30 I /- CA!~? !1M MANDREL . .': ":'. >: . '..: ..t.';: '.' , ..,.' . '13.01, :E: "'.,', ,.'" " '. ,u.J' I ,',' ' ',' .. ,.", 15 JTS-2~" EUE'8rd ''rBG .:, " .:., .' ':;' ., 4!£J 64 !.: : . , I ! 0 .;. . '. 0 . . . .~.. ."'0 . . :.~<: o~. .:.;.: . .: . . Ø) - 5412..95 CA1-1CO Mr4MA.NDREL ''', . " ",:::... !>:'"~~~: "': "., 13.05 ..f , ...' -, .~ 9 JTS. 2%n' ~Œ 'Srei TOO... "7:~"'" ,281.:39 I -.. .~' I - 57C17.39t CAt.~O l"n~ l.fANDREL ' ..' .~ ". .-':~ ' 13.06 ~... ~ S". . ')"'~ ..~ ,.' ,V'; '. 9 JTS. 2'á':' 'EUE 8rii'TOO.' . .' '.:" ,.70. !.~I ....":~'~':,' -, 7119' ~~/ . -5998:921 , C.A!.:CO l~.f JwJAl;JJÈEL '. ... : .~< ,"':'~"", ":'~':"';:~"""~' .:. 12.83~ '~. 0 '..,J: I~C.~7208 ,.., ,:.': '. '.':':':'0 0'.. <: ~/ .¿;':, ,..7228 A::> a... . 0 .' o' .' . '. '1/0 ""'s r- EUE ,8 d ..TBG' . '::.'. :.", 4605 0' .""''';'''''¡:''~: , -L o. '. t.q.U, ,~,., ... .7á , r . .' .. .,. ~ ~!¡'!:¡:!'A: "'. . ~ " Þ V. 8 t 7 e .' . '0- 'h" , .' , ..-."C.:~~(.~. .f:.J;. .~\ ..... r " . . . '... ." -, .. ~;.~~~,.~.(~~: :. !\.\ \ ~' . -10 616 79 ~ r. , or, IS 'nv "ft S~~'VE' 2:!lft""" '. :." : . . ". ,.." .":': 2 46: . :r,¡(;'~:ì' .. '^~~ . . 0' .. AA ~ i ""'. "... . ".'.:^f~;:~I...' , V;l' ,1/]" :'. . ,.." 0 . ..', '.' '.',.,' , . ~~ìt,:.:~. . ::J '. .."." :1'."'" ?~a EUE '8rd -.roo ....: '.,... '.:', .:.. 31 06 . ~~1;.. ".' " .. . -'. . 0 . ' ,,¿ . -. '." . . . ., . ~ " . , '~~tÆ~ ":: . .' ,.' :8 ~ -10,6~~3t'''';~ BROWtf .1IS-1~~ HID. .1'~ 2%n. 'xSìn. .'. 3.9.6: : ". "'.: ¡~~"H2 ~. ,;',~" Sß<ð }vJ.~í If1 . '172, "~ JTS... 2%11, EUE SrdTBG.<"": ,:. .' : 00: : 62.80' ":'. it' >(' --10.,717.b7' BROWN KS-16-1" ~.. PACl:ER 2%". 'X. ~ . . .:: .,'~' :3.94' ..:'.lioi.' c: :5 1---:10,'721.01',.. arJS~.~1r t:IPPI:E',' Position ,13.,...-:,.. .J.:'.;/"'.','. ..,..,...,:~.;..:'~ . 1.~O, . ;;'~':", S~D.! : 2' .. ,. BA1~R BLAST JT. " "" .,....; :.." 20.", ; =~.-:~"~'~~""~"::~'O . H'3": .: -10,7~..'82f BROWN .CCh S'.!L~TI JT.' '.:""'" .:~" .'.'. ".'.' .92, .' . ¡.to.' '. . : : . . ' , 'BAr,£R DIJ~T JT.' .. . ',," 6.10~ f.:; '., oP~~..~. ..:S¿'-'OJ~49.&4r trr1S .XA" SI..ESVE 2%"""" :. .: '.' " '. ' '~ . 2.86~ -. ..~, to."'!" Xl -10,t¡'52.70' - ÉRo:ü: }!5~16":1 HID, 'PACKER 2%" x ~,,".' , 3.94' ",13 II{))S I ~ l!.J~ 10,'156.64,' OT15 I\Stl ,N~PRŒ"Po:sition i,..l... ,.j' '..: 1.50 1,~~,tr~H4' : : .Flu... 10/'&4- .- 'D4\IŒRB.LAS1 JTS~ & pup2Jån I~~: "', :.. ~'o. /07'5'S' "'. '(20.318)'(5.0BI)(1S.00.')'(~UP 1.0~') '41.48: ',~~, St.'Þ ~ --I'O,799~62t~, 0I'1S "XA" SLEEVE 2%" ":'" . :.' ..:".' - 2.88, Ff v.o 1'6-~ =,10,B02,,?: STOP SUB . 0 . ... . '.' . '.' .5~ J...;. 'J-J XI ()( '0,80j.00 'STOP SU;\ &: ~~!lt m{TI'S INSIDB MOD.' "F" PACKER 4.6:'); t'.f¡..: . ~ ~ '''I~ 10,807.69' , CAMeO "D" NIPPLE (~,1'urnod dow coll:lr) , . .93 ~<' H 5 ~ ~ IJ 1C- CA PuJG ?f-1' IO~ 72 . to. I11!