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) ) ¡j ~TO ~kRGY May 2, 2005 XTO Energy Inc. 200 North Loraine Suite 800 Midland, Texas 79701 432-682-8873 432-687-0862 (Fax) RECE'\/ED MAY 0 4 Z005 Alaska Oil and Gas Conservation Commission Attn: Mr. John Norman 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Alaska Oii & Gas Cons. Commission Anchorage Jfus-¡ J~. RE: Well Completion Report: Well C41-23 P&A Dear Mr. Norman, XTO Energy, Inc. hereby submits its Well Completion Report (Form 10-407) for the work performed to plug and abandon well C41-23 on Platform C, in the Middle Ground Shoal Field of Cook Inlet, AK. After the abandonment of the lower portion of the wellbore, the well was sidetracked as the C41-23LN. Please find attached the following information for your files: 1. Form 1 0-407 Well Completion 2. Daily Operations Report 3. Post P &A Wellbore Schematic If you have any questions or require additional information, please contact me at (432) 620-6743. S incerel y, 9~ j. Ý Paul L. Figel Engineering Manager Cc: Scott Griffith Tim Smith S'ANNED MAY 2 3 2005 C-) C\) ¡ (:~ ~ t\.i ii, L c r I ~¡ ~ ~ \i 1\ ALASK.< l AND ~:~T~g~S~~;~ON COMMIS&.1 RECEIVED WELL COMPLETION OR RECOMPLETION REPORT ANDA~W 2005 OilU GasU Plugged ~ Abandoned~ SuspendedU WAGU 1b. Well Class: . r~~ r.O[lS Corrmission 20AAC 25.105 20AAC 25.11 0 DevelopmA\a~ 011 & t:5<'þlõratorY [.J GINJD WINJD WDSPLD No. of Completions Other Service 0 Strat~Rf.u~D 2. Operator Name: 5. D~o~; Susp., or 12. Permit to Drill Number: XTOEnergylnc. CAband"';'/ 1-19-05 ¡ 68-112 3. Address: 6. Date Spudded: 13. API Number: 200 N. Loraine, Ste 800, Midland, Texas 79701 12-17-68 50-733-20163 4a. Location of Well (Governmental Section): Pl a tform C ,Lea 4"; 7. Date TD Reached: 14. Well Name and Number: Surface: Cond 28, 504' FSL, 1532' FEL, Sec 23, T8N, R13W S'.M. NA C41-23 Top of Productive Horizon: 'f~¡=f-?(,.. ~ 8. KB Elevation (ft): 15. Field/Pool(s): 1194'.FSt.., &iHHWL, Sec 23, T8N, R13W, S.M. 105 ':Nt ¡:: 1Ei,- \4-0 9. Plug Back Depth(MD+TVD): 506' féf:., 1243'~, Sec 23, T8N, R13W, S.M. 10535' + 9355' 4b. Location of Well (State Base Plane Coordinates): 10. Total D~1J1JMD + TVD): Surface: x- 231423 y- 2474190 Zone- Ak4 lo."1I')J~07' TPI: x- 232218 y- 2477758 Zone- GN ~Pth vvhere SSSV Set: Total Depth: x- 231811 y- 2478456 Zone- HZ NA 18. Directional Survey: Yes l.::J No U 19. Water Depth, if Offshore: 73 feet MSL ~ ., 1 a. Well Status: Total Depth: MGS 16. Property Designation: ADL-18756 17. Land Use Permit: NA 20. Thickness of Permafrost: NA 21. Logs Run: NA 22. CASING WT. PER GRADE FT. 10-3/4" 40.5 J55 7" 26-29 N80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD TOP BOTTOM TOP BOTTOM HOLE SIZE Surf 1653' Surf 1584' 15" Surf 10593' Surf 9405' 8-1/2" CEMENTING RECORD AMOUNT PULLED o 1945 1350 sxs 900 sxs 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): NA SIZE NA TUBING RECORD DEPTH SET (MD) PACKER SET (MD) 24. 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 2000-2615' 131 sxs cement 26. Date First Production: PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.): NA Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period -. Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity - API (corr): Press. 24-Hour Rate -+ 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". .s.Aba.x~u'H1-~+ NA RBDMS BFL MAY 1 2 2005 , - /~. /&¡~'?$.-: ~-,' ./ ~y ORIGINAL Form 10-407 Revised 12/2003 CONTINUED ON REVERSE NAME GEOLOGIC MARKER' ) ML, " TVD 29. '\ FORMATION TESTS Include and briefly sur.. lrize test results. List intervals tested, and attåch detailed supporting data as necessary. If no tests were conducted, state "None". 28. NONE NONE 30. List of Attachments: Wellbore Schematic & Daily Operations Report 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Paul Figel Printed Name: Paul Figel Title: Engineer Manager Signature: ?aJ /. {.,í Phone: 432-620-6743 Date: 5/3/05 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 1ä: Classification of Service wells: Gas Injection, Water í'njection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for I njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. 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 b~ 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None", Form 10-407 Revised 12/2003 ) ) 1 XTO Energy Inc. C41-23 Daily Well Report Obj ecti va: P&:A Well Rig: Coil Tubing Unit 1st Rapt: 12/31/2004 12/31/04 Unloaded & RU coil tbg unit. Prep to TIH w/wash tool on CT. 1/1/05 1/2/05 1/3/05 1/4/05 1/5/05 1/5/05 1/7/05 1/8/05 1/9/05 - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - -- - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - -- - - - - - - - - - - - - - --- Build Mud Vol. Fin RU CTU & tstg. MU wash tool & washed to 5221/ POOH & SD CT operations for night. Build 9.2 ppg kill mud. Prep to cont clean out w/CT. - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - -- - - --- - -- -- - - - - -- - - -- - - - - - - - - - - - - - -- - - - -- - - - - - -- - - - - - - - -- - - - - - -- - - - - - - - - - - - - - - - - - - --- - -- - - - - - - -- - - - - --- Build Mud Vol & Monitor Well. Disp diesel fr CT. MU mtr & 2-1/2" mill. Washed in hole & mill scale 522'-4,000'. POOH w/coil & SDF night. Build vol & bled well to flow tnk. Prep to cont clean out w/CT. - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - -- - - - - - -- - -- - - - - - - - -- - - --- - - - - - - - - - - - - - -- - - - - - - -- - - - - - - - - - - - - - -- - - - -- - - - - - - - -- - - - - - -- - - -- - - - -- -- - - - - - --- Pmpg 10.2 PPG Kill Mud. Chg1d out mill to 2.7" ODe Milled hard scale 4,0001-9,763'. Circ btms up & pmpd 30 bbls high vis sweep. Prep to CO w/CT. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - --- - - - - - - - -- - - - - - - - - - -- - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - -- - - - - -- - - - - - - -- - - - - - - - - - - -- - - - - - - - - - - - - - - - - -- - - - - -- - - - - - - - - - - - - -- - - - - - - - - - -- - - -- Wash In Hole With CT. Pmpd sweep. POOH. MU 2.59" jet cutter & RIH. Cut tbg @ 8,875'. Loaded CT w/10.2 ppg mud & prep to wash in hole. Prep to wash in hole w/CT. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - -- RDMO Coil Tbg Unit. Washed to tbg cut @ 8,875' w/coil. Circ btms up & pmpd 11.0 ppg kill wt mud. Monitored well - well dead. POOH w/coil. RD CTU & back loaded on boat. Prep to pull 3-1/2" tbg. - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - -- Killing Well w/12.1 PPG Mud. Monitored well - flwg 4 bbls/hr w/press increasing. RU CTU. RIH & disp w/12.1 ppg mud. Prep to kill well & RD CTU. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- --- - - - - - - - - - -- - - - - - - - - - - - - - -- - - - - - - - - - -- - - - - - - - - -- - - - - - - - - - - - -- - - - --- - - - - - - - - - - - - - - - - --- -- - - - -- - -- - - -- NU BOP's. Killed well w/12.1 ppg mud. Monitored well - no flow. RU CTU. ND BOP1s. Prep to ND BOP's. --- -- -- --- - ----- ----- ------ ----- - --- -- --- -- -- --- - -- -- ---- -- - - --- - ------- -- - --- - -- --- - ------ -- -- --- - --- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - --- - - - - - - - - -- -- LD 3-1/2" Tbg. Tstd BOP's. RIH w/tbg spear & attempted to pull tbg free (unsuccessful). RIH w/jet cutter & cut tbg @ 631'. TOOH & LD tbg. Prep to TOOH & LD 3-1/2" tbg. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - -- Attempted to Circ. LD 18 jts 3-1/2" tbg. Ran tst plug & tstd BOP1s, tstd OK. MU & TIH w/3-1/2" OS & jars. Unable to get below 4021 due to fill. TOOH. PU 6" clean out bit & TIH. Washed to 521', flowline plugged off. Attempted to circ & unplug flowline. Prep to TIH w/OS. -- - - - - - -- --- --- - ------ - - - -- - - ---- - - - - - - - -- -- --- - -- - - - - - --- - - - - - - - - - -- - --- - -- - -- - -- - - - - -- - --- -- -- -- ---- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - -- 1/~0/05 MU 6 II Bi t & Clean Out Assembly. Worked on plugged flowline. Washed & reamed to 5811, flowline plugged. Repl section of flowline. Washed to top of fish # 632'. TOOH. TIH w/OS. Worked over tbg & · ' ) ') 2 pulled free. LD tools & 45 jts 3-1/2" tbg. MU 6" bit & clean out assembly to clean out to TOF @ 2/060'. Prep to clean out to TOF @ 2/060' . - - - - - - - - -- - - - - -. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - -- - -- - - - - - - - -- - - - - - - - - - - - - - - - -- - - -- - - - - - - - -- 1/11/05 Fishing 3-112" Tubing. RIH w/611 bit & clean out assembly to 2/060'. TOOH. PU 5-3/4" OS & TIH. Worked over fish. TOOH, no recovery. TIH, worked over fish. TOOH, recovered 1-112 jts (ttl 65-1/2 jts LD). Prep to fish 3-112" tbg. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - -- - - --- - - -- - -- - - - - - - - - - - - -- - - - - -- - - - - - - -- - - -- - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - -- 1/12/05 Fishing 3-112" Tubing. Made 3 fishing runs, recovered 4 jts (ttl recovery 69 jts). TOF @ 2/217.15'. TOOH @ rept time. Prep to fish 3-1/211 tbg. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - -- - - - - - - - - - -- - - - - - - - - - - - -- - - - - - - - - - - - - - -- - - - - - - - - - - -- - - - - - - - - - - -- - -..... -- - - - - - - -.................... --..... - - _.........................- 1/13/05 washing Over 3 -1 12" Tubing. TOOH / no recovery. PU & TIH wi shoe & 20 jts 5" wash pipe. Washed over fish to 2/283', MU new shoe & TIH. Prep to wash over fish. - - - -- - - - -- - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - -..... - - - -- -..... - -..... - - -..... - - - - - - - - - -- - - -..... - - - - - - - -..... - - - - - - - - -..... - - - -- - - - - - - - - -- - - - - - -..... --..... -..... - -.......... - -..... - - - - - - - - - - - - - -..... - - - - - - - -..... - - - - -..... -- - - - - - - - -..... - - - - - - - - - - - - -..... - -..... - - - - - - - - - - - - - -- 1/14/05 Washing Over 3-1/2" Tubing @ 2/572'. Washed over fish to 2/505'. TOOH, chg1d shoe. TIH & washed over fish to 2/572'. TOOH for new wash shoe. - - - - -..... -..... -..... -..... - - -..... - - - - - - - - - -..... - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - -..... - - - - -.......... - - - -..... - - - - - - -.......... --- -- - - - - - - -- - - - - -..... - - - - - -..... -- -..... - - - - - - - - - - - - - - --..... - - - - - - - - - - - -..... - -..... --- --.......... - -.......... - - -..... - - - - -- - - -..... - - - - - -- - - - - -- -_.....- 1/15/05 Fishing Tubing @ 2/582'. TOOH, LD 300.17' of 3-1/2 II tbg wi OS (unable to work over fish). TOOH. MU & TIH wi concave mill. Milled 2/572'-2/582'. Pmpd sweep & TOOH. Prep to fish 3-1/2" tbg. - - - - - -.......... - - - -..... - - -..... - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - -.......... - - - - - - - -..... - - - - - - -.......... - - - - - -.......... - -_..... - - - - - -- - - -..... -- - - - - --..... - - - - - - - - - - - - - - -..... - - - - - - - - - - - - - - - -..... - - -.......... - _..... -.......... - -- - - - - -..... - -..... - - - - - - - - - - - -..... - - - - - - - - - -- 1/16/05 Fishing Tubing. TOOH / LD mill. MU OS. TIH. Worked over fish. TOOH. Recovered 11' of tbg. Made 2 runs w/OS, no recovery. Prep to fish 3-11211 tbg. = = = = = = = = = = = = = = == = = = == = = = = = = = = = = = = = = == =::::::::: = = = = = = = =:::: = = = == = = = = = = = = == = = = = =::: = = = = == = = = =:= = = == = =:::: = = = == = = = = = = === = = 1/17/05 Fishing 3-11211 Tubing. TOOH, tstd BOP's, OK. PU mill. TIH & milled fr 2/590'-2/599'. TOOH. MU burning shoe & TIH. Washed over fish @ 2/599'. Prep to fish 3-1/211 tbg. = = = = = = = = = = = = = = = = == == = = = = = = = = = = = = = = = = = = = = = = = = = = = = = =::: = === = = = = = = = == = = = = = = = = = =:: = = = = = = = = ==:::::: = = == == = = = = = == == = 1/18/05 POOH For 7 II Csg Scraper. Attempted to burn over fish, unable to get to TOF. POOH, PU 41 extension, TIH. Worked over fish & POOH~ Recovered 22 jts of 3-1/2" tbg. PU mill & milled 2/618'-2/625'/ TOOH. PU OS. TIH & attempted to work over fish. TOOH to PU 7" csg scraper. Prep to run csg scraper. = = = = =::;: = = = = = = = =:::= = = == = = =::;: = =::: = = = = = = = = = =:=:: = = = = = = = = = = = == = === = = = = = = = = = = = = = = = = = = = = = = = =:= = = = = = = = = = = = = = = =:= = =:::: = = = 1/19/05 WOC. LD OS/ no recovery. RIH w/7" csg scraper to 2/625' / TOOH. MU Baker 3BB K-1 cmt retainer. RIH & set @ 2/615'. RU BJ Services & pmpd 27 bbls(131sx Cl G) cmt plug. TOOH & WOC. Prep to dress cmt / plug. - --- ---- - - - ----- --- --- -- - ---- --- - -- - ---- - -- - ---- - -- -- -- --- - ---- --- - --- -- ----- ---- ---- --- -- ------------ - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 1/20/05 ND BOP's. MU 6" bit & TIH. Dressed off cmt plug @ 2/000'. TOOH. MU 711 csg cutter & TIH. Cut 711 csg @ 1/950'. TOOH. Redressed cutter. TIH & cut 7" csg @ 45'. ND BOP's. Prep to pull 711 csg. ·' ' ~TO ~kRGY MGS C41-23 WIW Cook Inlet, Alaska Leg 4, Conductor 28 API No.: 50-733-20163 Spud: 12-17-68 Surf Csg: 10 3/4", 40.5# J55 BTC. Set @ 1,653'. Cmt'd w/1 ,350 sx. ') Current P&A --- ~ljil1lìl CIBP @ 2615'. Spotted 131 sk cmt. TOC @ 2000'. (1-19-05) Longstring: 7", 26-29 Ib N80 BTC. Set @ 10,593'. Cmt w/900 sk. TOe by CBL @ 7,800'. 26#: Surf - 8,450' 29#: 8,450 -10,593'. Deepest Coil Tbg Mill Depth @ 9763'. (1-3-05) Fish: RBP 10,509' (9/87) P~: ,..,36 T~ 10,712' > > . J,,,,,, ~l...·,"."<"· ~""""I i·'·~:':' ,I' .~"...:~..~?: ;ræ.."...'.' ~"'''''' ., " ~rs,·.,..·.:.'..,;,."......:,.",., ' , /1.,'",.,' ,I . :~":\.,, ,I -- -.J, Ir':/,'.'""'..'. ø...'x, ~t ~ Þ-" ' &r-,..;:i' f2S7~ ~'- . ( ~ ) PLF 1-20-05 KB: 35' Water Depth: 73' MSL Tbg: 3 1/2", 9.3#, N80 EUE, AB-MOD @ 10160' Set 1 0-11-87 31/2" Otis "X" Nipple (2,75" ID) @ 8863' MD (7891' TVD) Baker "E" Anchor Seal Assembly @ 8895' MD (7920' TVD) Baker FB-1 Packer wI Mill Out Ext @ 8898' MD (7920' TVD) 31/2" Camco KBUG wI Dummy @ 9295' MD (8269' TVD) Baker "G" Locator wI 2 X-Seal Units @ 9579' MD (8529' TVD) Baker FB-1 Packer wI Mill Out Ext @ 9582' MD (8529' TVD) 31/2" Otis "X" Nipple (2.75" ID) @ 10123' MD (8994' TVD) Baker "G" Locator wI 2 X-Seal Units @ 10155' MD (9023' TVD) Baker FB-1 Packer @ 10157' MD (9023' TVD) 9/12/87 Sqz csg leak 2,123-59' w/ 50 sk. TOF @ 2625' (1-18-05) Tbg Cut @ 8875' (1-4-05) GN-GO: 9087'-9108' GR-GS: 9450'-9495' HC-HN: 9706'-10147' (Sqz in 9-87 w/1 00 sk) HN-HR: 10180'-10235' HR-HZ: 10254'-10316' HR-HZ: 10340'-10480' Re: C41-23 ') ) Subject: Re: C41-23 From: Paul_ Figel@xtoenergy.com Date: Thu, 27 Jan 2005 07:58:45 -0600 To: Thomas Maunder <tom_maunder@admin.state.ak.us> \<0<6-'-\ \ )" Sorry Torn, I've been out of town from Sat through Wed. Most all the 7" was cut & pulled except for the last 300'. They metal munched down to 1945', 5' above the 1st cut @ 1950', and started spinning on the stub. They set the kickoff plug on Tues. Tagged TOC @ 1665', 12' below the 10-3/4" shoe. Last night when I got in, I found out that they could not get the 10-3/4" packer through the wellhead to test the surface casing & contacted the AOGCC. In lieu of the packer press test, a equivalent mud weight leak off test was going to be done before kicking off. Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 432-620-6743 Mobil: 432-553-5217 Fax: 432-687-0862 SC(;C\NNED MAY 1120mi Thomas Maunder <torn maunder@admi n.state.ak.us> To Paul Figel@xtoenergy.com 01/26/2005 11:27 AM cc Subject Re: C41-23 Paul, What is going on with C41-23?? Tom Thomas Maunder wrote: Paul, Winton mentioned that you had been in contact regarding C41-23. Doesn't look like things improved any. What is the current status?? Looks like this experience might be important when considering when to abandon other old wells. Tom Maunder, PE AOGCC Paul Figel@xtoenergy.com wrote: (See attached file: C41-23 Current Wellbore Status as of 1-18-05.doc) (See 5/6/2005 10:57 AM ) (,{of ~ Ii L ) From: PauLFigel@xtoenergy.com Date: Tue, 18 Jan 2005 09:30:12 -0600 To~ winton- aubert@admin.state.ak.us, bill@fairweather.com, Alaska - Drilling@xtoalaska.com, Bobby - Smith@xtoenergy.com, Kyle _Hammond@xtoenergy.com, Scott - Griffith@xtoalaska.com, Tbm_Reese@xtoalaska.com, Tim _~mith@xtoenergy;com, Mike _Langeler@xtoenergy.com . CO: tom - maunder@admin.state.ak.us, Doug- Marshall@xtoalaska.com (See attached file: C41-23 Current Well bore Status as of 1-18-05.doc)(See attached file: C41-23 Proposed P&A.doc)(See attached file: MGS C41-23LN Summary 1-18-05.pdf) "304 - 4fc, 3 Winton, Attached are the daily well reports, the current wellbore diagram & proposed P&A schematic. As discussed, we have not been able to make progress in fishing this 18 year old injection string. We have only retrieved :!:400' in the last 6 days as it easily breaks apart either with the overshot or wash pipe due to the severe corrosion. The TOF is presently @ 2625'. The quality of the tubing did not improve once we got below the 7" sqzjob done in '87 between 2123-59'. The well is full of scale and have been unable to pump into the tbg when the overshot is engaged. When attempting to kill the well with coil tbg on 1-4-05, the press was communicating between the 3-1/2" tbg & 7" casing. There was also 200-400 psi on the 10-3/4" annulus. Therefore, with AOGCC approval, a CIBP will be set on top of the tbg fish @ 2615' and a cement plug will be set across to 1950'. The drilling program will continue with cutting the old 7" @ 1950' (300' below the 10-3/4" casing shoe). After the 7" is pulled, a 10-3/4" packer will be used to determine if the 1 0-3/4" is intact or will require a sqz. An open hole cement kickoff plug will be set from 1950 -1800'. The new 7" intermediate set @ :!:9,550' will need to have cement tied back into the 10-3/4" casing. Please contact me with any qUestions} @ 43~~6fO-67 ~'. ..1.. '117 /z. 0 O. t:; f Thank you, P1 ç CA/(J.(Jþ lMÅ t1.A... {'-"1 ~ .. Paul \fJ6W~vr-' Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 432-620-6743 Mobil: 432-553-5217 Fax: 432-687-0862 SCANNED JAN 2 0 2005 Content-Type: application/msword C41-23 Current Well bore Status as of 1-18-05.doc Content-Encoding: base64 C41-23 Proposed P&A.doc Content-Type: application/msword MGS C41-23 WIW Cook Inlet, Alaska Leg 4, Conductor 28 API No.: Spud: 12-17-68 Surf Cs~", 40.5# J55 BTC. Set @ ~ Cmt'd w/1 ,350 sx. Longstring: 7", 26-29 Ib N80 BTC. Set @ 10,593'. Cmt wI 900 sk. TOC by CBL @ 7,800'. 26#: Surf - 8,450' 29#: 8,450 -10,593'. Deepest Coil Tbg Mill Depth @ 9763' 1-3-05 Fish: RBP @ 10,509' (9/87) PBTD: 10,535 TO: 10,712' ) WELL SI Nov '99 Current Status as of 1-18-05 > > . -- ) PLF 1-18-05 KB: 35' Water Depth: 73' MSL Tbg: 3 1/2",9.3#, N80 EUE, AB-MOD @ 10160' Set 10-11-87 31/2" Otis "X" Nipple (2.75" ID) @ 324' 31/2" Otis "X" Nipple (2.75" ID) @ 8863' MD (7891' TVD) Baker "E" Anchor Seal Assembly@ 8895' MD (7920' TVD) Baker FB-1 Packer wI Mill Out Ext@ 8898' MD (7920' TVD) 31/2" Camco KBUG w/Dummy@ 9295' MD (8269' TVD) Baker "G" Locator w/2 X-Seal Units @ 9579' MD (8529' TVD) Baker FB-1 Packer wI Mill Out Ext@ 9582' MD (8529' TVD) 3 1/2" Otis "X" Nipple (2.75" ID) @ 10123' MD (8994' TVD) Baker "G" Locatorw/ 2 X-Seal Units @ 10155' MD (9023' TVD) Baker FB-1 Packer @ 10157' MD (9023' TVD) 9/12/87 Sqz csg leak 2,123-59' wI 50 sk. TOF @ 2625' 1-18.05 ./ Tbg Cut @ 8875' GN-GO: 9087'-9108' GR-GS: 9450'-9495' HC-HN: 9706'-10147' (Sqz in 9-87 wI 100 sk) HN-HR: 10180'-10235' HR-HZ: 10254'-10316' HR-HZ: 10340'-10480' MGS C41-23 WIW Cook Inlet, Alaska Leg 4, Conductor 28 API No.: Spud: 12-17-68 Surf Csg: 103/4",40.5# J55 BTC. Set @ 1,653'. Cmt'd wI 1,350 sx. /CIBP@ 2615' wI TOC @ 1950'. Longstring: 7",26-29 Ib N80 BTC. Set @ 10,593'. Cmt wI 900 sk. TOC by CBL @ 7,800'. 26#: Surf - 8,450' 29#: 8,450 -10,593'. Deepest Coil Tbg Mill Depth @ 9763' 1-3-05 Fish: RBP @ 10,509' (9/87) PBTD: 10,535 TO: 10,712' ) Proposed P&A . ., . . .. . - > > . ..............- ') PLF 1-18-05 KB: 35' Water Depth: 73' MSL Tbg: 3 1/2",9.3#, N80 EUE, AB-MOD @ 10160' Set 10-11-87 3 1/2" Otis "X" Nipple (2.75" ID) @ 324' 31/2" Otis "X" Nipple (2.75" ID) @ 8863' MD (7891' TVD) Baker "E" Anchor Seal Assembly @ 8895' MD (7920' TVD) Baker FB-1 Packer wI Mill Out Ext@ 8898' MD (7920' TVD) 31/2" Camco KBUG wI Dummy@ 9295' MD (8269' TVD) Baker "G" Locator wI 2 X-Seal Units @ 9579' MD (8529' TVD) Baker FB-1 Packer wI Mill Out Ext@ 9582' MD (8529' TVD) 3 1/2" Otis "X" Nipple (2.75" ID) @ 10123' MD (8994' TVD) Baker "G" Locator wI 2 X-Seal Units @ 10155' MD (9023' TVD) Baker FB-1 Packer@ 10157' MD (9023' TVD) 9/12/87 Sqz csg leak 2,123-59' wI 50 sk. ,- TOF @ 2625' 1-18-05 Tbg Cut @ 8875' GN-GO: 9087'-9108' GR-GS: 9450'-9495' HC-HN: 9706'-10147' (Sqz in 9-87 wI 100 sk) HN-HR: 10180'-10235' HR-HZ: 10254'-10316' HR-HZ: 10340'-10480' ~TO ~kRGY Well Name: MGS C41-23LN ) ûaiiy Âctivity and Cost Summary ) API/UWI 50-733-20163-01 Ground Elevation (ft) 0.00 Surface Legal Location IField Name Sec. 23, T-8-N, R-13-W Middle Ground Shoal Casing Flange Elevation (ft) IKS.GrOUnd Distance (ft) 105.00 License No. State1Province 204-236 Alaska KB-Casing Flange Distance (ft) Spud Date ¡Well Configuration Type Deviated I Rig Release Date Job Category Drilling Start Date I-'rlmary Job I ype Drilling - re-entry End Date 12/30/2004 Objective Summary Contractor Inlet Drilling Rpt r .) 21.;;11 C'""..:' 1 0 1 2,'30l2004 2.0 12/31/2004 Er,d úðle 12/3112004 1/1/2005 DOt Tc.to 66,983 00 14,417.00 3.0 1/1/2005 1/2/2005 28,243.00 4.0 1/2/2005 1 13/2005 5.0 1 /3/2005 1 14/2005 6.0 1/4/2005 1/5/2005 7.0 1 /5/2005 1 16/2005 8.0 1/6/2005 1/7/2005 9.0 1/7/2005 1 1812005 10.0 1/8/2005 1/9/2005 19,435.00 41,503.00 67,340.00 55,663.00 62,812.00 49,419.00 30,373.00 11.0 1/9/2005 1/10/2005 31,272.00 12.0 1/10/2005 1/11/2005 36,539.00 13.0 1/11/2005 1/12/2005 49,682.00 14.0 1/12/2005 1/13/2005 36,174.00 15.0 1/13/2005 1/14/2005 33,477.00 16.0 1/14/2005 1/15/2005 39,036.00 17.0 1/15/2005 1/16/2005 36,006.00 18.0 1/16/2005 1/17/2005 31,351.00 19.0 1/17/2005 1/18/2005 30,119.00 www.peloton.com Secondary Job Type Drilling - re-entry AFE Number Working Interest (%) 100.00 Total AFE Amount 402251 IRi9 Number I Cum To Dat\~ I Rig Type Drilling - Triple .sumn1arV' 66,983.00 Unload and RU COil Tubing Unit. 81,400.00 Finish RU CTU and test. MU wash tool and wash to 522'. POH and SD CT operations for night. Build 9.2 ppg kill mud. 109,643.00 Displace diesel from CT. MU motor and 2-1/2" mill. Wash in hole and mill scale 522' - 4000'. POH w/ coil and SD for night. Build volume and bleed well to flow tank. 129,078.00 Change out mill to 2.7" OD. Mill hard scale 4000' - 9763'. Circ bottoms up and pump 30 bbl hi-vis sweep. 170,581.00 Pump sweep, POOH. MU 2.59" jet cutter and RIH. Cut tubing @ 8875'. Load CT with 10.2 ppg mud and prep to wash in hole. 237,921.00 Wash to tubing cut @ 8875' with coil. Circulate bottoms up and pump 11.0 ppg kill weight mud. Monitor well - well dead. POOH with coil. RD CTU and back load on boat. 293,584.00 Monitor well - flowing 4 bblslhr with pressure increasing. RU CTU, RIH and displace with 12.1 ppg mud. 356,396.00 Kill well with 12.1 ppg mud. Monitorwell- no flow. RD CTU. NU BOP's. 405,815.00 Test BOP's. RIH with tbg spear and attempt to pull tbg free (unsucessful). RIH with jet cutter and cut tbg @ 631'. TOH & LD tbg. 436,188.00 LD 18 jts 3-1/2" tbg. Run test plug and test BOP's - OK. MU & TiH with 3-1/2" overshot & jars. Unable to get below 402' due to fill- TOH. PU 6" clean out bit & TIH. Wash to 521' - flowline plugged off. Attempt to circulate and unplug flo'v...line. 467,460.00 Work on plugged flowline. Wash & ream to 581', flowline plugged, replace section of flowline. Wash to top of fish @ 632'. TOH. TIH with overshot, work over tbg & pull free. LD tools & 45 jts 3-1/2" tbg. MU 6" bit & clean out assy to clean out to TOF @ 2060'. 503,999.00 RIH wI 6" bit & clean out assy to 2060'. TOH, PU 5-3/4" overshot & T!H. Work over fish, TOH - no recovery. TIH, work over fish, TOH - recover 1 1/2 jts (total 65112 jts LD). 553,681.00 Make 3 fishing runs, recover 4 jts (total recovery 69 jts, TOF @ 2217.15'. TOH at report time. 589,855.00 TOH - no recovery. PU & TIH with shoe and 20 jt 5" wash pipe. Wash over fish to 2283'. TOH, MU new shoe and TIH. 623,332.00 Wash over fish to 2505'. TOH, change shoe, TIH and wash over fish to 2572'. 662,368.00 TOH, LD 300.17' of 3-1/2" tbg. TIH with overshot (unable to work over fish). TOH, MU & TIH with concave mill. Mill 2572' - 2582'. Pump sweep & TOH. 698,374.00 TOH, LD mill. MU overshot, TIH. Work over fish, TOH. Recover 11' of tbg. Make 2 runs with overshot - no recovery. 729,725.00 TOH. Test BOP's - OK. PU mill, TIH and mill 2590' - 2599'. TOH, MU burning shoe and TIH. Wash over fish @ 2599'. 759,844.00 Attempt to bUíiì oveí fish - unable to get to TOF. POll, PU ~eiìs¡on, TIH. Work over fish and POH. Recover 22 jts of 3-1/2" tbg. PU mill and mill 2618' - 2625', TOH. PU overshot, TIH and attempt to work over fish. TOH to PU 7" I casi~Q-Screper. Page 1/1 Report Printed: 1/18/2005 ) ) . ~~!Æ:E :J! !Æ~!Æ~&!Æ / . AI.ASIiA. OIL AND GAS / CONSERVATION COMMISSION / FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 I<"~~fl'~ Bobby Smith XTO Energy, Inc. 3000 North Garfield, Ste 175 Midland, Texas 79705 Re: C41-23 Sundry Number: 304-463 Dear Mr. Smith: 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. . 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. c4i~ Daniel T. Seamount, Jr. Commissioner DATED this2'l day of November, 2004 Encl. SC"'A'N" \,IE" v: D E- r\ n 1" 20 0:, ~"' ,... \1'.n "~,CO v,';. ) Ii , (, ') ) ~TO AkRGY November 18, 2004 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval; P&A ofMGS Well C41-23, Cook Inlet, Alaska Dear Mr. Norman, XTO Energy, Inc. hereby applies for Sundry Approval of its plan to permanently abandon the perforations existing in Middle Ground Shoal Well C41-23 to allow the sidetracking of that well to drill C41-23LN. The Application for Permit to Drill C41-23LN is submitted under separate cover. The anticipated commencement date of this work is approximately December 5,2004. The existing tubing will be pulled and the well plugged by squeezing cement through the existing three packers which will be left in the hole. Sufficient cement will be squeezed below the top packer to cover all of the open perforations and the top of cement will be a minimum of 189' above the topmost perforation. After the cement plug integrity is tested, the well will be sidetracked from just below the shoe of the 10-3/4" surface casing to a new location in the reservoir. Pertinent information attached to this application includes the following: 1) Form 10-403 Application for Sundry Approval 2) A summary of the proposed abandonment procedure 3) A schematic showing the current condition of the wellbore 4) A schematic showing the proposed abandonment If you have any questions or require additional information, please contact me at (432) 620-6718 or Bill Penrose at (907) 258-3446. Sincerely, XTO ENERGY, INC. f~L~ Boboy L. Smith Drilling/Operations Manager ORIGINAL enclosures XTO Energy Inc. . 200 North Loraine, Suite 800 . Midland, Texas 79701 (432) 682-8873 . Fax (432) 687-0862 , . ) STATE OF ALASKA) ALASKA OIL AND GAS CONSERVATION COMMISt) ÓN APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well C~ Development ~ Stratigraphic' 0 Suspend U Repair well 0 Pull Tubing 0 Perforate U Waiver U Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: ~~~ Ø1¡S n)~4 Annular Dispos. U Other 0 Abandon L::J Alter casing 0 Change approved program 0 2. Operator Name: XTO Energy, Inc. 3. Address: 1. Type of Request: Exploratory 0 Service ~ 6. API Number: Af/1M.. 50-733-20163-00 r./' 9. Well Name and Number: 168-112 v' 3000 North Garfield, Suite 175, Midland TX 79705 7. KB Elevation (ft): 105' ASL MGS C41-23 8. Property Designation: 10. Field/Pools(s): ADL-18756 Middle Ground Shoal 11. Total Depth MD (ft): 10,712' Casing Structural Total Depth TVD (ft): 9,507' Length PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 10,535' 9,355' Plugs (measured): None Junk (measured): RBP @ 10,509' Collapse Size MD TVD Burst Conductor Surface j:370' 1,653' 24" +370' 1,653' j:370' 1,584' N/A N/A 3,130 psi 1,580 psi 7,240 psi 5,410 psi 10-3/4" Intermediate Production 1 0,593' 7" 1 0,593' 9,404' Liner Perforation Depth MD (ft): 9,087' - 10,480' Packers and SSSV Type: Perforation Depth TVD (ft): 8,099' - 9,308' All packers Baker FB-1 Tubing Size: 3-1/2" Packers and SSSV MD (ft): Tubing Grade: Tubing MD (ft): N-80 10,155' Packers @ 8898', 9582 & 10157' 12. Attachments: Description Summary of Proposal L::J Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 12/5/2004 16. Verbal Approval: Date: \ \, ':Þ ~- 0'-\ Commission Representative: ¿"2 ~~-~) - ..1.,. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 13. Well Class after proposed work: Exploratory 0 Development 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 0 Service 0 Plugged 0 WINJ 0 Abandoned WDSPL 0 0 Printed Nam4? . / c; ~~bbY Smith Signature ~ L ~ Phone Title (432) 620-6718 COMMISSION USE ONLY Contact Bill Penrose 258-3446 Drilling/Operations Manager /øa/o¥' Date Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 30~-Y03 Plug Integrity ~ BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 ~ CD" ~C..~':I:N?C.(" ~('" .çt) t"" C) ~ ~O W' ~ v.); ~\'\t. '> ~ ? "" ~ ~">.\- Other: \~~~~\-'~~N~\ ~()\\-'"''"~ ~ð,"- f::.. '\ ~o..'(~, RBDMSBFL NOV 302004 ~..~c.'''\''~~ t o.~~\U':J Ù,,~(r v>'\t> Date: / 1/27/4- \..\o~ Subsequent Form Required: COMMISSIONER BY ORDER OF THE COMMISSION INSTRUCTIONS ON REVERSE Submit in Duplicate ) ) XTO Energy, Inc. MGS C41-23 P&A Procedure 1. Move the rig over the well, RID wireline and RIR with tubing punch. Perforate 3-1/2" tubing at 8,875'MD. POR and RID wireline. 2. Kill well by circulating 9.0 ppg oil-base mud down the tubing, through the perforations at 8,875' and up the annulus. While circulating, weight up the mud in small increments until it is heavy enough to kill the well. 3. Install BPV, N/D tree, N/U BOPE. Test BOPE to 5,000 psi. [Note: at the discretion of the Drilling Supervisor and AOGCC Inspector (if present), blind rams will be tested after tubing is pulled from hole if there is a chance a gas bubble will settle under BPV, making it difficult or dangerous to release.] Pull BPV. 4. MIU landing joint to tubing hanger, back out lock-down screws and pull hanger loose from tubing spool. PIU :t5,000 lbs over string weight and rotate to the right 12 - 15 turns (at depth) to release Baker "E" anchor seal assembly from the top packer. 