> J'I. 2\" Eœ TOO. CUT. ~:F .CJ 450 12. 12 : (.-'."." '". ~.¡ ~. : -:--10,820.741-. Top ot Tubing , . '.' f . .' ' M,S.O, - I' . 32 -. '. '. '.) ¡.' 108"1" ~..,.. I stub (j¡'10gJ,' , '..., '.' . ~'-~..~'! '.'.~ ~. -:-~g';::' . Top of P1U¡:. .' .' SR,~..,;d"~Çf~:?,7:... ;F:";\~ ~. ~~I~.~6' I 1 CA.S IN G '..a .:;.,T.U.J31 N G DE TAIL, . f~t> '~X -11,.395' ",' Top or p~ SECT.I'~~:'::,~~';!8,~..,R.Ð.W~",:;,,'_.. ~~r,ii.~t.~~:~~.9?' ~4. - d... If 1 1:(\,-' J '. . . . .. '. . 15' . . '. (...~ I I i'" " f{)" II') . -:. It lit') .¡. " .4 0 It) ".~ CD ~ .. ..... .,~=t. . . I t ~: ~ Z if';£.. 2736' :..¡~ III. .. .!~, ~~:~.:;; 0 .. ~,C() f~' N Pn b.,~ho!~.- fI ----:..Ao ~.~:"'f.2~\~';"~, ~ ~ ~~~'.: o' . '.:',' .. 4037 ~ 'l~~~ . ~'I . ,':~ . 0 0 ~~~~;"I ! ~, ~ \"~!i;¡;'" t: ~ t}Z;~ .~ .". l Þ II ." .1 ~;.:~~ .-. ~. Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 ( UNOCAL8 Jim Harrison Drilling Manager 05/31/02 Alaska Oil and Gas Conservation Commission 333 West ¡th Avenue Anchorage, Alaska 99501 Attn: Commissioner Cammy Taylor Re: Permit To Orill Application (Form 10-.401) Kenai Gas Storage Facility Well #2 Swanson River Field, Kenai Peninsula, Alaska Commissioner Taylor: Enclosed for your approval is a completed application (form 10-401) for a Permit to Drill the Kenai Gas Storage Facility Well #2. It is our intention to abandon the completion in well SRU 12-27, sidetrack, and drill to establish a horizontal completion in the 62-5 Tyonek Sand. A Sundry Application (form 10-403) for the planned final abandonment of well SRU 12-27 is also enclosed for your approval. Additionally, in order to utilize the subject well as a gas storage well, an Application for Injection order for Gas Storage Permit to Inject was filed with the AOGCC and the Bureau of Land Management on March 6, 2002. Subject to AOGCC approval, it is our intention to sidetrack from the existing vertical wellbore at :t6016' MO/VO, through the existing 5 %" and 9 5/8" casing strings, and drill :t300' of 4 5/8" hole to land horizontally in the 62-5 Tyonek Sand, followed by drilling :t500' of 4 5/8" horizontal hole to a total depth of :t6859' MO /6250' VO. The completion will consist of a 2 / 7/8" long string cemented from TO up to :t5516' MONO, which is 500' above the window. . Your earliest attention to this application will be greatly appreciated, since we would like to begin work on approximately June 15, 2002. If additional information is required, please contact Jerry Bowen at 263-7640. Sincerely, Jim Harrison Drilling Manager RECEIVED JUN 0 3 2002 Alaska Oil & Gas Oons. Commtssion Anchorage . AOGCC re-drill cover letter.doc JFB c> FOR INQUIRIES CONTACT LOCATION WHERE INVOICES WEnE SUBMI1TED VENDOR NO. DATE CHECK NO. -ÇJ 31-May-02 2006793 DATE INVOICEICREDIT MEMO NO. VOUCHER NO. GROSS DISCOUNT NET ------ -- 31-May-02 100.00 100.00 II) ~ ~ RECEI\'ED JUN 0 :3 2002 .- ~..GasQÞns. Gomssjoo Mdmrage r .// - J.-A, '-L ,.., I~ '?(././~--¿ ;d þ'l1/¿G _SV'é'-.LYf;¥/ílj..t.t7;JL'T7CC,¿ I ';;;;:L FORM 4.28181 (REV. 11-95) PRINTED IN U.S.A TOTAL þIr. DETACH STUB BEFORE DEPOSITING CHECK -~-~--~--~--~-_._------_.-~---. 100.00 100.00 --~-~---"----_._--~-~ A Subsidiary of Citicorp ONE PENN'S WAY NEW CASTLE, DE 19720 Union Oil Company of California Accounts Payable Field Disbursing 2006793 UN8CALe Pay One Hundred Dollars And OOCents******************************** _. Date 31-May- 0 2 Check Amount 1 0 0 . 0 0 * * * * * of 333 West 7th Ave. Anchorage, AK99i5!Ol Void after six months from above date. ~ "1<-- D.A. PAGE MAY 3 1 2002 III 200 ß?g:¡uI.: 0 :¡ ..00 20 g I: :i g . . a . :i 7,,8 . -...~............ """" '." . CHECK 1 ST ANDARD LETTER DEVELOPMENT DEVELOPMENT RED RILL EXPLORA TION INJECTION WELL INJECTION WELL REDRILL v Rev: 5/6/02 C\jody\templates ( ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API number last two (2) digits are between 60-69) PILOT HOLE (PH) \~(~S ç- \:L ~ "CL UE" The permit is for a new wellbore segment of existing well ---' Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). ANNULAR DISPOSAL Please note that an disposal of fluids generated. . . INTO ANNULUS OF ANOTHER WELL ON SAME PAD l--> Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order. approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. /) ~et( WELL PERMIT CHECKLIST COMPANY ()þtoC~ / WELL NAME k.. <95> F 'Z-- FIELD& POOL 7/ 2.,~.- !!k INITCLASS ..s~. 65TtJ/2.. ADMINISTRATION 1. pe~it~~tiãch~~. . . . . . . . . . . . . . . . . . . . . ~N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . .' 'N ~: ~~~~~c~~~~~~:ed:~~:du~:~r...: : : : : : :.: : :: :. : : ~.~ ~ ~~wd~~ 4J-;/( k ~(o-þ-.~ð4M 5. Well located proper d~stance from drilling U".n. i.t.,boUndary. . . . .' N ç,;,2.- 5" ~ . ~. --rJ...:i. ðó( e.~ ¿~., A L~-,!Þ 6. Well located proper distance from other wells~ . . . . . . . . N .f... Æ-r'~ ~ ~Z-S-. ~ ~ ~ z.1 Z - z. 7 /~ 7. Sufficient acreage available in drilling unit~~ . . . . . . . . . . N . ~ ../t.X¡" ¿ 4Þ~#Þ?t-,,t?. . 8. If deviated, is well bore plat included.. . . . . . . . . . . . . . N "¡"~ ,¡(~. 2t.'./~~ ~~~¥2$"Z,.(~: \('"3:) ~ (<; )C~')? + t~~;( c~~"Þ...-J 9. Operator only affected party.. . . . .. . . .. . . ...' .. . . ~~. a 5..:l.d .~..~":f ~(- 'Æ_,;.,4-P ;é, /Ý ;u..t".- ~'-'5. APPR DATE 10. Operator has appropriate bond in force. . . . . . . . . . . . . N ¥'-~ ~ ~7 6,~ ... I tR. /r :11--11. Permit can be issued without conservation order*",Ú". . . . N.' ..' ' tI /7' /. A"""Ið ." - d ... / /';:;/-3-".lt; ...,S. '. t. 12. Permit can be issued without administrative approval.. . . . . N ~, .