5. Ensure well is dead and POR with tubing, checking for NORM while POR. LID tubing and completion jewelry and send to shore. 6. MIU a Baker 4" OD 80-40 seal assembly on 4" drill pipe, and Rill to the top packer at 8,898'. Displace the drill pipe with filtered inlet water. When the water reaches the end of the drill pipe, stop pumping and engage the seal assembly into the FB-1 packer and set 20,000 lbs down on it. 7. Establish injection rate and pressure through the packer and into the perfs~ Record rates and pressures 8. Mix and pump 10 bbls of fresh water followed by 63 bbls of cement as follows: 9. Cement to consist of 308 sx Class G + 0.4% bwoc R-3 + 0.3% bwoc CD-32 + 0.5% bwoc FL-63 + 1 gall100sx FP-6L + 43.7% fresh water: Slurry Wt. 15.8 ppg Slurry Yield 1.15 cf/sk Mix Water 4.92 gps ) ) 10. Drop a 4" wiper dart behind the cement and displace with mud until the dart is i)OO' above the top packer. At this point, pull the seal assembly out of the packer and place the remaining cement on top of the packer. 11. After setting the plug, pull up 5 stands, reverse out drill pipe and PORe 12. MID a 7" test packer and Rlli to 8,800'. Set the test packer and pressure test the cement below it to 3,000 psi for 30 minutes. 13. POR and proceed with sidetrack procedure to drill C41-23LN. '~TO ..ntkRGY MGS C41-23 WIW Cook Inlet, Alaska Leg 4, Conductor 28 API No.: Spud: 12-17-68 Surf Csg: 103/4",40.5# J55 BTC. Set @ 1,653'. Cmt'd w/1,350 sx. Longstring: 7", 26-29 Ib N80 BTC. Set @ 10,593'. Cmt w/900 sk. TOe by CBL@ 7,800'. 26#: Surf - 8,450' 29#: 8,450 -10,593'. Fish: RBP @ 10,509' (9/87) PBTD: 10,535 TO: 10,712' ) WELL SI Nov '99 Current Completion ') PLF 8-10-04 KB: 35' Water Depth: 73' MSL Tbg: 3 1/2", 9.3#, N80 EUE, AB-MOD @ 10160' Set 1 0-11-87 31/2" Otis "X" Nipple (2.75" ID) @ 324' 31/2" Otis "X" Nipple (2.75" ID) @ 8863' MD (7891' TVD) Baker "E" Anchor Seal Assembly @ 8895' MD (7920' TVD) Baker FB-1 Packer wI Mill Out Ext @ 8898' MD (7920' TVD) 31/2" Camco KBUG wI Dummy@ 9295' MD (8269' TVD) Baker "G" Locator wI 2 X-Seal Units @ 9579' MD (8529' TVD) Baker FB-1 Packer wI Mill Out Ext @ 9582' MD (8529' TVD) 31/2" Otis "X" Nipple (2.75" ID) @ 10123' MD (8994' TVD) Baker "G" Locator wI 2 X-Seal Units @ 10155' MD (9023' TVD) Baker FB-1 Packer@ 10157' MD (9023' TVD) 9/12/87 Sqz csg leak 2,123-59' w/ 50 sk. GN-GO: 9087'-9108' GR-GS: 9450'-9495' HC-HN: 9706'-10147' (Sqz in 9-87 w/1 00 sk) HN-HR: 10180'-10235' HR-HZ: 10254'-10316' HR-HZ: 10340'-10480' ';[!R MGS C41-23 WIW Cook Inlet, Alaska Leg 4, Conductor 28 API No.: Spud: 12-17-68 SurfCsg: 103/4",40.5# J55 BTC. Set @ 1,653'. Cmt'd w/1,350 sx. Longstring: 7", 26-29 Ib N80 BTC. Set @ 10,593'. Cmt w/ 900 sk. TOC by CBl @ 7,800'. 26#: Surf - 8,450' 29#: 8,450 -10,593'. Fish: RBP @ 10,509' (9/87) PBTD: 10,535 TD: 10,712' ) Proposed P&A ~'. - -;.f ~".:'::~ :\:.~-. . ..." ". .. . . .~', :'<..~ -..- .":-";'~ ~W-. . r. -.. : e'..~' ..' ..: -: . .. f' <. ... ... .... -,,-'. \. ..~~- -_\. r...." ( ~ '..~ c"."... ../' - - # '- , ~. ') WJP 11-15-04 KB: 35' Water Depth: 73' MSl 9/12/87 Sqz csg leak 2,123-59' w/ 50 sk. Baker FB-1 Packer wi Mill Out Ext @ 8898' MD (7920' TVD) 31/2" Camco KBUG wi Dummy @ 9295' MD (8269' TVD) Baker "G" Locator wi 2 X-Seal Units @ 9579' MD (8529' TVD) Baker FB-1 Packer wi Mill Out Ext @ 9582' MD (8529' TVD) 31/2" Otis "X" Nipple (2.75" ID) @ 10123' MD (8994' TVD) Baker "G" Locator wi 2 X-Seal Units @ 10155' MD (9023' TVD) Baker FB-1 Packer @ 10157' MD (9023' TVD) GN-GO: 9087'-9108' GR-GS: 9450'-9495' HC-HN: 9706'-10147' (Sqz in 9-87 w/100 sk) HN-HR: 10180'-10235' HR-HZ: 10254'-10316' HR-HZ: 10340'-10480' Re: C-41-23 (168-112) )( ) Subject: Re: C-41-23 (168-112) From: Paul- Figel@xtoenergy.com Date: Tue, 23 Nov 2004 15:35:03 -0600 To: Thomas Maunder <tom - maunder@admin.state.ak.us> Tom, According to my internal cover letter for the AFE back in 2001, we saw nothing on the horizon for the wellbore since the area was flooded out & decided to just T&A the perfs with coil tbg since the drilling rig was on Platform A. The work was put off for the winter. After which, we were looking at the S1 wellbores for a possible coalbed methane candidate on Platform C. That was voted down after evaluating the economics & the risks. Sorry to say but the original intention was forgotten. We had a well review this past summer & identified this well to be a candidate to sidetrack to the north West Flank to help provide water flood support. The A23-01LW, drilled in May 2001, was supposed to be a short term producer with plans to convert to injection for support to the other West Flank wells. But the A23-01LW has been flat @ 375 BOPD for the last 2 years and, therefore, was not obviously going to be given up for injection. Therefore, it was decided to use a S1 well, that had no other plans, to sidetrack far north to give that area the needed water support that the A23-01LW was supposed to provide. The intent is to drill the C41-23LN and have a slotted liner across the Hemlock. We will initially produce the well but will convert to injection after the oil rate is insufficient or see the other offset producers decline. Hope this make sense. Paul Thomas Maunder <tom maunder@admi n.state.ak.us> 11/23/2004 02:38 PM ~-~~;h_~~~.9.~.;.~~.!:..?.~E~~.E9X...:._çgr!] Re: C-41-23 (168-112) SCANNED DEC 1 '7 2004 (See attached file: C.htm) C.htm Content-Type: text/html 1 of 1 Subject To cc 12/17/20048:30 AM mailbox:IIIF lemailldefault/Maillancmaill.state.ak.us/lnbox?number ... ) Paul, Would you enlighten me a bit on C41-23LN?? A three year old sundry is getting a little stale. Is the basis for the proposed work still accurate?? At present, there is not a mandated valid time length for a sundry although we do have a proposal being considered to make them the same as the drilling pennit--2 years. Tom Paul Fígel@~xtoenergy.coln wrote: Several of us are heading up to Alaska on Monday, Nov 29th, for a spud mtg for the C41-23LN on Tues. I have a 10-403 form signed by Cammy Taylor on 11-6-01. Hope you & the family have a good Thanksgiving. Hard to believe it's already here! Paul Thomas Maunder <tom maunder@admi n.state.ak.u8> To Paul F i 9.~_~..~~.!:.?~.~~E.9Y..~...S::?~ 11/23/2004 02:14 PM cc Subject Re: C-41-23 (168 -112) Thanks Paul. When will you next be up here?? I just got a note that there is a EOR CO2 conference set in Midland in early Dec. No, I won't be going to that one. Did you get our letter and that sundry back?? Just need to close a few loops there. Catch you later. Tom Paul Figel@xtoenergy.com wrote: Tom, Yes, you are correct. I submitted a Sundry to T&A the well across the perf's with coil tbg in Nov '01. It was not done that winter due to the lof2 12/17/20048:30 AM mailbox:IIIF I email/default/Maillancmaill.state.ak.us/lnbox?number ... ') ') cold weather for coil tbg operations. The approval I had was 301~311 Vs. 301-211 you referenced. Paul Thomas Maunder <tom mau.nder@admi n':"'s't'ã"t"e"':"a]<":11's';"""""'-"-" To 11/23/2004 01:39 PM Paul Figel .:::.P.~:~~.~._.~..~.9:~..~.~~~.Tq.~.~~.E9.y'...:...ç.?!!:~.?.. cc Bill Miller <bill miller@xtoalaska.com> Subject C-41-23 (168-112) Paul and/or Bill, I am processing the sundry submitted to P&A this well and prepare for sidetrack. In looking at our file information, it appears that an approval was given in November 2001 (301-211) to use coil to plug the perf intervals. I presume that work was not accomplished, is that correct?? Thanks in advance, Tom Maunder, PE AOGCC > 2of2 12/17/20048:30 AM ) ) November 18,2004 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval; P&A ofMGS Well C41-23, Cook Inlet, Alaska Dear Mr. Norman, XTO Energy, Inc. hereby applies for Sundry Approval of its plan to permanently abandon the perforations existing in Middle Ground Shoal Well C41-23 to allow the sidetracking of that well to drill C41-23LN. The Application for Permit to Drill C41-23LN is submitted under separate cover. The anticipated commencement date of this work is approximately December 5, 2004. The existing tubing will be pulled and the well plugged by squeezing cement through the existing three packers which will be left in the hole. Sufficient cement will be squeezed below the top packer to cover all of the open perforations and the top of cement will be a minimum of 189' above the topmost perforation. After the cement plug integrity is tested, the well will be sidetracked from just below the shoe of the 10-3/4" surface casing to a new location in the reservoir. Pertinent information attached to this application includes the following: 1) Form 10-403 Application for Sundry Approval 2) A summary of the proposed abandonment procedure 3) A schematic showing the current condition of the wellbore 4) A schematic showing the proposed abandonment If you have any questions or require additional information, please contact me at (432) 620-6718 or Bill Penrose at (907) 258-3446. Sincerely, XTO ENERGY, INC. ~~L~ Boböy L. Smith Drilling/Operations Manager ORIGINAL enclosures XTO Energy Inc. . 200 North Loraine, Suite 800 . Midland, Texas 79701 (432) 682-8873 . Fax (432) 687-0862 ) STATE OF ALASKA ") ALASKA OIL AND GAS CONSERVATION COMMIS~,ÓN APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well C~ Development ~ Stratigraphic' 0 Abandon L::J Alter casing 0 Change approved program 0 2. Operator Name: XTO Energy, Inc. 3. Address: 1. Type of Request: Suspend U Repair well D Pull Tubing 0 3000 North Garfield, Suite 175, Midland TX 79705 7. KB Elevation (ft): 8. Property Designation: 11. Total Depth MD (ft): 10,712' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 9,087' - 10,480' Packers and SSSV Type: 105' ASL ADL-18756 Á, Ø¡S f1/~~ Annular Dispos. U Other 0 Perforate U Waiver U Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 168-112 ../ Exploratory 0 Service Sl' 6. API Number: Afè.'IM. 50-733-20163-00 ('/'" 9. Well Name and Number: MGS C41-23 10. Field/Pools(s): Middle Ground Shoal PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Total Depth TVD (ft): 9,507' Length Size Plugs (measured): None Junk (measured): RBP @ 10,509' Collapse 10,535' 9,355' :t370' 1,653' 24" 10-3/4" MD TVD Burst 10,593' 7" +370' 1,653' :t370' 1,584' N/A N/A 3,130 psi 1,580 psi 7,240 psi 5,410 psi Perforation Depth TVD (ft): 8,099' - 9,308' All packers Baker FB-1 10,593' 9,404' Tubing Size: 3-1/2" Tubing Grade: Tubing MD (ft): N-80 10,155' Packers @ 8898', 9582 & 10157' Packers and SSSV MD (ft): 12. Attachments: Description Summary of Proposal L::J Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for 12/5/2004 Date: \ \ '"a ~- 0'-"\ ¿'2~~..~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Commencing Operations: 16. Verbal Approval: Commission Representative: Printed Nam41 / ("; ~~bbY Smith Signature frrtty L ~ Phone 13. Well Class after proposed work: Exploratory 0 Development 15. Well Status after proposed work: Oil 0 GasD WAG D GINJ D 0 Service 0 Plugged 0 WINJ D Abandoned WDSPL 0 D Title Contact Bill Penrose 258-3446 Drilling/Operations Manager /øa/ot'/' (432) 620-6718 COMMISSION USE ONLY Date Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~Lf-L{&"3 Plug Integrity ~ BOP Test 0 Mechanical Integrity Test D Location Clearance 0 ""'--'t CD" ~~e:\- '1:N\>t. t.. ~(' .çt) r C) \> ~ 0" ~ Vo.) '\ ~ "to. '> ~ \> "'" ~ ~ '> .\.. Other: \~~~~~'~~N~\ .çC)r-\-"''''~ ~ð,"- ~ '\ ~~'(~I RBDMSBFL NOV 3 02004 Subsequent Form Required \..\,O~ ~c. ",,"C.:, "\"~ '~'A t o.~\..c.t-\'U'iJ ù" ~((' y.\'b (7\ ~ /" # BY ORDER OF I 7/ Approved bY:'t,).{ ~ COMMISSIONER THE COMMISSION Date: II Z?¡ 4- Form 10-403 Revised 1r INSTRUCTIONS ON REVERSE Submit in Duplicate ) ) ,¡. XTO Energy, Inc. MGS C41-23 P&A Procedure 1. Move the rig over the well, RIO wireline and RIR with tubing punch. Perforate 3-1/2" tubing at 8,875'MD. POR and RID wireline. 2. Kill well by circulating 9.0 ppg oil-base mud down the tubing, through the perforations at 8,875' and up the annulus. While circulating, weight up the mud in small increments until it is heavy enough to kill the well. 3. Install BPV, N/D tree, N/U BOPE. Test BOPE to 5,000 psi. [Note: at the discretion of the Drilling Supervisor and AOGCC Inspector (if present), blind rams will be tested after tubing is pulled from hole if there is a chance a gas bubble will settle under BPV, making it difficult or dangerous to release.] Pull BPV. 4. M/U landing joint to tubing hanger, back out lock-down screws and pull hanger loose from tubing spool. P/U 2=5,000 lbs over string weight and rotate to the right 12 - 15 turns (at depth) to release Baker "E" anchor seal assembly from the top packer. 5. Ensure well is dead and POR with tubing, checking for NORM while POR. LID tubing and completion jewelry and send to shore. 6. M/U a Baker 4" OD 80-40 seal assembly on 4" drill pipe, and Rill to the top packer at 8,898'. Displace the drill pipe with fittered inlet water. When the water reaches the end of the drill pipe, stop pumping and engage the seal assembly into the FB-l packer and set 20,000 lbs down on it. 7. Establish injection rate and pressure through the packer and into the perfs~ Record rates and pressures 8. Mix and pump 10 bbls of fresh water followed by 63 bbls of cement as follows: 9. Cement to consist of 308 sx Class G + 0.4% bwoc R-3 + 0.3% bwoc CD-32 + 0.5% bwoc FL-63 + 1 gaVI00sx FP-6L + 43.7% fresh water: Slurry Wt. 15.8 ppg Slurry Yield 1.15 cf/sk Mix Water 4.92 gps ) ) 10. Drop a 4" wiper dart behind the cement and displace with mud until the dart is j:)OO' above the top packer. At this point, pull the seal assembly out of the packer and place the remaining cement on top of the packer. 11. After setting the plug, pull up 5 stands, reverse out drill pipe and POR. 12. MID a 7" test packer and Rlli to 8,800'. Set the test packer and pressure test the cement below it to 3,000 psi for 30 minutes. 13. POR and proceed with sidetrack procedure to drill C41-23LN. '~TO ~kRGY MG5 C41-23 WIW Cook Inlet, Alaska Leg 4, Conductor 28 API No.: Spud: 12-17-68 Surf Csg: 10 3/4", 40.5# J55 BTC. Set @ 1,653'. Cmt'd w/1 ,350 sx. Longstring: 7", 26-29 Ib N80 BTC. Set @ 10,593'. Cmt w/900 sk. TOC by CBL@ 7,800'. 26#: Surf - 8,450' 29#: 8,450 -10,593'. Fish: RBP @ 10,509' (9/87) PBTD: 10,535 TD: 10,712' ) WELL 51 Nov '99 Current Completion ~ ---- W- ") PLF 8-1 0-04 KB: 35' Water Depth: 73' MSL Tbg: 3 1/2", 9.3#, N80 EUE, AB-MOD @ 10160' Set 10-11-87 31/2" Otis "X" Nipple (2.75" ID) @ 324' 31/2" Otis "X" Nipple (2.75" ID) @ 8863' MD (7891' TVD) Baker "E" Anchor Seal Assembly @ 8895' MD (7920' TVD) Baker FB-1 Packer wi Mill Out Ext @ 8898' MD (7920' TVD) 31/2" Camco KBUG wi Dummy@ 9295' MD (8269' TVD) Baker "G" Locator wi 2 X-Seal Units @ 9579' MD (8529' TVD) Baker FB-1 Packer wi Mill Out Ext @ 9582' MD (8529' TVD) 31/2" Otis "X" Nipple (2.75" ID) @ 10123' MD (8994' TVD) Baker "G" Locator wi 2 X-Seal Units @ 10155' MD (9023' TVD) Baker FB-1 Packer@ 10157' MD (9023' TVD) 9/12/87 Sqz csg leak 2,123-59' w/50 sk. GN-GO: 9087'-9108' GR-GS: 9450'-9495' HC-HN: 9706'-10147' (Sqz in 9-87 w/100 sk) HN-HR: 10180'-10235' HR-HZ: 10254'-10316' HR-HZ: 10340'-10480' >'~TO ~~RGY MGS C41-23 WIW Cook Inlet, Alaska Leg 4, Conductor 28 API No.: Spud: 12-17-68 SurfCsg: 103/4",40.5# J55 BTC. Set @ 1,653'. Cmt'd wI 1,350 sx. Longstring: 7", 26-29 Ib N80 BTC. Set @ 10,593', Cmt wI 900 sk. TOCby CBL @ 7,800', 26#: Surf - 8,450' 29#: 8,450 -10,593'. Fish: RBP @ 10,509' (9/87) PBTD: 10,535 TD: 10,712' ') Proposed P&A ~ ....: ... ' ~: .. ". - "1: ... ..... -... - I. - -; ,f ~"': '::~ : ,~. ~-" . "'.. '.. .. . -: '. ~:.'~ -..- :':':'~ 7ff ~ ...' ~-" ..';..: -: ~ :.. :.,. ~ <... ~ ... r"", ~ -_\.(".....'(... "..~ .., .' ') WJP 11-15-04 KB: 35' Water Depth: 73' MSL 9/12/87 Sqz csg leak 2,123-59' wI 50 sk. Baker FB-1 Packer wI Mill Out Ext @ 8898' MD (7920' TVD) 31/2" Camco KBUG wI Dummy @ 9295' MD (8269' TVD) Baker "G" Locator wI 2 X-Seal Units @ 9579' MD (8529' TVD) Baker FB-1 Packer wI Mill Out Ext @ 9582' MD (8529' TVD) 31/2" Otis "X" Nipple (2.75" ID) @ 10123' MD (8994' TVD) Baker "G" Locator wI 2 X-Seal Units @ 10155' MD (9023' TVD) Baker FB-1 Packer@ 10157' MD (9023' TVD) GN-GO: 9087'-9108' GR-GS: 9450'-9495' HC-HN: 9706'-10147' (Sqz in 9-87 wI 100 sk) HN-HR: 10180'-10235' HR-HZ: 10254'-10316' HR-HZ: 10340'-10480' November-2602 C23-23 ACT DATE & NOTES l~J INJ ANNU 01 -Nov-2602 02-Nov-2002 03-Nov-2002 ' 0~-Nov-2002 05-Nov-2602 06-Nov-2602 07-Nov-2602 08-Nov-2002 09-Nov-2602 i0-Nov-2002 I l-Nov-2002 12-Nov-2602 13-Nov-2002 I4-Nov-2602 15-Nov-2002 16-Nov-2002 17-Nov-2002 18-Nov-2002 19-Nov-2602 20-Nov-2002 21 -Nov-2602 22-Nov-2002 23-Nov-2602 24-Nov-2002 25-Nov-2002 26-Nov-2002 27~Nov-2002 2g-Nov-2002 29-Nov-2602 30-Nov-2602 1854 3450 1848 3450 1764 3450 1759 3450 1769 3450 1814 3450 1823 3450 1851 3450 1861 3450 1815 3450 1818 3450 1793 3450 1750 3450 1758 3450 1763 3450 1751 3450 1707 3450 1716 3450 1722 3450 1722 3450 1732 3450 1704 3450 1706 3450 1729 3475 1709 3475 1703 3475 1700 3475 1704 3450 1675 3450 1686 3450 WATER INIECTION REPORT PLATFORM C ACT INJ INJ ANNU C34-23 C23-26 INJ INJ ANNU 0 50 510 0 50 510 0 50 510 0 50 510 0 50 510 0 50 510 0 50 560 0 50 560 0 50 56~ 0 50 56~ 0 50 56~ 0 50 56~ 0 50 56~ 0 50 56~ 0 50 56C 0 50 56~ 0 50 56( 0 50 56( 0 50 56( 0 50 56( 0 50 511 0 50 511 0 50 5If 0 50 511 0 50 51( 0 50 511 0 50 511 0 70 56( 0 70 56( 0 70 56( 398 3475 3550 399 3500 3550 389 3500 3500 388 3450 350~ 386 3450 3560 393 3400 345{3 396 3550 350~ 402 3550 350~ 402 3550 350~ 396 3500 350~ 394 3500 350~ 397 3500 345~ 398 3500 345( 66 1350 135C 0 1100 I10~ 0 1050 105C 0 1050 1051 0 1060 0 1000 100( 0 I000 1001 440 3500 347.~ 421 3500 347'~ 418 3500 345( 421 3500 3475 397 3500 347.~ 413 3500 347.~ 411 3500 347.~ 409 3450 345( 403 3450 345( 404 3450 345( ACT ~J ~J ANNU 587 3450 573 3450 496 34~0 498 3400 · 502 3400 533 3400 599 3450 634 3450 597 3450 605 3450 662 3450 667 3450 620 3450 670 3450 566 3450 494 3450 555 3450 583 3450 583 3450 604 3450 634 3500 631 3500 697 3450 682 3500 665 3500 683 3450 673 3475 687 3450 714 3450 715 3450 ACT INJ IN~ ANNU 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C41-26 ACT IN~I IN3 ANNU 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C44-14RD A~---- ~ ' INJ 1NJ ANNU 0 0 55~ 0 0 55( 0 0 55( 0 0 55( 0 0 55t` C24A-14 ACT /NJ INJ ANNt 369 4450 370 4450 373 4450 442 4550 421 4550 TOTAL 52,706 0 9.341 18.409 0 0 MAXIMUM 3,475 70 56( 3.550 3,55C 3.500 0 0 AVER. AGE 1,757 3,453 0 52 535 311 2.928 2,92~ 614 3,451 0 0 0 0 # DAYS 30 0 24 30 0 0 12/12/2002 0 0 575 0 0 55( 0 0 0 0 55( 0 0 55( 0 0 55( 0 0 55(. 0 0 55(. 0 0 55(. 0 0 55(. 0 0 55( 0 0 55(. 0 0 55( 0 0 55(. 0 0 55( 0 0 55( 0 0 55( 0 0 55( 0 0 55C 0 0 55( 0 0 57.~ 0 0 55( 0 0 55( 0 0 5O( 0 0 55( 407 4525 416 4550 412 4550 412 4550 405 4560 380 4560 389 4550 407 4550 403 45OO 395 4500 400 4500 4O4 45OO 402 4450 387 4450 396 4450 399 445O 394 4450 385 4~50 401 4500 381 4500 388 4500 369 4500 357 4450 362 4450 387 4450 0 11,813 0 575 4,560 0 0 551 394 4,497 0 30 C41-23 shut in due ~o annular communication problem. WATER INJECTION REPORT PLATFORM C October-2002 C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44--14RD C24A-14 ACT ACT ACT ACT ACT ACT ACT ACT DATE & NOTES INJ INJ ANNU INJ INS ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU IN3 INJ ANNU INJ INJ ANNU ][NJ INJ ANNL 0 i-Oc1-200~ 02-Oct-2002 03-Oet-2002 04-Oct-2002 05-Oct-2002 06-Oct-2002 07-Oct-2002 08-Oct-2002 09-Oct-2002 10-Oct-2002 11-Oct-2002 12-Oct-2002 13-Oct-2002 14-Oet-2002 15-Oct-2002 16-Oct-2002 17-Oct-2002 18-0ct-2002 19-Oct-2002 20-Oct-2002 2I-Oct-2002 22.0ct-2002 23-Oct-2002 24-Oct-2002 25-Oct.2002 26-Oet-2002 27-Oct-2002 28-Oct-2002 29-Oct-2002 30-Oct-2002 31-Oct-2002 TOTAL MAX]MUM AVERAGE # DAYS 1808 3450 1809 3475 1808 3475 1815 3475 1809 3475 1795 3475 1813 3475 1824 3475 1803 3475 1756 3475 1755 3475 1776 3475 1771 3450 1830 3450 1775 3450 1807 3450 1820 3450 1827 3450 1836 3450 1808 3450 1827 3450 1799 3450 1832 3450 1802 3460 1812 3460 1708 3460 1874 3450 1784 3475 1810 3460 1846 3460 1851 3450 55,990 3,475 1,806 3,461 31 0 50 51( 0 50 56( 0 50 56( 0 50 56( 0 50 56( 0 50 56( 0 50 56( 0 50 56( 0 50 56( 0 50 56( 0 50 56( 0 50 56( 0 50 56( 0 50 56( 0 50 56( 0 50 56( 0 50 56( 0 50 56( 0 50 56( 0 50 56( 0 50 56( 0 50 56~ 0 50 56( 0 80 52( 0 80 0 80 51( 0 50 51( 0 50 51.' 0 50 51( 0 50 51( 0 50 51( 0 80 56( 0 53 54~ 0 411 3500 345( 408 3525 347.' 405 3525 347.' 404 3525 347.' 395 3525 347: 404 3525 347: 405 3525 347.' 405 3525 347.' 400 3525 347: 398 3525 347: 399 3525 347: 403 3525 347: 400 3500 350( 410 3500 350( 394 3500 350( 401 3500 350( 402 3500 350( 402 3500 350( 406 3500 350( 400 3500 350( 405 3500 350( 400 3500 350( 405 3500 350( 402 3500 347: 407 3500 347.' 389 3500 347.~ 410 3500 350( 389 3500 345¢ 390 3500 347: 397 3500 347.' 397 3500 350( 12,443 3,525 3,50( 401 3,509 3,484 31 669 3500 80 637 3500 60 617 3500 60 688 3500 60 650 3500 60 628 3500 60 687 3500 60 631 3500 60 629 3500 60 548 3500 60 546 3500 60 579 3500 60 640 3450 654 3450 574 3450 558 3450 565 3450 491 3450 522 3450 556 3450 584 3450 572 3450 546 3450 551 3500 595 3500 543 3450 628 3475 699 3450 579 3500 615 3475 630 3450 18,6ll 3,500 80 600 3,476 24 31 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 .0 0 0 0 0 0 0 0 0 0 0 0 0 0 C 0 C 11/12/2002 0 55O 0 550 0 550 0 550 0 550 0 575 0 550 0 550 0 550 0 550 0 550 0 550 0 550 0 550 0 550 0 550 0 550 0 550 0 550 0 550 0 550 0 550 0 550 0 550 0 550 0 575 0 55O 0 550 0 500 0 55O 0 50O 0 575 0 548 410 4500 192 3500 337 4500 428 4500 413 4500 397 4500 417 4500 402 4500 403 4500 425 4500 413 4500 381 4500 379 4500 405 4500 407 4575 387 4575 412 4550 412 4550 419 4550 415 4550 412 4550 410 4550 437 4550 409 46OO 418 46O0 388 4500 405 4500 373 4500 382 4500 393 4500 394 4450 12,275 4,600 396 4,489 31 C41-23 shut in due to annular communication problem. SCANNED MAR 1 0 2_003 WATER INJECTION REPORT PLATFORM C September-2002 C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 C24A-14 ACT ACT ACT ACT ACT ACT ACT ACT ACT DATE & NOTES INJ INI ANNU INJ INJ ANNU INJ ][NJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANN1 INJ INJ ANNL 01-8ep-2002 02-Sep.2002 03-Sep-2002 04-Sep-2002 05-Sep-2002 06-$ep-2002 07-Sep-2002 08-8ep-2002 09-$ep-2002 10-Sep-2002 11 -Sep-2002 12-Sep-2002 13-Sep~2002 14-Sep-2oo2 15-Sep-2002 16-$ep-2002 17-$ep-2002 18-5ep-2002 19-Sep-2002 20-$ep-2002 21 -Sep-2002 22-S¢p-2002 23-Sep~2002 24-$ep-2002 25-Sep-2002 26-Sep-2002 27-Sep-2002 28-$ep-2002 29-Sep-2002 30-$¢p-2002 1844 3475 30 1859 3475 35 1861 3500 35 1865 3500 30 1863 3500 30 1864 3500 3(3 1860 3500 25 1861 3500 25 1868 3500 25 184[ 3500 25 1853 3500 25 1841 3500 25 1836 3500 23 1850 3500 25 1868 3500 25 1870 3500 27 1845 3500 25 1864 3500 25 1693 3500 25 1768 3450 25 1777 3450 25 1767 3450 25 1765 3450 25 1778 3450 25 1778 3450 1798 3450 1804 3450 1827 3475 1674 3450 1429 3450 0 50 51( 0 50 50( 0 50 51( 0 50 51( 0 50 51( 0 50 51( 0 50 510 o 50 5tO o 50 51o o 50 51o 0 50 510 0 40 555 0 40 555 0 40 560 0 50 560 0 80 560 0 60 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 555 0 50 550 0 50 510 415 3550 3500 417 3550 3500 417 3550 3500 415 3550 3500 416 3550 3500 414 3550 3500 415 3500 3500 412 3500 3500 413 3500 3500 410 3500 3500 412 3500 3500 408 3500 350(] 407 3500 3500 408 3500 3500 406 3500 3525 405 3500 3500 399 3500 3525 400 3500 350(] 372 3500 3500 388 3450 3450 131 3450 345(3 0 1100 110(3 0 1050 105(3 0 1000 IOOO 173 3500 350(] 419 3500 346~ 413 3500 346~ 417 3550 3475 393 3500 3475 328 3550 3475 833 3550 12~ 880 3550 12~ 917 3550 13( 909 3550 12~ 862 3550 12~ 790 3550 12~ 783 3500 Il( 773 3500 111 755 3500 I1( 766 3500 11{ 774 3500 11~ 746 3500 105 787 3450 105 769 3500 107 826 3500 102 794 3500 110 688 3500 110 666 3500 110 626 3500 107 678 3450 103 601 3450 103 697 3450 103 760 3450 103 801 3450 103 597 3450 0 605 3450 25 632 3450 25 660 3475 110 621 3500 90 600 3500 60 0 0 0 0 0 0 0 0 0 0 0 ' 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 730 60( 0 730 60( 0 730 60( 0 730 60( 0 730 60( 0 730 60( 0 730 60( 0 730 60( 0 730 60( 0 730 60( 0 730 60( 0 730 57: 0 730 5751 0 735 575: 0 735 575 0 735 575 0 735 575 0 735 575 0 735 575 0 735 575 0 735 575 0 735 575 0 735 575 0 735 575 0 735 575 0 735 600 0 735 600 0 735 600 0 730 600 0 730 600 0 0 55(3 0 0 55(3 0 0 55(3 0 0 55C 0 0 55C 0 0 575 0 0 55C 0 0 55( 0 0 55( 0 0 55( 0 0 55( 0 0 55(} 0 0 55( o o 0 0 0 0 0 0 0 0 550i 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 550 0 0 550 0 0 500 0 0 550 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 400 '4450 412 4500 417 4500 430 4525 424 4525 432 4525 415 4500 402 4500 391 4500 ~02 4500 394 4500 389 4450 396 4450 391 4~5o 396 4500 398 4500 408 4500 401 4500 368 4500 391 4500 391 4500 393 4500 394 4500 394 4500 380 4450 360 4450 360 4450 389 4500 416 4550 342 4525 TOTAL 54,271 0 10,423 22,196 0 0 0 0 11,876 MAXIMUM 3,500 35 80 560 3,550 3,525 3,550 130 0 735 600 0 575 0 4,550 AVERAGE 1,809 3,481 21 0 50 539 347 3,265 3,248 740 3,494 I00 0 0 0 733 588 0 0 550 0 0 396 4,493 # DAYS 30 0, 27 30 0 0 0 0 30 10/[412002 241-23 shut in dun to annular communication problem. C24A-23 shut in for field study and evaluation per Doug Marshall. SCANNED MAR i 0 ; 003 WATER INJECTION REPORT PLATFORM C June~2002 C23-13 C41-23 C24-23 C34-23 C23o26 C41-26 C44--14RD C24A-23 C'24A- 14 ACT I ACT ACT ACT ACT ACT ACT ACT ACT DATE & NOTES INJ l~'J i ANNU ~II ]NJ ANN[~ ~J ~J ANNU INJ l~J AiNNU [ l~at l~J AiNrNUIN'J I~NJ ANNU ~$ INS ANNU I~J ~J ANNU l~J l~J AIN'NI 0t -Jun-2002 t770 3500 0 0 615] 371 3450 345~]0 0 0 0 0 440 250 1,080 1.800 550 0 0 0 191 3500 £ 02-1un-2002 1776 3500 0 0 61.~ 373 3450 345(30 0 0 0 0 440 250 325 1,800 550[ 0 0 0 175 3500 03~$un-2002 1760 3500 0 0 615i 369 3450 345(] 0 0 0 0 0 440 250 220 I,$00 55( 0 0 0203 3500 04-Jun-2002 1764 3450 0 0 611 373 3425 3425 0 0 0 0 0 440 25( 0 0 55( 0 0 0203 3500 05-Iun.2002 t376 3450 0 0 61: 291 3425 3425 0 0 0 0 0 440 25( 0 0 55( 0 0 0 155 3500 06-Jun-2002 1198 3~ 0 0 61.~ 242 3350 340~ 0 ~ 0 0 0 ¢ 0 570 40( 0 0 57.s 0 0 0 1411 3500 (] 07-Jun-2002 970 34~30 0 0 61.' 219 3350 340(] 0 0 0 0 ¢ 0 570 40( 0 0 55£ 0 0 01181 3500 (] 08-Jun-2002 612 34~0 0 0 6H 398 3400 345(] 0 0 0 0 C 0 590 40( 272 1,900 55C 0 0 0 2251 3500 (] 09-Jun-2002 1416 34~0 0 0 61( 291 3400 3450 0 : 0 0 0 C 0 600 40( 377 1,800 55£ 0 0 0 152! 3500 (] 10-Jun-2002 1950 3430 0 0 61( 394 3425 3475 229 3500 0 0 ~ 0 600 401 0 0 55( 0 0 0 203 3500 I 1 -Jun-2002 1876 3450 0 0 61( 386 3450 3500 410 3500 0 0 {~ 0 610 45( 0 0 55¢ 0 0 0 222 3500 t2-Jun-2002 1849 3500 0 0 61( 387 3450 3500 370 3500 0 0 (] 0 620 45( 372 1,800 55£ 0 0 205! 3500 [3-Jun-2002 1846 3500 0 0 61( 382 3450 3500 430 3500 0 0 (] 0 620 45( 686 1,800 55¢ 0 0 194 3500 [4-Jun-2002 1858 3500 0 0 6If 382 3450 3500 484 3500 0 0 (] 0 620 45( 432 1.800 55f~ 0 0 432 4100 0 [5-Jun-2002 1864 35~0 0 0 61( 384 3450 3500 619 3500 0 0 (] 0 620 45( 0 0 55(3 0 0 403 4500 0 16-Jco-2002 1865 3500 £ 0 0 61£ 384 3450 3500 634 3500 0 0 (] 0 620 45( 393 1.800 55(] 0 0 457 4500 0 17-$un-2002 t877 3500 £ 0 0 61£ 383 3450 3500 636 3500 0 0 (] 0 620 45( 0 0 55(] 0 0 438 4500 0 18-Jun-2002 1895 3500 £ 0 0 61£ 384 3450 3500 625 3500 0 0 0 0 620 45( 386 1.850 55(] 0 0 341 44-50 0 19-Iun-2002 1864 3500 ¢ 0 0 61¢ 380 3450 3500 661 3500 0 0 0 0 620 45( 312 2.100 550 0 0 352 4450 0 20-Jun-2002 1885 3500 ¢ 0 0 615 381 3475 3500 693 3500 ¢ 0 0 0 0 660 5(X 0 0 550 0 0 347 4450 21 -Jun-2002 1824 3500 fl 0 0 615 374 3475 3500 579 3500 C 0 0 0 0 665 50( 340 1.900 550 0 0 317 4500 22-Jun-2002 1848 35~0 fl 0 0 615 390 3450 350( 470 3500 ¢ 0 0 0 0 720 50( 0 0 550 0 0 30I 4400 23-Jun-2002 1874 3500 (] 0 60 615 386 3500 350( 491 3500 ¢ 0 0 0 0 670 50( 0 0 550 0 0 314 4400 24-Jun-2002 1757 34i)0 (] 0 60 62(] 370 3400 345( 388 3425 {] 0 0 0 0 675 50( 354 1,900 550 0 0 ¢ 342 4500 25-Jun-2002 1843 3450 0 0 60 62(]379 3450 350( 485 3500 (] 0 0 0 0 725 50~ 0 0 550 0 0 ¢ 346 4500 26-Jun-2002 1867 3500 0 0 60 615 371 3450 350( 568 3500 (] 0 0 0 0 680 50(3 332 1.900 575 0 0 ¢ 358 4500 27-Jun-2002 1923 3430 0 0 60 615 373 3500 350( 559 3500 (] 0 0 ~ 0 680 50(] 360 2.000 550 0 0 ¢ 336 4500 28-Jun-2002 1922 3430 0 0 60 615 365 3500 350( 557 3500 (] 0 0 (~ 0 680 50~ 0 0 550 0 0 ¢ 0 2800 29dun-2002 1916 34~0 0 0 60 615 362 3500 350( 524 3500 0 0 0 0 680 50~ 0 0 500 0 0 ¢ 19 2800 30~Jun-2002 1903 34~0 0 0 60 615 359 3500 350( 547 3500 0 0 0 0 680 50~ 353 2.000 550 0 0 G 526 4400 TOTAL 51,948 ~0 0 10,883 10.959 0 0 6.594 0 MAXIMUM 3,5 0 60 620 3,500 3,50( 3,500 0 0 725 500 2,100 575 0 0 4,500 AVERAGE 1,732 3,472 0 0 16 614 363 3,446 3,478 365 2,448 0 0 0 0 607 427 220 998 550 0 0 0 267 3.925 # DAYS 30 i 0 30 20 0 0 16 0 29 07/11/2002 I C41-23 shut ia due to annular communication problem. C24A-23 shut in for field study and evaluation per Dcog M~rahal[. I , i : WATER INJECTION REPORT PLATFORM C August-2002 C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 C24A-14 ACT ACT ACT ACT ACT ACT ACT ACT ACT DATE & NOTES INJ INf ANNU 1NJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ l]qJ ANNU INJ INJ ANNU INJ l~J ANNU INJ INJ ANNE ][NJ INJ ANNU 0 l-Aug-2002 965 2500 6~ 0 80 55(] 198 1250 125(]481 1950 10 0 0 0 720 550 454 2,050 550 0 0 C 470 4450 5 02-Aug-2002 1985 3500 2~0 70 55(] 408 3500 350<]860 3500 10 0 0 0 720 575 409 2.200 550 0 0 ¢ 503 4600 O 03-Aug-2002 1919 3500 3( 0 70 55(] 405 3500 3525 959 3500 10 0 0 0 725 575 0 0 550 0 0 £ 485 4600 0 04-Aug-2002 1897 3500 3( 0 60 55(] 404 3500 355(] 927 3500 10 0 0 0 725 575 390 1,950 550 0 0 C 463 4650 0 05-Aug-2002 1865 3500 3~ 0 60 55(] 400 3500 350{] 855 3500 10 0 0 0 725 575 0 0 550 0 0 C 47l 4700 0 06-Aug-2002 1850 3500 3.' 0 60 55(] 298 3500 355(] 865 3500 10 0 0 0 725 575 300 1.800 575 0 0 ~3 449 4700 0 07-Aug-2002 1880 3500 250 60 55(] 0 0 115(] 862 3500 10 0 0 0 725 575 0 0 550 0 0 C 432 4650 0 08-Aug-2002 1871 3500 250 60 55(] 0 0 115(] 840 3500 10 0 0 0 725 575 0 0 550 0 0 (] 350 4650 0 09-Aug-2002 1867 3500 250 60 55(] O 0 115(] 809 3500 10 0 0 0 725 575 0 0 550 0 0 (] 407 4650 0 10-Aug-2002 1863 3500 25 0 60 55(] 0 0 115(] 670 3500 10 0 0 £ 0 725 575 0 0 550 0 0 (] 406 4450 0 1 l-Aug-2002 1826 3500 25 0 60 55(] 0 0 115(] 592 3500 10 0 0 0 725 575 0 0 550 0 0 (] 392 4450 0 12-Aug-2002 1852 3500 25 0 60 55(] 0 0 115(] 573 3500 lO 0 0 0 725 575 0 0 550 0 0 (] 410 4450 ~ 13-Aug-2002 1867 3500 25 0 60 55(] 0 0 115(] 614 3500 10 0 0 0 725 575 0 0 550 0 0 (] 411 4450 ~ l 4~Aug-2002 1852 3500 25 0 60 55(] 0 0 115(] 660 3500 10 0 0 £ 0 725 575 0 0 550 0 0 (] 418 4450 15-Aug-2002 1870 3500 1.~ 0 80 56(] 0 0 975 660 3500 10 0 0 0 725 575 0 0 550 0 0 (] 420 4500 16-Aug-2002 1854 3475 1~0 60 555 0 0 95(] 640 3500 IO 0 0 0 725 575 0 0 550 0 0 (] 402 4500 17-Aug-2002 1812 3500 1.' 0 80 56~ 32 3500 95(] 622 3500 10 0 0 ( 0 725 575 0 0 550 0 0 (] 411 4500 18-Aug-2002 1808 3475 4( 0 70 56(1 303 3500 3125 870 3450 10 0 0 {] 0 725 575: 0 0 550 0 0 (] 413 4500 19-Aug-2002 1763 3500 4.' 0 50 555 326 3500 315(] 793 3450 10 0 0 £ 0 725 575i 0 0 550 0 0 (] 380 4500 20-Aug-2002 1786 3450 4( 0 50 555 390 3500 350(} 754 3450 10 0 0 {] 0 725 575i 0 0 550 0 0 (] 389 4400 21-Aug-2002 1810 3450 3~ 0 50 555 391 3500 350~ 804 3400 10 0 0 ~] 0 725 575i 0 0 550 0 0 0 384 4400 22-Aug-2002 1817 3475 3{ 0 50 555 390 3500 350~ 875 3475 lO 0 0 ¢ 0 725 575 0 0 550 0 0 0 390 4400 23~Aug-2002 1811 3475 3{ 0 50 555 340 3500 350~ 835 3475 10 0 0 {] 0 725 575[ 0 0 550 0 0 0 384 4400 24-Aug-2002 1764 3475 3~ 0 50 555 0 0 350~2 593 3475 10 0 0 C 0 725 57/ 0 0 550 0 0 0 391 4400 25-Aug-2002 1782 3475 3{ 0 50 555 0 0 3500 625 3475 10~ 0 0 C 0 725 57: 0 0 550 0 0 0 401 4~0 26-Aug-2002 1785 3450 0 50 555 198 3500 100~ 682 3450 I 0 0 C 0 725 57.~ 0 0 575 0 0 0 421 4400 27-Aug-2002 1787 3450 0 50 555 265 3475 3475 864 3450 1( 0 0 ~ 0 725 57.' 0 0 550 0 0 0 407 4400 28-Aug-2002 1734 3475 0 50 555 145 3500 3350 852 3450 1{ 0 0 C 0 725 57.' 0 0 550 0 0 0 372 4500 29-Aug-2002 1528 3475 0 50 555 363 3500 3350 724 3450 1( 0 0 G 0 725 57.~ 0 0 500 0 0 0 380 4500 30-Aug-2002 1793 3475 0 50 505 417 3550 3500 770 3550 1( 0 0 (] 0 730 57.' 0 0 550 0 0 0 385 4400 3 l-Au~-2002 1830 3475 3(0 50 510 417 3550 3500 848 3550 1{ 0 0 (] 0 730 60( 0 0 550 0 0 0 399 4450 TOTAL 55,693 0 6,090 23,378 0 0 1,553 0 12,796 MAXIMUM 3,500 62 80 5~0 3,550 3,550 3,550 1£ 0 0 730 60~ 2,200 575 0 0 4,700 5 AVERAGE L797 3,453 26 0 59 550 196 2,075 2,465 754 3,435 I£ 0 0 0 0 725 575 50 258 550 0 0 0 413 4,498 2 #DAYS 31 0 19 31 0 0 4 0 31 09116/2002 iC41-23 shut in due to annular communication problem. :C24A-23 shut in for field study and evaluation per Doug Marshall. SGANNED MAR 1 ~) 2003 1. Type of Request: STATE OF ALASKA ~i~11) ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Abandon ~ Suspend _'~. After casing Repair well Change approved program Operation shutdown Re-enter suspended well ~.~ Plugging.~ Time extension Stimulate ~'"- ~-- Pulltubing Variance Perforate Other __~ · · 2. Name of Operator 3. Address 3000 N. ~ield, S'ce 175, Mid.laz~, ~ 79705 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface Platform "C", Leg 4, Conductor 28 @ 4776'S & 1532'W o~= ~ NE ~ o£ Sec. 23," TS~, R13W, At top of productive interval ~1194'S & 819'W of the NE Oorner of Sec. 23, T8N, R13W, S.M. At effective depth @583'S & 1195'W of the NE Oorr~r of Sec. 23, T8N, R13W, S.M. At total depth ~506'S & 1243'W of the NE Oorner of Sec. 23, T8N, R13W, S.M. 12. Present well condition summary Total depth: measured 10,73.2/.feet Plugs (measured) true vertical 9,507 v feet 6. Datum elevation (DF or KB) 106' ~ 7. Unit or Property name 8. Well number C~1-23 9. Permit numb~[~' 68-112 10. APl number 50- 733-20163 11. Field/Pool "~-F-~" ~OO1 feet Effective depth: measured 10,535 feet Junk (measured) true vertical 9,355 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 1,653' 10-3/4",40.5#, J-55 1350s~ 1,653' 10'593' 7", 26-29#, N-80 900sx 10,593' m eas u red 9087'-10480' · See attacheG Wor~ Pro~. true vertical RECEIVED 8099'-9307' Tubing (size, grade, and measured depth) 3-1/2", 9.3# N-80 lift.lB, ~3~-~ ~- 10,160'. Packers and SSSV (type and measured depth) Packers set ~ 8898', 9582', anc~ 10,157'. "t~' ~t[~le @ 324'. NOV 0 % 7_001 Naska 0il & Gas Cons. commission Anch0mse 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation 11-15-01 16. If proposal was verbally approved Name of approver Date approved. 15. Status of well classification as: Oil Gas Service ~nje~clcm Suspended __ 17. I hereby(CCs'~ that the fo~oi, ng i~ true and correct to the best of my knowledge. Signed--~/'~,._~/,~ Title DzXZ~ac~cic~ FOR COMMISSION USE ONLY Date 10/30/01 Conditions of approval: Notify Commission~ 9o representative may witness Plug integrity BOP Test 7,~ Location clearance Mechanical Integrity Test ~ Subsequent form required 10- Approved by order of the Commission Original Signed By Cammy Oechdi Form 10-403 Rev 06/15/88 Commissioner nP. IGINA!_ XTO C41-23 T&A revision Subject: XTO C41-23 T&A revision Date: Mon, 5 Nov 2001 17:18:42 -0600 From: Paul_Figel@xtoenergy. com To: tom_maunder@admin.state.ak.us (See attached file: C41-23 Coil Tbg Cement Plug Final Revl.doc) Tom, as seen in the Revised procedure, I have set a Max press of 750 on the CT annulus & 3 1/2" tbg annulus. I'!1 have press transducers on those points of press + the WH. There should be a water column to surface while we sqz, so we more or less have a dead string press to make sure we don't get over the 750 psi w/o having to worry about friction pressure throwing us off. But if for some reason we don't have water column to surface, Dowell said @ 1 BPM down their 15,000' of CT, the friction of water is about 2,300 psi., making max WHP = +/- 3,000 psi. Let me know of any other questions, Paul C41-23 Coil Tbg Cement Plug Final Revl.doc Name: C41-23 Coil Tbg Cement Plug Final Revl.doc Type: WINWORD File (application/msword) Encoding: x-uuencode Description: Mac Word 3.0 1 of 1 11/6/01 11:45 AM XTO Energy Inc. MGS C41-23 WlW COOK INLET, ALASKA WELL DATA: SURFACE CASING: LONGSTRING: TUBING: PACKERS: PERFORATIONS: 10 3/4" 40.5#, J55, BTC. Set ~ 1,653'. Cmt w/1,350 sx. 7" 26 - 290, N80, BTC. Set ~ 10,593'. Cmt w/900 sx. TOC ~ 7,800' 26#: Surf- 8,450', 29#: 8,450' 10,593'. 3 ~" 9.3#, N80, EUE AB-MOD ~ 10,160' 7" Baker FB-1 Packer ~ 8,898'. All Pkrs set in Oct 1987. 7" Baker FB-1 Packer ~ 9,582'. 7" Baker FB-1 Packer ~ 10,157'. GN-GO: 9,087-9,108' GR-GR: 9,450-9,495' HC-HN: 9,706- 10,147' (Sqz'd w/50 sk in 9/87) HN-HR: 10,180- 10,235' HR-HZ: 10,254- 10,316' HR-HZ: 10,340- 10,480' BHST: 160 Deg F PROFILE NIPPLES: PRESENT STATUS: OBJECTIVE: X Nipples: 2.75" ID ~ 324', 8,863', & 10,123' SI since Nov 1999 w/570 psi WHP, Tbg Ann = 570 psi, SurfCsg = 475 psi. Last Injection Rate in 1999 ~ 900 BWPD ~ 650 psi WHP. Temporary Abandon the well by setting 2 cement plugs via Coil tbg across the perf'd GN-GS & HN-HZ zones. NOTE: Utilize the Dowell Coil Tbg Unit after it completes the C42-23 workover to eliminate logistic costs of a second rig up. PROCEDURE: MIRU the following: Equipment Required; · Dowell 1 ~A" CTU: Install press gauges on CT, CT annulus and 3 ¼" tbg annulus. 2 ea HP Triplex Pump (1 pump for CT unit & 1 for transfer fluids) Schlumberger 2" HSD P J2006 HMX Perforating Gun · 2 ~" PDM bit & motor (Jet Blaster & 7" Under-reamer on Standby) · Baker 3 ½" Cement Retainer 50 bbl Cement Blender 250 bbl Surface Production Vessel Materials Required: · 235 sk Class G Cement + Dispersant + Retarder + Fluid loss additives ~ Cement to have minimum 6-8 hr TT & Fluid Loss < 150 c¢/30 min. · 50 lb Fie-Vis + Biocide Final Procedure REV1 11-~-fll X'TO Energy Inc. MGS C41-23 Cook Inlet, Alaska 1. Back-flow the well 4 days prior to workover to bleed down WH press. 2. RU Slickline & test lubricator to 2,000 psi. RIH with gauge ring to 9,300' (Dummy GLV ~ 9,295'). POH. 3. RIH to retrieve the dummy valve @ 9,295'. POH w/valve. RD slickline. NOTE: Will use Coil tbg to perf3 Va" tbg if unable to retrieve the valve (~ 9,295'. . MIRU Dowell 1 ~A" Coil Tbg unit. RU press transducers on the CT WH treating line, CT annulus & 3 ½" tbg annulus. Pmax for the 7" .~.sing. & CT annulus i~. 750 psi. Install 2 ~A" PDM bit & motor. Press test BOP's & treating lines to 5,000 psi. RIH with coil tbg and clean out the 3 ~A" and 7" to 10,509' using FIW. Take returns to the 250 bbl Surface Prod Vessel. Dispose of water to the disposal well C44-14RD. Once on bottom, circ bottoms up w/20 bbl pill containing 2.5 lb/bbl Flo-Vis. POH & LD bit & motor. . RIH open ended 80 ft/min to TD @ 10,509'. Est circ w/fresh water to ensure coil tbg is clear. SI Coil tbg annulus & est an injection rate into perfs w/pmax = 750 .psi the Coil T.b~ annulus. SD. Batch mix 85 sk (17 bbl) Class G cement ~ 15.8 ppg. Pump 5 bbl fresh water. Lay a 14 bbl (70 sk) cement pill from 10,509' to 10,080' (100' above HN perf@ 10,180'). Displace w/fresh water. PU to 9,150' &circ coil tbg clean w/fresh water. Send cement returns overboard after performing a sheen test on the cement slurry. Clean out Batch mixer. POH w/coil tbg. Keep CT annulus closed until retainer is set in Step 8. 6. RU Schlumberger Wireline 2" HSD PJ2006 HMX perfgun loaded w/4 shots @ 60 deg phasing on coil tbg. RIH w/gun to 9,100'. Drop ball & fire gun. POH. 7. RU slickline & press test lubricator to 1,000 psi. RIH w/3 ½" gauge ring to 8,850'. POH & RD SL. If gauge ring fails to make it to 8,850', RIH w/Jetblaster tool & CO tbg scale w/Coil tbg before running retainer. 8. RU Baker 3 ~" Cement Retainer on Coil Tbg. RIH to 8,840' and set retainer. POH. . PU stinger & RIH. Sting into the retainer & est an injection rate into perf's w/Pmax =. 750 psi the C0il Tb~ annu!~ & 3 bbl of fresh water. SD & sting out of the retainer. Batch mix 150 sk (31 bbl) Class G cement ~ 15.8 ppg. Open the CT annulus and pump 29 bbl (142 sk) cement and displace w/fresh water. SI the CT annulus 3 bbl before the cement exits the reel & sting into the retainer. SQZ the cement through the 3 ½" tbg perf's into the GN-GO perf's ~ 9,087 - 9, 108' & GR-GS perf's ~ 9,450 - 9,495'. Sting. out of the retainer w/ 2 bbl left in coil tbg leaving a 250' cement on top of the retainer while pulling up to 8,610'. 10. Pull up 8,400' &circ coil tbg clean w/fresh water. POH & RD Dowell Coil Tbg. Record any use of the disposal well with fluid type, volume and injection rates & press. Overflush by 125 bbl FIW at end of disposing fluids. Paul Figel Production Engineer Doug Schultze Vice President Operations, Alaska Final Procedure REV1 11-5-01 XTO Energy Inc. MGS C41-23 WIW COOK INLET, ALASKA WELL DATA: SURFACE CASING: 10 3/4" 40.5//, J55, BTC. Set @ 1,653'. Cmt w/1,350 sx. LONGSTRING: 7" 26 - 29//, NS0, BTC. Set @ 10,593'. Cmt w/900 sx. TO 26//: Surf- 8,450', 29//: 8,450' 10,593'. 7,800' TUBING: 3 V2" 9.3#, N80, EUE AB-MOD @ 10,160' PACKERS: 7" Baker 7" Baker 7" Baker FB-1 Packer @ 8,898'. All Pkrs set in FB-1 Packer @ 9,582'. FB-1 Packer @ 10,157'. 1987. PERFORATIONS: BHST: GN-GO: GR-GR: HC-HN: HN-HR: HR-HZ: HR-HZ: 9,087 - 9,108' 9,450 - 9,495' 9,706- 10,147' (Sqz'd 10,180- 10,235' 10,254- 10,316' 10,340- 10,480' 160 Deg F sk in 9/87) PROFILE NIPPLES: X Nipples: 2.75" ID @ ,8,863', & 10,123' PRESENT STATUS: SI since Nov 1999 570 psi WHP, Tbg Ann = 570 psi, Surf Csg = 475 psi. Last Injection 1999 @ 900 BWPD @ 650 psi WHP. OBJECTIVE: Temporary the perf'd NOTE: Utilize the Dowell Coil Tbg Unit second rig up. PROCEDURE: the well by setting 2 cement plugs via Coil tbg across & HN-HZ zones. it completes the C42-23 workover to eliminate logistic costs of a MIRU the following: _Equipment Required:. · Dowell 1 3A" Install press gauges on CT, CT annulus and 3 ¥2" tbg annulus. · 2 ea HP Trip Pump (1 pump for CT unit & 1 for'transfer fluids) · r 2" HSD PJ2006 HMX Perforating Gun · 2 ¥2" &motor · Baker Cement Retainer · 50 Blender · 251 Surface Production Vessel Material uired: · 5 sk Class G Cement + Dispersant + Retarder + Fluid loss additives > Cement to have minimum 6-8 hr TT & Fluid Loss < 150 cc/30 min. · 50 lbFlo-Vis + Biocide Final Procedure 10-30-01 '~TO Energy Inc. MGS C41-23 Cook Inlet, Alaska 1. Back-flow the well 4 days prior to workover to bleed down WH press. 2. RU Slickline & test lubricator to 2,000 psi. RIH with gauge ring to 9,300' (Dummy GLV @ 9,295'). POH. 3. RIH to retrieve the dummy valve @ 9,295'. POH w/valve. RD slickline. · NOTE: Will use Coil tbg to perf 31/2" tbg if unable to retrieve the valve @ 9,295'. . MIRU Dowell 1%" Coil Tbg unit. Install 2 ½" PDM bit & motor. Press test BOP' treating lines to 5,000 psi. RIH with coil tbg and clean out the 3 ½" and 7" to 10,509' using returns to the 250 bbl Surface Prod Vessel. Dispose of water to the disposal well C44-14RD. on bottom, circ bottoms up w/20 bbl pill containing 2.5 lb/bbl Flo-Vis. POH & LD bit & motor. . RIH open ended 80 ft/min to TD @ 10,509'. Est circ w/fresh water coil tbg is clear. SI Coil tbg annulus & est an injection rate into perf's w/max 3,500 psi. SD. B mix 85 sk (17 bbl) Class G cement @ 15.8 ppg. Pump 5 bbl fresh water. Lay a 14 bbl (70 sk) from 10,509' to 10,080' (100' above HN perf @ 10,180').. Displace w/fresh water. PU to 9,150' & coil tbg clean w/fresh water. Send cement returns overboard after performing a sheen test on :ment slurry. Clean out Batch mixer. POH w/coil tbg. Keep CT annulus closed until retainer is set in 7. 6. RU Schlumberger Wireline 2" HSD PJ2006 HMX R[[-I w/gun to 9,100'. Drop ball & fire gun. POH. loaded w/4 shots @ 60 deg phasing on coil tbg. . RU Baker 3 ½" Cement Retainer on Coil Tbg. perf' s w/MAX 3,000 psi & 3 bbl of fresh Class G cement @ 15.8 ppg. Open the CT water. SI the CT annulus 3 bbl before the through the 3 ½" tbg perf' s into the Sting out of the retainer w/2 bbl left in to 8,610'. to 8,840' and set retainer. Est an injection rate into SD & sting out of the retainer. Batch mix 150 sk (31 bbl) ~lus and pump 29 bbl (142 sk) cement and displace w/fresh exits the reel & sting into the retainer. SQZ the cement perf's @ 9,087- 9, 108' & GR-GS perf's @ 9,450- 9,495'. tbg leaving a 250' cement on top of the retainer while pulling up 8. Pull up 8,400' & circ coil tbg fresh water. POH & RD Dowell Coil Tbg. Record any use of the disposal w, bbl FIW at end of disposing Paul Figel Production Engineer with fluid type, volume and injection rates & press. Overflush by 125 Doug Schultze Vice President Alaska Final Pr 10-30-01 C41-23 WIW Cook Inlet, Alaska Leg 4, Conductor 28 Spud: Surf Csg: 10 3/4", 40.5# J55 BTC. Set @ 1,653'. Cmt'd w/1,350 sx. Current Completion PLF 10-26-01 DF: 105' Water Depth: Tbg: 3 1/2", 9.3#, N80 EUE, AB-MOD @ 10160' Set 10-11-87 3 1/2" Otis 'X" Nipple (2.75' ID) @ 324' 3 1/2" Otis "X" Nipple (2.75" ID) @ 8863' MD (7891' TVD) Baker "E" Anchor Seal Assembly @ 8895' MD (7920' TVD) Baker FB-1 Packer w/Mill Out Ext @ 8898' MD (7920' TVD) 31/2" Camco KBUG w/Dummy @ 9295' MD (8269' TVD) Baker "G" Locator w/2 X-Seal Units @ 9579' MD (8529' TVD) Baker FB-1 Packer w/Mill Out Ext @ 9582' MD (8529' TVD) 3 1/2" Otis "X" Nipple (2.75" ID) @ 10123' MD (8994' TVD) Baker "G" Locator w/2 X-Seal Units @ 10155' MD (9023' TVD) Baker FB-1 Packer @ 10157' MD (9023' TVD) 9/12/87 Sqz csg leak 2,123-59' w/50 sk Prod Csg: 7", 26-29 lb N80 BTC. Set @ 10,593'. Cmt w/900 sk. TOC by CBL @ 7,800'. 26#: Surf - 8,450', 29#: 8,450 -10,593'. GN-GO: 9087'-9108' GR-GS: 9450'-9495' HC-HN: 9706'-10147' (Sqz in 9-87 w/100 sk) HN-HR: 10180'-10235' HR-HZ: 10254'-10316' HR-HZ: 10340'-10480' Fish (RBP):10,509' (WO 9/87) PBTD: 10,535 TD: 10,712' ~EN~ERGY C41-23 WIW Cook Inlet, Alaska Leg 4, Conductor 28 Spud: Proposed Temporary Abandonment PLF 10-26-01 DF: 105' Water Depth: Tbg: 3 1/2", 9.3~, N80 EUE, AB-MOD @ 10160' Set 10-11-87 Surf Csg: 10 3/4", 40.5# J55 BTC. Set @ 1,653'. Cmt'd w/1,350 sx. 3 1/2" Otis "x" Nipple (2.75" ID) @ 324' 3 1/2" Otis "X" Nipple (2.75" ID) @ 8863' MD (7891' TVD) Baker "E" Anchor Seal Assembly @ 8895' MD (7920' TVD) Baker FB-1 Packer w/Mill Out Ext @ 8898' MD (7920' TVD) 31/2" Camco KBUG w/Dummy @ 9295' MD (8269' TVD) Baker "G" Locator w/2 X-Seal Units ¢~ 9579' MD (8529' TVD) Baker FB-1 Packer w/Mill Out Ext O 9582' MD (8529' TVD) 3 1/2" Otis "X" Nipple (2.75" ID) @ 10123' MD (8994' TVD) Baker "G" Locator w/2 X-Seal Units @ 10155' MD (9023' TVD) Baker FB-1 Packer @ 10157' MD (9023' TVD) 9/12/87 Sqz csg leak 2,123-59' w/50 sk Prod Csg: 7", 26-29 lb N80 BTO. Set @ 10,593'. Cmt w/900 sk. TOC by CBL @ 7,800'. 26#: Surf - 8,450', 29#: 8,450 -10,593'. 3 1/2" CMT Retainer @ 8,840' SQZ Plug 2:8,610 - 9,582' w/142 sk Class G GN-GO: 9087'-9108' GR-GS: 9450'-9495' HC-HN: 9706'-10147' (Sqz in 9-87 w/100 sk) Spot Plug 1:10,080 - 509' w/70 sk Class G HN-HR: 10180'-10235' HR-HZ: 10254'-10316' HR-HZ: 10340'-10480' Fish (RBP):10,509' (WO 9/87) PBTD: 10,535 TD: 10,712' October 30, 2001 E~N~ERGY XTO Energy Inc. 3000 North Garfield Suite 175 Midland, Texas 79705 915-682-8873 915-687-0862 (Fax) Alaska Oil and Gas Conservation Commission Attn: Cammy Taylor 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Subject: Request the approval of temporary abandonment of the C41-23 Well, in the existing "EFG" pool, a shut-in water injector, in the Middle Ground Shoal Field, Platform C. Dear Ms. Taylor, XTO Energy Inc., operator of Platform C, requests that the Alaska Oil and Gas Conservation Commission (AOGCC) approve the workover on the C41-23 Injection Well in the "EFG" pool. This well was shut-in in November 1999. There are no immediate plans for the wellbore since this area has been flooded out, but a sidetrack in the future is possible. Therefore, XTO would prefer to abandon the injection intervals, which serve no purpose, without a complete P&A of the well to the surface. Current pressures for the Surface Casing, tbg & tbg annulus are 475 psi, 570 psi, and 570 psi, respectively. The procedure enclosed is designed to place cement across the open injection intervals, as per state P&A requirements, using coil tbg. I apologize for the short notice on this workover, but utilizing a coil tbg unit behind another planned coil tbg workover in November would save XTO a considerable amount of money in rig up & logistical costs. Also, XTO would prefer to perform this treatment prior to the activation of the drilling rig for the Platform C Project that should start early December. In summary, XTO Energy requests the AOGCC permit the temporary abandonment of the C41-23 Well. Please direct any operational questions to Paul Figel at (915) 620-6743. Questions of a reservoir, or geologic nature may be directed to Tim Smith, Reservoir Engineer (817) 885-2246 or Mike Langeler, Geologist (817) 885-2581. Please notify me at my number included above as soon as the approval has been granted. Thank you for your assistance. Sincerely, Paul L. Figel Production Engineer RECEIVED NOV 0 001 ORIOINAL Alaska 0il & Gas Cons. Commission Anchorage Cc: Doug Schultze Doug Marshall Tim Smith Mike Langeler List of Attachments: 1. Present Wellbore Diagram 2. Proposed Wellbore Diagram 3. Workover Procedure RECEIVED NOV 0 ~ 2r)~),'~ Naska Oil & Gas Cons, commission Anchorage ORIGINAL XTO C41-23 T&A revision Subject: XTO C41-23 T&A revision Date: Mon, 5 Nov 2001 17:18:42 -0600 From: Paul_Figel@xtoenergy. corn To: tom_maunder@admin.state.ak, us (See attached file: C41-23 Coil Tbg Cement Plug Final Revl.doc) Tom, as seen in the Revised procedure, I have set a Max press of 750 on the CT annulus & 3 1/2" tbg annulus. I'll have press transducers on those points of press + the WH. There should be a water column to surface while we sqz, so we more or less have a dead string press to make sure we don't get over the 750 psi w/o having to worry about friction pressure throwing us off. But if for some reason we don't have water column to surface, Dowell said @ I BPM down their 15,000' of CT, the friction of water is about 2,300 psi., making max WHP = +/- 3,000 psi. Let me know of any other questions, Paul C41-23 Coil Tbg Cement Plug Final Revl.doc Name: C41-23 Coil Tbg Cement Plug Final Rev1 .doc Type: WINWORD File (application/msword) Encoding: x-uuencode Description: Mac Word 3.0 1 of 1 11/6/01 11:45 AM February-200 I OI-Fcb-2001 02-F~b-200 1 03-Feb-200 ! 04-Feb-2001 05-Feb-2001 06-Feb-2001 07-Feb-2001 08-Feb-2001 09-Feb-20OI lO-Feb-2001 1 ! -Feb-2001 12-Feb-2001 i 3-Feb-200 I 14-Feb-2001 15-Feb-2001 16-Feb-2001 ! 7-Feb-200 ! 18-Feb-2001 19-Feb-2001 20-Feb-200 I 2 ! -Feb-200 ! 22-Feb-20Oi 23-Feb-2001 24-Feb-200 ! 25-Feb-200 i 26-Feb-200 I 27-Feb-200 I 28-Feb-2001 TOTAL MAXIMUM AVERAGE # DAYS 03/12/2001 WATER INJECTION REPORT PLATFORM C C23-23 C41-23 ACT ~J ~J ANNU 1762 3250 325( 0 500 52( ACT INJ INJ ANNU C24-23 C34~23 1632 3250 325( 1702 3250 325( 1696 3250 3250 1693 3250 3250 1710 3200 320~ 1694 3200 3200 1708 3200 3200 1667 3200 3200 1653 3200 3200 1680 3200 3200 1674 3200 3200 1667 3200 3200 1674 3200 3200 1647 3250 3200 1652 3250 3200 1649 3250 3200 1648 3250 3200 1654 3250 3200 1644 3250 320~ 1445 3250 320~ 0 500 52( 0 500 52( 0 500 52( 0 500 521 0 500 52 0 500 520 0 500 ~ 52 0 500 52 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 ACT INJ INJ ANNU 386 3500 3500 379 3500 3500 393 3500 3500 389 350O 3500 386 3500 3500 386 3450 3450 384 3450 3450 385 3450 3450 382 3450 3450 375 3450 3450 379 3450 3450 382 3450 3450 380 3450 3450 381 3450 3450 372 3450 3425 373 3450 3425 368 3500 345~ 368 3500 345~ 367 3500 345~ 366 3500 345~ 333 3500 345~ ACT INJ INJ ANNU 1742 3200 3200 1665 3200 3200 1741 3200 3200 1730 3200 3200 1727 3200. 3200 1733 3200 3200 1727 3200 3200 1745 3200 3200 1728 3200 3200 1711 3200 3200 1729 3200 3200 1739 3200 3200 1728 3200 320~ 1737 3200 320~ 1707 3200 3175 1714 3200 3175 1706 3500 320~ 1704 3500 320~ 1708 3500 320C 1696 3500 31=75 1533 3500 3175 C23-26 ACT INJ INJ ANNU o o o o o o o o o o o 0 o o o o o o o o 0 o o o o o o o o o o o o o o o o o o o o o C41-26 ACT ~J ~J AN'NU 0 800 65C 0 800 65C 0 800 65C 0 800 65~ 0 800 65C 0 800 65C 0 800 65¢ 0 800 65~ 0 800 65C 0 800 65(~ 0 800 65C 0 800 65£ 0 800 65£ 0 800 65f 0 800 65C 0 800 65f 0 800 65( 0 800 65f 0 800 65( 0 180 10( 0 300 C44-14RD C24A-23 C24A- 14 ACT ACT ACT INJ INJ ANNU l'NJ IHJ ANN1 INJ ' rNJ 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55~ 0 0 550 0 0 550I 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 248 4400 253 4475 277 4500 272 4500 259 4500 266 4525 262 4525 252 4525 250 4500 246 4500 243 4500 258 4500 256 4500 247 4500 246 4450 253 4450 251 4450 248 4450 247 4500 257 4500 260 4500 356 4475 357 '4525 399 4575 392 4575 387 4575 382 4575 370 4575 369 4575 366 4550 369 4550 364 4550 359 4550 355 4550 362 4550 359 4500 359 4500 356 450r 360 45~ 362 4500 365 4500 368 4500 0 2200 220~ 0 2200 220C 0 1900 1825 0 1850 1775 0 1750 175~ 0 1750 165( 0 1750 165C 34,951 3,250 3,250 1,248 2,900 2,875 21 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 o 500 525 0 500 523 o 237 1500 165c 77 1500 165~ 425 3450 345c 406 3450 345( 406 3450 345c 425 3500 350{ 423 3500 350{ 10,313 3,500 3,50~ 368 3,332 3,332 28 887 1800 1625 291 1800 1625 1949 3050 330{ 1863 3300 330{ 1873 3300 330{ 2003 3400 340{ 2000 3400 340( 0 0 0 0 0 0 0 0 0 0 0 0 0 0 46,816 0 3,500 3,400 0 !,672 3,170 3,109] 0 0 28 : 0 0 300 10~ 0 300 10~ 0 300 105 0 300 105 0 300 105 0 300 105 0 300 105 o o 800 650 o o 635 475 o o o 550 o o 550 0 o 550 o o 550 o o 550 o o 550 o o 550 0 o 550 o o 550 o 162 4500 19 4500 263 4350 283 4400 286 4550 286 4500 268 4500 6,918 4,550 247 4,484 28 225 3000 32 3000 423 4350 426 4350 421 4550 401 4550 396 4550 10,040 4,575 359 4,414 0 28 C41=23 shut in due to annular communication problem. C34-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. C23-23 shut in for upcoming drilling operation at the end of March. All injectors hnve reduced inected barrels on 2122 & 2/23 to change accumulator relief valve. RECEIVED MAR 1 3 2001 Alaska Oil & Gas Cons. Commission Anchorage WATER INJECTION REPORT PLATFORM C January-2001 01 o Jan-2001 02-lan-2001 03-$an-2001 04Jan-2001 05-Jan-2001 06-Jan-2001 C23-23 ACT INJ INJ ANNU 1732 3250 3250 1749 3250 3250 1775 3250 3250 1822 3300 3250 1748 3300 3250 1726 3250 3250 C41-23 ACT INJ INJ ANNU 0 500 520 0 500 52(1 0 500 52~ 0 500 52¢ 0 500 52C 0 500 52C 07-Jan-200 ! 08-Jan-2001 09Jan-2001 10-Jan-2001 11 -San-2001 12-Jan-2001 13-$an-2001 14-Jan-2001 15-Jan-2001 16-Jan-2001 17-Jan-2001 18-Jan-2001 19-Jan-2001 20-Jan-2001 2 l-Jan-200 1 22-$an-2001 23-Jan-2001 24-Jan-2001 25-Jan-2001 26-Jan-2001 27-Jan-2001 28-Jan-2001 29-Jan-2001 30-Jan-2001 31 -Jan-200 1 TOTAL MAXIMUM AVERAGE # DAYS 02/12/2001 1758 3300 3250 1792 3250 325O 1783 3250 325~ 1773 3300 325C 1750 3300 325C 1748 3300 325C 1760 3250 325C 1752 3250 325( 1760 3250 325( 1773 3250 3250 1730 3250 3225 1737 3225 3225 1653 3250 3225 1781 3250 3250 1562 3250 3250 1709 3250 3250 1730 3250 3250 1732 3250 3250 1738 3250 3250 1748 3250 3250 1707 3250 3250 1758 3250 325~ 1741 3250 325~ 1752 3250 325¢ 1752 3250 325£ 54,031 3,300 3,250 1,743 3,259 3,248 31 0 500 52C 0 500 52.~ 0 500 52.~ 0 500 525: 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 52(1 0 5OO 52~ 0 500 522 0 500 525 0 500 525 0 50O 525 0 500 52.~ 0 500 52.~ 0 500 52.~ 0 500 52~ 0 50O 5251 0 500 525 0 500 525 0 500 525 0 500 525 o 500 525 0 500 524 o C24-23 ACT INJ INJ ANNU 371 3400 3400 370 3400 3400 373 3400 3400 C34-23 ACT INJ INJ ANNU 1618 2950 3150 1616= 2950 3150 1630 2950 315~ C23-26 ACT INJ INJ ANNU o o o 0 o o 389 3500 3500 377 3500 3500 371 3400 3400 380 3450 3450 386 3450 3450 384 3450 345G 387 3450 3450 379 3450 345¢ 376 3450 345C 378 3450 345( 1678 3200 320~ 1609 3000 320( 1623 2950 315( 1634 2950 320( 1654 3200 320( 1642 3200 320( 1640 2950 320( 1621 2950 320( 1610 2950 3200 '1621 3200 3200 o o o 0 0 o o o o o 0 o 0 o o o o 0 o 0 380 3450 345C 382 3450 345( 382 3450 345( 371 3425 342~ 371 3400 3450 371 3450 3450 393 3450 3450 355 3450 3450 375 3450 3450 378 3450 3450 377 3450 3450 376 3450 3450 377 3450 3450 376 3450 3450 390 3450 3450 382 3450 345~ 387 3450 345~ 381 3450 345~ ! 1,725 3,5OO 3,50~ 378 3,444 3,446 31 1616 3200 320O 1627 32O0 32OO 1631 3200 3200 1589 3200 3200 1593 3200 320~ 1529 3200 320~ 1657 3200 320~ 1454 3200 320( 1610 3200 320( 1625 3200 · 32(~ 1626 3200 320( 1628 32O0 320( 1632 3200 320( 1600 3200 320( 1706 3200 320( 1729 3200 320( 1735 3200 320( 1725 3200 3200 50,5O8 3,200 3,2OO 1,629 3,129 3,194 31 o o 0 o o o 0 0 0 0 o o o o o o 0 0 o o o 0 o o 0 o o o o 0 o o o o 0 o 0 0 0 0 0 C41-23 shut in due to annular communication problem. C34-23 has developed an annular communication problem. AOGCC notifi~l on 12/12/99. Verbal approval to continue to inject ~ceived from Mr. Wondzell on 12/14/99. C41-26 ACT INJ INJ ' ANNU 0 780 625 0 780 625 0 0 780 625 0 0 780 650 0 0 780 625 C44-14RD C24A-23 C24A- 14 0 0 780 625 0 0 780 625 0 0 785 65( 0 785 65£ 0 785 65( 0 785 65f 0 785 65( 0 785 65( 0 785 650 0 785 650 0 785 650 0 790 650 0 650 790 0 790 650 o 790 650 0i 0 790 650 0 0 790 650 0 0 790 65~ 0 790 65¢ 0 790 65C 0 790 65C o 790 65C 0 790 65C 0 790 65( 0 790 65( 0 79O 65( o 790 79C 0 782 650 0 ACT INI INJ ANNU 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 ACT INJ I.NJ ANNU 141 3400 132 3400 135 3400 -129 3500 11 120 3500 105 INJ I. NJ ANNU 212 3500 243 3500 257 3500 264 3500 260 3500 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55~ 0 0 55¢ 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55o 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55~ o 0 55o! o o 550 o o 550 o 144 3350 .0 252 4100 10~ 294 4250 271 4350 272 4350 269 4350 260 4350 264 4450 283 4450 271 4450 01 233 4450 0 234 4525 0 238 4550 0 248 4400 288 4500 228 4500 279 4500 285 4500 230 4450 233 4450 273 4450 217 4450 269 445O 253 4450 257 4450 262 4450 7,264 4,550 11(~ 234 4,231 10 31 287 3500 374 4100 405 4300 400 4400 409 4350 411 4350 414 4350 412 4400 402 4400 398 , 4400 403 4400 403 4575 400 4600 346 4450 397 4550 317 4550 380 4550 385 4550 369 4500 371 4500 374 4500 348 4500 398 4500 379 '4500 379 4500 378 4500 11,175 4,600 360 4,267 31 WATER INJECTION REPORT PLATFORM C December-2000 [ C23-23 INJ INJ ANNU 01-Dec-2000 02-D¢c-2000 03-D¢c-2000 04-Dec-2000 05-D¢c-2000 06-Dec-2000 07-Dec-2000 0g-Dec-2000 09-Dec-2000 10-Dec-2000 11-Dec-2000 12-Dec-2000 13-D¢c-2000 14-Dec-2000 15-Dec-2000 16-Dec-2000 17-D¢c-2000 18-Dec-2000 19-Dec-2000 20-Dec-2000 21 -Dec-2000 22-Dec-2000 23-Dec-2000 24-Dec-2000 25-Dec-2000 26-Dec-2000 27-Dec-2000 28-Dec-2000 29-Dec-2000 30-Dec-2000 3 l-Dec-2000 TOTAL MAXIMUM AVERAGE # DAYS 1872 2550 32O0 1716 2550 3200 0 2550 32O0 184 2550 32O0 1853 2550 320(3 1961 2550 320~ 1739 3250 3250 468 2500 25O0 166 2500 250~ 2048 325O 320~ 1899 3250 325¢ 1867 3250 325C 1839 3250 325¢ 1817 3250 325( 1809 3250 325( 1815 3250 325( 1820 3250 325( 1838 3250 3250 1834 3250 3250 1723 3250 3250 1793 3250 3250 1787 3250 3250 1778 . 3000 3250 1775 3300 3250 1774 3300 3250 1444 3300 3250 1723 3250 3250 1733· 3250 3250 1680 3250 3250 1726 3250 3250 1720 3250 3250 49,201 3,300 3,250 1,587 3,063 3,190 30 C41-23 ACT INJ INJ ANNU 0 500 54( 0 500 54( 0 500 54( 0 500 54( 0 500 54f 0 500 54( 0 500 52( 0 500 52( 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 · 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 o 500 520 o 5O0 520 0 500 520 0 500 520 0 5oo 520 0 500 520 0 5O0 520 0 500 520 0 500 520 0 500 520 0 500 540 0 500 524 0 0111.2/2001 C24-23 ACT INJ INJ ANNU 389 3400 5425 352 3400 3425 0 3400 3425 76 3400 3425 412 3400 3425 410 3400 3425 406 3500 3500 4O9 35OO 35O0 404 35OO 3500 4O2 35OO 35O0 404 3500 35O0 404 3500 3500 403 3500 3500 C34-23 ACT INJ - INJ ANNU 1862 3050 3275 1681 3050 3275 0 3050 3275 202 3050 3275 1848 3050 3275 1947 3050 3275 1825 3300 330( 1762 3300 330( 1728 3500 325( 1729 3500 3250 1740 3500 3250 1751 3500 325( 1738 3500 325( C23-26 ACT INJ INJ ANNU 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C41.26 ACT INJ INJ ANNU 0 770 650 0 770 650 0 770 650 0 770 650 0 770 650 0 770 650 0 775 625 0 775 550 0 770 55¢ 0 770 625 0 770 625 0 770 625 0 770 625 C44-14RD ACT INJ INJ ANNU 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 C24A-23 ACT INJ INJ ANNU 147 3400 123 3400 0 3400 56 3400 182 3400 180 3400 171 3500 141 3500 131 3500 120 3500 154 3500 162 3500 152 3500 C24A- 14 ACT I_NJ INJ 291 3450 259 3450 0 3450 79 3450 366 3450 313 3450 299 ~500 287 3500 276 3500 279 3500 273 3500 271 3500 268 3500 398 3500 35O0 401 3500 350~ 402 3500 350( 404 3500 350( 406 3500 350( 407 3500 350( 375 3400 340( 398 3500 350( 398 3500 350( 393 3450 3450 392 3450 345f 395 3450 345( 321 3450 345( 375 3400 340( 371 3400 340( 365 3400 340( 371 3400 340( 369 3400 3400 11,412 3,500 3,500 368 3,455 3,460 30 1726 3500 325( 1726 3500 325C 1730 3500 3250 1734 3500 3250 1746 3500 3250 1740 3500 3250 1611 2950 3150 1724 3500 3200 1711 3200 3200 1698 3300 3200 1689 3450 3200 1681 3000 3200 1363 2950 3200 1611 2950 3150 1635 2950 3150 1587 2950 3150 1623 2950 3150 1614 2950 3150 o o o o o o o o 0 0 o . o o o o o o o o o o o o o o o o o 0 0 o o o o o 0 0 770 625 0 770 625 0 770 · 62~ 0 770 62~ 0 770 625 0 770 625 0 780 625 0 780 625 0 780 625 0 780 625 0 780 625 0 780 625 0 780 625 0 780 625 0 780 625 0 780 625 0 780 625 0 780 625 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 O' 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 145 3500 138 3500 132 3500 110 3500 123 3500 237 4100 227 4250 287 4250 263 4250 259 4325 268 4350 247 4400 267 4400 227 4250 201 3350 223 4250 144 3350 198 3400 3,500 3,300 1,605 3,242 3,229 3O 0 o 0 0 o 780 650 774 625 0 o 550 0 0 550 O' 5A15 4,400 175 3,720 30 257 3500 270 3500 275 3500 275 3500 289 3500 389 4100 395 4350 443 4250 434 4300 450 4350 432 4400 433 4450 423 4~50 395 4350 317 2700 363 4350 287 3500 310 3500 9,698 4A50 313 3,734 30 C41-23 shut in due to annular communication problem. C34-23 has developed an annular communication problem. AOC_d2C notified on 12/12/99. Vednl approval to continue to inject received from Mr. Wondz~il on 12/14/99. ITl WATER INJECTION REPORT PLATFORM C ~ · N ovember-,20(~O 0 ! .. Nov..2 02.. Nov- 03.