~. ~~er-r~.. " ~~.' +t. ~ (.;;/~, ~ v I' ~ ~' ~ (.ið 13. Can permit be approved before 15-day wait.. . . . . . . . . . N ~¿~/t ¿~r ~¡c-a... hc:~ ~q'¡"'~ . 14. ACMP Final Consistency Determination issued for this project 411 Y N . ..L-'l-f ~~ ~.4...t/ { 15. Conductor string provided. . . . . . . . . . . . . . . . . . . '-¥--f'.J-.. . /". . 16. Surface casing protects all known USDWs. . . . . . . . . . . /JA.. Y t4. .$~~~L. t:.y ~/$-h:J èeJrl!/1 .. 17. CMT vol adequate to circulate on conductor & surf csg. . . . . --¥--N- I'oi/j;- 0 18. CMT v~1 adequate to tie-in long s~ring t~ surf csg. . . . . . . . ~. y , N 19. CMT will cover all known productive hOrizons. . . . . . . . . . . N 20. Casing designs adequate for C, T, B & permafrost. . . . . . . . " N 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N 22. If a re-drill, has a 10-403 for abandonment been approved. .. -Ie Y N 23. Adequate wellbore separation proposed.. . . . . . . . . . . . (j) N 24. If diverter required, does it meet regulations. . . . . . . . . . 1N Ai./k- 25. Drilling fluid program schematic & equip list adequate. . . . . , ,. N 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . '. N r 27. BOPE press rating appropriate; testto 3000 psig. . N ¡Vi So P =- 2-5 'N fS,t , 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . " N 29. Work will occur without operation shutdown. . . . . . . . . . . . ~ 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y ~ . 31. Permit can be issued wlo hydrogen sulfide measures. . . . . Y ~ - /J / ,-¿- / / /J 32. Data presented on potential overpressure zones. . . . . . . Y'N ~,.¡...,.R ~ '"'--UL (.-q //.~ #I...J( .¡, . ~'-?T IL~ ' . 33. Seismic anal~~is of shallo~ gas zones. . . . . . . . . . . .. )J'A Y N AP~ DATE" 34. Seabed condItion survey (If off-shore). . . . . . . . . ',....~L Y N ¿:.~ ' 0" S .02.-35-. Contact namelphone for weekly progress reports [eXPI/vry only] Y N . ANNULAR DISPOSAL 36. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . Y N . I I- APPR DATE (B) will not contaminate freshwater; or cause drilling waste. .. Y N Æiot F? UcÞ;t-f j . to surface; Q (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage formation or impair recovery from a pool; & Y N (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N ENGINEERING APPR DATE W4* &fr.,fOi- :r2.~ýl (ø {t~ GEOLOGY PROGRAM: Exp - Dev - Redrll - Serv /Wellbore seg - Ann. disposal para req - GEOLAREA 8?1) UNIT# ~///?, ON/OFF SHORE é"5Þ, ) GEOLOGY: ENGINEERING: UIC/Annular: RPC-Q-- ---JEM,t2?/fZ<Olo JBR SFD~ -' WGA \l.J61lf" COMMISSION: COT DTS Commentsllnstructions: b '\<) ~'1 \"E:"-\ o.\>~\)'i .\<ë;~c.t>t'\. (. h ~ -~:;) G: \geology\perm its \checklist.doc