- Nov. 2~'VJ0 04-Nov-2000 05..Nov.-20~J (k~-Nov-2000 07.Nov.2000 08-.Nov..2CK)0 09..Nov..2C~X) I 0-Nov-2C~)0 I t .-Nov.2~)0 12-Nov-2~ 13 -N ov..2CgJg) 14-Nov-2C(D 15.Nov.20(~I I 1 1 g-NOv- 19..Nov. 2~Nov-2~ 21 22-Nov-2C~0 23-.Nov-2~O0 25.-Nov..2(R}0 27..Nov.2~ 28-Nov-2~YO 29-Nov..2(g3) 3(~Nov- TOTAL MAXIMUM AVERAGE # DAYS i 2/1112000 C23-23 C41-23 C24-23 ACT ACT ACT INI INJ ANNU INJ INJ ANNU INJ INJ ANNU 1807 ' 3300 3300 1788 3300 3300 1815 3300 3300 1799 3300 3300 1795 3300 3300 1804 3300 3300 1806 3300 3300 1780 3300 3300 1808 3300 3300 1800 3300 3300 1726 3300 3300 1698 3250 3250 1695 3250 3250 1718 3250 3250 1705 3250 3250 1687 3250 325{ 1702 3250 325{ 1710 3250 325( 1694 3250 325( 1707 3250 325( 1690 3250 325( 1693 3250 325( 1688 3250 325( 1693 3250 325( 1694 3250 325( 1711 3250 3250 1695 3250 3250 1301 3250 3250 1704 3250 3250 1767 3300 3300 51,680 3,300 3,300 1,723 3,270 3,270 30 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 0 500 52C 0 500 52C 0 500 525 0 500 52~ 0 500 52~ 0 500 523 0 500 523 0 500 52( 0 500 52( 0 500 52( 0 500 520 0 500 520 0 500 520 0 500 520 0 500 530 0 500 530 0 500 530 0 500 520 0 500 520 0 5OO 52O o 500 520 0 500 535 0 500 520 0 500 535 0 500 522 0 435 3500 350( 430 3500 350( 436 3500 350( 431 3500 350( 428 3500 3500 430 3500 3500 432 3500 3500 422 3500 3500 433 3500 3500 431 3500 3500 426 3500 3500 424 3500 3500 423 3500 3500 431 3500 350~ 427 3500 3500 420 3500 350{ 425 3500 350{ 426 3500 350{ 422 3500 350{ 426 3500 350{ 420 3500 350{ 420 3500 350{ 418 35OO 350( 421 3500 350( 419 3500 350( 424 3500 350( 420 3500 350( 321 3500 350( 404 3450 3462.5 422 35OO · 35OO 12,647 3,5OO 3,500 422 3,498 3,499 30 C34-23 ACT I'NJ INJ ANNU 1730 3300 3300 1710 3300 3300 1736 3300 3300 1714 3300 3300 1710 3300 3300 1720 3300 33O0 1727 3300 3300 1690 3300 33O0 1733 3300 330~ 1723 3300 330{ 1673 3300 33O0 1648 3250 325C 1643 3250 325C 1668 3250 325C 1657 3250 325C 1639 3250 325C 1663 3250 325( 1674 3250 325( 1662 3250 325( 1684 3250 325( 1667 3250 325( 1669 3250 '325( 1667 3500 3250 1676 3550 3250 1684 3500 3250 1708 3500 3250 1693 3500 3250 1297 3500 3250 1769 3275 3250 1683 3300 33O0 50,317 3,550 3,300 1,677 .3,323 3,270 30 C23-26 ACT INJ rNJ ANNU 0 0 o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C41-26 ACT INJ INJ ANNU 0 760 600 0 760 600 0 760 600 0 760 .600 0 760 600 0 760 600 0 760 600 0 760 600 0 760 600 0 760 60~ '0 760 600 0 770 60{ 0 770 60{ .0 770 60{ ',0 770 625 0 770 625 0 770 '62~ 0 770 623 0 770 623 0 770 62~ 0 770 62~ 0 770 62~ 0 770 625' 0 770 625 0 770 625 0 770 625 0 770 625 0 770 625 0 770 625 0 76O 60~ 0 770 625 0 766 613 '0 C44-14RD C24A~23 ACT ACT ~J ~J AN'N'U ~J INJ ANNU 0 0 550 108 3500 165 0 0 ' 550 104 3500 165 0 0 550 112 3500 165 0 0 550 116 3500 165 0 0 550 120 3500 165 0 0 550 117 3500 165 0 0 550 118 3500 165 0 0 550 121 3500 165 0 0 550 129 3500 165 0 0 550 126 3500 145 0 0 550 120 3500 145 0 0 550 ' 120 3500 160 0 0 550 127 3500 150 0 0 550 116 3500 150 0 0 550 121 3500 "KSx 0 0 550 126 3500 0 0 550 135 3500 0 0 550 123 3500 155 0 0 550 129 -3500 145 0 0 550 137 3500 145 0 0 550 135 3500 145 0 0 550 136 3500 142 0 0 550 132 3450 142 0 0 550 137 3450 140 0 0 550 130 3500 135 0 0 550 135 3500 135 0 0 '550 131 3500 135 0 0 550 104 3500 135 0 0 550 151 3500 150 0 0 550 103 3500 175 0 3,719 0 550 3,500 175 0 0 550 124 3,497 153 0 30 C41-23 shut in du," tO annular communication problem. C34-23 has developed an annular communication problem. AOGCC miffed on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzeli on 12/14/99. RECEIVED DEC g 1 000 Alaska Oil & Gas Cons. Commi~n WATER INJECTION REPORT PLATFORM C · ,'.~) ~l o [~ ~, ~...'" (: ~ '~ C23 -23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14E.D C24A-23 C24A- 14 ::::::::::::::::::::::::::::::::: :::::::::: ::::: ACT ACT ACT ACT ACT ACT ACT ACT ACT 0~-('~ct-200(} 1879 3350 330( 0 500 515 422 3450 34501824 3350 3300 0 0 0 0 750 600 0 0 550 80 3450 225 344 3450 02..(.')ct · 20()(~ . 1861 3350 330( 0 500 515 420 3450 34501813 3500 3300 0 0 0 0 750 600 0 0 550 74 3450 225 341 3500 03 -('.)c~..200(~ 1886 3450 330(0 500 510426 3450 3450 1839 3500 33000 0 0 0 750 600 0 0 550 71 3450 210341 3500 04-(.3ct.200(} 1852 3450 330( 0 500 510 416 3450 34501798 3500 3300 0 0 0 0 750 60(] 0 0 550 61 3450 210 337 3500 (.~ -(')ct- 21~)0 1864 3450 330( 0 500 510 419 3450 34501812 3500 3300 0 0 0 0 750 600 0 0 550 77 3450 210 343 3500 ~6-C)c~.2~() 1658 3350 320( 0 500 51¢ 411 3450 34501812 3350 3300 0 0 0 0 745 60~ 0 0 550 86 3450 230 329 3500 ¢~ · .7-(~c~-2~)0' 1830 3450 330( 0 500 51C 409 3450 34501771 3500 3300 0 0 0 0 750 600 0 0 550 68 3450 210 308 3500 · 08-(~)c~.20~)~} 1837 3450 330( 0 500 510 410 3450 34501773 3500 3300 0 0 0 0 750 600 0 0 550 67 3450 210 306 3500 (~-('.~c~- -%~00 · 1854 3450 330( 0 500 51C 414 3450 34501785 3500 3300 0 0 .0 0 750 60~ 0 0 550 80 3450 210 312 3500 t0-~.')c~. 200(~ 1839 3450 330( 0 500 51~ 411 3450 345(~ 1767 3500 3300 0 0 0 0 750 600 0 0 550 99 3450 210 316 3500 t [ -C)cl- 2 f,'.00 1844 3450 330( 0 500 51C 413 3450 345~1775 3500 3300 0 0 0 0 750 600 0 0 550 100 3450 21~ 318 3500 t ~-(.')c~-2000 1871 3350 330(0 500 51~418 3450 345C 1803 3500 33000 0 0 0 750 60~ 0 0 550 83 3450 185312 3500 l.~-(~)cl-~01 1896 3350 330( 0 500 51~ 427 3450 345£1835 3500 3300 0 0 0 0 750 60~ 0 0 550 73 3450 185 311 3500 14-C)¢;t.2000 1870 3350 330( 0 500 51~ 423 3450 345{1817 3500 3300 0 0 0 0 750 60( 0 0 550 78 3450 185 307 3500 I ~-C')ct-2(~)0. 1881 3350 3300 0 500 51{ 424 3450 345{1824 3500 3300 0 0 {~ 0 750 60( 0 0 550 74 3450 18£ 306 3500 I ,~ -(.')ct .2~X)(~ 1791 3350 3300 0 500 51( 423 3450 345C1730 3500 3300 0 0 ¢ 0 750 60( 0 0 550 72 3450 18C 306 3500 1 '? -Oct- .'2(.~10 1783 3300 3200 0 500 51.~ 427 3450 345( 1717 3500 3250 0 0 ¢ 0 750 60( 0 0 550 70 3450 18~308 3500 18-C')ct.2(X)(~ 1772 3300 3200 0 500 51.~ 424 3450 345(1705 3500 3250 0 0 C 0 750 60( 0 0 550 70 3450 18~ 309 350( 19-OcI-~(~.)(} 1783 3300 3200 0 500 51.~ 426 3450 345(1713 3500 3250 0 0 C 0 750 60( 0 0 550 70 3450 18~ 271 3500 20-C)c~. 20~)0 1794 3300 3200 0 500 51.~ 429 3450 345( 1717 3500 32500 0 ( 0 750 60( 0 0 55068 3450 18~345 3500 21-(3¢t-200(~ 1766 3300 3200 0 500 51.~422 3450 345( 1694 3500 32500 0 ( 0 750 60( 0 0 55074 3450 18~302 3500 22-Oc~-2000 1747 3300 3200 0 500 51.~ 416 3450 345( 1669 3500 325¢0 0 0 750 60( 0 0 550103 3450 181 298 3500 2.~-C)ct-2~E~0 1788 3300 3200 0 500 51.~ 426 3450 345(1708 3500 325¢ 0 0 0 750 60( 0 0 550 86 3450 181 259 3500 24-0ct.2(X)0 1782 3300 3200 0 500 51: 428 3450 345(1704 3500 325C 0 0 0 750 60( 0 0 550 94 3450 188 197 3500 ~.~.-(3ct-2~,)0 1802 3300 3300 0 500 52( 432 3500 350(1723 3300 330( 0 0 0 760 60( 0 0 550 117 3500 185 256 3400 26-(.')c;.20'0~') 1780 3300 3300 0 500 520 426 ' 3500 350( 1703 3500 330C 0 0 0 760 600 0 0 550 100 3500 . 190 284 3500 ~'?-¢'~ct-2000 1785 3300 3275 0 500 520 426 3450 345(~ 1704 3300 330( 0 0 0 760 600 0 0 550 104 3450 190 281 3500 28-~)ct-20~)0 1796 3300 3300 0 500 520 430 3500 3500 .1712 3300 330( 0 0 0 760 600 0 0 550 107 3500 185 278 3500 '~9-Oc1-2~)0 1864 3300 3300 0 500 520 446 3500 350( .1777 3300 330( 0 0 0 760 600 0 0 550[ 105 3500 185 294 3500 30-Oc~.2000 1767 3300 3300 0 S00 520 422 3500 3500 1683 3300 330( 0 1 0 0 0 760 600 0 0 5501 103 3500 175 280 3500 3 t-C)cl-.~000 1782 3300 3200 0 500 515 428 3450 3450 1704 3500 325( 0 0 0 0 750 600 94 3450 188 197 3500 TOTAL 56,304 0 13,094 - 54,411 0' 0 0 2,608 9,296 MAXIMUM 3,450 3,300 500 520 3,500 3,500 3,500 3,300 0 0 760 600 0 550 3,500 230 3,500 AVERAGE 1,816 3,352 3,267 0 500 514 422 3,458 3,458 1,755 3,458 3,285 0 0 0 0 752 600 0 0 550 84 3,458 196 300 3,495 #,DAYS 31 0 31 31 0 0 0 31 31 11/14/2000 ~1-23 shut in due to annular conm~nication problem. · 34-23 has developed an annular conmsmication problent AC)GCC notified on 12/12/99. Verbnl approval to continue to inject received from Mr. Wondzell on 12/14/99. WATER INJECTION REPORT PLATFORM C .~\ ~.,.,.~.~ ~:I .. 2 (,'.00C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 C24A-14 :: i'!i i iii ! i! i :: i !i ::i! i :: i :: il !:: i il ~ iii:: i ii~ i ACT ' A~T ACT ACT ACT ACT ' ACT ACT ' ACT i: D~'~. ~ ~,~ .~).~]~Sl: !: ~i :i~ i:i:!!~: I~NIJ [NJ ANaLI [NJ l~J .A~U [NJ [NJ ANNU ]NJ [NJ ANNU INJ INJ ANNU INJ i]~J ANNU IN.[ IN.[ ANNLJ [NJ INJ ANNLI INJ' INJ · ,.'J ~ ..~. ~.~-..~ o~,<} 1916 3350 33513 o 500 50~ 449 3500' 350( 2149 3400 340( 0 15 0 0 702 56¢ ' '0 ' o 550 126 3500 255 358 3500 02 -A ~g- ~ 0.'..'.~ 1905 3350 335¢ 0 500 50~ 446 3500 3500 2131 3400 340( 0 15 0 0 702 56¢ 0 0 550 130 3500 255 347 3500 03..Au._o.. ~ :.~.~ 1931 3350 335(:0 500 50~ 442 3500 3500 2146 3400 340( 0 15 (~0 702 56C 0 0 550 123 3500 190350 3500 04-A ~{:'...20~) 2026 3350 335(~ 0 500 50~ 445 3500 350( 2151 3400 340( 0 15 0 0 702 56¢ 0 0 550 128 3500 200 329 3500 05. At~..?OO0 2018 3350 340( 0 500 51( 446 3500 3500 2151 3400 345( 0 15 0 0 702 55C 0 0 550 124 3500 200 335 3500 06-A~.2000 2000 3350 340( 0 500 51( 443 3500 3500 2135 3400 345( 0 ]5 (~0 702 55C 0 0 550 123 3500 250329 3500 0?..A ~. ? ~,',)~ 1975 3350 340( 0 500 5l( 437 3500 3500 2104 3400 3450 0 15 C 0 702 55£ 0 0 550 135 3500 260322 3500 08 -.'\ ~..20~ 1982 3350 340( 0 500 51¢ 438 3500 3500 2106 3400 345( 0 15 O 0 702 55C 0 0 550 135 3500 265 322 3500 09..A t~..?: 0~0 1957 3350 340C 0 500 51{ 432 3500 3500 2078 3400 345( 0 15 (~ 0 702 55( 0 0 550 128 3500 260 321 3500 10-At~g- 2(.~)0 1969 3350 340( 0 500 51( 435 3500 3500 2085 3400 3450 0 15 (~ 0 702 55( 0 0 550 130 3500 26(~ 325 3500 ] ] -..'\Lt..o..20,'~h~) 1956 3350 340C 0 500 51( 433 3500 3500 2073 3400 3450 0 15 (~0 702 55C 0 0 550 129 3500 260323 3500 12-A~g..2000 1987 3350 340( 0 500 51( 438 3500 3500 2108 3400 3450 0 15 (~ 0 702 55( 0 0 550 139 3500 26(~ 323 3500 13 ..~.'~g..~ 0~..'0 38 3350 340( 0 500 51( Ii 3500 3500 37 3400 3450 0 15 C 0 702 55( 0 0 550 23 3500 26(3 20 3500 14-A g-2000 1173 3250 325( 0 500 510 301 3500 3500 1048 3300 3300 0 15 C 0 702 55( 0 0 550 125 3500 26(~ 343 3400 15..,'\~t~..20 ~0 1965 3300 330( 0 500 51( 488 3500 3500 1944 .3300 3300 0 15 C 0 702 55( 0 0 550 145 3500 26(3 405 3500 I 6-Aug-20C<) 1909 3300 330( 0 500 510 475 3500 3500 1938 3300 3300 0 15 C 0 702 55{ 0 0 550 159 3500 268 363 3500 I ? .A:~g...'2. 0~*r0 1900 3350 330( 0 500 510 475 3500 3500 1941 3300 3325 0 15 C 0 720 575 0 0 550 145 3500 265 356 350( 1 ~-At~g-2000 243 3350 330( 0 500 510 62 3500 350~ 248 3300 3325 0 15 C 0 720 575 0 0 550 20 3500 265 47 3500 19-.,,\ug..2000 2079 3350 330( 0 500 510 481 3500 3500 2008 3300 3300 0 15 C 0 720 575 0 0 550 164 3500 25C441 3500 20-Aug-2(F,X) 1949 3350 330( 0 500 510 460 3500 3500 1982 3300 3300 0 15 C 0 720 575 0 0 550 140 3500 25C370 3500 ~ .A~g..~000 1930 3375 332.~ 0 500 510 458 3500 350~ 1973 3325 3325 0 0 0 720 575 0 0 550 143 3500 255 356 3500 22-At~g-20~) 1919 3375 332.~ 0 500 510 458 3500 3500 1972 3325 3325 0 0 ( 0 720 575 0 0 550 141 3500 25'~ 352 3500 · ).3..,'\ uB..2(~2~) 1920 3375 332.~ 0 500 510 458 3500 350(}1970 3325 3325 0 0 0 720 575 0 0 55~ 144 3500 255 345 3500 24-Au~p2000 1895 3375 3325 0 500 510 453 3500 350~ 1947 3325 3325 0 0 0 720 575 0 0 55(~135 3500 25.~347 3500 ~5..&o_~-.2000 1895 ~ 3375 3325 0 500 510 452 3500 350~ 1943 3325 3325 0 0 (~ 0 720 575 0 0 550 127 3500 25.~ 345 3500 26-A u.s. p2000 .1900 3375 3325 0 500 510 455 3500 350~ 1948 3325 3325 0 0(~ 0 720 575 0 0 55(] 128 3500 255 346 3500 27..A t~..20 ':,<) 1897 3375 3325 0 500 510 454 3500 350~ 1942 3325 3325 0 0 ~ 0 720 575 0 0 550 125 3500 255 350 3500 28-Au~-2(Y,X) 1898 3350 3350 0 500 510 454 3500 350(~ 1940 3350 335{~ 0 0 0 0 720 575 0 0 550 133 3500 25.~342 3500 ~ 9 -.,x.o.~/,..~ 000 1886 3350 3350 0 500 510 450 3500 350~ 1925 3350 335~ 0 0 I~ 0 720 575 0 0 550 135 3500 25.~ 330 3500 30-Attg-20~X~ 1891 3350 3350 0 500 510 451 3500 350~ 1935 3350 335(~ 0 0 (~ 0 720 575 0 0 550 141 3500 25.t 328 3500 ~ I --,'\uR.2~'a'~ 1872 3350 3350 0 500 510 445 3500 350~ 1916 3350 ' 335(1 0 0 0 0 720 575 0 0 550 143 3500 270 324 3500 ...... TOTAL 55,781 0 13,025 ~7,974 0 0 0 ' ' 3,966 10,094' MAXIMUM 3,375 3,400 500 510 3,500 3,500 3,400 3,450 15 0 720 575 0 550 3,500 270 3,500 AVERAGE 1,799 3,349 3,346 0 500 509 420 3,500 3,500 1,870 3,354 3,370 0 10 0 0 711 563 0 0 550 128 3,500 2521 326 3,497 # DAYS 31 0 31 31 0 0 0 31 31 0~/18/2000 ' ~ust 13th - Wells temporarily offline duc to repairs to waterflond tm'bine. 1-23 shut in due to annular con'a'nunication problem. 4-23 has developed an annular corrm'nmication problem. AOGCC notified on ! 2/12/99. Verbal approval to continue to inject received fi'om Mr. Wond~ll on 12/14/99. WATER INJECTION REPORT PLATFORM C ,h.~ly-~:r) ' '~ C23-23 C41o23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 C24A-14 :: ::::: ?: ?: ?: :: ?: ::::: :: ?: :: ?:::: :: :: ::::::: :: :: ACT ACT ACT ACT ACT ACT ACT ACT ACT 0~ .J~tl..2000 192 34~ 34~ 0 550 49( 88 35~ 35~ 259 34~ 34~ 0 0 ~ 0 700 55( 0 0 550' 60 3500 14c 166 3500 02-Jul-2000 1665 34~ 34~ 0 550 49( 465 3500 · 35~ 2288 34~ 34~ 0 0 ~ 0 700 55( 0 0 550183 35~ 14C 664 3500 03..J~t]..2 ~'~t 2063 34~ 34~ 0 550 49( 454 3500 35~ 2366 34~ 34~ 0 0 ~ 0 7~ 55( 0 0 550 126 35~ 14c 558 3500 (~-.Iul-2(~o 2124 34~ 34~ 0 550 49( 452 35~ 35~ 2368 34~ 34~ 0 0 ~ 0 7~ 55( 0 0 550112 35~ 175 531 35~ 05.Jitl.-~o~ 2~6 34~ 34~ 0 550 49( ' 446 35~ 35~ 2337 34~ 34~ 0 0 ~ 0 7~ 55( 0 0 550lOg 3500 175 508 3500 06-Jul-2000 2073 34~ 33~ 0 550 485] 456 35~ 35~ 2369 34~ 340~ 0 0 ~ 0 700 55( 0 0 550 107 35~ 18c 509 35~ 07..J ul..2~) 2~7 34~ 33~ 0 550 485~456 35~ 35~ 2357 34~ 340~ 0 0 ~ 0 700 55( 0 0 550113 35~ 185 482 3500 o8-J'u]-2(~) 2029 34~ 33~ 0 550 490 455 35~ 35~ 2345 34~ 34~ 0 0 ~ 0 7~ 55( 0 0 550 107 35~ 19C 482 3500 09-Jttl..~ooo 2006 34~ 33~ 0 550 4~ 451 ~5~ ' 35~ 2323 34~ 34~ 0 0 ~ 0 7~ 55( 0 0 550 106 3500 19C 470 35~ 1 o-Jul-2000 1996 34~ 33~ 0 550 490 451 35~ 3500 2312 34~ 34~ 0 0 ~ 0 7~ 55( 0 0 550 112 35~ 20c 466 3500 I I..Ju].2~)0 1987 34~ 33~ 0 550 490 ~g 35~ 3500 23~ 34~ 34~ 0 0 c 0 7~ 55( 0 0 550 126 3500 205 443 35~ 12-Jul-20~) 1977 34~ 332~ 0 550 490 447 35~ 35~ 2283 34~ 34~ 0 0 c 0 7~ 550 0 0 550 129 3500 22( 428 3500 13.J~l..~oo 1977 3400 332~ 0 550 490 448 35~ 35~ 2283 35~ 34~ 0 0 c 0 7~ 555 0 0 550 130 35~ 225 421 35~ 16=Jul-2000 1974 34~ 3325 0 550 490 449 35~ 35~ 2279 35~ 34~ 0 0 ( 0 7~ 555 0 0 55~ 125 35~ 225 415 3500 15--.[u1.20(~) 1955 3350 3350 0 550 490 444 35~ 35~ 2258 35~ 34~ 0 0 ~ 0 700 555 0 0 550~124 35~ 235 414 35~ 16-Jul-20L~ 1954 3350 3350 0 550 490 445 35~ 35~ 2255 35~ 34~ 0 0 ~ 0 7~ 555 0 0 550 118 35~ 235 413 35~ 17.Jttl..~0C~ 1937 ~350 3350 0 550 490 442 35~ 35~ 2238 35~ 34~ 0 0 ~ 0 7~ 555 0 0 550 119 3500 235 411 35~ I ~-Jul-2000 1945 3350 3350 0 550 490 445 35~ 35~ 2241 35~ 34~ 0 0 ( 0 7~ 555 0 0 550 117 35~ ~ 411 35~ 19-.Jul.2~n~) 1927 3350 3350 0 550 490440 35~ 35~ 2222 ~5~ 340C 0 0 C 0 7~ 555 0 0 550 118 35~ 23( 407 . 35~ 20-.ful-2(F~ 1911 3360 3325 0 495 495 437 3495 35~ 2200 35~ 34~ 0 0 C 0 7~ 560 0 0 550 119 3495 235]401 3500 2 I.Jtll..~0~ 1872 3360 33~ 0 5~ 5~ 428 3450 34752148 ~5~ 34~ 0 0 C 0 7~ 560 0 0 550115 3450 240390 3500 22-J~tl-2fK~) 1895 3360 }3~ 0 5~ 5~ 436 3450 3495 2167 3150 340C 0 0 ( 0 705 560 0 0 550 127 3450 243 387 3525 23--Ju1.-2000 1908 3360 33~ 0 5~ 5~ 441 3450 3495 2180 3150 ~4~ 0 0 0 705 560 0 0 550128 3450 243383 3525 24-.laI-2~ 1905 3360 3315 0 5~ 5~ 441 3495 35~ 2172 3150 3405 0 0 0 7~ 560 0 0 550 i18 3475 245 357 3540 ~ 5.J ttl..~ 1910 3360 3325 0 5~ 505 44~ 3450 35~ 2170 3175 '341~ 0 0 0 705 · 560 0 0 550 117 3475 245 364 3550 26-Jul-20~6~ 1905 3375 3335 0 5~ 502442 3495 35~2157 32~ 342~ 0 0 0 702 560 0 0 550121 3475 245 355 3550 27-.Jul..2t~ 1~6 3350 3350 0 5~ 5~ 445 35~ 35~ 2153 34~ ~4~ 0 0 0 702 560 0 0 550139 3500 255353 35~ 28-Jul-2(~0 1886 3350 3350 0 5~ 502 441 35~ ~5~ 2124 34~ ~4~ 0 0 0 0 702 56G 0 0 550 140 3500 255 358 3500 29.Jttl-~000 1931 3350 3350 0 5~ 502 452 35~ 35~ 2179 34~ 34~ 0 0 0 0 702 568 0 0 550126 35~ 255360 3500 30-J~d-2{K~) 1917 3350 3350 0 5~ 502 448 35~ 35~ 2155 34~ ~4~ 0 0 0 0 702 56~ 0 0 550 121 35~ 255 360 3500 ~ I..~ul..~0cK~ 1922 3350 3350 0 5~ 502451 ~5~ 35~ 2158 34~ 34~ 0 0 0 0 702 56C 0 0 550129 35~ 255354 35~ ...... TOT~ 58,762 0 13,487 67,~6 0 0 0 3,740 13,021 ~ 3,4~ 3,4~ 550 505 3,5~ 3,500 3,5~ ~,425, 0 0 705 560 0 550 3,5~ 255 3,550 A~GE 1,896 3,375 3,338 0 530 494 435 3,493 3,499 2,182 3,391 3,4010 0 0 0 701 555 0 0 550121 3,493 217 420 3,5~ g DAYS 31 0 31 31 0 0 0 31 31 ~8/08/2~ -23 shut in due to ~ ~i~on p~l~ }4-23 ~ devel~ ~ ~ ~i~on p~l~ AO~C ~ifi~ ~ 1~1~99. V~al ~p~ to ~ m ~j~ ~v~ ~ Mr. W~II ~ 1~14/99. WATER INJECTION REPORT PLATFORM C Jt~r,~-2000 C23-23 C41-23 C24-23 C34-23 C23-26 CA1-26 C44-14RD C24A-23 C24A-14 :::::::::::::::::::::::::::::::::::::: ACT ACT ACT ACT ACT ACT ACT ACT A~T 01..J~m..2000 0 1300 130C 0 550 50~ 0 1200 125( 0 800 1~0(~0 0 0 (:0 700 550 0 0 550 0 500 41(] 02-Jun-2(~'}O 0 1300 130( 0 550 50( 0 1200 1250 0 800 I 0 0 (~ 0 700 55(] 0 0 550 0 500 41(~ 03..JRt~-2(~'J 0 1300 130( 0 550 50C 0 1200 125( 0 800 100( 0 0 C 0 700 55(] 0' 0 550 0 500 41G 04-Jun-20OO 0 1300 130( 0 550 50( 0 1200 1250 0 800 1000 0 0 ¢ 0 700 55(] 0 0 ' 550 0 500 41(] 05-Jtm-2000 0 1300 130( 0 550 50( 0 1200 1250 0 800 1000 0 0 C 0 700 55(~0 0 550 0 500 41(] 06-Jtm-2000 0 1300 130( 0 550 50( 0 1200 1250 0 800 1000 0 0 C 0 700 55(:0 0 550 0 500 41(: (~7-Jul~-20(~,~ 0 1300 130( 0 550 50( 0 1200 1250 0 800 1000 0 0 C 0 700 55(:0 0 550 0 500 41C 08-J~m-2000 0 1250 120( 0 550 495 0 1.150 1200 0 750 975 0 0 C 0 700' 55C 0 0 550 0 255 425 09..J~n..~.000 0 1250 120( 0 550 495 0 IJS0 1200 0 750 975 0 0 C 0 700 55C 0 0 550 0 255 425 10-Jtm-20(~,'~ 0 1200 120( 0 555 49,~ 0 1150 1200 0 740 960 0 0 C 0 695 55C 0 0 550 0 255 43C 11 ..Jut~..20(~ 0 1200 119.~ 0 555 49.~ 0 1150 1200 0 700 950 0 0 ( 0 700 55C 0 0 550 0 205 432 ! 2-J~-2000 0 ! 175 117-~ 0 550 48~ 0 1150 1195 0 700 950 0 0 { 0 700 55(:0 0 550 0 200 435 0 0 75 1.3-Jt~-~000 0 ! 175 ! 160 0 550 48( 0 ! 150 1190 0 700 950 0 0 0 700 55{ 0 0 550 0 175 43~ 0 0 88 14-Jtm-2~'.~-) 0 1160 1150 0 550 49( 0 1'140 1190 0 700 94~ 0 0 0 700 55( 0 0 550 0 150 44( 0 0 98 15~Ju~t.20(~ 0 1160 i 150 0 550 490 0 1140 119(: 0 700 94~ 0 0 0 0 700 55( 0 0 550 0 150 44( 0 0 98 16-Jttr~.2000 0 1160 1150 0 550 490 0 1140 119(: 0 700 94~ 0 0 0 0 700 550 0 0 550 0 150 44( 0 · 0 17-J~m..2000 96 1160 1150 0 550 490 46 1140 119C 155 700 94(:0 0 0 0 700 550 0 0 55~ 35 150 440 0 · 0 18-Jtm-20(~0 1533 1160 i150 0 550 490 332 1140 119C 34 700 94C 0 0 0 0 700 550 0 0 550 206 150 440 686 ' 0 19..J ut~..20~.~'.~ 2401 1160 1150 0 550 490 464 i!40 119(: 2528 700 94( 0 0 0 0 700 550 0 0 55(]171 150 440 850 0 20-Jun-2000 2339 3300 330C 0 550 490 488 3450 345(: 2486 3350 300( 0 0 0 0 700 550 0 0 550 148 3450 3450 578 3500 350( 2 I.-Jun-2000 2270 3300 3300 0 550 490 467 3450 345{ 2463 3350 300(: 0 0 0 0 700 550 0 0 550 132 3450 3450 576 3500 350( 22-Jun-2r~X~ 2219 3300 330(] 0 .550 490 464 3450 345( 2445 3350 300( 0 0 (] 0 700 550 0 0 550 i 19 3450 3450 549 3500 350( 23-J m~..2t.~30 2210 3350 330C 0 550 49(] 469 3500 350( 2457 3400 340( 0 0 (] 0 700 550 0 0 550 122 3450 10C 537 3500 ( 24-Jun-2000 2182 3350 335(] 0 550 49(3465 3500 350( 2437 3400 340( 0 0 (] 0 700 55(] 0 0 550 113 3500 105 . 516 3500 ( 25-J~m-2000 2162 3350 335(] 0 550 4~(]462 3500 350( 2412 3400 340( 0 0 (] 0 700 55(] 0 0 550 115 3500 12(] 495 3500 26-Jun-26~o0 2141 3350 335(] 0 550 49~458 3500 350( 2397 3400 340( 0 0 (] 0 700 55(] 0 0 550 123 3500 135 476 3500 27-J uw2CR'~.s 1867 3400 340C 0 550 49C404 3500 350( 2095 3400 340( 0 0 (: 0 700 55(] 0 0 550 92 3500 14(: 417 3500 2~-Jun-2000 0 3400 340C 0 550 49C0 3500 350( 0 3400 340( 0 0 (: 0 700 55(:0 0 550 0 3500 14(: 0 3500 29-Jun-2000 0 3400 340( 0 550 49C 0 3500 3500 0 3400 340( 0 0 (: 0 700 55(: 0 0 550 0 3500 14(: 0 3500 30-Jtm-20~) 0 3400 340( 0 550 49C 0 3500 3500 0 3400 3400 0 0 C 0 700 55(:0 0 550 0 3500 14C 0 3500 TOTAL 21,420 0 4,519 21,909 0 0 0 ! ,376 5,680 MAXIMUM 3,400 3,400 555 500 3,500 3,500 · 3,400 3,400 0 0 700 550 0 550 3,500 3,450 3,500 3,500 AVERAGE 714 2,007 1,9~9 0 550 493 151 2,016 2,048 730' 1,713 1,820 0 0 0 0 700 550 0 0 550 46 1,468 649 210 1,283 375 .~ DAYS 11 0 11 11 0 0 0 11 10 07/10/2000 1-23 slur in due to annular commanication problem, 4-23 has developed an annular communication problem AOGCC notitied on 12/i 2/99. Verbal approval to continne to inject received from Mr. Wondzell on 12/14/99, Platform "C" injectors shut-in f~om May 11 thnt June 16 du~ to pump failure~ RECE!VED Gas ¢o~s. Comm'~on Anchorage WATER INJECTION REPORT PLATFORM C May-2000 01 -IV[ay-2000 02.May.2000 03..May..2000 04-May-2000 05 -M ay-2000 06..May-;~o00 07. May. 2000 08-May-2000 09-May-2000 I 0.May.2000 11 ..M'ay~20tV0 [ 2 -May-2000 13 -M ay-20CR) 14-May-2000 15.May.2000 16-M ay-2000 ! ?-iMay-2000 ~ 8.May.2000 19-M'ay-2000 20-May-2000 21 -M ay-2000 22-May.2000 23.M. ay.2000 24-M~,-2000 25-May-2000 26.May.201X) 27-May-20(K) 2g-May-2000 29-May-2000 30-May..2000 31 .May. 2000 TOTAL AVERAGE # DAYS 0611412000 C23-23 C41-23 C24-23 C34-23 C23-26 ACT ACT ACT ACT ACT ~J INJ ANNU ~J llqJ ANNU INJ INJ ANNU ~J INJ ANNU ~J INJ ANNU 1743 3340 3300 1814 3340 3300 1873 3340 3300 1827 3340 3300 1810 3340 3300 ! 703 3340 3300 1831 3340 3300 1846 3340 3300 1836 3340 3300 366 3340 3300 0 2100 2050 0 1900 1895 0 1840 1840 0 1750 1760 0 1710 1710 0 1700 1690 0 1650 16413 0 1650 164~ 0 1650 16413 0 1650 16413 0 1650 16413 0 1650 16413 0 1650 16413 0 500 52( 0 500 52( 0 500 525 0 500 52.~ 0 500 525 0 500 5251 0 500 525 0 500 525 0 500 525 0 5OO 525 0 55O 525 0 550 520 0 550 525 0 550 525 0 550 525 0 560 525 0 550 520 0 550 520 0 550 520 0 550 520 0 55O 52O 0 550 520 0 550 520 374 3500 350C 393 3500 350( 404 3500 350( 393 3500 350( 388 3500 3500i 385 3500 3500 394 3500 35001 401 3500 3500: 397 3500 35001 79 3500 3500 0 1500 1500 0 1400 1450 0 1410 1410 0 1400 1400 0 1360 1390 0 1350 1360 0 1350 1350 0 1350 1350 0 1350 1350 0 1350 1350 0 1350 1350 0 1350 1350 0 1350 1350 1949 3450 34013 2010 3450 340¢ 2102 3450 340C 2060 3450 340¢ 2035 3450 340~ 2028 3450 340£ 2074 3450 340( 2104 3450 340( 2090 3450 346C 417 3450 340C 0 1500 165~ 0 1350 1525 0 1450 145( 0 1200 140( 0 1300 135( 0 1300 1310 0 1200 1275 0 1200 1275 0 1200 1275 0 .1200 1275 0 1200 1275 0 1200 1275 0 1200 1275 0 0 0 0 o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C41-26 C44-14RD C24A-23 ACT ACT ACT INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU 0 670 55C 0 0 670 55( 0i 0 670 55C 0 0 670 550! 0 0 670 550 0 0 670 550 0 0 670 550 0 0 670 550 0 670 550 0 670 550 0 680 500 0 675 550 0 675 540 0 675 550 0 675 550 0 675 550 0 675 550 0 675 550 0 675 55O 0 675 550 0 675 550 0 675 550 0 675 550 0 0 550 113 3500 30 0 0 550 112 3500 30 0 0 550 114 3500 30 0 0 550 I13 3500 30 0 0 550 113 3500 30 0 0 550 !13 3500 30 0 0 550 !13 3500 30 0 0 550 113 3500 30 0 0 550 113 3500 30 0 0 550 113 3500 30 0 0 550 0 2200 257 0 0 550 0 1855 293 0 0 550 0 1700 310 840 1,500 550 0 1550 325 0 0 550 0 1440 37' 0 0 550 0 1325 3 0 0 550 0 1255 35~ 0 0 550 0 1255 3513 0 0 550 0 1255 3513 340 1~00 550 0 1255 3513 !,020 I~00 550 0 1255 3513 0 0 550 0 1255 3513 .0 0 550 0 1255 35C 0 1650 164C 0 1400 140( 0 1400 140( 0 1400 140( 0 1350 135C 0 1350 135{ 0 1350 135f 0 1300 1300 16,649 3,340 3,300 537 2,166 2,149 10 0 550 520 0 550 510 0 550 510 0 550 510 0 550 50~ 0 550 500 0 550 50~ 0 550 50~ 0 1350 1350 0 1300 1300 0 1300 1300 0 1250 1250 0" 1250 1250 .0 1250 12513 0 1250 125~ 0 '1200 12513 0 1200 1275 0 900 1100 0 900 1100 0 900 1 i 00 0 900 1100 0 900 1100 0 850 1050 0 800 1000 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 675 5513 0 1150 5513 0 1000 5513 0 1250 5513 0 1400 5513 0 1500 5513 0 1200 55C 0 700 55C 0 560 525 0 534 519 0 0 0 550 0 0 550 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 3,608 3,500, 3,500 116 2,O33 2,O37 10 18,869 3,450 3,400 609 1,882 !,950 10 0 0 0 0 0 0 1,500 550 0 786 548 0 2,200 i ,500 550 73 143 550 3 0 1255 35C 0 725 38C 0 725 38C 0 500 40C 0 400 40( 0 400 40( 0 250 41{ 0 500 41~ 1,130 3,500 410 36 1,891 250 I0 11-23 shut in due to annular communication problem. 14-23 has developed nn annular communication problem. AOGCC notified on ! 2/12/99. Verbal approval to continue to inject received from Mr. Wondzeil on 12/14/99. II Platform "C" injectors shut-in from Mayl I thru today due to pump failure. Pump has been repaired ~ad is currently being installed. WATER INJECTION REPORT PLATFORM C April-2000 C23-23 C41-23 C.24-93 C34-23 C23-26 C41-26 C44-14RD~ C24A-23 ? ?':: ::?~ ? ? ?'? ? ~ ~? :: ? ? :: ? ?~? ? ? :: :: ? :: ? ~? ~ ~?::=:~ ?~ ::~ ACT A~ A~ A~ ACT A~ ACT A~ 01-Apr-20~ 1817 33~ 33~ 0 ~50 520 394 35~ 35~ 1982 3450 34~ 0 0 ~ 0 ~0 50g 0 0 550 150 35~ 02-Apr-2000 1762 33~ 332~ 0 550 520 380 3500 35~ 1932 3450 340C 0 0 g 0 640 5~ 0 0 550 150 35~ 03-Apr-2~ 1834 33~ 3325 0 550 515 397 35~ 35~ 2019 3450 34~ 0 0 ' C 0 650 5~ 0 0. 550 150 35~ 04-Apr-2~0 1850 3300 3325 0 550 515 399 3500 3500 2038 3450 340C 0 0 C 0 650 50g 0 0 550 150 3500 60 0S-Apr-2~ 1858 33~ 3325 0 ' 550 515 401 35~ 35~ 2050 3450 340C 0 0 C 0 650 5~ 0 0 550 150 35~ ~-Apr-2~0 1839 33~ 3325 0 550 ' 515 397 35~ 35~ 2025 3450 340C 0 0 C 0 650 5~ 0 0 550 I~0 3~00 07-Apr-2~ 1841 33~ 3325 0 550 515 395 35~ 35~ 2024 3450 340C 0 0 C 0 650 5~ 0 0 550 150 3~00 60 08-Apr-2~ 1837 3300 3325 0 5~0 515 3~ 35~ 35~ 2025 3450 340C 0 0 C 0 6~0 5~ 0 0 550 107 35~ 60 09-Apr-2~0 1846 33~ 3325 0 ~50 51~ 3~ 3~00 35~ 2036 3450 340C ~0 0 C 0 650 50C 0 0 550 108 35~ 60 0-Apr-2~0 ! 826 33~ 3325 0 550 515 395 35~ 3~ 2~9 3450 34~ 0 0 C 0 650 50C 0 0 550 ! 08 3500 60 I-Apr-2~ 1838 33~ 3325 0 ~0 ~1~ 39~ 35~ 35~ 202~ 3450 34~ ' 0 0 C 0 650 50C 0 0 550 108 35~ 12-Apr-20~ 1838 33~ 3325 0 550 ~20 393 35~ 35~ 2024 3450 34~ 0 0 C 0 650 5~ 0 0 550 107 3~00 13-Apr-2~ 1823 33~ 3350 0 550 52~ 392 35~ 35~ 2016 34~0 34~ 0 0 C 0 650 5~ 0 0 550 107 35~ 14-Apr-2~ 1833 3375 3350 0 550 525 395 35~ 35~ 2023 35~ 342C 0 0 C 0 ~50 50C 0 0 ~50 107 ! 5-Apr-2~ 18~ 3375 33~0 0 550 525 389 35~ 35~ 1954 3~ 342C 0 0 C 0 650 ~ 0 0 ~50 108 35~ 16-Apr-2~ 1784 3375 3350 0 S~0 525 383 3~ 35~ 1933 35~ 342C 0 0 C 0 650 5~ 0 0 ~50 108 3~ 17-Apr*2~ 1779 33~0 33~ 0 ~S0 SI0 382 3450 3450 1934 3450 34~ 0 0 C 0 650 S~ 0 0 SS0 107 34~0 18-Apr-20~ 1774 33~0 33~ 0 SS0 ~10 381 3450 3450 1932 3450 34~ 0 0 ~ 0 650 5~ 0 0 550 110 3450 19-Apr-2~ 178~ 3350 33~ 0 S~0 S20 389 3450 3450 1919 3450 337~ 0 0 C 0 650 5~ 0 0 S50 108 3450 40 20-Apr-2~ 1783 3350 33~ 0 550 S20 387 3450 3450 i926 3450 337~ 0 0 C 0 650 5~ 0 . 0 5~0 113 35~ 40 21-Apr-2~ 1293 3350 33~ 0 550 520 288 3450 3450 13~ 3450 337~ 0 0 C 0 ~n -- 0 SS0 80 35~ 40 22-Apr-2~ 1878 3350 33~ 0 S~0 520 402 3450 3450 2010 3450 337~ a ~ 0 550 147 35~ 40 . 23-Apr-2~ 1622 33~0 33~ 0 S50 520 3~2 3450 3450. ~ ' ' '~ 0 550 112 35~ 40 24-Apr-2~ 0 21~ 33~ 0 S50 S20 ............ 0 ~50 0 23~ 4~ 2S-Apr-2~ 0 0 33~ 0 S~ 520 0 SS0 0 0 4~ 2~Apr-2~ 459 0 33~ 0 S~ ~20 I I 0 550 112 0 27-Apr-2~ 1953 3325 ' 3275 0 5~ 52~ 39. 0 SS0 113 3~ 25 29-Apr-2~ 18~ 3340 33~ 0 5~ 520 3~ ~~~ 0 550 113 35~ 3~Apr-2~ IM8 3340 33~ 0 5~ 520 3~__ ~ 0 550 113 35~ 3,3~ M~I~M 3,375 3,350 550 525 ~ 550 3,5~ 65 AVENGE i,639 3,~ 3~ I S 0 540 519 353 ~ ~~ 550 I 12 3,222 49 DAYS 28 0 28 28 · . 11-23 shut in due to annula~ communication problem C~gx~ 14-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Vedal approval to eonti~ WATER INJECTION REPORT PLATFORM C March-2000 C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 01 -Mar-2000 1802 '3240 3200 0 550 505 377 3440 3450 1998 3425 337.~ 0 50 0 0 645 50( 0 0 550 160 4500 02-Mar-2000 1820 3250 3225 0 550 510 384 3500 3500 2041 3450 34001 0 0 0 0 640 50( 0 0 550 294 4550 03-Mar-2000 i807 3250 3225 0 550 511: 382 3500 3500 2037 3450 3400 0 0 0 0 640 50( 0 0 550 248 4600 04-Mar-2000 ~1924 3350 330( 0 550 511: 386 3500 3500 2054 3450 3400 0 0 0 0 640 50( 0 0 550 72 3500 05-Mar-2000 19~0 3350 3321: 0 550 511: 385 3500 350(} 2056 3450 3400 0 0 0 0 640 500 0 0 550 124 3500 06-Mar-2000 2794 3150 310( 0 550 511: 380 3500 350( 2021 3425 3400 0 0 0 0 640 500 0 0 550 136 3500 07-Mar-2000 667 3200 3151: 0 550 51C 379 3500 350((3 2022 3450 3400 0 0 0 0 640 500 0 0 550 143 3500 0g-Mar-2000 1637 3150 3141: 0 550 51¢ 384 3500 350( 2044 3450 3400 0 0 0 0 640 500 0 0 550 119 3500 09.Mar-2000 1664 3150 3141: 0 550 51( 388 3500 350( 2082 3450 3400 0 0 0 0 640 500 0 0 550 52 ,2650 10-Mar-2000 1652 3150 3141: 0 550 51 ( 386 3500 350( 2061 3450 3400 0 0 0 0 640 500 0 0 550 i 9 2650 I l-Mar-2000 1844 3150 314C 0 550 51C 383 3500 350( 2049 3450 3400 0 0 0 0 640 500 0 0 550 0 2650 i 2-Mar-2000 1646 3150 3141: 0 550 51{ 384 3500 350( 2024 3450 3400 0 0 1: 0 640 500 0 0 550 0 2650 13-Mar-2000 1634 3150 314C 0 550 511: 388 3500 350( 1906 3450 3400 0 0 0 0 640 500 0 0 550 0 2650 14-Mar-2000 1590 3 ! 50 314C 0 550 5 i ( 370 3500 350( i 896 3450 3400 0 0 (] 0 640 500 0 0 550 0 2650 15.Mar.2000 1617 3150 314C 0 550 51{ 380 3500 350( 1917 3450 3400 0 0 16-Mar-2000 1621 3150 3151: 0 550 51C 382 3500 350( 1943 3420 3400 0 0 17-Mar-2000 1771 3275 3231: 0 550 51( 393 3500 350( 2002 3440 3400 0 0 18-Mar-2000 1761 3275 3241: 0 550 51( 391 3500 350( 2009 3440 3400 0 0 19-Mar-2000 1787 3300 325C 0 550 510 388 3500 350( 2003 3450 3400 0 0 20-Mar-2000 1778 3300 3251: 0 550 515 387 3500 350( 200~ 3450 2 i-Mar-2000 1790 3350 330( 0 550 510 386 3500 350( 2001 3450 340~ 0 0 22-Mar-2000 1846 3350 330( 0 550 510 393. ' 3500 350( 2040 3450 340~ 0 0 23-Mar-2000 1805 3350 330( 0 550 510 385 3500 350( 1994 3450 340( 0 0 ¢ 0 640 24-Mar-2000 1814 3350 330( 0 550 510 387 3500 3500 2009 3450 25.Mar-2000 1801 3300 3300 0: 550 510 384 3500 3500 1997 3400 340( ' 0 0 C 0 640 50( 0 0 550 303 4500 26-Mar-2000 1812 3300 3300 0 550 51C 387 3500 3500 2014 3400 340( 0 0 27-Mar-2000 1777 3300 3300 0 520 51{~ ' 386 3500 3500 1953 3400 340( 0 0 0 0 500 50( 0 0 550 161 4500 28-Mar-2000 1718 3300 3200 0 520 506 390 3500 3500 1975 ' 3400 340( 0 0 0 0 500 50( 0 0 550 97 3500 29-Mar-2000 1704 3300 3200 0 520 50( 391 3500 3500 1962 3400 3400 ' 0 0 0 0 500 50( 0 0 550 126 3500 I 1958 3450 3400 0 0 0 0 640 50( 0 0 550 147 3500 30-Mar-2000 1748 3250 3250 0 550 50( 386 3500 3 l-Ma~:.2000 1687 3300 3275 0 550 50( 375 3500 3500 1866 3425 3400 0 0 0 0 640 500 0 0 550 150 3500 TOTAL 54,058 0 ! !,927 62,000 0 0 O 4,539 MAXIMUM 3,350 3,320 550 515 3,500 3,500 3,450 3,400 50 0 645 500 0 550 4,600 AVERAOE 1,744 3,250 3,219 0 547 509 385 3,498 3,498 2,000 3,438 3,399 0 2 0 0 622 500 0 0 550 146 3,646 # DAYS 31 0 31 31 0 0 0 27 :41-23 shut in due to annular communication problent :34-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Womlnll on 12/14/99. RECEIVED APR Alaska 0il & Gas C ns. C 3mmissi0n Anchorage ebrumT-2000 01-Feb-2000 02-Feb-2000 03-Feb-2000 04-Feb-2000 05-Feb-2000 06-Feb-2000 07-Feb-2000 0g-Feb-2000 09-Feb-2000 I 0-Feb-2000 I i-Feb-2000 12-Feb-2000' 13-Feb-2000 14-Feb-2000 i 5-Feb-2000 16-Feb-2000 ! 7-Feb-2000 18-Feb-2000 19-Feb-2000 20-Feb-2000 21 -Feb-2000 22-Feb-2000 23-Feb-2000 24-Feb-2000 25-Feb-2000 26-Feb-2000 27-Feb-2000 28-Feb-2000 29-Feb-2000 TO~AL MAXIMUM AVERAGE . ,~' # DAYS" 03/00/2000 WATER INJECTION REPORT PLATFORM C C23-23 C41-23 ACT ACT INJ INJ ANNU rNJ INS 0 3175 3175 0 0 1770 0 0 1750 0 0 1700 0 0 1700 0 1600 1675 0 1600 1650 0 1600 1625 0 1600 1600 0 1600 1600 0 1600 1600 0 1600 1600 0 1600 1600 0 1600 1600 0 1600 1600 0 1450 148( 0 1500 148( 0 1500 150( 0 1500 147.~ 0 1450 145( 0 1450 145( 0 1450 142C 0 1400 140C 2066 3200 i 40( 1998 3200 140( 1919 3200 140( i 882 3200 i 40( 1835 32OO 140( 1811 3200 140( 11,511 3,2OO 3,17 397 !,727 1,597 6' 0 575 532 0 570 528 0 575 530 0 570 536 0 560 525 0 560 526 0 560 526 0 560 520 0 520 520 0 520 520 0 520 520 0 520 520 0 520 520 0 520 520 0 520 520 0 550 515 0 55O 512 0 550 510 0 550 510 0 550 5i0 0 550 51( 0 550 0 550 50~ 0 550 50! 0 550 508 0 550 508 0 550 508 0 550 508 0 550 508 C24-23 C34-23 C23 -26 C41-26 C44- ! 4RD C24A-23 ACT ACT ACT ACT ACT ANNU INJ INJ ANNU [NJ [NJ ANNU [NJ [NJ ANNU [NJ [NJ ANNU [NJ [NJ ANNU 1926. 3450 3400 1930 3460 3400 1952 3450 3425 1948 3450 3425 1934 3450 3420 1933 3450 3425 1926 3450 3425 1557 3450 3425 33 2900 3425 2047 3450 3425 2036 3470 3425 2072 3470 3420 2074 3450 342C 2026 3450 342C 1991 3500 342C 2012 3470 342C 2011 3460 340~ 1973 3450 340C 1989 3450 340~ 1982 3450 340~ 1999 3450 340~ 1993 3450 340(] 1653 3450 340~ 2002 3500 340~ 1994 3500 340~ 1999 3500 340(] 2008 3500 340~ 1992 3500 340~ 2003 3500 340C 0 5O 0 5O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 50 0 5O 0 5O 0 50 0 5O 0 5O 0 5O 0 5O 0 5O 0 5O 0 50 0 50 0 5O 0 50 0 0 26 0 0 0 0 640 500 0 0 640 500 0 0 640 500 0 0 640 500 0 0 640 500 0 0 640 500 0 0 640 500 0 640 500 0 640 500 0 o 640 5OO 0 0 640 500 0 0 640 500 0 640 500 0 640 50( · 0 640 50( 0 640 50( 0 645 50~ 0 648 50~ 0 647 50~ 0 650 50~ 0 650 50~ 0 650 50~ o 650 0 650 50~ 0 650 50~ 0 650 0 650 0 650 50~ 0 650 50~ 0 650 500 0 644 500 0 0 0 550 o 0 550 o 0 550 o o 550 o 0 550 0 0 550 o o 550 0 0 550 0 0 550 0 0 550 o 0 550 0 o 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 o 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 532 0 547 516 0 [NJ [NJ 373 3475 3490 375 3480 3495 380 3500 3500 381 3500 3500 378 3500 3500 377 3500 3500 378 3500 3500 305 35O0 35OO 341 3500 3500 401 3500 3500 379 3500 3500 391 35O0 3500 391 3500 3500 382 3500 3500 381 3500 3500 382 3500 3500 382 3490 350( 375 3485 349( 377 3470 347! 380 3485 3482 384 3485 3482 382 3475 - 359( 328 3475 349C 382 3500 349( 375 3500 349( 375 3500 349C 377 3500 349( 373 35O0 349( 376 35O0 341 10,861 3,500 3,590 37529 3,494 3,498 3,500 3,425 1,896 3,44~ 3,411 29 160 4500 294 4550 248 4600 72 3500 124 3500 136 3500 143 3500 119 3500 52 2650 19 265O 0 2650 0 2650 0 2650 0 2650 138 3500 174 3800 248 4050 240 4100 243 4250 99 3500 138 3500 142 3480 153 4000 310 43OO 3O3 4500 303 4500 161 4500 97 3500 126 3500 4,242 4,600 146 3,656 25 -23 shut in due to annular communication problem. .23 hns developed an annular communication problem. AOGCC notified on 12/12/99. Ved~l approVd .m ~ to ~n~ect ~:e~ved from Mr. Wondzell on 12/14/99. -23 down for flange repairs. January-2000 0 I-lan-2000 02-Jan-2000 03-Jan-2000 04-Jan -2000 05-Jan-2000 06-Jan-2000 07-Jan-2000 08-Jan-2000 09-Jan-2000 I 0-Jan-2000 I I-Jan-2000 12-Jan-2000 13-Jan-2000 14-Jan-2000 15-Jan-2000 16-Jan-2000 17-Jan-2000 i 8-Jan-2000 19-Jan-2000 20-Jan-2000 2 ! -Jnn-2000 22-Jan-2000 23-Jan-2000 24-Jan-2000 25-Jan-2000 26-Jan-2000 27-Jan-2000 28-Jan-2000 29-Jan-2000 30-Jan-2000 3 l-San-2000 TOTAL MAXIMUM AVERAGE # DAYS 02/! 0/2OOO . '~ '- WATER INJECTION REPORT PLATFORM C C23-23 ACT [NJ [NJ ANNU 1428 3190 3075 1433 3190 3075 1419 3190 3075 1429 3190 3075 1427 3190 3075 1421 3200 3075 1406 3200 3075 1392 3200 3075 1389 3200 310~ 1384 3200 315C 1386 3200 3150 1398 3200 3150 1396 3200 3150 1411 3200 3150 1407 3200 3150 1410 3200 3150 1408 3200 3150 1405 3200 3150 1410 3200 3150 1406 3200 3150 1399 3200 3150 1408 3180 3145 1417 3190 3150 1388 3175 3175 1392 3175 3175 585 3175 3175 0 3175 3175 0 3175 3175 0 3175 3175 0 3175 3175 0 3175 3175 35,754 3~00 3,175 1,153 3,191 3,135 26 C41-23 ACT [NJ [NJ ANNU C24-23 ACT [NJ [NJ ANNU C34-23 ACT INJ [NJ ANNU 0 580 65( 0 580 65( 0 580 65( 0 580 650 0 580 650 0 580 650i 0 580 65C 0 580 65C 0 525 0 530 53C o 540 53C 0 575 535 0 575 535 0 575 535 0 575 535 0 575 535 0 575 535 0 575 54~ 0 575 532 0 575 522 0 575 515 0 575 538 0 575 538 o 575 53! 0 575 532 0 575 532 0 575 532 0 575 532 0 575 532 0 575 532 0 580 65¢ 0 572 567 395 3500 350C 396 3500 350C 391 3500 350C 393 3500 350C 392 3500 3500 390 3500 3500 387 3500 350C 381 3500 350¢ 381 3500 350C 381 3500 350C 381 3500 350C 382 3500 350C 379 3500 3500 383 3500 3500 381 3500 3500 382 3500 3500 380 3500 3500 383 3500 3500 382 3500 3500 381 3500 350~ 379 3500 3500 381 3490 350~ 383 3500 350(] 375 3490 3500 376 347O 3475 374 3475 349~ 368 3475 349~ 370 3475 3490 368 3475 3490 370 3475 3490 370 3475 3490 I i,815 3,500 3,500 38 ! 3,494 3,497 1950 3560 3425 1955 3560 3425 1931 3560 3425 1942 ~560 3425 1940 J560 3435 1910 3500 3425 78 2300 1950 0 2300 1950 0 1900 1750 352 1750 1700 2155 3450 3400 2100 346O 340C 2079 3460 340C 2088 3460 340C 2069 3460 3400 2064 3460 3400 2054 3460 340C 2050 3460 340¢ 2049 3500 3425 2031 3465 341C 2020 3475 3425 2030 3460 341¢ 2039 3470 3425 1986 3450 341~ 1988 3450 340C 1971 3450 340~ 1937 3450 340¢ 1937 3450 340~ 1925 3450 340~ 1926 3450 340C 1918 3450 340~ 54,474 3,560 3,435 !,757 3,296 3,207 C23.26 ACT [NJ [NJ ANNU 0 50 0 0 50 0 0 5o 0 5o 0 5o 0 0 0 0 0 0 ' 0 0 0 0 0 0 0 0 0 0 · 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 50 0: 0 5O 0 50 0 50 0 5O 0 50 0 50 0 50 0 50 0 50 0 5o 0 5o 0 50 C41-26 ACT [NJ [NJ 0 650 450 0 650 450 0 650 450 0 65O 45O 0 630 450 0 630 450 0 630 450 0 630 450 0 630 450 0 630 500 0 640 500 0 640 500 0 640 500 0 640 500 0 640 500 0 640 500 0 640 500 0 640 500 0 640 500 0 640 500 0 640 500 0 640 500 0 640 500 0 640 500 0 640 500 0 640 500 0 640 500 0 640 500 0 640 500 0 640 500 0 640 500 C44-14RD ACT INJ [NJ ANNU 0 0 550 0 0 55O 0 0 550 0 0 550 0 0 '550 o ~ 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 o O. 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 o 0 550 0 0 550 0 0 550 0 0 550 0 0. 550 0 0 550 0 0 550 0 0 550 o 0 550 0 0 550 0 0 550 0 0 550 0 0 550 C24A-23 INJ INJ ANNU 175 3500 175 3500 173 3500 174 3500 174 3500 173 3500 173 3500 171 3500 171 3500 171 3500 172 3500 173 3500 169 35~ 172 . 35b~ 170 3500 171 3500 169 3500 170 3500 170 3500 167 3500 167 3500 168 3500 168 3500 163 3500 166 3475 162 3490 238 4500 370 4500 331 4500 302 4500 419 4500 0 27 0 650 500 639 485 0 0 550 0 6,087 4,500 196 3,660 :41-23 shut in due to annular communication problem. :34-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzdl on 12/14/99. '.23-23 down for five days due to flanse repairs and expected to be back online in mid-February. 134-23 shut in for two days for survey. December-99 01 -Dec-99 02-Dec-99 03 -De¢-99 04-De¢-99 05-Dec-99 06-De¢-99 07-Dec-99 08-Dec-99 09-Dec-99 I 0-Dec-99 I I-De¢-99 12-De¢-99 13 -Dec-99 14-Dec-99 ! 5-De¢-99 16-De¢-99 17-De¢-99 18-Dee-99 19-Dee-99 20-De0~99 2 l-Dec-99 22-De¢-99 23-De¢-99 24-De0-99 25-De¢-99 26-D00-99 27-De0-99 28-De0-99 29-Deo-99 30-Deo-99 3 !-De0-99 TOTAL MAXIMUM AVERAGE # DAYS 01/13/00 WATER INJECTION REPORT PLATFORM C C23-23 ACT INJ INJ ANNU 1389 3175 310~ 1394 3175 310~ 1394 3175 310C 1392 3175 310¢ 1391 3175 310C 1389 3175 310C 1388 3175 310¢ 1332 3175 310C 1386 3175 310C 1388 3200 305C 1390 3200 305C 1391 3200 305( 1395 3200 3050 1386 3200 3050 1379 3200 305~ 1382 3200 3050 1372 3200 3050 1364 3200 3050 1371 3200 3050 1391 3200 3050 1378 3200 3050 1396 3200 3050 1383 3160 3050 1404 3170 3050 1391 3160 3050 1409 3195 3075 1425 3190 3060 1419 3190 3075 i413 3i90 3075 1408 3190 3075 1423 3190 3075 43.113 3,200 3,100 1,391 3,187 3.069 31 C41-23 ACT INJ INJ ANNU C24-23 ACT INJ INJ ANNU C34-23 ACT INJ INJ ANNU 0 575 65C 0 575 65C 0 575 65C 0 575 65C 0 575 650 0 575 650 0 575 650 0 575 650 0 575 650 0 525 650 0 525 650 0 580 650 O- 580 650 0 580 650 0 580 650 0 580 650 0 580 650 0 580 650 0 580 650 0 580 650 0 580 650 o 580 650 0 575 650 0 575 650 0 580 650 0 580 0 575 65C 0 580 65C 0 580 65C 0 580 65C 0 580 65C 0 580 650 0 575 650 0 C23-26 383 3460 3475I 390 3460 3475! 382 3500 3475 382 3500 3475 380 3500 3475 379 3500 3475 378 3500 3475 373 3500 3475 383 3500 3475 386 3500 3500 386 3500 3500 386 3500 3500 388 3500 3500 385 3500 3500 382 3500 3500 379 3500 3500 374 3500 350O 371 3500 3500 375 3500 3500 380 3500 3500 379 3500 3500 383 3500 3500 379 3450 3450 385 3475 3485 383 3450 3475 394 3500 395 3500 394 3500 350C 390 3500 350~ 387 3500 350~ 392 3500 350~ i !,883 3,500 3,500 383 3,493 3,490 31 1941 3525 0 1945 3525 0 1941 3500 0 1931 3500 0 1928 3500 0 1931 3500 0 i928 3500 0 1844 3500 0 1921 3500 0 1933 3500 1937 3500 205 1943 3500 3400 1953 3500 3400 1938 3500 3400 1704 3500 3400 1683 3500 3400 1738 3500 3400 1738 3500 3400 1757 3500 3400 1814 3500 340~ 1807 3500 340~ 1837 3500 340~ 1839 3525 340~ 1882 3550 3400 1869 3525 340C 1907 3550 342~ 1923 3555 342~ 19Il 3560 342~ 1905 3560 3422 1898 3560 3422 1930 3560 3422 58,156 3,560 3,425 !,876 3,516 2,205 31 ACT INJ INJ ANNU 0 50 0 29 0 C41-26 ACT INJ INJ ANNU 0 50 0 0 645 450 0 50 0 0 645 450 0 50 0 0 645 ~50 0 50 0 0 645 450 0 50 0 645 450 0 50 0 645 450 0 50 0 645 450 0 50 0 645 450 0 50 0 645 45~ 0 0 0 645 450 0 0 0 645 0 0 0 650 45C 0 0 0 650 45C 0 0 0 650 45C 0 0 . 0 650 45~ 0 0 0 650 45C 0 0 0 650 45C 0 0 0 650 45C 0 0 0 650 45C 0 0 0' 650 45C 0 0 0 650 45C 0 0 0 650 45C 0 50 0 650 45C 0 50 0 .640 45( 0 50 0 650 45C 0 50 0 650 45( o 5o o 65o 450 0 50 0 650 450 0 50 0 0 650 450 0 50 0 0 650 450 0 50 0 .0 650 450 0 0 650 450 0 0 648 450 0 C44-14RD ACT INJ INJ ANNU 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 o 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 C24A-23 108 3460 150 3460 325 4500 376 4500 335 4500 317 4500 314 4500 309 4500 276 4500 89 3500 343 3500 297 4400 285 4450 277 445C 103 4450 0 4450 0 4450 140 4450 109 4450 146 4450 151 4450 160 4450 162 3475 168 3490 167 ' 3475 171 35OO 173 3500 171 3500 171 3500 170 3500 174 3500 6,137 4,500 198 4,057 29 41-23 shut in due to annular communication problem. 34-23 has developed an annular communication problem. AOGCC notilled on 12JI2/99. Varb~l qqmnml to continuo to inj~ reooived from Mt. Wondzdl on 12/i4/99. November-99 01 -Nov-99 02-Nov-99 03-Nov-99 04-Nov-99 05-Nov-99 06-Nov-99 07-Nov-99 08-Nov-99 09-Nov-99 ! 0-Nov-99 ! I-Nov-99 12-Nov-99 13-Nov-99 14-Nov-99 i 5-Nov-99 16-Nov-99 17-Nov-99 18-Nov-99 19-Nov-99 20-Nov-99 2 i -Nov-99 22-Nov-99 23-Nov-99 24-Nov-99 25-Nov-99 26-Nov-99 27-Nov-99 28-Nov-99 29-Nov-99 30-Nov-99 TOTAL MAXIMUM AVERAGE # DAYS 12/13/99 C23-23 ACT INJ INJ 1316 3500 3ilc 1316 3500 311C 1313 3500 311¢ 1365 3500 311C 1378 3500 311C 1386 3500 311~ 1385 3500 311~ 1380 3500 311~ 1382 3500 311C 1381 3500 311C 1379 3500 311C 1376 3500 311C 1379 3500 311~ 1383 3500 3110 1373 3500 3110 1384 3500 3110 1369 3500 3110 1375 3500 3110 1359 3500 3110 1374 3500 3110 1375 3500 3110 1377 3500 3110 1375 3500 3110 1388 3500 3110 1379 3200 310~ 1385 3200 310~ 1394 3200 310~ 1398 3200 310~ 1391 3195 310~ 1392 3195 310~ C41-23 ACT WATER INJECTION REPORT PLATFORM C ACT C24-23 ] INJ INJ ANNU C34-23 ACT [NJ INJ ' C23-26 ACT ANNU [NJ [NJ ANNU 0 0 50 0 0 50 0 0 50 0 0 50 0 0 50 0 0 50 0 0 50 0 0 5O ' 0 0 50 0 0 50 o 0 5O 0 0 50 0 0 5O 0 5O 0 50 . 0 50 0 50 0 5O 0 50 Ol o 50 0! 0 50 o! o 50 0 0 50 ol o 5o o; o so o o 50 0 0 50 0 0 50 G 0 50 ~ 0 50 C41-26 C44-14RD C24A-23 41,207 3,500 3,110 1,374 3,440 3,108 30 394 3500 3500 398 3500 3500 395 3500 3500 396 3500 3500 397 3500 3500 400 3500 3500 401 3500 3500 394 3500 3500! 396 3500 350C 397 3500 350C 393 3500 350C 391 3500 350C 393 3500 350¢ 392 3500 350~ 388 3500 350~ 392 3500 350g 387 3500 350~ 387 3500 350~ 381 3500 350~ 387 3500 350~ 387 3500 350~ 388 3500 350C 387 3500 350~ 389 3500 350~ 387 3490 350¢ 385 3~90 35O( 388 3500 350C 389 3500 350¢ 386 3490 35O( 384 3490 35O( INJ [NJ 0 750 650 0 750 650 0 750 650 0 750 650 0 750 650 0' 750 650 0 750 650 0 750 650 0 750 650 0 750 650 0 750 650 0 750 650 0 750 65C 0 750 65C 0 750 65C 0 750 65C 0 750 65C 0 750 65C 0 750 65C 0 750 65C 0 750 65C 0 750 65¢ 0 750 65C 0 750 65C 0 575 65( 0 575 65( 0 575 650 0 575 650 0 575 650 0 575 I 1,729 3,500 3,500 1940 3550 1962 3550 1965 3550 1978 3550 1987 3550 1998 3550 1993 3550 1978 3550 1959 3550 1964 3550 1974 3550 1976 3550 1976 3550 1978 3550 1960 3550 1979 3550 1958 3550 1958 3550 1930 3550 1950 3550 1950 3550 1958 3550 1959 3550 1973 3550 1951 35O0 1955 3550 1963 3550 1963 3560 1956 3550 1951 3550 0 50 0 750 58,942 3,560 0 715 0 391 3,499 3,500 30 i,965 3,549 30 o 50 0 ACT [NJ [NJ ANNU 0 635 450 0 635 450 0 635 '450 0 635 450 0 635 45C 0 635 45~ 0 635 450 0 635 450 0 635 450 0 635 450 0 0 635 450 0 0 635 450 0 0 635 450 0 0 635 450 0 635 450 0 635 450 0 635 450 0 635 450 0 635 450 0 0 635 450 0 0 635 450 0 0 635 450 0 0 635 450 0 0 .635 450 0 0 645 450 0 0 645 450 0 0 645 450 0 0 645 450 0 0 645 450 0 0 645 450 0 0 645' 450 0 0 637 450 0 I ' ACT [NJ [NJ ANNU [NJ rNJ ANNU 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 .0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 244 3500 140 247 3500 140 230 3500 125 120 3500 125 114 3500 125 113 35O0 125 114 3500 125 109 3500 125 109 3500 125 109 35O0 125 ill 3500 125 !12 3500 109 3500 II0 3500 109 3500 125 112 3500 125 II0 3500 125 i12 3500 125 106 3500 125 112 3500 125 I!1 3500 125 i15 3500 125 415 3500 125 112 3500 125 109 3490 75 i10 3475 7i 113 3495 7~ 116 3500 65 114 3490 60 114 3490 60 3,741 3,500 0 0 550, 125 3,498 0 ~ 30 i-23 shut in due to annulnr oommunication problem. January-99 C23-23 C41-23 C24-23 C34-23 C23-26 C41o26 C44-14RD C24A-23 !iii!i!iii!iiiii!i!i!iii!i(iiii!i!!iii ACT ACT ACT ACT ACT ACT ACT ACT iiii~i~iiiiiiiii INJ INJ ANNU INJ INJ ANNU INJ INS ANNU INJ INS ANNU INJ INJ ANNU FNJ INJ ANNU INJ INJ ANNU INJ INJ AHNU 01-Jan-99 1357 3200 3125 978 700 660 386 3500 3500 1841 3500 0 0 0 01 0 0 400 0 0 550 0 1200 75 02-Jan-99 1340 3200 3125 967 700 660 383 3500 3500 1811 3500 0 0 0 0 0 0 400 0 0 550 0 1200 75 03-Jan-99 300 3200 3125 368 700 660 85 3500 3500 487 3500 0 0 0 0 0 0 400 0 0 550 0 1200 75 04-Jan-99 0 3200 3125 0 700 660 0 3500 3500 0 3500 0 0 0 0! 0 0 400 0 0 550 0 1200 75 05-Jan-99 0 2000 2000 0 575 575 0 1600 1600 0 1275 0 0 0 01 0 0 400 0 0 550 0 1050 80 06-Jan-99 0 2000 2000 0 575 575 0 1600 1600 0 1275 0 0 0 0i 0 0 400 0 0 550 0 1025 80 07-Jan-99 1220 3100 3000 677 700 630 347 3500 3500 1533 3500 0 0 0 0 0 0 400 0 0 550 0 3500 0 08-Jan-99 1431 3100 3000 915 700 630 411 3500 3500 1888 3500 0 0 0 0 0 0 400 0 0 550 0 3500 0 09-Jan-99 1352 3100 3000 907 700 630 339 3500 3500 1845 3500 0 0 0 0 0 0 400 0 0 550 0 3500 0 10-Jan-99 1300 3150 3050 896 700 640 407 3500 3500 1799 3500 0 0 0 0 0 0 400 0 0 550 0 3500 0 fl-Jan-99 1351 3150 3050 511 700 640 386 3500 3500 1825 3500 0 0 0 0 0 0 400 0 0 550 0 1800 0 /~12-Jan-99 1332 3150 3050 744 700 640 438 3500 3500 1826 3500 0 0 0 0 0 0 400 0 0 550 0 1050 0 Ian-99 1327 3200 3100 755 700 640 426 3500 3500 1824 3500 0 0 0 0 0 0 400 0 0 550 0 3500 0 , .-Jan-99 1325 3200 3100 751 700 640 80 3500 3500 1832 3500 0 0 0 0 0 0 400 0 0 550 0 3500 0 15-Jan-99 1334 3200 3100 752 700 640 0 3500 3500 1856 3500 0 0 0 0 0 0 400 0 0 550 0 3500 0 16-Jan-99 1334 3200 3100 754 700 640 45 3500 3500 1856 3500 0 0 0 0 0 0 400 0 0 550 0 2050 0 17-Jan-99 1337 3200 3100 754 700 640 417 3500 3500 1858 3500 0 0 0 0 0 0 400 0 0 550 0 1750 0 18-Jan-99 1329 3200 3100 753 700 640 432 3500' 3500 1856 3500 0 0 0 0 0 0 400 0 0 550 0 1750 0 19-Jan-99 1329 3200 3100 756 700 640 415 3500 3500 1863 3500 0 0 0 0 0 0 400 0 0 550 0 1300 0 20-Jan-99 1339 3200 3100 755 700 640 419 3500 3500 1886 3500 0 0 0 0 0 0 400 0 0 550 408 3500 0 21-Jan-99 1341 3200 3100 757 700 640 421 3500 3500 1903 3500 0 0 0 0 0 0 400 0 0 550 156 3500 0 22-Jan-99 1348 3200 3150 759 700 630 419 3500 3500 1897 3500 0 0 0 0 0 0 400 0 0 550 57 3500 0 23-Jan-99 279 2200 2400 254 650 590 92 1700 1725 409 1000 0 0 0 0 0 0 400 0 0 550 0 1825 35 24-Jan-99 0 2150 2400 0 650 590 0 1700 1725i 0 1000 0 0 0 0 0 0 40{ 0 0 550 0 1500 35 25-Jan-99 0 2150 2050 0 650 590 0 1600 1600i 0 1000 0 0 0 0 0 0 400 0 0 550 0 1500 85 26-Jan-99 829 3200 2050 392 700 590 245 3500 1600 1222 3500 0 0 0 0 0 0 400 0 0 550 0 I100 85 27-Jan-99 1345 3200 3110 732 700 630 405 3500 3500 2125 3500 0 0 0 0 0 0 400 0 0 550 206 3500 0 28-Jan-99 1319 3200 3110 754 700 630 404 3500 3500 2141 3500 0 0 0 0 0 0 400 0 0 550 300 3500 0 29-Jan-99 1296 3200 3110 758 700 630 403 3500 3500' 2121 3500 0 0 0 0 0 0 400 0 0 550 122 3500 0 30-Jan-99 1281 3200 3110 750 700 630 400 3500 3500 2117 3500 0 0 0 0 0 0 400 0 0 550 25 3500 0 31-Jan-99 1241 3200 3110 744 700 630 394 3500 3500 2071 3500 0 0 0 0 0 0 400 0 0 550 0 1625 0 TOTAL 31,916 18,893 8,599 45,692 0 0 0 1,274 MAXIMUM 3,200 3,150 700 660 3,500 3,500 3,500 0 0 0 0 400 0 550 3,500 85 [ ..... ~RAGE 1,030 3.008 2,908 609 687 629 277 3,200 3.140 1,474 3,115 0 0 0 0 0 0 400 0 0 550 4! 2,359 23 . aAYS 26 26 25 26 0 0 0 7 v2/~ 0/99 All injectors down January 4, 5 & 6 due to waterflood turb~e annu~ maintenance. All i~ectors down January 24 & 25 due to waterflood turbine annu~ m~ntenance. ~) ~.~C ~ i V ~D Anchorage March-99 C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 iilii ~ ~i~iiiiiiii! ACT ACT ACT ACT ACT ACT ACT ACT !:i:i:i!:!!:i:i:i:i:i:i:!:~:i:i:i:!:i:!: INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ 01-Mar-99 1265 3250 3175 782 700 635 381 3500 3500 1932 3500 0 0 0 0 0 550 425 0 0 550 57 3500 02-Mar-99 1306 3250 3175 786 700 635 391 3500 3500 1981 3500 0 0 0 0 0 550 425 0 0 550 0 3500 03-Mar-99 1307 3250 3175 786 700 635 391 3500 3500 1990 3500 0 0 0 0 0 550 425 0 0 550 0 3500 04-Mar-99 1320 3250 3150 792 700 640 395 3500 3500 2014 3400 0 0 0 0 0 550 425 0 0 550 0 1600 05-Mar-99 1314 3250 3150 793 700 640 393 3500 3500 2007 3400 0 0 0 0 0 550 425 0 0 550 0 1400 06-Mar-99 1316 3250 3150 791 700 640 392 3500 3500 2015 3400 0 0 0 0 0 550 425 0 0 550 371 3500 07-Mar-99 1311 3250 3150 790 700 640 394 3500 3500 2000 3400 0 0 0 0 0 550 425 0 0 550 176 3500 08-Mar-99 1298 3250 3150 778 700 640 392 3500 3500 2000 3400 0 0 0 0 0 550 425 0 0 550 66 3500 09-Mar-99 1315 3250 3150 791 700 640 396 3500 3500 2000 3400 0 0 0 0 0 550 425 0 0 550 74 3500 10-Mar-99 1296 3200 3150 780 700 640 390 3500 3500 2000 3500 0 0 0 0 0 550 475 0 0 550 0 2100 Il-Mar-99 1320 3250 3150 792 700 640 395 3500 3500 2014 34000 0 0 0 0 550 425 0 0 550 0 1600 ..19,Mar-99 1310 3200 315C 787 700 640 395 3500 3500 2000 3500 0; 0 0 0 0 550 475 0 0 550 0 2100 lar-99 1335 3200 315C 783 700 64C 404 3500 350~ 2000 3500 0 0 0 0 0 550 475 0 0 550 0 2100 dar-99 1327 3200 31501 781 700 640 400 3500 3500 2000 3500 0 0 0 0 0 550 475 0 0 550 0 2100 ,_ - 15-Mar-99 1330 3200 315C 782 700 640 401 3500 350~ 2000 3500 O 0 0 0 0 550 475 0 0 550 0 2100 16-Mar-99 1329 3200 3150 787 700 64~ 399 3500 3500 2000 3500 0 0 0 0 0 550 475 0 0 550 0 2100 17-Mar-99 1342 3200 3150 790 700 64~ 402 3500 3500 2000 3500 0 0 0 0 0 550 475 0 0 550 0 1925 18-Mar-99 1333 3200 3150 789 700 640 399 3500 3500 2000 3500 0 0 0 0 0 550. 475 0 0 550 0 1925 19-Mar-99 1337 3200 3150 790 700 640 399 3500 3500~ 2000 3500 0 0 0 0 0 550 475 0 0 550 54 3500 20-Mar-99 1333 3200 3150 779 700 64~ 396 3500 3500 2000 3500 0 0 0 0 0 550 475 0 0 5501 0 3500 21-Mar-99 1340 3200 3150 783 700 6401 397 3500 3500 2000 3200 0 0 0 0 0 550 425 0 0 5501 0 3500 22-Mar-99 1358 3200 3150 793 700 64~ 403 3500 3500 2000 3200 0 0 0 0 0 550 425 0 0 550 0 2800 23-Mar-99 1338 3200 3150 789 700 64~ 396 3500 3500 2000 3200 0 0 0 0 0 550 425 0 0 550 0 1800 24-Mar-99 1339 3200 3150 788 700 640 396 3500 3500 2000 3200 0 0 0 0 0 550 425 0 0 550 0 1800 25-Mar-99 1343 3200 3150 790 700 640 397 3500 3500 1885 3200 0 0 0 0 0 550 425 0 0 550 0 350 26-Mar-99 1354 3200 3150 792 700 640 400 3500 3500 1881 3200 0 0 0 0 0 550 425 0 0 550 0 650 27-Mar-99 1347 3200 3150 785 700 640 397 3500 3500 1854 3200 0 0 0 0 0 550 425 0 0 550 0 640 28-Mar-99 1357 3200 3150 794 700 640 401 3500 3500 1866 3200 0 0 0 0 0 550 425 0 0 550 0 600 29-Mar-99 1357 3200 3150 792 700 640 399 3500 3500 1860 3200 0 0 0 0 0 550 425 0 0 550: 0 525 30-Mar~99 1366 3200 3150 794 700 640 401 3500 3500 1868 3200 0 0 0 0 0 550 425 0 0 5501 0 475 31-Mar-99 1361 3200 3150 792 700 640 398 3500 3500 1854 3200 0 0 0 0 0 550 425 0 0 550i 0 475 TOTAL 41,204 24,421 12,290 61,021 0 0 0 798 MAXIMUM 3,250 3,175 700 640 3,500 3,500 3,500 0 0 0 550 475 0 550 3,500 ( ,~"'~RAGE 1,329 3,216 3,152 788 700 640 396 3,500 3,500 1,968 3,371 0 0 0 0 0 550 441 0 0 550 26 2,134 ~AYS 31 31 31 31 0 0 0 6 ~-~/08/99 I ,,,, C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 ACT ACT ACT ACT ACT ACT 'AC~ ACT l'NJ INJ ANNU INJ INJ ANNU ]NJ INJ ANNU INJ INJ ANNU INJ INJ ANNU [NJ INJ ANNU INJ INJ ANNU INJ INJ 1290 3200 3110 795 700 630 438 3500 3500 2151- 3500 0 0 0 '0 0 0 400 0 0 550 0 i400 1249 3200 3110 751 700 630 401 3500 3500 2121 3500 0 0 0 0 0 0 400 0 0 550 366 1400 1243 3200 3110 751 700 630 399 3500 3500 2114 3500 0 0 0 0 0 0 400 0 0 550 81 1400 1243 3200 3110 750 700 630 396 3500 3500 2104 3500 O 0 0 0 0 0 400 0 0 550 21 3500 1235 3200 3110 751 700 630 394 3500 3500 2082 3500 0 0 0 0 0 0 400 0 0 550 40 3500 1245 3200 3110 751 700 630[ 397 3500 3500 2095 3500 0 0 0 0 0 0 400 0 0 550 24 3500 1264 3200 3175 754 700 630 399 3500 3500 2126 3500 0 0 0 0 0 0 400 0 0 550 13 3500 1260 3200 3175 753 700 630 398 3500 3500 2119 3500 0 0 0 0 0 0 400 0 0 550 20 3500 1273 3200 3200 821 700 630: 433 3500 3500 2313 3500 0 0 0 0 0 0 400 0 0 550 20 3500 1254 3200 3200 747 700 630 392 3500 3500 2094 3500 0 0 0 0 0 0 400 0 0 550 14 3500 1272 3200 3200 757 700 630 396 3500 3500 2118 3500 0 0 0 0 0 0 400 0 0 550 8 3500 1269 3200 3200 752 700 630 396 3500 3500 2106 3500 0 0 0 0 0 0 400 0 0 550 O 3500 1279 3200 3200 755 700 630 399 3500 3500 2104 3500 0 0 0 0 0 0 400 0 0 550 O 3500 1286 3200 3200 770 700 630 399 3500 3500 2099 3500 0 0 0 0 0 0 400 0 0 550 O 3500 1272 3200 3200 793 700 630 393 3500 3500 2073 3500 0 0 0 0 0 0 400 0 0 550 O 3500 1275 3200 '3200 796 700 630 393 3500 3500 2046 3500 0 0 0 0 0 0 400 0 0 5501 373 3500 1264 3250 3150 795 700 680 395 3500 3500 2091 3500 0 0 0 0 0 0 400 0 0 550 120 3500 1248 3250 3175 793 700 640 392 3500 3500 2086.- 3500 0 0 0 0 0 0 400 0 0 550 40 3500 1262 3250 3175 799 700 640 396 3500 3500 2115 3500 0 0 0 0 0 0 400 0 0 550 12 3500 1243 3250 3175 785 700 635 395 3500 3500 2056 3500 0 0 0 0 0 ' 0 400 0 0 550 3 3500 1263 3250 3175 801 700 635 399 3500 3500 2059 3500 0 0 0 0 .0 0 400 0 0 550 O 3500 1251 3250 3175 792 700 635 399 3500 3500 1945 3500 0 0 0 0 0 0 400 0 0 550 O 2200 1250 3250 3175 795 700 635 400 3500 3500 1900 3500 0 0 0 0 0 '0 400 0 0 550i 0 1900 1257 3250 317~ 774 700 635 402 3500 3500 1980 3500 0 0 0 0 0 0 400 0 0 550 O 1850 1240 3250 3175 780 700 635 386 3500 3500 1912 3500 0 0 0 0 0 0 400 0 0 550 O 1600 1224 3250 3175 780 700 635 367 3500 3500 1884 3500 0 0 0 0 0 0 400 0 0 550 O .1425 1233 3250 3175 .782 700 635 370 3500 3500 1881 3500 0 0 0 0 0 0 400 0 0 550 356 3500 1292 3250 3175 788 700 635 393 3500 3500 1981 3500 0 0 0 0 0 0 400 0 0 550 147 3500 , , 35,236 21,711 11,117 57,755 0 0 0 1,658 3,250 3,200 700 680 3,500 3,500 3,500 0 0 0 ' 0 400 0 550 3,500 1,258 3,221 3,167 775 700 634 397 3,500 3,500 2,063 3,500 0 0 0 0 0 0 400 0' 0 550 59 '2,971 28 28 28 28 0 0 0 17 February-99 0 l-Feb-99 02-Feb-99 03-Feb-99 04-Feb-99 05-Feb-99 06-Feb-99 07-Feb-99 08-Feb-99 09-Feb-99 10-Feb-99 ii-Feb-99 12-Feb-99 · -99 · -99 15-Feb-99 16-Feb-99 17-Feb-99 18-Feb-99 19-Feb-99 20-Feb-99 21-Feb-99 22-Feb-99 23-Feb-99 24-Feb-99 25-Feb-99 26-Feb-99 27-Feb-99 28-Feb-99 TOTAL MAXIMUM AVP '~GE ,rS February 3, 1992 Shell Western E In~ ~ .... 601 West Fifth Avenue · Suite 800 ~ Anchorage, Alaska 99501 ~ State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Gentlemen'. SUBJECT: SUBSEQUENT REPORT FOR MIDDLE GROUND SHOAL WELL C41-23 Enclosed are duplicates of the Subsequent Report for the recently completed Mechanical Integrity Test (MIT) on Middle Ground Shoal well C41-23. The MIT was performed on October 23, 1991, and was witnessed by an AOGCC representative. If you need additional reports or information, please contact Mr. Paul Huckabee at (907) 263-9646. Very Truly Yours, Manager Alaska Operations Western Division RGB/SBBM/dlw Enclosures SBBM~020392B.WP5 RECEIVED FEB - 5 1992 Alaska Oil & Gas Cons..Commiss,,ion Anchorage UKIbl AI. STATE OF ALASKA Al'""~ OIL AND GAS CONSERVATION COMMI~ ~N REPORT OF SUNDRY WELL OPERATIONS 1. Operations pedormed: Operation shutdOWn __ Stimulate Pluggingm Perforate __ Pull tubingm Alter casing__ Repair well B Other X , 5. Type et Well: 6. Datum elevation (DF or KB) i2. Name of Operator Shell Western E&P Inc. Development 106' DF feet 3. Address 601 W. 5th Avenue, Suite 810 Exploratory .. 7. Unit or Property name Anchorage, AK 99501 Stratigraphic . Middle Ground Shoal Service X 8. Well' Number 4. Location of well at surface Platform C, Leg 4, Conductor 28, 503.51'N and 1531.56'W of C41-23 SE Corner of Sec. 23, T8N, R13W, SM 9. Permit number/approval number At top of productive interval @ 1194'S and 819'W of the NE Corner of Sec. 23, T8N, 68-112/91-294 R13W, SM 10. APl number @ 583'S and 1195'W of the NE Corner of Sec. 23, T8N, 50-733-20163 At effective depth R13W, SM @ 506'S and 1243'W of the NE Corner of Sec. 23, T8N, 11. Field/Pool At total depth R13W, SM "G" Pool 12. Present well condition summary Total depth: measured 10,712 feet Plugs (measured) true vertical 9507 feet Effective depth: measured 10,535 feet Junk (measured) true vertical 9355 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface I nte rmed iate 1653' 10-3/4", 40.5#, J-55 1350 sx 1653' Production 10,509' 7", 26-29#, N-80 10,593' Liner RECEIVED Perforation depth: measured 9087'-10,438' true vertical 809g'-9273' FEB - 5 t992 Alaska 0il & Gas Cons. Commissi Tubing (size, grade, and measured depth) 3-1/2", 9.3#, N-80 EUE, AB-MOD @ 10,160' Anchorage Packers and SSSV (type and measured depth) Packers set at 8898', 9582', and 10,157'. "X" Nipple at 324'. 13. Stimulation or cement squeeze summary Intervals treated (measured) Thisprocedure has been completed in compliance with Administrative Approval No. AIO 9.5, dated10/21/91. Treatment description including volumes used and final pressure 14. Representative Daily Avera(~e Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments: MIT test form 16. Status of well classification as: Copies of Logs and Surveys run -- Oil Gas Suspended__ Service Injection Daily Report of Well Operations -- 17. I hereby certity that the toregomg is true and correct to the best ot my knowledge Signed ,~_ ,~-.~° ~- ---,'~----- Tit lo C~ ~1= r~ 9~,,.,,.~ ~.~, ,,~,.r=~ Date P ..... ~ ....... ~1,,~1 il-iii ii"~ lkl &-i~,l iir~l Form 10-404 Rev 06/1 SUBMIT IN DUPLICATE WALTEFI J. HICKEL, GOVERNOFI ALASKA OIL AND GAS CONSERVATION COM~IlSSION October 21, 1991 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-14,.33 TELECOPY: (907) 278-7542 ADMINISTRATIVE APPROVAL NO. AIO 9.5 Re: Amend Rule 6 of Area Injection Order (AIO) No. 9 W. F. Simpson Manager, Regulatory Affairs Shell Western E & P Inc. 601 West 5th Ave., Suite 810 Anchorage, AK 99501-2257 Dear Mr. Simpson: Shell Western E & P Inc. (SWEPI), as operator of the central portion of the Middle Ground Shoal (MGS) field, by letter dated September 23, 1991, requested modification to Rule 6 of AIO No. 9 (as amended by AA No. AIO 9.2, 9.2-A, 9.3-A and 9.4). The modification would allow a lower surface pressure for testing the mechanical integrity of MGS well No. C41-23. Pressuring the annulus to the required pressure of 25 psi/ft multiplied by the true vertical depth of the casing shoe may break down the cement repair of 'the casing at 2147' which was squeezed cemented and tested to 1000 psi in 1987. To minimize the risk of such damage, yet still confirm casing integrity, SWEPI requests authorization to test MGS well No. C41-23 using a surface pressure of 1000 psig. The Commission has determined that MGS well No. C41-23 does not inject into, through, or above an underground source of drinking water, and therefore less stringent requirements for testing mechanical integrity may be approved per 20 AAC 25.450. The Commission concludes that the mechanical integrity of the MGS well No. C41-23 will be demonstrated if the casing annulus holds 1000 psig surface pressure for 30 minutes with less than a 10 percent leakoff. · RECEIVED FEB - § Alas.Fa 0it & Gas Cons. ~ommiSSte~ Anchorage · "-: ', ~. ~'! .'~.F;'~ " ' W. F. Simpson -2- October 21, 1991 Therefore, as provided by "Rule 9 Administrative Relief," Rule 6 is amended to read: Rule 6 Demonstration of Tubing/Casing Annulus Mechanical Inte~ity ae A schedule must be developed and coordinated with the Commission which ensures that the tubing/easing annulus for each injection/disposal well is pressure tested prior to initiating injection and at least once every four years thereafter. A test surface pressure of 1500 psi or 0.25 psi/ft multiplied by the vertical depth of the packer, which ever is greater, but not to exceed a hoop stress greater than 70% of the easing's minimum yield strength, must be held for 30 minutes with no more than a 10% decline. be As an alternative, injection/disposal wells may be survey-tested to verify that fluids injected as confined to designated injection strata using an EPA approved method every other year for wells with tubing-to-casing pressure communication. The proposed test method and detailed operations program shall be submitted to the Commission for approval on Form 10-403 prior to testing the well. c. The Commission must be notified at least 24 hours in advance to enable a representative to witness the test. d. The tubing-casing annulus of Middle Ground Shoal Well No. A34- 14RD2 shall be tested to 1000 psig surface pressure. This pressure must be held for 30 minutes with no more than a 100 psi decline to qualify as a valid test. Daily monitoring of the annulus pressure between integrity tests shall be performed Should the well be worked over and permanent packers installed the testing criteria of paragraphs a. and b. shall take effect. se The tubing-casing annulus of Middle Ground Shoal Well No. C41-23 shall be tested to 1000 psi~ surface pressure. This pressure mus.t. be held for 30 minutes with no more than a 100 psi decline to qualify as a valid test. Daily monitoring of the annulus pressure between integrity tests shall be performed. David W. Joh'~ Chairman BY ORDER OF THE COMMISSION RECEIVED FEB - 997 Alaska Oil & Gas {~ons. (;ommiss~O~ ~nchora~e 0IL ~l~D G/~ ~6EI~¥RIION COHHISSIOH REOIRIIIOL IN~E(;RI TY TEST *P *l TYP£ or PtCR CAS I ,~ TBG REq r T~ ~iHE ~ TIH~ START N~ ~ ~ FLU ID ~ PR[~ PRESS . CSG CSG PRESS PRESS C~IEN [5: : :~ ~ ~ _ , ,.~ ................. , ,, ,,,, ~ ~ , __ COHHE~T S: .......................... D~ Ir ~ .. ' . ...,, ......... , ,, ~ELL Initl ll__~ i-.yearL ¥orko.~r__ C~,plat r:. a~OGCC ~ITHE~S SIGIP, IURE COHPAIIY REP SI CIIAIUR[ Shell Western E&P Inc. O 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 September 23, 1991 Alaska Oil and Gas Conservation Commission ATTN: Lonnie Smith 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen: SUBJECT: SUBMITTAL OF APPLICATION FOR SUNDRY APPROVAL REQUESTING ADMINISTRATIVE RELIEF TO AREA INJECTION ORDER (AIO) -~ NO. 9, RULE 6 FOR MIDDLE GROUND SHOAL WELL NO. C41-23 Please find attached the subject application requesting administrative relief as provided by Rule 9 of AIO No. 9 to reduce the Rule 6 test pressure requirement for Middle Ground Shoal (MGS) Well No. C41-23. Casing damage at 2147' was repaired via cement squeeze operations in S~~_1~.8~7~ and pressure tested to 1000 psi. We are proposing a test pressure of 1000 psi at this time to reduce the risk of inducing a casing failure at the 2147' squeezed depth while demonstrating mechanical integrity of the tubing/casing annulus. Demonstration of Tubing/Casing Annulus Mechanical Integrity is scheduled for October 1991. A 10.3 ppg brine was left in the annulus following the 1987 workover which translates to a Rule 6 (AIO #9) required test pressure of 1500 psi. We propose a surface pressure test of 1000 psi as sufficient to verify mechanical integrity in this well. This test pressure is equivalent to a 2100 psi differential at the top packer assuming a 0.465 psi/ft pressure gradient external to the casing. If you have any questions, or wish to discuss, feel free to contact Paul Huckabee of our staff at (907) 263-9646. Very Truly Yours, W. F. Simpson Manager Regulatory Affairs - Alaska Operations Shell Western E&P Inc. PTH RECEIVED s E P 2,5 1991 Alaska 0JJ & 6as Cons. Commission Anchorage STATE OF ALASKA ALA,-'~, OIL AND GAS CONSERVATION COMMIS,~,,.)N APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspendm Operation shutdown__ Re-enter suspended well Alter casing __ Repair Well Plugging __ Time extension Stimulate Change approved program __ Pull t----ubing Variance X Perforate __ Other 6. Datum elevation (DF or KB~ 2. Name of Operator Shell Western E&P Inc. 3. Address 601 West 5th Avenue, Suite 800 Anchorage, AK 99501 5. ~ype of Well: Development Exploratory Stratigraphic Service 106' DF feet 7. Unit or Property name Middle Ground Shoal 8. Well number 4. Location of well at surface At top of productive interval At effective depth At total depth Platform "C", Leg 4, Conductor 28 @ 4776'S and 1532'W of the NE Corner of Sec. 23, T8N, R13W, S.M. @ 1194'S and 819'W of the NE Comer of Sec. 23, T8N, R13W, S.M. @ 583'S and 1195'W of the NE Corner of Sec. 23, T8N, R13W, S.M. @ 506'S and 1243'W of the NE Corner of Sec. 23, T8N, R13W, S.M. C41-23 9. Permit number 68-112 10. APl number 50-733-20163 11. Field/Pool "G" Pool 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Sudace Intermediate Production Liner true vertical measured true vertical Length 10,712 feet 9507 feet 10,535 feet 9355 feet Plugs (measured) Junk (measured) Size Cemented Measured depth True vertical depth 1653' 10-3/4",40.5#,J-55 1350sx 1,653' 10,509' 7",26-29#,N-80 10,593' RECEIVED Perforation depth: measured 9,087'- 10,438' See attached Completion Equipment Detail Sheet S E P 2 5 1991 true vertical 8,099'-9,273' Alaska 0il & Gas Cons. Corem[', Tubing (size, grade, and measured depth) 3-1/2", 9.3#, N-80 EUE, AB-MOD @ 10,160' Anchorage Packers and SSSV (type and measured depth) Packers set at 8898', 9582', and 10,157'. "X" Nipple at 324'. 13. Attachments Description summary of proposal ~ Detailed operations program ~ BOP sketch__ 14. Estimated date for commencing operation 10/01/91 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Suspended Service Injection 17. I hereby certify that~l~e foregoing is true and correct to the best of my knowledge Signed ~'. /~',~ Title Manager Regulatory Affairs Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness jApproval No. Plug integrity BOP Tt~s.t__ Location clearance Mechanical In~grity TestT~ Subsequent form requi-~d 10- ~o ? Approved by order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE APPLICATION FOR SUNDRY APPROVAL DESCRIPTION SUMMARY OF PROPOSAL We are requesting administrative relief as provided by Rule 9 of AIO No. 9 to reduce the Rule 6 test pressure requirement for Middle Ground Shoal (MGS) Well No. C41-23. Casing damage at 2147' was repaired via cement squeeze operations in September 1987 and we would like to minimize the risk of inducing a mechanical integrity problem from the Rule 6 MechaniCal Integrity Testing (MIT) requirements. Demonstration of Tubing/Casing Annulus Mechanical Integrity is scheduled for October 1991. A 10.3 ppg brine was left in the annulus following the 1987 workover which translates to a Rule 6 required test pressure of 1500 psi. We propose a surface pressure test of 1000 psi as sufficient to verify mechanical integrity in this well. This test pressure is equivalent to a 2100 psi differential at the top packer assuming a 0.465 psi/ft pressure gradient external to the casing. The reduced test pressure is intended to reduce the risk of inducing a casing failure at the 2147' squeezed depth while demonstrating mechanical integrity of the tubing/casing annulus. RECEIVED S E P 2 5 t991 Alaska Oil & Gas Cons. L;ommissio'~ Anchorage PTH 2 COMPLETION EQUIPMENT DETAIL SHEET MGS C41-23 [0/[9/87 NO. ITEM APPROXIMATE TVD. MD. 1] 3-1/2" OTIS "X" NIPPLE 324 324 2. 3-1/2" OTIS "X" NIPPLE 7891 8863 3. BAKER "E" ANCHOR SEAL ASSEMBLY 7920 8895 4. BAKER FB-1 PACKER w/MILL OUT EXT 7920 8898 5. 3-1/2" CAMCO KBUG w/DUMMY 8269 9295 6. BAKER "G" LOCATOR w/2 X-SEAL UNITS 8529 9579 7. BAKER FB-1 PACKER w/MILL OUT EXT 8529 95B2 8. 3-1/2" OTIS "X" NIPPLE 8994 10123 g. BAKER "G" LOCATOR w/2 X-SEAL UNITS 9023 10155 10. BAKER FB-1 PACKER 9023 10157 CASING 10 3/4", 40.5#, BUTTRESS @ 1653' 7" 26-29#, N-80 BUTTRESS @ 10593' COD : 10,509'(W.0. 9/87) TD = 10,TIE' TUBING 3 1/2", 9.3#, N-80 EUE, AB-MOD @ 10160' PERFORATED ZONE GROSS INTERVAL GN-GO GR-GS HC-HN HN-HR HR-HZ HR-HZ 9087-9108' 9450-9495' 9706-10147'(SQUEEZED) 10180-10235' 10254-10316' 10340-10480' Alaska Oil & G~s Cons. 2 7 8 g 10 'COMPLETION EQUIPMENT DETAIL SHEET MGS A34-1qRDII 3/12/87.. NO. ITEM APPROXIMATE TVD.. HD.....=.. PSI OR 1. OTIS "X" NIPPLE 2. CAMCO MANDREL 3. GUIBERSON UNI-PACKER VII 4. CAMCO MANDREL 5. GUIBERSON UNI-PACKER VII 6. GUIBERSON UNI-PACKEIL.~.VI). 7. CAMCO MANDREL 8. GUIBERSON UN[-PACKER VII 9. OTIS "X" NIPPLE 10. GUIBERSON SHEAR SUB (E.O.T.) 296 296 8010 10830 DUMMY 8186 11o59 oumY 8264 11158 8568 11532 8673 11659 DUMMY 8778 11787 8794 11806 8820 11838 CASING 13 3/8", 61#, J-55 @ 0 - 1565' 9 5/8", 40#, N-80 BTC @ 0 - 5638' 7" 29#, N-80 @ 0 - 66' 26#, S-95 NEW @ 66 - 6667' 29#, N-BO USED X-LINE @ 6667 - 12100' W/845 SX PBTD = 12,010' : TO = 12,100' TUBING 3 1/2", 9.3#, N-80 EUE 8RD @ 0 - 11838' PERFORATED ZONE · . GROSS INTERVAL HC-HO 11049-11110' HE-HF 11210' HK-HN 11574-11576' HN-HR 11700-11740' HR-HZ 11806-11872' HR-HZ 11890-11940' Shell .Western E&P Inc. 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 . .... . August 7, 1991 Ms. Joan Miller State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99502 Dear Ms. Miller: SUBJECT: MONTHLY INJECTION REPORT FOR THE MIDDLE GROUND SHOAL FIELD (MGS) FOR THE MONTH OF JULY, 1991 The Monthly Injection Report for the Waterflood project at MGS for July is enclosed in duplicate. If you have any questions regarding this report, please call Ms. Susan Murnan at (907) 263-9614. Very truly yours, W. F. Simpson Manager Regulatory Affairs Alaska Division WFS/slm Enclosures \AOGCC\MTHLY INJ. JULY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMHISSION MONTHLY INJECTION REPORT 2O AAC 25.432 o. SHELL gESTERN E&P INC. Na~ of Operator MIDDLE GROUND SHOAL Field and Pool JULY, 1991 Month and Year of Injection TUBING PRESSURE 1. 2. 3. 4. 5. 6. ?. Welt # API# Class Field & Days in MAX Average 50- Pool Code Operation PSIG PSIG A 11-12 733-10083-00 W 524114 31 3,'550 3,502 A 11-13 733-20007-01 W 524114 31 3,550 3,502 A 12-12 733-20044-00 W 524114 31 3,550 3,502 A 23-01 733-20?.38-00 W 524114 31 3,550 3,502 A 33-14 733-20057-00 W 524114 31 3,550 3,502 A 34-11 733-10084-01 W 524114 31 4,400 4,348 A ~4-14 733-10086-01 W 524114 31 3,550 3,500 A 44-11 7"53-20027-00 W 524114 0 N/A N/A C 23-26 733-20071-00 W 524114 31 3,500 3,500 C 24-23 733-20145-01 W 524114 31 3,500 3,500 - · C 34-23 733-20041-00 W 524114 0 1,050 1,050 C 41'?.3 733-20163-00 W 524114 31 3,200 3,200 c 41-26 733-20409-01 w 524114 31 3,500 3,500 CASING PRESSURE 8. 9. HAX _ Average PSIG PSIG DAILY AVERAGE INJECTZON 10. 11. Liquid Gas (BBL) (MCF) TOTAL MONTHLY INJECTION 12. 13. Liquid Gas (BBL) (MCF) 100 67 884 80 46 334 3,300 3,250 581 120 63 1,243 95 48 1,330 24 20 196 170 107 680 100 86 0 3,475 3,451 104 3,500 3,069 731 1,050 1,050 0 0 0 2,450 0 0 157 27,404 10,349 18,024 38,54? 41,219 6,066 21,085 0 3,209 22,661 0 4,837 hereby certify that the foregoing is true and correct to the best of my knowledge. Total 269,245 Signed~ Title: Manager ALaska Operations Date: Fom 10-406 Rev. 12-1-85 RECEIVED AU G 1 2 1991 /~.Oll & flu Cons. Corm~iss~ Submit in Duplicate LOTUS\MTHLYINJ\JULY-RPT.WK5 January-2002 01-Jan-2002 02-Jan-2002 03-Jan-2002 04-Jan-2002 05-Jan-2002 06-Jan-2002 07-Jan-2002 08Jan-2002 09-Jan-2002 10-Jan-2002 1 l-Jan-2002 12-Jan-2002 13-Ian-2002 · 14-Jan-2002 15-Jan-2002 16-Jan-2002 17Jan-2002 18-Jan-2002 19-Jan-2002 20-Jan-2002 21 -Jan-2002 22-Jan-2002 23-Jan-2002 24-Jan-2002 25-Jan-2002 26-Jan-2002 27-Jan-2002 28-Jan-2002 29-Ian-2002 30-Jan-2002 31 -Jan-2002 TOTAL MAXIMUM AVERAGE # DAYS 02/11/2002 C23-23 ACT INJ INI ANNU 2025 3450 1977 3450 2010 3450 275 3450 2219 3400 2046 3400 2045 3450 2039 3450 1978 3450 1999 3425 2028 3425 2027 3425 1964 3425 1926 3400 1941 3400 1962 3400 1982 3400 1320 3400 1991 3425 1966 3425 1897 3425 1949 3425 1864 3425 1928 3425 1944 3425 1907 3425 1926 3425 1924 3425 1930 3425 1898 3425 1884 3450 58,771 3,450 1.896 3,426 31 WATER INJECTION REPORT PLATFORM C C41-23 ACT INJ INJ ANNU 0 1800 20 0 1800 20 0 1800 20 0 1800 20 0 570 570 0 570 570 0 570 570 0 570 570 0 570 570 0 570 570 0 570 570 0 570 570 0 570 57{3 0 570 57C 0 570 57C 0 570 57( 0 570 57( 0 570 57( 0 570 57{ 0 570 570 0 570 570 ~ 0 575 575 0 580 580 0 580 580 0 580 580 0 580 580 0 580 580 0 580 580 0 580 58{3 0 580 58{3 0 580 58C 0 1,800 58{3 · 0 732 502 0 C24-23 C34-23 ACT ACT INJ INJ ANNU INJ INJ ANNU 383 3450 345{3 330 3450 345{3 0 3450 345C 0 3450 345C 0 1150 115{ 0 1150 115{ 0 1150 115{ 85 1150 115( 364 1150 115{ 359 3300 3300 309 3300 3300 232 3300 3300 231 3300 3300 265 2800 2800 351 2800 2800 1578 3100 305( 1558 3100 305( 1597 3100 305( 212 3100 305( 1643 3050 30O{ 1585 3050 30O{ 1591 3100 305{ 1597 3100 3050 1563 3100 3050 1574 3100 3050 1598 3100 3050 1595 3100 3050 1559 3100 3050 1546 3100 3025 1557 3100 3025 C23-26 ACT INS - Rq$ ANNU 0 0 0 0 0 0 0 0 0 o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C41-26 ACT INJ INI ANNU 0 700 600 0 700 60~ 0 700 60{3 0 700 60~ 0 800 625 0 800 625 0 800 625 0 800 62.~ 0 800 625 0 800 62! 0 800 62.~ 0 800 625 0 800 625 0 800 625 0 800 625 C44-14RD ACT INJ IN'J ANNU 0 0 550 0 0 550 0 0 550 0 0 550 958 1,800 550 0 0 575 0 0 550 0 0 550 0 0 550 380 1,300 550 0 0 550 0 0 550 350 1,300 550 0 0 55{3 360 1,200 55£ 350 3275 3250 352 3275 3250 228 3275 32.50 354 3275 3250 350 3300 3275 343 3300 3275 348 3275 327~ 341 3275 3275 349 3275 327~ 351 3275 327~ 347 3275 327! 351 3275 3275 349 3275 3275 349 3275 3275 346 3275 3275 395 3425 3425 8,412 3,450 3,450 271 2~34 2,929 26 1564 3100 3025 1573 3100 3025 986 3100 3025 1589 3100 302~ 1577 3075 302~ 1529 3075 302~ 1566 3075 302~ 1529 3075 302~ 1551 3075 302~ 1563 3075 3025 1533 3075 30'25 1559 3075 3025 1556 3075 3025 1558 3075 3025 1537 3075 3025 1511 3100 3025 46,634 3,100 3,050 1,504 3,088 3,032 31 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 800 625 0 795 625 0 795 625 0 790 625 0 790 650 0 790 65{3 0 790 65C 0 790 65C 0 790 65{ 0 790 65{ 0 790 65( 0 790 65{ 0 790 650 0 790 650 0 790 650 0 850 650 0 850 650 0 0 785 631 0 0 0 55C 390 1,550 550 0 0 550 0 0 550 356 1,800 550 0 0 550 0 0 550 330 1,500 550 0 0 550 309 1,400 550 0 0 575 0 0 550 210 1,300 550 0 0 56~ 324 1,300 57{3 0 0 55{3 3,967 1,800 575 128 466 553 10 C24A-23 ACT INJ INJ ANNL 0 0 6OO 0 0 600 0 0 6O0 0 0 600 0 0 600 0 0 600 0 0 600 0 0 600 0 0 60O 0 0 60~ 0 0 60~ 0 0 60~ 0 0 60~ 0 0 6O{ 0 0 6O{ 0 0 6O{ 0 0 6O{ 0 0 6O{ 0 0 60( 0 0 600 0 0 6O0 0 0 6OO 0 0 6OO 0 0 600 0 0 60~ 0 0 600 0 0 60~ 0 0 60(3 0 0 60~ 0 0 60~ 0 0 6O{ 0 0 60~ 0 0 60C 0 1-23 shut in due to annular communication problem. 4-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. 4A-23 shut in for field study and evaluation per Doug Marshall. C24A- 14 ACT INJ INJ 0 2750 0 2750 0 2750 0 2750 0 2000 0 2000 0 1700 140 1600 306 1600 268 3450 258 3450 252 3450 235 3450 229 3500 234 3500 284 3500 498 4470 456 4470 433 4550 419 4550 410 4550 413 4550 376 4550 368 455O 252 3100 31 4100 449 4100 306 4100 392 4100 370 4100 352 4400 7,731 4,550 249 3,498 24 December-2001 C23-23 ACT DATE & NOTES INJ INJ ANNU 01-Dec-2001 02-Dec-200 ! 03-D¢c-2001 04-De¢-2001 05-Dec-200 ! 06-Dec-200 I 07-Dec-200 I 08-Dec-200 I 09-Dec-2001 I O-Dec-2001 1 l-Dec-200 ! 12-Dec-2001 13-Dec-2001 14-Dec-2001 ! 5-Dec-200 I 16-Dec-2001 ! 7-Dec-2001 18-Dec-2001 19-Dec-20Ol 20-Dec-200 I 2 l-Dec-2001 22-Dec-200 I 23-Dec-2001 24-Dec-200 I 25-Dec-2001 26-Dec-2001 27-Dec-2001 28-Dec-2001 29-Dec-2001 30-Dec-2001 31 -Dec-2001 TOTAL MAXIMUM AVERAGE # DAYS 2070 3425 2054 3425 2057 3425 2053 3425 2032 3425 2067 3425 205 ! 3425 2055 3425 2044 3425 2042 3440 2064 3440 1998 3450 266 3450 2323 3450 2103 3400 2092 3400 2120 3400 2097 3400 2091 3450 2067 3450 2072 3450 2046 3450 2073 3450 2059 3450 2027 3450 2076 3450 2049 3450 2058 3450 2038 3450 1922 3450 1837 3450 62,003 3,450 2,6O0 3,436 31 01/15/2002 WATER INjEcTION REPORT PLATFORM C C41-23 ACT INJ INJ ANN1 565 565 565 565 565 565 565 565 565 565 565 565 565 565 565 565 565 565 550 570 550 570 550 570 550 57~ 550 57C 550 57C 550 57( 550 57( 550 57( 550 57( 20 2( 1300 1800 95O 500 650 1800 1800 1800 1800 1800 1800 1,800 570 858 356 C24-23 ACT INJ INJ ANNU 370 3450 345~ 368 3450 345C 369 3450 345C 369 3450 345£ 366 3450 345C 373 3450 345C 371 3450 345{ 371 3450 345{ 367 3450 345f 371 3450 345( 376 3450 345( 369 3450 345( 62 1300 135{ 403 3500 3500 378 3450 3450 382 3450 3450 388 3450 3450 387 3450 345O C34-23 C23-26 384 3450 3450 381 3450 3450 2( 380 3450 3450 20 375 3450 3450 20 382 3450 345~ 20 379 3450 345~ 20 370 3450 345~ 20 381 3450 345~ 20 377 3450 345C 20 378 3450 345{ 20 374 3450 345{ 20 355 3450. 345( 20 362 3450 345( ACT INJ INJ ANNU ACT INJ INJ ANNU 11,318 3,500 3,50~ 365 3,382 3,384 C41-26 C44-14RD C24A-23 1538 3100 305C 1533 3100 305{ 1538 3100 305( 1537 3100 305( 1526 3100 305( 1549 3100 305( 1545 3100 305( 1550 3100 305( 1546 3100 305¢ 1548 3100 3050 1568 3100 3050 1543 3100 '3050 203 1550 1525 1651 3100 3050 1590 3100 3050 1582 3100 3050 1601 3100 3050 1593 3100 3050 1594 3100 3050 1583 3100 305~ 1586 3100 305~ 1570 3100 305C 1590 3100 305~ 1581 3100 305{ 1558 3100 305{ 1596 3100 305( 1573 3100 305( 1576 3100 305( 1565 3100 305( 1483 3100 305( 1437 3100 305( 47,033 3,100 3,050' 1,517 3,050 3,001 31 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 '0 0 0 '0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ACT INJ INJ ANNU 0 760 6OO 0 760 600 0 760 600 0 760 600 0 76O 6O0 0 750 60(3 0 750 6O0 0 750 6O0 0 750 6O~ 0 770 60~ 0 770 0 770 6OC 0 770 60~ 0 770 60f 0 770 6Of 0 770 60( 0 770 60( 0 770 60{ 0 780 600 0 785 600 0 790 600 0 785 600 0 785 600 0 765 600 0 780 6O~ 0 700 6O0 0 700 600 0 700 6O0 0 700 60~ 0 700 6O~ 0 700 60~ ACT INJ INJ ANNU 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55~ 0 0 55~ 0 0 55¢ 0 0 55C 0 0 55C 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 550 0 0 550 0 0 56O 0 0 570 0 0 0 790 600 0 575 · 0 0 755 6O0 0 0 553 .0 0 ACT INJ ' INJ ANNI 0 0 6O( 0 0 6O( 0 0 60C 0 0 0 0 6O( 0 0 595 0 0 59~ 0 0 59~ 0 0 595! 0 0 60O 0 0 6OO 0 0 6O0 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 59~ 0 0 59~ 0 0 59~ 0 0 5951 0 0 595 0 0 595 0 0 595 0 0 595 0 0 6OO 0 0 596 0 C24A-14 ANNE 318 4600 326 4600 323 4600 322 4600 319 4600 319 4450 323 4450 317 4450 266 4500 370 4600 319 4550 0 30O0 0 2600 349 4250 392 4500 372 4525 359 4525 248 4525 377 4550 351 4600 322 4600 305 4600 297 4600 310 4500 319 4500 324 4500 320 4500 312 4500 309 4500 304 4500 234 4500 9,326 4,600 301 4,415 29 C41-23 shut in due to annular communication problem. C34-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. C24A-23 shut in for field study and evaluatior~ per Doug Marshall. C23-23 November-2001 ACT DATE & NOTES INJ ][NJ ANNU 01-Nov-2001 02-Nov-200 I 03-Nov-200 ! 04-Nov-2001 05-Nov-2001 06-Nov-2001 07-Nov-2001 08-Nov-2001 09-Nov-200 I 10-Nov-2001 1 l-Nov-2001 ! 2-Nov-2001 13-Nov-2001 14-Nov-2001 15-Nov-200 ! 16-Nov-2001 ! 7-Nov-2001 18-Nov-2001 19-N0v-200 ! 20-Nov-2001 2 l-Nov-2001 22-Nov-2001 23-Nov-2001 24-Nov-200 I 25-Nov-2001 26-Nov-200 I 27-Nov-2001 28-Nov-2001 29-Nov-2001 30-Nov-2001 TOTAL MAXIMUM AVERAGE #DAYS 2004 3450 2032 3450 2019 3450 2022 3450 2029 3450 20 ! 43450 2010 3450 2028 3450 2012 3450 2035 3450 2079 3450 2075 3450 2114 3450 2093 3450 2104 3450 2117 3450 2098 3450 2096 3450 2 ! 023450 2100 3450 2081 3450 2103 3450 2115 3450 2129 3450 2142 3450 2116 3450 2034 3450 2096 3425 2069 3425 2067 3425 62,135 3,450 2,071 3,448 30 12/1212001 WATER INJECTION REPORT PLATFORM C C41-23 C24-23 C34-23 ACT ACT ACT INJ INJ ANNU INJ INJ ANNU IN~ INJ ANNU 0 555 555 0 555 555 0 555 555 0 555 555 0 555 555 0 555 555 0 555 55.~ 0 555 55~. 0 550 56{ 0 550 56~ 0 550 56( 0 560 56.' 0 560 565 0 560 565 0 560 565 371 3450 345C 377 3450 345C 375 3450 345( 374 3450 345( 374 3450 345( 374 3450 345( 370 3450 3450 373 3450 3450 365 3450 3450 365 3450 3450 370 3450 3450 366 3450 3450 372 3450 3450 365 3450 3450 366 3450 3450 1508 3100 3060 1523 3100 3060 1516 3100 3060 1522 3100 3060 1524 3100 3060 1516 3100 3060 1511 3100 3060 1526 3100 3060 1511 3100 3050 1510 3100 305{3 1532 3100 305(] 1527 3100 305(] 1543 3100 305(] 1528 3100 305(] 1532 3100 305(3 C23-26 ACT INJ INJ ANNU 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C41-26 ACT INJ INJ ANNU 0 745 59( 0 745 59( 0 745 59( 0 745 59( 0 745 59( 0 745 590 0 745 590 0 745 590 0 750 600 0 750 600 0 750 600 0 ~50 600 0 750 60O 0 0 750 600 0 750 600 C44-14RD ACT 1NJ INJ ANNU 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 55(] 0 0 55(] 0 0 55(3 0 0 55(3 0 0 55(3 0 0 55(3 0 0 55£ 0 0 55£ 0 0 55O C24A-23 ACT INJ INJ ANNU 0 0 60~ 0 0 60~ 0 0 60~ 0 0 60~ 0 0 60~ 0 0 60~ 0 0 60~ 0 0 60C 0 0 0 0 60~ 0 0 0 0 60~ 0 0 0 0 6O( 0 0 60~ C24A- 14 ACT INJ ][NJ ANNt 337 4500 335 4500 337 4500 343 4500 341 4500 334 4500 320 4500 313 4500 301 4450 307 4450 309 4450 305 4425 306 4425 292 4425 292 4400 0 560 565 0 560 565 0 560 565 0 560 565 0 56O 565 0 56O 565 0 565 565 0 565 565 0 565 565 0 565 565 0 570 57£ 0 570 57(3 0 565 0 565 56.~ 0 565 56*. 0 570 57£ 0 560 562 0 370 3450 3450 365 3450 3450 369 3450 345(] 367 3450 345(] 367 3450 345(3 362 3450 345(3 366 3450 345C 369 3450 345C 369 3450 345( 370 3450 345{ 367 3450 345( 364 3450 345( 373 3450 3450 368 3450 3450 369 3450 3450 11,072 3,450 3,450 369 3,450 3,450 30 1541 3100 305C 1527 3100 305( 1533 3100 305{ 1531 3100 1523 3100 305( 1515 3100 305( 1529 3100 1533 3100 306{ 1541 3100 3060 1549 3100 3060 1532 3100 3060 1501 3100 3060 1547 3100 3050 1532 3100 3050 1537 3100 3050 45,800 3,100 3,060 1,527 3,100 3,055 30 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 750 60~ 0 750 60~ 0 750 60~ 0 750 6O~ 0 75O 0 750 60(3 0 76O 60~ 0 76O 6OC 0 7~ 0 7~ 0 7~ 0 7~ 0 7~ 0 7~ 0 7~ 0 760 600 0 752 '597 0 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 550 0 0 550 0 0 5~ 0 0 57(] 0 0 575 0 0 553 0 0 0 60( 0 0 .600 0 0 6OO 0 0 6OO 0 0 600 0 0 6OO 0 0 60O 0 0 60O 0 0 600 0 0 60~ 0 0 60~ 0 0 60~ 0 0 600 0 0 60~ 0 0 60~ 0 0 60~ 0 0 60(] 0 301 4400 297 4400 308 4400 310 4400 310 4400 · 308 4450 310 4475 309 4475 310 4475 309 4475 301 4450 273 4450 339 4600 324 4600 321 4600 9,402 4,600 313 4,469 30 241-23 shut in due to annular communication problem. 234-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received fi'om Mr. WondzcH on 12/14/99. 224A-23 shut in for field study and evaluation per Dong Marshall. October~2001 01-Oct-2001 02-Oct-2001 03-Oct-2001 04-Oct-200 ! 05-Oct-2001 06-Oct-200 ! 07-Oct-2001 08-Oct-2001 09-Oct-2001 10-Oct-2001 1 l-Oct-2001 12-Oct-2001 13-Oct-2001 14-Oct-2001 15-Oct-2001 16-Oct-2001 17-Oct-2001 18-Oct-2001 19-Oct-2001 20-Oct-2001 21-Oct-2001 22-Oct-2001 23-Oct-2001 24-Oct-2001 25-Oct-2001 26-Oct-2001 27-Oct-2001 28-Oct-2001 29-Oct-2001 30-0ct-200 ! 3 l-Oct-2001 TOTAL MAXIMUM AVERAGE # DAYS C23-23 ACT . INJ INJ ANNU 2077 3400 2084 3400 2082 . 3400 2071 3400 1290 3400 783 3400 2254 3400 2128 3400 2056 3400 1906 3400 0 34O0 762 3350 0 3350 2189 3350 2126 3400 2089 3400 1992 3400 1942 3400 1952 3400 1336 3400 2020 3400 200! 3400 2009 3400 2003 3400 2011 3400 2010 3400 ! 94434OO 2029 3400 1963 3450 1963 3450 2007 3450 55,079 3,450 1,777 3,400 29 WATER INJECTION REPORT PLATFORM C C41-23 [ C24-23 ACT ACT INJ INJ ANNU INJ INJ ANNU C34-23 ACT INJ ' ]]qJ A~NU C23-26 [ C41-26 ACT ACT INS INJ ANNU INS INJ ANNU 735 550 735 550 735 550 735 550 735 550 735 550 735 55O 735 550 735 550 735 550 735 550 C24A-14 0 550 56~ 0 550 56~ 0 560 56~ 0 560 56~ 0 560 56~ 0 56O 56~ 0 56O 56~ 0 560 56~ 0 560 56~ 0 560 56~ 0 560 56~ 0 550 56~ 0 550 56~ 0 550 56~ 0 570 57f 0 570 57( 0 570 57C 0 570 57C 0 570 57( 0 570 570 0 570 571 0 570 57 0 570 570 0 570 570 0 570 570 0 570 570 0 570 570 0 570 570 0 570 570 0 570 570 0 555 555 381 3450 3460 388 3450 ~ff~ 384 3450 380 3450 3460 236 3450 3460 150 3450 3450 390 3450 3450 381 3450 3450 370 3450 3450 349 3450 3450 0 3450 3450 150 3450 3450 0 '3450 3450 399 3450 3450 398 3450 3450 397 3450 3450 388 '3450 3450 378 345O 3450 384 3450 3450 261 3450 345~ 383 345O 3450 377 3450 345~ 379 3450 3450 373 3450 345( 373 3450 3450 380 3450 345( 371 3450 345( 389 3450 345( 374 3450 345£ 372 3450 345( 375 3450 345( 1521 3150 3150 1545 3150 3150 1542 3150 3125 1530 3150 3125 955 3150 3125 540 3100 3050 1579 3100 3050 1556 3100 3050 1521 3100 3050 1430 3100 3050 0 3100 3050 517 3000 300~ 0 3000 300~ 1572 3000 300~ 1565 3100 305~ 1556 3100 305( 1513 3100 305~ 1490 3100 305¢ 1490 3100 305( 1019 3100 305( 1500 3100 305( 1530 3100 305( 1538 3100 305( 1530 3100 305( 1531 3100 305.s 1534 3100 305.~ 1504 3100 305.~ 1568 31 00 305.' 1508 3100 306( 1496 3100 306( 1518 3100 3060 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O' 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 730 550 0 730 550 0 730 550 0 730 56~ 0 730 56~ 0 730 56~ 0 730 56~ 0 730 56~ 0 730 56~ 0 730 0 730 56~ 0 730 56~ 0 730 56~ 0 745 575 0 745 572 0 745 572 0 745 59( 0 745 59( 0 745 59( 0 745 59( 0 745 59~ 0 735 561 0 C~14~ ACT ACT ~J ~J ~NU ~J ~NL ~I ~J 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 550 0 0 5512 0 0 550 0 0 550 0 0 550 10,310 3,450 3,4612 333 3,450 3,452 29 0 570 570 0 563 565 0 41,198 3,150 3,150 1,329 3,098 3,060 29 0 0 0 0 0 0 0 550 0 0 550 0 0 55( 0 0 55( 0 0 55£ o 0 5501 0 0 550: 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 550 0 0 550 0 0 560 0 0 570 I C24A-23 ACT 0 0 598 0 0 598 0 0 60( 0 0 60( o o 0 0 0 0 6OO 0 0 6OO 0 0 60O 0 0 600 0 0 6O0 0 0 6OO 0 0 60O 0 0 6OO 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 60~ 0 0 60~ 0 0 60~ 0 0 60( 0 0 60f 0 0 0 0 60( 0 0 60~ 0 0 598 0 11113/2001 241-23 shut in due to annular communication problem. 234-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. 224A-23 shut in for field study and evaluation per Dong Marshall. 0 0 575 0 0 553 0 248 4450 145 4450 72 2575 12 433 2575 120 240 2575 120 86 4300 10 442 4300 10 385 4300 10 387 4450 10 342 4450 10 0 4450 !0 0 2400 140 0 2400 140 269 2000 230 500 4450 439 4450 409 4450 353 4450 340 4450 228 4450 0 445O 446 4450 385 4450 370 4450 351 4500 340 4500 330 4500 345 4500 330 4500 333 4500 340 4500 8,888 4,500 23( 287 4,054 3{ 27 WATER INJECTION REPORT PLATFORM C C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 C24A- 14 ACT ACT ACT ACT ACT ACT ACT ACT INJ INJ ANNU [NJ [NJ ANNU INJ [NJ ANNU INJ INJ ANNU [NJ [NJ ANNU INJ INJ ANNU INJ [NJ ANNU INJ [NJ ANNL September-2001 01.SeP_2001 02-Sep-2001 03-$ep-2001 04-Sep-2001 05-Sep-2001 06-Sep-2001 07-Sep-2001 08-8ep-2001 09-Sep-2001 10-Sep-2001 I l-Sep-2001 12-Sep-2001 13-Sep-2001 14-Sep-2001 15-Sep-2001 16-Sep-2001 17-Sep-2001 ! 8-Sep-2001 19-Sep-2001 20-Sep-2001 21-Sep-2001 22-Sep-2001 23-Sep-2001 24-Sep-2001 25-Sep-2001 26-Sep-2001 27-Sep-2001 28-Sep-2001 29-Sep-2001 30-Sep-2001 TOTAL MAXIMUM AVERAGE # DAYS 10115/2001 C23-23 ACT ][NJ [NJ ANNU 2179 3400 1627 3400 2262 3400 2199 3400 2223 3400 2228 3400 2247 3400 2253 3400 2260 3400 2264 3400 2264 3400 2264 3400 2251 3400 2284 3400 2256 3400 2251 3400 2252 3400 2181 3400 2146 3400 2171 3400 2163 3400 2184 3400 2189 3400 2177 3400 2191 3400 2187 3400 2196 3400 2172 3400 2146 3400 2138 3400 65,805 3,400 2,194 3,400 30 0 500 530 0 500 530 0 500 540 0 500 54O 0 500 540 0 500 540 0 550 540 0 500 540 0 54O 550 0 540 500 0 540 550 0 540 550 0 550 550 0 550 550 0 550 550 0 550 550 0 550 550 0 550 550 0 550 550 0 550 550 0 550 550 0 550 550 0 550 550 0 550 550 0 550 550 0 550 55O 0 550 560 0 550 560 0 550 560 0 550 560 550 560 537 546 374 3400 3450 292 3400 3450 377 3400 345~ 366 3400 3450 372 3400 3450 372 3400 3450 375 3400 3450 374 3475 3450 374 3475 3450 371 3450 3450 371 3450 3475 370 3450 3475 370 3450 3425 376 3450 3450 373 3450 3450 373 3450 3475 374 3450 3475 373 3450 3475 377 3450 3475 372 3450 3450 371 3450 3450 372 3450 3450 372 3450 3450 372 3450 3450 375 3450 3450 372 3450 345~ 380 3450 3460 376 3450 346C 380 3450 346C 376 3450 346C 11,122 3,475 3,475 371 3,440 3,456 30 1567 2850 310( 1185 :'~850 310( 1582 2850 310( 1553 2850 310( 1566 2800 310( 1560 2850 310( 1567 2800 310( 1563 2850 310( 1562 2850 310( 1556 2850 310( 1549 2850 310( 1545 2850 310( 1537 2850 310C 1561 2830 310( 1553 2850 310( 1551 2850 3!0( 1552 2850 3i0( 1534 2850 310( 1552 2850 31o~ 1531 2850 3 ! 1528 .2850 31~ 1528 2850 3:1 1530 3100 31°° 1520 3100 ' 3100 1528 3100' 3i00 1518 3150 3100 1537 3150 3~50 1530 3150 3150 1543 3150 3150 1523 3150 3150 46,011 3,150 3,150 1,534 2,922 3,107 30 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 .0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 .0 0 0 710 510 0 710 510 0 710 550 0 710 550 0 710 550 0 710 550 0 710 550 0 735 550 0 710 550 0 710 550 0 710 550 0 710 550 0 715 550 0 770 550 0 770 550 0 770 550 0 770 55~ 0 770 55~ 0 770 55~ 0 770 55~ 0 770 0 770 55C 0 770 55C 0 770 55~ 0 770 55¢ 0 770 55£ 0 735 55C 0 735 55£ 0 735 55£ 0 735 55£ 0 770 550 0 740 54'/ 0 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 550 0 0 550 0 0 560 0 0 57O 0 0 575 0 0 553 0 0 75 585 0 75 585 0 0 585 0 0 585 0 0 585 0 0 570 0 0 585 0 0 585 0 0 585 0 0 585 0 0 585 0 0 585 0 0 590 0 0 590 0 0 580 0 0 585 0 0 585 0 0 58~ 0 0 580 0 0 59~ 0 0 59(3 0 0 59~ 0 0 595 0 0 595 0 0 595 0 0 599 0 0 599 0 0 599 0 0 599 o o 0 75 598 0 5 588 0 C41~23~shut in due to annular communication problem. , C34-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. C24A-23 shut in for field study and evaluation per Doug Marshal]. 370 4500 339 4500 335 4500 337 4500 344 4450 346 4450 341 4450 337 4400 339 4400 341 4400 347 4400 343 4400 326 4400 335 4400 345 4400 360 4400 361 4400 337 4450 352 4450 339 4450 340 4450 348 4450 350 4450 342 4450 342 4450 338 4450 331 4450 335 4450 339 4450 342 4450 10,281 4,500 343 4,440 30 August-2001 0 l-Aug-2001 02-Aug-2001 03-Aug-2001 04-Aug-2001 05-Aug-2001 06-Aug-2001 07-Aug-2001 08-Au8-2001 09-Aug-2001 10-Aug-2001 11 -Aug-200 ! 12-Aug-2001 13-Aug-2001 14-Aug-2001 15-Aug-2001 16-Aug-2001 17-Aug-2001 ! 8-Aug-2001 19-Aug-2001 20-Aug-2001 21-Aug-2001 22-Aug-2001 23-Aug-2001 24-Aug-2001 25-Aug-2001 26-Aug-2001 27-Aug-2001 28-Aug-2001 29-Aug-200 ! 30-Aug-2001 3 ! -Au~-2001 TOTAL MAXIMUM AVERAGE # DAYS 09/12/2001 WATER INJECTION REPORT PLATFORM C C23-23 C41-23 C24-23 C34-23 ACT ACT ACT ACT INJ INJ ANNU INJ INJ ANNU 1NJ 1NJ ANNU INJ INJ ANNU! 2275 3400 2276 3400 2283 3425 2277 3400 2268 3400 2274 3400 2269 3400 2258 3400 2299 3400 2324 3400 2334 3400 2334 34OO 2352 3400 2341 3400 2332 3400 1640 3400 2300 3425. 2267 3425 2269 3425 2240 3425 2244 3400 1939 3400 2195 3400 2192 3400 2205 3400 2181 3400 2210 3400 2176 3400 2189 3400. 2195 3400 2133 3400 69,071 3,425 2,228 3,404 31 0 490 490 0 500 510 0 500 510 0 500 500 0 500 510 0 500 510 0 500 510 0 500 510 0 500 510 0 500 510 0 500 51(3 0 500 510 0 500 510 0 500 51{3 0 500 510 0 500 51(3 0 5O0 470 0 500 470 0 500 470 0 5OO 470 0 5OO 47( 387 3450 345~ 388 3450 3450 389 3450 345C 388 3450 345( 386 3450 3450 389 3450 345( 391 3450 345( 391 3450 345( 390 3450 345£ 389 3450 345( 391 3450 345( 390 3450 345( 390 3450 345( 390 3450 345( 389 3450 345~ 286 3450 34501 385 3475 3475 381 3475 3475 381 3450 3450 377 3450 3450 380 3450 3450 1569 2800 3100 1566 3500 3100 1564 3500 3100 1559 3500 3100 1554 3500 3100 1556 3500 3100 1554 3500 3100 1555 2900 3100 1556 2900 3100 1549 2900 3100 1553 2900 3100 t552 2900 3100 1549 2900 3100 1545 2900 3100 1540 2900 3100 1132 2900 3100 1602 2900 3100 1582 2900 3100 1576 2850 3100 1557 2850 310~ 1556 2850 310~ C23-26 ACT INJ INJ ANNU 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C41-26 ACT INJ INJ. ANNU 0 495 30( 0 650 49~ 0 650 50( 0 660 50( 0 660 50( 0 660 50( 0 660 50( 0 670 50( 0 670 50( 0 670 50( C44-14RD ACT INJ INJ ANNU 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 550 0 0 550 0 0 550 0 0 550 C24A-23 ACT RqJ INj ANNU 0 505 54~ 0 505 54~ 0 490 545 0 450 550 0 425 5512 0 400 550 0 375 55C 0 350 555 0 35O 555 0 350 555 C24A-14 ACT INJ INJ ANNL 368 4500 246 4500 395 4550 375 4550 372 4500 370 4500 370 4500 359 4500 357 4500 · 334 4500 0 670 50( 0 670 5~ 0 670 5 0 670 500 0 670 500 0 670 500 0 690 500 0 690 500 0 690 500 0 690 500 0 690 500 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 325 56( 0 325 56( 0 325 56( 0 325 56( 0 325 56( 0 325 56( 0 250 53( 0 250 53( 0 200 57{ 0 200 57( 0 175 570 362 4500 363 4500 362 4500 365 4500 361 4500 367 4500 359 4550 361 4550 357 4525 367 4525 351 4525 0 500 470 0 500 47£ 0 500 47( 0 500 47( 0 500 47( 0 500 47( 0 500 471 0 500 47 o 500 530 0 550 530 0 550 530 0 501 494 0 309 3450 3450 322 3450 3450 322 3450 3450 324 3450 3450 329 3450 3450 351 3450 3450 348 3450 3450 351 3450 3450 351 3450 34512 356 3400 3450 11,391 3,475 3,475 367 3,450 3,452 1389 2850 310~ 1560 2850 310~ 1558 2850 310~ 1562 2850 310~ 1546 2850 310( 1556 2850 310( 1538 2850 310~ 1533 2850 310( 1533 2850 310( 1509 2850 310( 47,610 3,500 3,10~ 1,536 2,992 3,10~ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 690 500 690 500 690 50(1 690 500 690 50~ 690 50~ 690 50~ 690 50(] 710 55(~ 710 550 0 710 550 0 673 496 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 5512 0 0 5512 0 0 56~ 0 0 570 0 0 55C 0 0 575 0 0 552 0 175 570 0 175 570 0 175 570 0 125 580 0 125 580 0 125 580 0 125 580 0 75 582 0 75 582 0 75 585 505 585 273 561 273 4525 0 4525 356 4525 383 4525 362 4525 362 4525 363 4525 364 4450 349 4450 356 4450 10,689 4,550 15 345 4,510 1 30 C41-23 shut in due to annular communication problem. C34-23 hns developed an annular communication problem. AOGCC notif~l on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/1.4/99. C24A-23 shut in for field study and evaluation per Doug Marshall. July-2001 01-Jul-2001 02-Jul-2001 03-Jul-2001 04-Jul-2001 05-~ul-2001 06-Jul-2001 07-Jul-2001 08-Jul-2001 09-Jul-2001 10-Jul-2001 I 1 -Jul-2001 12-~ul-2001 13-Jul-2001 14-Jul-2001 15-Jul-2001 16-Jul-2001 17-]ul-2001 18-Jul-2001 ! 9-Jul-2001 20-Jul-2001 21-Jul-2001 22-Jul-2001 23-Jul-2001 24-Jul-2001 25-Jul-2001 26qul-2001 27-Jul-2001 28-Jui-2001 29-Jul-2001 30-Jul-2001 31-Jul-2001 TOTAL MAXIMUM AVERAGE # DAYS i c23-23 ACT INJ 1NJ ANNU 2383 3400 2383 3400 2391 3400 2382 3400 2371 3400. 2365 34OO 2364 3400' 2264 3400 2373 3400 2362 3400 2291 3400 2319 3400 2347 3400 2339 3400 2341 3400 2352 3400 2369 3400 2352 3400 2355 3400 1987 3400 2305 3400 2291 3400 2292 3400 2297 3400 WATER INJECTION REPORT PLATFORM C C34-23 C41-23 C24-23 C23-26 ACT ACT ACT ACT INJ INJ ANNU IN~ INJ ANNU INJ INJ ANNU INJ INJ ANNU 370 3450 345( 368 3450 345( 367 3400 340( 368 3400 340( 370 3400 340( 365 3450 3450 365 3450 3450 361 3450 3450 376 3450 3450 373 3450 3450 319 3450 3450 343 3450 3450 345 3450 3450 346 3450 3450 348 3450 3450 354 3450 3450 362 3450 3450 363 3450 3450 · 3673475 3475 338 3475 3475 0 450 44~ 0 450 44(: 0 450 44(] 0 450 44~ 0 470 0 480 47(~ 0 480 47~ · 0 480 47(~ 0 490 0 490 47-~ 0 490 48C 0 490 48C 0 490 48( 0 490 48C 0 490 48( 0 490 48( 0 490 48( 0 490 48C 0 490 49( 0 490 49( 1551 2900 3100 1570 29O0 310~ 1572 2800 3100 1566 2800 310~ 1561 2800 310~ 1558 2800 310~ 1563 280O 310~ 1512 2750 310~ 1610 2800 310{3 1602 2850 310~ 1556 2800 310~ 1568 2800 310G 1576 2800 310~ 1568 2800 310~ 1570 2800 310~ 1573 2800 310~ 1581 2800 310( 1567 2800 310~ 1575 2800 310( 1349 2800 310( 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 CAI-26 ACT 1NJ INJ ANNU 0 130 50 0 130 50 0 130 50 0 130 50 0 430 250 0 0 450 250 0 0 450 250 0 0 470 250 0 0 480 300 0 0 490 300 0 495 300 0 495 300 0 495 30~ 0 495 300 0 495 30(] 0 495 30~ 0' 495 30~ 0 495 30~ O. 495 0 495 30~ 2343 3400 2332 3400 2322 3400 2313 34OO 2318 34OO 2124 3400 2294 34O0 71,921 3,400 2,320 3,400 31 4~0 4~0 490 4~0 4~0 4~0 490 490 490 490 490 4~0 490 490 490 4~0 490 490 490 490 490 490 390 3450 3450 385 3450 3450 385 3450 3450 386 3450 3450 392 3450 345~ 392 3450 345G 390 3475 3475 390 3475 3475 391 3475 3475 372 3500 350~ 390 3500 350( 0 0 490 490 0 0 483 477 0 !1,431 3,500 3,500 369 3,452 3,452 31 1588 2800 310( 1573 2850 310( 1569 2850 310( 1566 2800 310( 1587 2800 310( 1576 2850 310( 1569 2850 310~ 1559 2850 3100 1567 2850 3100 1466 2800 3100 1587 2800 3100 48,355 2,900 3,100 !,560 2,816 3,100 31 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 495 30( 0 495 30( 0 495 30~ 0 495 30( 0 495 30( 0 495 30( 0 495 30( 0 495 30( 0 495 30( 0 495 30( 0 495 30( 0 495 3O( 0 441 261 0 08/14/2001 C41-23 shut in due to annular communication problem. C34--23 has developed an annular communica~m problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. C24A-23 shut in for field study and evaluation per Doug Marshall C44-14RD C24A-23 ACT ACT 1NJ INJ ANNU INJ INJ ANN~ 0 0 550 0 0 550 0 0 550 0 0 55C 0 0 550 0 0 575 0 0 55G 0 0 0 0 55G 0 0 55(3 0 0 55¢ 0 0 55~ 0 0 55C 0 0 55C 0 O' 55( 0 0 550I 0 0 550 0 0 550 0 0 55O 0 0 550 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 550 0 0 550 0 0 560 0 0 570 0 0 575 0 0 553 0 0 2150 39.~ 0 2000 41( 0 1850 42.~ 0 1750 43( 0 1750 48( 0 1600 45( 0 1600 455] 0 1500 460 0 1350 465! 0 1300 475 0 1300 475 0 !150 485 0 1125 490 0 1075 495 0 1025 495 0 975 500 0 .950 505 0 950 505 0 900 500 0 900 50~ 0 810 525 0 760 52G 0 740 52G 0 740 52G 0 740 52G 0 675 525 0 650 53G 0 625 53~ 0 575 535 0 575 535 0 575 53~ 0 2,150 535 0 !,118 49~ 0 C24A-14 ACT INJ ][NJ. ANNU 360 4500 352 4500 348 4500 355 4525 347 4600 339 4500 343 4500 341 4550 337 455O 376 4550 364 4500 365 4500 340 4500 335 4500 353 4500 338 4500 389 4500 369 4500 361 4550 367 4550 360 4550 362 4550 360 4550 363 4550 377 4550 365 4500 367 4475 372 4500 369 4500 354 4500 375 4500 11,103 4,600 358 4,519 31 June-2001 01-Sun-2001 02-Jun-2001 03-Jun-2001 04-Jun-2001 05-Jun-2001 06-Jun-2001 07-$un-2001 08-Jun-2001 09-Jun-2001 lO-Jun-2001 ! l-Jun-2001 12-Jun-2001 13-Jun-2001 14-Jun-2001 15-Jun-2001 16-Jun-2001 17-Jun-2001 18-Jun-2001 19-Jun-2001 20-Jun-2001 21-Jun-2001 22-Jun-2001 23-Jun-2001 24-Jun-2001 25-Jun-2001 26-Jun-200 ! 27-Jun-2001 28-Jun-2001 29-Jun-2001 30-Jun-2001 TOTAL MAXIMUM AVERAGE # DAYS 07/10/2001 WATER INJECTION REPORT PLATFORM C C23-23 AC~ . INJ INJ ANNU 345 3475 352 3475 343 3475 340 3500 333 3500 886 3500 1596 340O 1574 3400 1912 3400 2029 3400 2363 34OO 257O 3400 2872 3400 2746 3400 2708 3400 2727 3400 2749 3400 323 1850 718 3375 2633 3375 2569 3375 2502 3375 2451 3375 2476 34O0 2399 3400 1972 2900 1789 3250 2099 3250 2439 3400 2407 3375 55,222 3,500 1,841 3,334 30 C41-23 ACT INJ INJ ANNI 0 425 43C 0 425 43~ 0 425 43~ 0 425 43C 0 425 43C 0 425 43C 0 450 42~ 0 420 42¢ 0 460 42~ 0 460 42q 0 425 422 0 425 43~ 0 430 43C 0 430 43C 0 430 43¢ 0 430 43C 0 430 43( 0 430 43( 0 430 43( 0 430 43( 0 450 44( 0 450 44( 0 45O 44( 0 450 44( 0 450 44( 0 450 44( 0 450 44( 0 450 ~ 0 450 0 450 440 0 46O 44O 0 438 432 0 C24-23 ACT INJ INJ ANNU 394 3500 3500 395 3500 3500 395 3500 3500 393 3500 35O0 391 3500 3500 368 35O0 35O0 390 3500 3500 388 3500 3500 386 35OO 3500 389 3500 3500 384 3500 3500 385 3500. 3500 380 3500 3500 376 3500 3500 369 3500 3500 367 3500. 3500 372 3500 3500 220 3475 3475 0 3475 3475 380 3450 345(1 372 3450 3450 407 34OO 3400 393 3400 3400 386 3400 3400 385 2800 280~ 277 3300 330G 325 3300 3300 372 3450 3450 371 3400 340~ 10,454 3,500 3,500 348 3,373 3,373 29 C34-23 ACT INJ HqJ ANNU 1923 3400 340C 1943' 3400 340~ 1941 3400 340C 1932 34O0 340C 1922 3400 340C 1466 3400 340~ 1814 3200 320~ 1703 3100 310( 1623 3100 310~ 1601 3150 315C 1588 3100 310~ 1590 3125 312-~ 1568 3125 3125 1572 3125 3123 1575 3125 3123 · 15863125 3123 1595 3125 312~ 189 I400 140( 755 3100 310( 1586 3100 310( 1585 3100 3100 1562 3100 310~ 1551 3100 3100 1573 3100 3100 1566 3100 3100 1302 2800 2750 ! 142 3000 3000 1361 2900 2900 1604 2900 3100 1593 2900 3100 46,311 3,400 3,400 1,544 3,080 3,O92 30 C23-26 ACT ~J ~J ANNU 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 '0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C41-26 ACT INJ INJ ANNU 0 7O 0 7O 0 70 6~ 0 7O 0 70 6(] 0 70 6(1 0 125 50 0 110 5G 0 80 50 0 7O 5~ 0 70 5C 0 70 50 0 70 5G 0 70 5(~ 0 70 5G 0 70 50 0 70 5~ 0 70 5C 0 70 5(~ 0 70 0 130 5C 0 130 0, 130 0 130 SC 0 130 5~ 0 130 0 130 5C 0 130 5C 0 130 5C 0 130 0 130 6~ 0 94 52 0 C44-14RD ACT INJ INJ ANNU 550 550 550 550 550 575 550 550 550 55O 550 550 550 550 550 550 550 550 550 550 550 550 550 550 550 575 550 550 560 570 0 0 575 0 0 553 0 C24A~23 ACT INJ ~J ANN 251 4550 23 253 4550 25 249 4550 23 246 4600 3( 256 4600 3C 196 4600 3C 246 4500 3{ 258 4600 3C 262 4600 3C 262 4550 33 246 4550 3~ 253 455O 33 219 4550 3~ 236 4550 3~ 228 4550 3~ 211 4550 3f 2O5 455O 3~ 132 4200 9( 62 3300 9( 61 3300 9( 72 3450 230 100 3400 2351 117 34oo 270 114 3450 260 138 3450 260 238 4200 90 189 4200 80 0 3050 250 0 2600 338 0 2300 375 5,300 4,600 375 177 4,062 107 27 C24A-14 ACT INJ INJ ANNL 357 4575 358 4575 358 4575 366 46OO 371 460O 280 4600 378 4500 368 460O 352 4600 · 354 4600 350 4600 353 4600 318 4600 350 4600 338 460O 317 4600 346 46OO 304 4275 122 3300 122 3300 151 3500 160 3500 155 3500 178 350O 181 3500 381 4250 330 4300 419 4500 405 4550 364 44OO 9,186 4,600 306 4,280 3O ~41-23 shut in due to nnnular communication problem. '.34--23 has developed an annular communica~on problem. AC)GCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. May-2001 OI-May-2001 02-May-2001 03-May-2001 04-May-2001 05-May-2001 06-May-200 ! 07-May-2001 08-May-2001 09-May-2001 lO-May-2001 1 l-May-2001 12-May-2001 13-May-2001 14-May-2001 15-May-2001 16-May-2001 17-May-2001 18-May-2001 19-May-2001 20-M. ay-2001 21 -May-200 ! 22-May-2001 23-May-2001 24--May-2001 25-May-2001 26-May-2001 27-May-2001 28-May-2001 29-May-2001 30-May-2001 31 -Ma~'-2001 TOTAL MAXIMUM AVERAGE # DAYS C23-23 ACT ~J ~J ANNU 1380 3400 930 34OO 738 3450 650 3400 596 3400 557 3400 534 3400 197 3400 0 2800 130 2600 704 3400 529 3450 480 3450 448 3450 436 3450 298 3400 416 3400 381 3400 365 3400 356 3400 363 3450 367 3400 556 3400 449 3450 401 3450 383 3450 373 3450 363 3450 364 3450 366 3450 359 3475 14.469 3.475 467 3.378 3O WATER INJECTION REPORT PLATFORM C 0 450 45~ <0 450 45C 0 450 45~ · ~0 450 45( :0 450 45( 0 450 45£ 0 45O 45C '0 450 45( 0 450 45( 5( 0 480 44~ 0 · 485 44~ 0 450 43.~ 0 475 43.~ 0 475 435 0 . 450 43.~ 0 435 43.~ 0 435 43.~ 0 435 435I 0 435 435' 0 435 435 0 0 425 430 0 0 435 435 0 435 435 0 400 425 0 400 425 0 425 430 0 425 430 0 425 430 0 425 430 0 425 430 0 425 430 C41r23 (234-23 C23-26 C41-26 C44-14RD C24A-23 ACT ACT ACT ACT ACT ACT ACT INJ INS ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU IHS INJ ANNU INJ INJ ANNU 377 34503450 0 485 450 0 441 438 0 384 3450 345O 377 3450 3450 378 3450 3450 378 3450 3450 375 3450 3450 380 3450 3450 146 3450 3450 0 1450 1450 51 1375 1375 410 3400 3400 1836 3350 335( 1874 3350 3350 1849 3350 3350 1853 3350 335~ 1852 3350 335£ 1843 3350 335~ 1857 3350 3350 713 3350 335£ 0 1500 150( 197 1475 1475 1977 3475 330( 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 50 50 0 50 5~ 0 50 5C 0 50 50 0 50 50 0 50 50 0 50 5C 0 50 50 0 50 50 0 50 5~ 0 50 5~ 0 0 550 0 .0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 550 0 0 550 0 0 55O 0 0 550 0 0 550 401 3450 3450 399 3450 345~ 392 3450 3450 402 3450 3450 266 3450 345~ 395 3450 345~ 388 3450 345C 383 3450 3450 380 3450 3450 389 3450 345( 382 3450 3450 383 3450 345( 395 3450 345( 391 3450 345( 391 3450 345( 389 3450 345( 389 3450 345( 393 3450 345( 399 345O 3450 396 3500 3500 10.959 3.500 3.500 354 3.319 3.319 30 1953 3500 332~ 1937 3500 335( 1903 3500 335( 1966 3500 335( 1247 3300 330( 1940 3300 330( 1880 3300 330( 1835 3300 330( 1819 3300 3300 1842 3350 3350 1799 3300 3300 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 50 5C 0 50 5( 0 50 50 0 60 5C 0 6O 5C 0 60 5( 0 60 5( 0 60 5( 0 60 5( 0 70 5( 0 6O 5( 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 .0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 1814 3300 33O0 1873 3350 3350 1854 3350 3350 1857 3350 3350 i843 3350 3350 1842 3350 335O 1857 3350 3350 1932 3350 3350 1945 3400 3400 52,789 3,500 3,400 1,703 3,244 3,218 3O ~0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 60 5( 0 7O 6( 0 70 60 0 70 6O 0 7O 6O 0 7O 6O 0 70 6O 0 7O 6O 0 7O 6O 0 7O 6O 0 58 53 0 0 0 550 0 0 550 0 0 55O 0 0 575 0 0 550 0 0 55C 0 0 56~ 0 0 570 0 0 56~ 0 0 575 0 0 553 0 167 4500 15 142 4500 15 193 4500 15 221 4550 15 161 4550 180 4550 15 173 4550 15 190 4550 15 115 4300 3C 178 4500 2C 160 4500 2C 171 4525 170 4500 162 4500 170 4500 92 3900 2( 128 45OO 2( 136 4550 134 4600 105 4400 218 4525 25 127 44O0 18 162 4400 18 174 4425 25 180 4425 25 176 4450 25 194 4500 25 218 4525 25 238 4550· 25 219 4550 25 221 4550 25 5.275 4.600 30 170 4,478 20 31 06/13/2001 241-23 shut in due to annular cemmunication problem. 234-23 has developed an annular communication problem. AOG-CC notified on 12/12/99. Verbnl approvnl to continue to inject received from Mr. Wondzell on 12/14/99. C24A- 14. ACT INJ INJ' ANN[ 370 4575 249 4575 399 4550 399 4575 332 4575 368 4575 371 4575 401 4575 209 4350 379 460O 398 4600 402 4600 395 4575 362 4575 218 4000 424 4500 377 4600 337 , 4450 363 4575 368 4450 354 4450 352 4500 353 45OO 369 4500 385 4550 363 4575 361 4600 359 4600 365 4575 11,186 4,600 361 4,527 31 April-2001 01-A 02-A 03-A 04-A 05-A 06-A 07-A 08-A 09-A 10-A 1 I-A 12-A 13-A 14-A I5-A 16-A 17-A I$-A 19-A 20-A 21-A 22-A 23-A 24-A 25-A 26-A 27-A 28-A 29-A 30-^ )r-2901 )r-2901 )r-2901 )r-2901 C23-23 TOTAL ACT INJ INJ ANNU MAXIMUM AVERAGE #DAYS WATER INJECTION REPORT PLATFORM C 0 88O 160~ 0 880 160(3 0 940 160(3 0 940 !60(3 0 480 160(3 0 35O 160~ 0 290 185 0 290 18 0 290 1 0 290 185 0 290 1 0 0 0 0 0 0 C41-23 0 0 0 0 o o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 172 2800 172 2,800 1,600 6 291 351 I ACT INJ INJ ANNU 0 590 49~ 0 500 49(3 0 590 49~ 0 590 49(3 0 500 49~ 0 500 49~ 0 500 49~ 0 590 4~ 0 590 49~ 0 590 49~ 0 ~ 4~ 0 4~ 475 0 4~ 47~ 0 4~ 47~ 0 490 47C 0 490 47( 0 490 47C 0 490 47( 0 490 47( 0 490 47( 0 490 47( 0 490 47( 0 490 470 0 490 470 0 490 470 0 450 450 0 450 450 0 450 450 0 450 450 0 450 450 C24-23 ACT l~J INJ ANNU 374 3450 345( 392 3450 3450 396 3450 3450 390 3450 3450 388 3450 3450 387 3450 3450 384 3450 3450 385- 3450 3450 386 3450 345O 384 3450 3450 382 3450 3450 388 3590 3450 387 3590 3450 391 3590 3450 394 3590 3450 396 3590 345O 393 3590 3450 395 3590 3475 394 3590 3475 392 3590 3475 390 3590 3475 389 3590 3475 385 3590 3475 383 3500 3475 379 3500 3475 382 3450 3450 378 3450 3450 379 3450 345(] 390 3450 345(] 385 3450 345(] C34-23 ACT INJ INJ ANNU 1765 3350 3350 1895 3350 3350 1891 3350 3350 1881 3350 3350 1856 3350 335(] 1836 3350 3350 1825 335O 335(] 1819 3350 3350 1806 3350 335(] 1801 3350 335(] 1786 3390 330~ 1808 3590 335(] 1808 3590 335~ 1833 3590 3375 1842 3590 3375 1847 3590 335¢ 1844 3590 3375 1855 3590 340C 1855 3500 340~ 1842 3500 340C 1832 3590 340{ 1828 3590 340~ 1810 3500 340C 1890 3590 340( 1774 3590 340{ 1792 3350 335{ 1770 3350 335( 1768 3350 335{ 1855 3350 335( 1839 3350 335( C23-26 C41-26 ACT ACT INJ INJ ANNU INJ INJ ANNU 0 0 0 0 760 600 0 0 0 0 760 60~ 0 0 0 0 770 600 0 0 0 770 600 0 0 0 77O 690 0 0 0 770 600 0 0 0 0 770 690 0 0 0 0 770 600 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 · 0 770 600 0 770 60~ 0 770 600 o 7~o 625 0 790 625 0 790 625 0 775 625 0 770 625 0 770 625 0 770 625 0 770 625 0 770 625 0 770 625 0 770 625 0 · 770 625 0 770 625 0 770 625 0 775 625 0 775 625 0 775 625 0 775 625 0 775 625 C44-14RD ACT INJ INJ ANNU 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 1,011 1,300 575 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 400 1,300 575 0 0 550 548 1,375 550 790 !,490 560 954 1,375 57(] C24A-23 ACT INJ INJ ANNU 256 4590 269 4590 259 4550 210 4550 216 4550 224 4550 242 4550 211 4550 203 4550 121 4550 264 4450 245 4590 237 4550 213 4550 C24A-14 ACT INJ 1NJ . ANNE 338 4550 346 4550 .( 370 4600 368 4600 370 4600 373 4600 367 4600 365 4600 380 4600 163 4600 384 4500 379 4550 386 4600 377 46O0 0 500 490 0 487 474 0 11,618 3,590 3,475 387 3,473 3,457 30 54,763 3,590 3,nool 1,825 3,418 3,364 3O 0 0 0 0 0 0 79O 625 0 772 616 0 3,703 !,400 575 123 225 553 5 179 4590 185 4590 186 4590 165 4525 157 4525 149 4525 139 4525 133 4525 129 4525 122 4450 126 4450 163 4450 174 4525 162 4590 156 4590 169 45OO 5,664 4,550 189 4,516 30 367 4600 374 4600 374 4600 368 4625 370 4625 366 4625 381 4625 392 4625 372 4625 238 3150 408 3150 381 4590 383 4600 381 4575 383 4575 368 4575 10,872 4,625 362 4,494 30 05115/290 1 241-23 shut in due to annular communication problem. 234-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. 223-23 shut in fo~ repairs from 4/1/01 thru 4/29/01. Returned to injection on 4/30/01 @ 1'30 p.m. ,? . WATER INJECTION REPORT PLATFORM March-2001 01 -M ar-2001 02-Mar-2001 03-Mar-2001 04-Mar-2001 05-Mar-2001 06-Mar-200 I 07-Mar-2001 08-Mar-2001 09-Mar-200 i I 0-Mar-2001 I l-Mar-2001 12-Mar-2001 13-M ar-200 I 14-Mar-2001 15-Mar-2001 16-Mar-2001 17-Mar-200 I 18-Mar-200 I 19-Mar-2001 20-Mar,2001 2 I-Mar-2001 22-Mar-200 I' 23-Mar-2001 24-Mar-200 I 25-Mar-200 I 26-Mar-2001 27-Mar-2001 28-Mar-2001 29-Mar-200 I 30-Mar-200 ! 3 l-Mar-2001 TOTAL MAXIMUM AVERAGE # DAYS 04/12/2001 C23-23 ACT : [NJ [NJ ANNU' C41-23 ACT [NJ [NJ ANNU C24-23 ACT [NJ [NJ ANNU C34-23 ACT [NJ INJ ANNU C23-26 ACT I'NJ INJ AbrNU C41-26 ACT l'NJ [NJ ANNU C44-14RD ACT [NJ [NJ ANNU C24A-23 ACT IlqJ INJ ANNU 262 4500 258 4500 258 4500 256 4500 242 4500 230 4500 209 4500 262 4500 201 4500 265 4500 248 4500 207 4500 236 4550 286 4550 224 4500 203 4550 198 4450 203 4425 256 4425 274 4400 242 4400 240 4400 272 4400 269 4400 22O 4550 273 4550 271 4550 265 4550 270 4550 272 4500 265 4500 C24A-14 [NJ [NJ A.NI~ 0 1700 1600 0 1700 1600 0 1500 1500 0 1500 1500 0 1500 1500 0 1450 145C 0 1450 145C 0 1700 160( 0 1500 140£ 0 1500 140( 0 1450 135( 0 1400 135( 0 1400 135( 0 1400 135( 0 1400 1000 0 580 800 0 360 900 0 295 925 0 295 1025 0 350 1175 0 480 1325 0 480 1325 0 620 1506 0 700 155¢ 0 615 155( 0 615 155( 0 615 155( 0 615 155( 0 615 155( 0 880 160( 0 880 160( 1,700 1,600 0 1,018 1,383 0 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 0 500 52~ 0 500 52¢ 0 500 52( 0 500 52( 0 500 52( 0 500 52( 0 500 52( 0 500 520 0 5oo 520 0 500 505 0 500 500 0 500 505 0 50O 5O0 0 500 500 0 500 50~ 0 5OO 50~ 0 500 50¢ 0 500 50( 0 500 50( 0 500 50( 0 500 50( 0 500 50( 0 500 50( 0 500 490 0 500 490 0 500 520 0 500 509 0 424 3500 3500 412 3500 3500 405 3500 350~ 402 3500 350~ 403 3500 350~ 4O9 3500 350C 402 3500 350£ 424 3500 350( 4O2 3450 345( 402 3450 345( 403 3450 345( 405 3450 345( 408 3400 335( 405 3400 3350 397 3400 3450 401 3500 3450 404 3500 3475 399 3500 3450 394 3500 3425 398 3500 345~ 399 3500 345~ 393 3500 345~ 391 3500 345£ 391 3500 345( 391 3500 345( 391 3500. 345( 394 ,3500 345( 394 3500 345( 392 3500 3450 392 3450 3450 393 3450 3450 12,420 3,500 3,500 401 3,481 3,456 31 2010 3400 3400 1940 3400 3400 1902 3400 3400 1885 3400 3400 1870, 3400 3400 1891 3400 340~ 1856 3400 340( 2010 3400 340( · 1852 3100 335( 1843 3100 335( 1847 3100 335( 1855 3100 335( 1865 3100 335( 1863 3100 335( 1825 3100 3345: 1845 35OO 335O 1861 3500 3375 1836 3500 3350 1824 3500 3325 1846 3500 3350 1858 3500 335O 1830 3500 3350 1830 3500 335~ 1853 3500 335¢ 1856 3500 . 335C 1869 3500 335( 1881 3500 335( 1872 3500 335( 1884 3500 335( 1843 3350 335( 1837 3350 3350 57,939 3,5OO 3,4O0 1,869 3,374. 3,363 31 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0' 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 650 50( 0 650 50( 0 650 50( 0 650 50( 0 700 55( 0 700 55( 0 700 55( 0 650 50( 0 700 550 0 700 550 0 700 550 0 700 550 0 700 550 0 700 550 0 740 60~ 0 750 60~ 0 750 60C 0 750 60( 0 750 60( 0 750 60( 0 750 60( 0 750 60( 0 750 60( 0 750 600 0 750 600 0 750 600 0 750, 600 0 750 600 0 750 600 0 760 60~ 0 760 60~ 0' 0 760 600 0 0 720 569 0 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 · 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 '550 0 7,637 4,550 246 4,490 31 390 4550 387 4550 380 4550 378 4550 382 4550 381 4550 377 4550 390 455O 347 4550 384 4550 389 4550 388 4600 398 4600 386 4600 376 4550 368 45C' ~'\ 361 45 ) 364 45~ .~ 368 4500 0 368 4500 387 4500 386 4500 380 4500 390 4500 344 4575 412 4575 392 4575 332 4575 389 4575 385 4550 375 4550 11,734 4,600 379 4,545 31 C4 i-23 shut in due to annular communication problem. C34-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received fi.om Mr. Wondzell on 12/14/99. 123-23 shut in for upcoming drilling operation in April. WATER IN3ECTIO# REPORT PLATFORH C C41-23 C24-25 C34-2..3 C23-26 C41-26 · INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU DATE BBLS PRESS PSIG BBLS PRESS PSIG BBLS PRESS PSIG BBLS PRESS PSIG BBLS PRESS PSIG 01-Nov-90 02-Nov-90 03-Nov-90 04-Nov-90 OS-Nov-90 06-NQv-90 07-Nov-90 08-Nov-90 09-Nov'90 lO-Nov-90 11-Nov-90 12-Nov-90 13-Nov-90 1&-Nov-90 " 15-Nov-90 16-Nov-90 1?-Nov-90' 18-Nov-90 19-Nov-90 20-Nov-90 21-Nov-90 22-Nov-90 23-Nov-90 24-Nov-90 25-Nov-90 26-Nov-90 27'Nov-90 28-Nov-90 29-Nov-90 30-Nov-90 2539 3200 0 2568 3200 0 2556 3200 0 2581 3200 0 2565 3200 0 2548 3200 0 2661 3200 0 2552 3200 '0 2690 3200 2585 3200 2605 3200 2618 3200 2601 3200 2608 3200 2657 3200 2587 3200 2605 3200 '0 2636 3200 0 2623 3200 0 2595 3200 0 2601 3200 0 2625 3200 ,0 2627 3200 0 2528 3200 0 26~5 3200. 0 ,2598 32OO 0 2654 3200 0 2652 3200 .0 26~1 32OO 0 2609 3200 0 TOTAL i78,160 MAXIMUM AVERAGE I 2605 # DAYS I 30 /12/17/90 I 1027 3500 3500 1030 3500 3525 1031 3500 3525 1036 3500 3525 1031 3500 3525 1026 3500 3500 1028 3500 3525 1011 3500 3525 1015 3500 3500 1014 3500 3500 1024 3500 3500 1035 3500 3500 1027 3500 3500 1028 3500 3500 1090 3500 3000 106~ 3500 3550 1058 3500 3550 1071 3600 3550 1070 3500 3550 1057 3500 3550 106~ 3500 3550 1076 3500 3550 1076 3500 3550 1043 3500 3550 1070 3500 3550 1048 3500 3550 1069 3500 3550 1068 3500 3550 1060 3500 3550 1039 3500 3550 0 s! 1250 0 Sl 1250' 0 si 1250 0 si 1250 0 si 1250 0 si 1250 0 si 1250 0 si 1250 0 sl 1250 0 Sl 1250 0 si 1250 0 si 1250 0 Sl 1250 0 SI 1250 0 S! 1200 0 Si 1200 0 S! 1200 0 Sl 1250 0 SI 1200 0 Si 1200 0 Sl 1200 0 SI 1200 0 Sl 1200 0 si 1200 0 si 1200 0 Sl 1200 0 si 1200 0 sl 1200 0 s! 1200 0 $1' 1200 96 3500 3475 102 35O0 3450 102 3500 3475 114 3500 3425 110 35OO 3425 110 3500 3425 111 3500 3425 109 3500 3425 109 35OO 34OO 105 3500 3400 106 3500 34OO 108 3500 3400 110 3500 3400 108 3500 3400 129 3500 3400 '123 3500 3410 0 3500 3410 238 3500 3400 124 3500 3410 124' 3500 3410 127 .'3500 3410 123 3500 3410 128 3500 3410 129 35OO 3410 127 3500 3410 112 35OO 3450 119 3500 3450 125 3500 3450 127 3500 3450 1'18 3500 3450 494 3500 0 466 3500 0 453 3500 0 446 3500 0 435 3500 0 430 3500 0 424 3500 0 416 3500 0 416 3500 0 415 3500 0 414 3500 0 413 3500 0 407 3500 0 4O6 3500 0 416 35OO 0 409 35on 0 405 3500 0 408 3500 0 412 3500 0 406 3500 0 404 3500 0 399 3500 0 392 3500 0 371 3500 0 378 3500 0 360 3500 0 369 3500 0 380 3500 0 386 3500 0 381 3500 0 31,388 '.0 3,471 '1' 12,311 3200 0 3600 3550 0 1250 I 3500 3475 3500 0 3200 0 1046 3503 3513 0 0 1225 I 116 3500 3422 410 3500 0 ' 30 30 I 30 30 RECEIVED DEC 7 9 7990 Alaska Oil & Gas COns. ~ommission AnChorage Shell Western E&P Inc. 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 June 11, 1990 Alaska Oil and Gas Conservation Commission ATTN: Elaine Johnson 3001 Porcupine Drive Anchorage, Alaska 99501 SUBJECT' TRANSMITTAL OF REQUESTED INFORMATION REGARDING THE SWEPI OPERATED MIDDLE GROUND SHOAL FIELD Dear Ms. JOhnson: In a recent telephone conversation you discussed with Ms. Susan Brown-Maunder information that would be helpful to you if we could provide it. Enclosed, for your convenience and use, are the following' location surveys showing the location of Platform A list of conductor/well locations (in relation to the SE corner of Sec. 11, T8N, R13W) for Platform A wells location survey showing the location of Platform C list of conductor/well locations (in relation to the SE corner of Sec. 23, T8N, R13W) for Platform C wells In addition you requested a revised copy of the Well Completion or Recompletion Report and Log (10-407) for the recently completed well C2]-23. The well location at the top of the producing interval and the well location at total depth as been changed to reflect the actual surveyed location. If you have any further questions regarding these matters, please continue to contact Susan Brown-Maunder at (907) 263-9613. Very Truly/Yours, W. F. Simpson. Manager, Regulatory Affairs Alaska Division WFS/SBBM/vj Enclosures cc: Susan Elsenbast-AOGCC \LETTERS\AOGCC\061190 .DOC RECEIVED JUN 1 Alaska Oil.& Gas Cons. Anchorag~ PLATFORM "C" MIDDLE GROUND SHOAL CONDUCTOR/WELL SURFACE LOCATIONS LEG 1 Centered 541.65 ft. North and 1596.41 ft. of the SE Corner of Sec. 23, TSN, R13W, SM. CONDUCTOR WELL LEG 2 1 C23-23 2 C32-23 3 C34-26 4 C24-26RD 5 C31-26 6 C34-23 7 C23-26 8 C22-26RD CONDUCTOR LEG 3 LEG 4 9 10 11 12 13 14 15 16 CONDUCTOR 25 26 27 28 29 3O 31 32 DISTANCE FROM SE CORNER NORTH WEST 547.10 1599.00 547.25 1594.46 544.25 1591.06 540.57 1590.68 536.91 1593.01 535.88 1597.22 538.03 1600.98 542.18 1602.22 Centered of the SE 618.65 ft. North Corner of Sec. 23 WELL and 1549.76 ft. , TSN, R13W, SM. DISTANCE FROM SE CORNER NORTH WEST C2~-23 623.65 1552.66 C24A-14 624.15 1548.36 C43-14 622.65 1544.76 C41-26 618.25 1543.86 C21-23 613.85 1546.26 C21-26 612.65 1550.46 C24A-23 614.85 1554.26 C13-23 619.15 1555.66 Centered 582.42 ft. North and 1489.90 ft. of the SE Corner of Sec. 23, T8N, R13W, SM. Centered 505.41 ft. North and 1536.56 ft. of the SE Corner of Sec. 23, TSN, R13W, SM. WELL DISTANCE FROM SE CORNER NORTH WEST C42-23 C31-23 C43-23 C41-23 C33-26 C-LINE C44-14RD C24-23 509.00 1541.00 509.81 1536.57 507.65 1532.61 503.51 '1531.56 499.00 1534.44 498.37 1538.72 500.87 1542.26 505.12 1543.10 west DISTANCE FROM CENTER OF LEG N/S E/W 5.45 -2.59 5.60 1.95 2.60 5.35 -1.08 5.73 -4.74 3.40 -5.77 -0.81 -3.62 -4.57 0.53 -5.81 West DISTANCE FROM CENTER OF LEG N/S E/W 5.00 -2.90 5.50 1.40 4.00 5.00 -0.40 5.90 -4.80 3.50 -6.00 -0.70 -3.80 -4.50 0.50 -5.90 West West DISTANCE FROM CENTER OF LEG N/S E/W 3.59 -4.44 4.40 -0.01 2.24 3.95 -1.90 5.00 -6.41 2.12 -7.04 -2.16 -4.54 -5.70 -0.29 -6.54 · L.O~.A'I'tON S.A.$. PL.ATFORH )'C' CO0~ INI-ET ,'"' .AL&S ICA SC.iL! I% ~'OOO' IMercl~ IN7 Hay 5, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Shell Western E&P Inc. O 601 West Fifth Avenue. Suite 810, i ~ t~?o,..A.~s'r~-" ST'AT Gentlemen: SUBJECT- AREA INJECTION ORDER' NO. 9 (CENTRAL PORTION MIDDLE GROUND SHOAL FIELD), RULE 6 As part of the requirements of Area Injection Order (AID) No. 9, Rule 6, a schedule for performing radioactive tracer surveys (RTS) must be submitted to and approved by the commission. During conversations with members of your staff it was indicated that the Commission may accept recent RTS's even though the commission representatives did not have the opportunity to witness the surveys. By waY of this letter, SWEPI is submitting our schedule for performing RTS's on injection wells and request that you accept the recent surveys as satisfying the requirements of Rule 6 based on the enclosed RTS logs. (See Attachment 1 for list of enclosed logs.) Attachment 2 is a table showing the mechanical integrity history for the MGS injection wells. Also shown is the proposed testing schedule noting those wells for which we are asking .your acceptance of the previously run surveys. Your early review of this proposal would be greatly appreciated. If we can be of further assistance, please do not hesitate to call Ms. Susan Brown-Maunder at (907) 263-9613. Very truly yours, Wo F. Simpson Manager Regulatory Affairs SBBM/hr Enclosures GTK1/050489 Attachment 1 LIST OF ENCLOSED LOGS Wel 1 No. ~ /111-12 ~. All-13 RD II ~ A12-12 ~ A33-14 v A34-14 RD II ~ A44-11 - C23-26 ~ C24-23 ~ C34-23 V' ~ C41-23 Log(s) RAT - 6/17/87 NFL- 1/17/86 NTL- 3/4/88 NFL - 3/5/88 RAT - 6/17/87 NFL- 9/5/86 RTS- 3/26/88 NFL- 1/26/87 NFL - 2/12/87 NFL- 1/27/87 NFL -. 2/10/87 NFL - 2/12/87 NFL - 10/24/87 GTK1/050489 ~j Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 February 26, 1988 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen- SUBJECT: REPORT OF SUNDRY WELL OPERATIONS FOR CASING REPAIR OF MIDDLE GROUND SHOAL WELL C41-23 Enclosed, in duplicate, is the Report of Sundry Well Operations for C41-23. The workover consisted of repairing the casing, performing a cement squeeze, and reperforating injection intervals. The well has been return to service as an injection' well. If you have any questions, please call Ms. Susan Brown at (907)263-9613. Very truly yours, W. F. Simpson Manager Regulatory Affairs Alaska Division WFS/SBB/kt Enclosures SBBG/ros.O223a STATE OF ALASKA /'~, ALAS,L., Oil AND GAS CONSERVATION COM,. JSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other~" 2. Name of Operator 5. Datum elevation (DF or KB) Shell Western E&P Inc. 105' DF Feet 36~d~t Fifth Ave , Suite 810, Anchorage AK 99501 6. Unit or ProDertvname · , Middle Ground Shoal 4. Location of well at surface Platform "C" Leg 4 Conductor 28 Center of Leg i @ 541.65'N & 1596.41'W of SE corner of Sec. 23,T8N,R13W,S. M. At top of productive interval 3827'N & 567'E of surface location 4/~§"f~ct~[ve3d3~'t~ of surface location 4~°'t~l ~e~9'E of surface location 7. Well number C 41-23 8. Approval number 9. APl number 50-- 733-20:1.63 10. Pool "G" Pool 11. Present Well condition summary Total depth: measured true vertical 10,712 ' feet Plugs (measured) 9,507' feet Effective depth: measured 10,535' feet Junk (measured) true vertical feet Casing Length Size Cemented Structural Conductor Surface Intermediate 1,653' 10-3/4",40.5#,J-55 1350sx Production 10,593' 7" 26-29# N-80 Liner Perforation depth: measured 9,087'-10,480' (5 INTERVALS) true vertical Tubing (size, grade and measured depth) Measured depth _l,653' 10,593' True Vertical depth RECE ¥ED ~ :t~Dil & G~s Cons. Gommis$io;~ - ' Anchorago 3-1/2", 9.3#, N-80, AB MOD EUE @ 10,160' Packers and SSSV (type and measured depth) Packers set @ 8898' 9582' 10 157' 12. Stimulation or cement squeeze summary Repaired casing leak @2147' with cement squeeze @ 2123'- 2159'. Pulled bridge plug and packers. Squeezed cement 10,160'-9600'. Set packers Intervals treated (measured) at 10,157', 9582', and 8898'. Ran tubing. Perforated. Acid Treatment description including volumes used and final pressure treated lower zoneso 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Well was shut in and temporaril~v abandoned· 2248 0 3300 Tubing Pressure 14. Attachments Daily Report of Well OperationsX[~ Copies of logs and Surveys Run [] 15. I her;,~~hat the foregoing is true and correct to the best of my knowledge ~~-. ~ -~L.O-- ~' ~ Signed~ Title Division Operations Manager Date'2' ~, ~ Form 10;404 Rev. 12-1-85 Submit in Duplicate DAILY REPORT OF OPERATIONS C41-23 09/12/87 Rig up. 09/13/87 Test equipment. Test casing to 2000 psi. Cement squeeze casing leak at 2147' with 20 sx calseal cement, followed by 30 sx "G" + 3% CaC12 (squeeze psi 1600 psi). Test casing to 1000 psi (okay). 09/14/87 Cleaned out cement. Circulate and condition mud. 09/15/87Circulate and condition mud. Clean out sand and attempt to pull RBP. 09/16/87 Pull RBP. Latch onto packer @ 9034'. 09/17/87 Work packer free and POOH. 09/18/87 Clean out hole. Circulate and condition mud. 09/19/87 Mill. Circulate and condition. 09/20/87Tested BOP and annular preventer. Latch onto second packer at 9651' and pulled out. 09/21/87 Clean out. Circulate and condition mud. 09/22/87Ran in hole with fishing tool and pulled out packer at 9781'. Wash and ream. 09/23/87 Circulate and condition. Pulled packer that was set @ 10,001'. Cleaned out to 10,150'. ~ ~ ~ 09/24/87 Circulate and condition fresh CaCl2 completion fluid. ~~C~ 09/25/87 Circulate and condition. Mill over packer @ 10,150'. ~ 29~'~ . , .... 09/26/87 Mill over packer. Circulate and condition. ~.~ ~c~O~B~B 09/27/87 Mill and circulate and condition. 09/28/87 Circulate and condition. Run casing caliper log. 09/29/87Squeezed 100 sx of "G" + .2% CFR + .5% Halad 344 + .1% LWS across interval 9600'-10,160'. Mill on EZSV. 9/30/87 Drill cement from 9603'-9973'. Circulate and condition. SBBG/0224 PAGE 2 10/01/87 Check for flow. Circulate and condition. Pumped 50 sx of "G" + .2% CFR + .5% Halad 344 + .1% LWL. Drill cement from 9939'-10,158'. 10/02/87 Circulate. Check for flow. Mill EZSV. Pump 20 bbl Safe Dense pill. Braidenhead squeeze pill below 8800'. Set packer @ 10,156'. 10/03/87 Circulate and condition. Filter brine. 10/04/87 Filter brine. Test equipment. 10/05/87 Ran 3-1/2" 9.3# N-80 AB MOD tubing to 10,504' 10/06/87 'Perforate the following intervals with Vann System 4" guns 4JSPF: 10,340 10,254 10,180 9,465 9,450 -480 -316 -235 -495 -465 9,087 -108 10/07/87 Work scraper through perforations. Circulate and condition. Work tight spots. 10/08/87 Work tight spots. 10/09/87 Ream casing. Check for flow. Pressure test annulus @ 1000 psi (okay). 10/10/87 Set packer @ 9582'. Circulate and condition brine. Check for fl ow. Set packer @ 8898'. 10/11/87 Ran in hole with 3-1/2", 9.3# N-80 AB MOD tubing to 8899'. Pressure test annulus to 1000 psi (okay). Install tubing hanger and tree. 10/12/87 Rig down. SBBG/0224 OCT. 17. 1987 SUBJECT: COIL TUBING ACID JOB C 41-23 · D/S AND OTIS RIOOED UP. HELD SAFETY MEETING. PRESSURE TESTED . FIXED LEAKS ON COIL TUBING UNIT AND ON LUBRICATOR. PRESSURE TESTED 5000 PSI OK. STARTED IN HOLE AT 1502 PM PUMPING AT A RATE OF 1/8+ BBL MIN. AT 4500 PSI. AT 10160 STARTED PUMPING 15% HCL AT 1/8+ BBL. MIN. AFTER DISPLACING ]5+ BBLS. PRESSURE DOWN TO 4200 PSI STARTED PUMPING AT 1/2 BBM. REMAINDER OF JOB WAS AS PER PROB. OUT OF HOLE AT 10:30 PM PUT WELL ON INJECTION AT 10:45 PM. AT A RATE OF 360 B/D AT 1350 Psi. INCREASED RATE TO 400 B/D AT $:b3~. 1510 PSI INCREASED RATE TO 500 B/D AT 8:00 AM 1575 PSI OTIS STARTED RIGGINO DOWN AT 6:00 AM. R. L. VICKERSON RE RETAIN THIS SECTION FOR YOUR RECORD,~ NGS C41,-2~ (SHELL LOGS) PLS-NFL '1 PRINTS_ 0 NEG. 1 SEPIA PRINTS 0.~_~ NEG. _~_ 1~- SEPIA PRINTS NEG.~ SEPIA PRINTS~ NEG. ~ SEPIA PRINTS NEG. SEPIA '- -- PRINTS NEG. SEPIA ATTENTION ~ SIGNED d~f~rage 19___ · August 20, 1987 Shell Westem E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 Gentlemen- SUBJECT: SUBMISSION OF AN APPLICATION FOR SUNDRY APPROVAL FOR UPCOMING WORKOVER OF MIDDLE GROUND SHOAL WELL NO. C 41-23 Enclosed, in triplicate, is the Application For Sundry Approval for the upcoming workover of Middle Ground Shoal well number C 41-23. The well is currently shut-in and has a retrievable packer at 9,000' and a 134' column of cement above that. The workover is scheduled to commence September 1, 1987. If you have any questions, please contact Susan Brown at (907) 263-9613. Very truly yours, a. L. Yesland Manager Regulatory Affairs Alaska Division SBB/kka Enclosure RECEIVED Alaska Oil & Gas Cons, Commission Anchor2qe SBBF/aogcc. O4e STATE OF ALASKA ~ ALA,_.~A OIL AND GAS CONSERVATION COI,,..,IlSSlON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing ~ Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator 5. Datum elevation(DF or KB) Shell Western E&P Inc. 105' DF feet 3. Address 6. Unit or Property name 601 West Fifth Ave., Suite 810, Anchorage, AK 99501 Middle Ground Shoal 4. Location of wellatsurfacePlatform "C" Leg 4 Conductor 28 Center of Leg 1 @ 541.65'N & 1596.41'W of SE corner 7. Wellnumber C 41-23 Attop of productiveinterval of Sec. 23, 3827'N & 567'E of surface location Ateffective depth 4193'N & 337'E of surface location Attotaldepth 4270'N & 289'E of surface location T8N, R13W, S.M. 8. Permit number 68-112 9. APl number 50-- 733-20163 10. Pool "G" Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 1 0,71 2 ' feet Plugs (measured) 1 0,1 47 ' feet feet Junk (measured) 1 0,535 ' feet Casing Length Structural Conductor Surface Intermediate I, 653 ' Production 10,593 ' Liner Perforation depth: measured Size Cemented 10-3/4" 40 5# J-55 7" 26-29# N-80 , , 9,087'-10,477' (11 true vertical Tubing (size, grade and measured depth) Measured depth 1350sx INTERVALS) True Vertical depth 1,653' 10,593' RECEIVED Oil & 6as 6ons, 60mm~ .... Anchorage 3-1/2" , 9.3#, N-80 EUE ~ 10, 810' Packers and SSSV (type and measured depth) Packers set @ 9,029'; 9,651'; 9,781'; 10,001'; 10,418' Cement plug (~ 8,866' 12.Attachments Description summary of proposal ~ Detailed operations program ~ BOP sketch [] 13. Estimated date for commencing operation September 1~ 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that th~j~~ and correct to the best of my knowledge Signed ~~ -- ' Title Producti on Superintendent Commission Use Only Conditions of approval Approved by Form 10-403 Rev 12-1-85 Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance ,~ r¢,~ch.~nica! Ir~¢grib/ Te~t Approval No. ?. ~--~'~ Commissioner the commission Date ~. ~ _~ triplicate ~ Submit in ¢ CASING REPAIR AND RETURN TO INJECTION MGS C 41-23 7/20/87 OPERATION: 1. Repair 7" casing leak at 2147'. 2. Recover RBP at 8996' 3. Clean out casing to ~BTD. 4. Squeeze cement HC-HN intervals. 5. Run 5" liner if warranted. 6. Re-perforate and acidize GN-GS and HN-HZ intervals. 7. Run completion equipment and establish injection into GN-GS and HN-HZ zones. STATUS: Shut-in with RBP at 8996' capped with sand and cement. TOC at 8866'. 11#/gal CaCl2 in casing. KILL WEIGHT: WELL DATA: TUBULARS: MECHANICAL: 11#/gal required during 1/87 workover. TD = 10,712' PBTD = 10,535' (Baker RBP junk e 10,269') Maximum hole angle is 31.4° at 4,090' 10-3/4", 40.5#/ft, J-55 e 1653' with 1350 sx 7", 26#/ft, N-80 @ 8450' 29#/ft, N-80 8450-10,593' See attached Tubing Detail sheet. (Attachment A) PERFORATIONS: Zone ..Top (TVD) Interval (MD) GN-GO 8088 9087-108 GR-GS 8423 9450-495 HC-HD 8648 9706-720 HC-HD 8648 9733-764 HE-HF 8766 9842-886 sqz cemented HI-HK 8863 9954-993" " HK-HN 8910 10003-147 HN-HR 9026 10180-316 HR-HZ 9169 10340-438 HR-HZ 9169 10462-477 RECEIVED Alaska Oil & Gas Cons. Anchorage JHFA/0720 REFERENCE LOG: SOS CBL 1/22/69 (Note corrected collar depths). PROCEDURE' 1, RU to take all returns through rented gas buster placed direct- ly upstream of mud pits. This should eliminate most of the H2S associated with wellbore fluid. , , ND tree. NU BOP and test. Mix pit volume of 11# CaC12 brine (154# CaC12/BBL). PU and RIH with Howco RTTS Champ II with circulation valve on 3-1/2" drillpipe and set at 2050'. Pressure test backside to 2000 psi. (Burst of 7", 26#, N-80 casing with 60% wall thick- ness and a safety factor of 1.3 is 3341 psi.) Drop below suspected hole at 2147' and set packer at 2250' and pressure test casing below packer to 2000 psi. If casing holds pressure above and below hole at 2147', continue to STEP 4. If pressure leaks off above or below hole at 2147', POH and pickup RBP and locate any additional holes. Contact Production Engineer if additional holes are located. SQUEEZE CEMENT 0 NOTE: Squeeze cement composition will be specified and lab tested for fluid loss and set time upon selection of cementing company. Thixotropic first stage slurry is to have a set time of 2 hours at 80°F. Second stage slurry is to have a set time of 4 hours at 80°F and a fluid loss of 50cc/30 min. All lab tests to be performed with actual cement sample and with water to be used on job. Set packer at 2050'. Open circulating valve and displace 13 BBL (500') fresh water to annulus. Close circulating valve and pressure test backside to 1000 psi. Leave 1000 psi on backside and monitor throughout squeeze operation. Open 10-3/4" X 7" annulus valve and attempt to circulate. Leave valve open and monitor throughout squeeze operation. NOTE: Formation will fracture at a low pressure at depth of casing hole. Assuming a fracture gradient of 0.6 psi/ft., less than 100 psi is necessary to fracture the formation with 11#/gal workover brine. Cement will be circulated to hole and up annulus (if possible). No squeeze pressure is anticipated. Squeeze will be pressure tested after drill out. R ECEiVE JHFA/0720 Atj~ 2 i ~c}~'~ Alaska Oil & Gas Cons, Commission 5, 0 With 10-3/4" X 7" casing valve open, mix and pump at 0.5 BPM, 5 BBL fresh water, 20 sx thixotropic cement, 20 sx cement and 2.1 BBL fresh water. Displace with 14.8 BBL of brine. This will leave 10 sx (50') of cement within casing and a hydrostatic balance across the packer. Unseat packer and POH. Leave well shut in for 12 hours. After 12 hours, pressure test to 1000 psi for 10 minutes. If squeeze holds pressure, drill out and re-test. Resqueeze with same procedure if squeeze fails pressure test. Clean out cement from 8866' to top of sand plugback at 8972' using 6" mill and 6 drill collars. Care must be taken to not damage retrieving stem of RBP (Halliburton Model "N") located at 8996' Circulate wellbore until clean. Use viscous HEC pill as ~eeded to ensure clean hole. POH and inspect mill. If mill is not full gauge, RIH with casing scraper and retrieving tool. Before circulating out sand on top of RBP, work scraper across cemented zone between 2200-2000' and 8972-8800'. Circulate wellbore clean (350+ BBL). Wash sand and latch onto and recover RBP. CASING CLEANOUT NOTE: For this workover to be successful, the well needs to be cleaned out to 10520'. 7. With 7" casing repaired, continue fishing operation to recover remaining packers and tubing. The bottom packer at 10,148', (Baker F-l) is a permanent packer and will have to be milled. A junked Baker RBP (Attachment C) is at 10,269'. During the 1978 workover, the stem and upper rubbers were recovered. It was milled on for over six hours with no further recovery. The slips and lower mandrel are still in hole. RIH with a junk mill, collars, and jars. Attempt to mill and push junk to PBTD at 10,535'. 8. With casing cleaned out to at least 10,520', RU Dia-Log and run caliper from new PBTD to earlier deepest logged depth. Tele- copy results to Anchorage Production office. Based on the condition of the casing, a decision will be made to run a 5" liner across the perforated interval (Attachment D). If liner is to be run, the HC-HN intervals will first be squeeze cemented. JHFA/0720 Alaska Oil & Gas Corls. Commissio~ Anchora,ge CEMENT SQUEEZE OF HC-HN INTERVALS 9. RIH with CIBP on E-line and set at 10,165'. RD Loggers. 10. RIH with squeeze packer on drillpipe. Tag CIBP and record depth. Use corrected drill pipe depths for remainder of operation. Set packer at 9800' and test for communication. Maximum squeeze pressure is 1900 psi. If communication occurs reset packer at 9600'. Test for communication. CEMENT- 16#/gal cement mixed in filtered injection water. Thickening time is 5 hours at 150°F. Fluid loss approximately 50 cc/30 min. Lab tested for compatibility with 11#/gal brine. Maximum surface squeeze pressure to avoid fracturing formation is 1900 psi. If no communication occurs with packer set at 9800', HC-HN will be squeezed in two stages. Use 50 sx for first stage and do hesitation squeeze when tail of cement is below packer, but do not over displace. If squeeze is not obtained, unseat packer, pull up to 9600' and circulate out any excess cement. Reset packer at 9600' and check for communication with upper perforations (9450-9495'). If well communicates, contact Anchorage Production Engineer. Mix and pump 50 sx cement and do hesitation squeeze when cement is below packer but do not over displace. If squeeze is not obtained POH. If communication occurs at 9800', all of HC-HN will be squeezed in one stage. Set packer at 9600' and mix and pump 100 sx of cement. When cement is below packer begin hesitation squeeze. If maximum squeeze pressure of 1900 psi is obtained, unseat packer, POH 1000', circulate out excess cement and POH. If squeeze is not obtained, do not over displace. POH 1,000', circulate, POH. 11. After leaving well shut in for 12 hours, RIH with bit and drill collars. Clean out to PBTD. Make note on Morning Report on hardness of cement drilled. POH. Make an additional trip through squeezed interval with bit and casing scraper. Circu- late hole clean. Displace hole with filtered (3 micron) workover fluid on final circulation. Filter all fluid for remainder of operation. POH. NOTE- If in Step 9 caliper indicated the need for a 5" liner, run liner as outlined in Attachment D. JHFA/0720 Alaska Oil & Gas AUG 2 i ~a~:~ 5 Alaska Oil & Gas Cons. Commission REPERFORATE GN-GS AND HN-HZ ZONES 12. The HN-HZ zones will be reperforated with 4" tubing conveyed gun 4JSPF. The GN-GS zones will be reperforated with 4" wireline casing guns 4JSPF. Pick up tubing conveyed perforating guns with mechanical firing head and assemble on 3-1/2", 9.3#/ft, AB-Mod injection string (Attachment E). Caliper all equipment and drift (2.85") all tubing as it's being picked up. Run radioactive collar two joints above firing head. Tally and record distance from R-A collar to top shot. Gun to be set up to perforate the follow- ing intervals: HN-HR 10180-235' HR-HZ 10254-316' HR-HZ 10340-480' When guns are on approximate depth, based on tubing tally, RU E-line unit and run Gamma-Ray log for correlation with REFER- ENCE LOG. POH logging tools and RD E-line. Space out guns to get on depth and hang tubing in slips. RU TCP service com- panies monitoring equipment. Screw in a valve on tubing and drop bar. Monitor for indications of firing and report on Morning Report. If there was no indication of firing, follow Attachment F, "Procedure for Tubing Conveyed Gun Failure". 13. After firing guns, reverse circulate bottoms up to remove gun debris before tripping out of hole. Monitor well for flow. Stand back tubing and lay down all TCP equipment. 14. RU wireline perforating company. RIH with 4" casing gun loaded 4JSPF, 90° phased. Perforate the following intervals with all depths based on REFERENCE LOG: GN-GO 9087-9108' GR-GS 9450-9495' RD perforators. RIH with bit scraper and make clean out run. 15. Depending on 7" Casing condition, a worksheet will be prepared to acidize all injection intervals using a RBP and packer run on completion tubing. Do not use drillpipe for acidizing. INSTALLATION OF COMPLETION EQUIPMENT 16. RU to run completion equipment as on attached Completion Diagram (Attachment H). RU E-line and RIH with permanent packer and set with rubbers at 10,160'. Pickup seal unit and JHFA/0720 RIH on drillpipe and sting into permanent packer. Pump 10 BBL of filtered water into HN-HZ zones while monitoring the annulus for any indication of communication. Contact Production Engineering if communication occurs. POH, laying down drillpipe. 17. Pick up and run remaining completion equipment. All gas lift mandrels are to be run with dummies in place and pressure tested to 5000 psi. Space out to set 10,000# on permanent packer and top hydraulic packer after donut is landed in tubing hanger. RU slickline and run Otis 3-1/2" "N-test" plug and set in "XN" nipple at 10170'. With a 10,000# on permanent packer, pressure up tubing to 3000 psi in a stepwise fashion. Report any indication of packer setting on Morning Report. Pull dummy at 8970'. Circulate down tubing to annulus 2 BBL of N. L. A" Baroid "Baracor mixed in 200 BBL of filtered injection water. Over-displace by 30 BBL and re-run dummy. Slack off an additional 10,000#, landing tubing in tubing hanger. POH "N-test" plug and RD slickline unit. 18. Install BPV and ND BOP. NU wellhead and attach injection line. Pickle rig and release crews. Have Platform Instrument Tech- nician calibrate turbine meter and waterflood panel. 19. Place well on injection, reporting injection on Daily Produc- tion Report. If an adequate injection rate of 400-500 BWPD is not established, well will be stimulated using a coiled tubing unit and mud acid. 20. One month after completion of operation, if the injection rate is stable, an injection survey will be run. RECOMMENDED: DATE: APPROVED: ~'~.L.Jt2 . Alaska OJJ & Gas Cons. Commission Anchom~e JHFA/0720 ICBM MANDRILS 0 FID. -- ii ii i i 1. B995' I)u~y 9066' Dummy 3. 9688' Dummy 4. 9819' Dummy S. 10038' Dummy Casing ~_ 10 3/4" 40.5t Buttress,' 0-1653' 7" 26t N-80 Buttress, 0-8450' 7" 291 N-BO Buttress, 8450-10593' ~9.3t N-80 EU£ 0-10180' (336 aT) Perfs -'~0~/- 9108' 6N- GO 9450- 9495' 6R-GS 9706- 9720' HC-HD _~7 33- 9764' "' 842- 9886' HE-HF sqz. 0 9954- 9993' H]-HK sqz. 009-10147 ' HK-HN 10180-10235 ''~ HN-HR 10256-10316' " 10340-10370' HR-HZ 10396-10438' " 10445-10454' " 10462-10477' '" ---NOTE***NOTE--- "Fish" in casing, Top ~ 10,269'. (Baker retrievable plug less center rod ass'y) C 41-~3 ATTACHMENT A Ball Valve 0 295' 10 3/4" [a 1653' RECEIVED Ai..J~3 2 i ].98.7 Alaska Oil & Gas Cons, Commission Anchorage KBM I1 {a 8995' Unipacker VII L) 9029' KBM 12 g 9066' Unipacker VII g 9651' ICBM 13 g 9688' Unipacker VII e 9781' KBM t4 g 9819' Unipacker VII ~ lOODl' KBM t5 L~ 10038' Baker F-1 Packer & Seal e 10148' X-Nipple e 10165' X-Nipple ~ 10173' Mule-Shoe Pup e lO180 (EOT) "Fish" Baker retrievable plug, less cent-' rod assembly ~ 10269' m ATTACHMENT D PROCEDURE FOR RUNNING AND CEMENTING 5" LINER STATUS: Tubing and equipment pulled. 7" casing cleaned out to PBTD at 10535' Casing caliper indicates extensive casing corrosiOn/erosion across perforated intervals. Hole full of 11#/gal brine. OBJECTIVE: Run and cement liner across damaged, perforated sections of 7" casing. The minimum acceptable liner lap is 100' above damage. PROCEDURE: Run liner as follows: Shoe Ijt 5" 18# N-80 Landing collar Remaining its 5" 18# N-80 Liner Hanger (mechanical) 20' PBR Tieback receptacle RECEIVED AUG 2 Alaska Oil & Gas Cons. Commission Anchorage Gauge PBR with 4-7/32" polishing mill prior to make up. Keep liner filled while RIH. e With shoe on bottom, break circulation and circulate bottoms up. Set liner hanger and release from liner. String into liner for cementing. CEMENT: Cement will be Class G mixed in filtered injection water with the following properties: 16#/gal Fluid loss 50cc/30 min -+ Thickening time of 4 hours at 155°F Cement to be tested for compatibility with brine prior to operation. e Mix and pump cement volume equivalent to 125% of annulus volume (0.0722 ft~/ft). Release pump down plug. Slow pump down as plug reaches liner wiper plug. me Continue pumping until plug bumps or total displacement is achieved. Release pressure to check float. JHFA/0720.1 Be 5 Be e Page 2 POH 10 stands and reverse circulate. POH. RIH with 6" bit and scraper. WOC 12 hours. Clean out to top of liner. POH. RIH with RTTS with circulating valve. Pressure bombs are to be placed above and below valve. Do not fill last 3900'-+ of drillpipe. This is equivalent to a 2000 psi drawdown test. Open tool and do drawdown test. POH. Read gauges. If lap leaks, squeeze with 100 sx cement. RIH with 4-1/8" mill on 2-3/8" tubing and 3-1/2" drillpipe. Clean out to landing collar. POH. RIH with 4-7/32" polishing mill and dress PBR. POH. Continue with main Prognosis, STEP 13, making necessary changes in choice of perforating equipment and completion equipment for smaller ID inside of liner. JHFA/0720.1 PRESENT CONDITION Attachment C MIDDLE GROUND SHOAL C41-23 PROPOSED COMPLETION 11 :~/GAL INHIBITED CaCI2 HOLE at 2147' Ib~10-3/4' at 1653' ~.~, CEMENT SQUEEZED 3-1/2' TUBING 30' SAND RBP at 9000' BG CUT at 9024' :TBG CUT at 9646' ~TBG CUT at 9774' ~TBG CUT -- at 9997' GN-GO:-- GR-GS HC-HN__ JUNKED RBP at 10269' HN-HR-- HR-HZi__ HR-HZ__ NOTE' Drawing Not To Scale GLM w/DUMMY at 8'970' 7' HYD PKR at 9000' GLM w/OR at 9100' 7' HYD PKR at 9250' GLM w/OR at 9475' 7' HYD PKR - at 9600' --GLM w/DUMMY at 10000' 7' PERM PKR at 10160' __OTIS 'XN' __ NIPPLE at 1O17O' PBTD at 10500' 7' at 10593' A1TACHMENI B PROCEDURE FOR PLUG AND ABANDONMENT (Will be prepared upon review of 7" casing condition) JHFA/1028 ATTACHMENT C Model 'C" Retrievable Bridge Plugs MODI[L "C" RETI~EYABLE BRIDGE IKUG Product No. 677-01 The MODEL "C" RETRIEVABLE BRIDGE PLUG is a dependable, leakproof plug that will hold pressure from above or below. It is used for acidiz- lng, formation fracturing and temporary pressure containment to aid in removing or installing wellhead equipment. The operation of the MODEL "C" uti- lizes pressure differential from either above or below to achieve and maintain packoff. Once the plug has been run to the desired depth and released, it will automal~.,ally set and packoff against pressure differentials from either direc- tion. The simple operation of the bridge plug, and the ease with which it may be picked up and relocated, make it ideal for the selective isolation and fracturing, aci- dizing or testing of several separate zones of a well in one round trip when used with the FULL BORE RETRIEV- ABLE CEMENTER or RETRIEV- AMATIC CEMENTER. Opposed Rocker-Type Slips. The slips prevent the plug from being moved either up or down by a pressure differen- tial across the tool. Either the upper or lower slips will automatically engage the casing and hold the plug, depending on the direction of the differential. bio Swabbing Bamjer. A circulation passage through the length of the MODEL "C" allows fluid bypass during either running or retrieving. · I ATTACHMENT C jr. ATTACHMENT E TUBING CONVEYED PERFORATING EQUIPMENT DETAIL SHEET {Will be prepared upon Partners approval of workover and service company bid selection) JHFA/1028 ATTACHMENT F PROCEDURE FOR TUBING CONVEYED GUN FAILURE If, after dropping the detonating bar, there has been no indication that the guns have fired, the following procedure should be followed: 1. Rig up slickline unit and the following slickline tools. a) b) c) d) An overshot to catch a standard 7/8" O.D. fishing neck alt'" O.D. bailer a chisel point bailer bottom for the 1½" bailer a l!)" O.D. impression block . Test lubricator to 1000 psi. Rig up the tool string for the first run with the overshot to catch the detonating bar. e Pay careful attention going in the hole to determine the exact fluid level in the tubing. 4. When the detonating bar is reached, latch onto the bar and spud down as hard as possible. NOTE: Have the slickline operator leave the weight of the tool down at the bottom of his stroke. Repeat this procedure a minimum of three (3) times. If the guns fire when spudding down, the slickline tools should remain on bottom until the well pressure is equalized. Then pull out of the hole with the well shut in. 6, If you still have no indication that the guns have fired, fish and remove the detonating bar from the hole. . Rig up the 1~" bailer with the "Chisel Point" bailer bottom. NOTE: Carefully dress the chisel point bottom to a very clean and sharp edge. , When reaching bottom with the chisel point bailer, jar down as hard as possible to bail to the firing pin, make certain that on each stroke the operator holds at the bottom of the stroke in case the guns fire. On each trip out of the hole with the bailer, carefully inspect the leading edge of the chisel point. If the bailer is striking the firing pin, there will be a clear 1" diameter impression in the leading edge of the chisel point bailer bottom. JHFA/0318.2 Alaska Oil & Gas 10. Material taken from the bailer on each run should be carefully inspected in order to determine the type of fill that may have kept the detonating bar from the firing pin. If the guns have fired, you will also normally find a very fine black powder material and will notice a burned cordite smell. 11. Continue running the chisel point bailer until you have determined that the bailer is striking down on the firing pin. 12. On each trip in and out of the hole, keep a careful watch on the fluid level in the production string in order to observe any increase or decrease in the fluid level. 13. If the bailer bottom appears to be striking any hard material other than the firing pin, an impression block should then be run in order to determine the obstruction that is keeping the bailer from the firing pin itself. 14. If you have determined that the firing pin has been struck and there is no indication of the guns firing, come out of the hole and rig down the slickline unit. POH and LD guns. Depending on the cause of the misfire, a decision will be made to perforate interval using casing guns or to re-run tubing conveyed guns. JHFA/0318.2 _{ 9 ATTACHMENT H PROPOSED COMPLETION EQUIPMENT DETAIL SHEET NGS C41-23 6/17/87 NO. ITEM APPROXIMATE TVD. MD. PSI OR 1. GAS LIFT MANDREL #1 2. ?" HYDRAULIC PACKER 3. GAS LIFT MANDREL #2 4. 7" HYDRAULIC PACKER 5. GAS LIFT MANDREL #3 6. 7" HYDRAULIC PACKER 7. GAS LIFT MANDREL #4 8. 7" PERMANENT PACKER 9. OTIS "XN" NIPPLE 7994 897O DUMMY 8021 9000 8111 9100 OR 8244 925O 8445 9475 OR 8555 9600 8902 10000 DUMMY 9037 10160 9045 10170 CASING 10 3/4", 40.5#, BUTTRESS 0 1653' 7" 26-29#, N-80 BUTTRESS 0 10593' PBTD = 10,500' TD = 10,593' TUBING 3 1/2", 9.3#, N-80 EUE, AB-MOD PERFORATED ZONE GROSS INTERVAL GN-GO GR-GS HC-HN tIN-HR HR-HZ HR-HZ 9087-9108' 9450-9495' 9706-10147'(SQUEEZED) ]0180-10235' 10254-10316' 10340-10480' June 24, 1987 Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 Gentlemen: SUBJECT: SUBMISSION OF SUBSEQUENT REPORT OF SUNDRY WELL OPERATIONS FOR MIDDLE GROUND SHOAL WELL C 41-23 Enclosed is the Report of Sundry Well Operations for the shut-in of the Middle Ground Shoal well No. C 41-23. The report is submitted in duplicate. If questions arise, contact Susan Brown at (907) 263-9613. V~r~.~ truly yours, I~ Managq~r/, Regulator~ Affairs AlaskavDivision SBB/kka Enclosures RECEIVED JUL- 6 1987 Alaska 0il & Gas Cons. CommissJorl Anchorage SBBF/a.SRSWO .~..~,. STATE OF ALASKA ' '. ALA,_. iA OIL AND GAS CONSERVATION COM,v, IssION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown E]( Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator Shell Western E&P Inc. 3. Address 601 West 5th Avenue, Suite 810, Anchorage, AK 99501 4. Location of well at surface Platform C, Leg 4, Conductor 28. Center of Leg I ~ 541.65'N & 1596.41'W from SE corner of 5. Datum elevation (DF or KB) 105' DF 6. Unit or Property name Middle Ground Shoal 7. Well number C 41-23 At top of productive interval Sec. 23, 3827'N & 567'E of surface location At effective depth 41 93'N & 337'E of surface location At total depth 4270'N & 289'E of surface location T8N, R13W, S.M. 8. Approval number 6-626 9. APl number 50-- 733-20163 10. Pool "G" Pool Feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10,71 2 ' feet 1 0,1 47 ' feet feet 10,269' feet Plugs (measured) Junk (measured) Casing Length Structural Conductor Surface I, 653' Intermediate 10,593' Produotion Liner Perforation depth: measured 9087-10,477' true vertical Size Cemented 1 0-3/4" 7", , 40.5#, J-55 26-29#, N-80 8 intervals Tubing (size, grade and measured depth) 3-1/2", 9.3#, N-80 EUE (~ 10,810' Packers and SSSV (type and measured depth) packers set at 9029', 9651 ', 9781 ' , 10001', 10148' Measured depth True Vertical depth 1350 sx 1,653' 10,593' RECEIVED JUL- 6 ]987 Naska 0il & Gas Cons. Commission A~chorage 12. Stimulation or cement squeeze summary top packer. Set RBP at 8,996'. Intervals treated (measured) 8,866 ' Killed well w/ 11 ppg CaC1 Capped with 700# sand and 100' Shut in well and demobilized. · Pulled tubing above of cement. TOC at Treatment description including volumes used and final pressure 13. Prior to well operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Well was shut in. Casing Pressure Tubing Pressure Subsequent to operation Shut I n. 14. Attachments Daily Report of Well Operations ~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ / ~.."- //'---¢~D~ Form 10-404 Rev. 12-1-85 Title Produe~.inn S u .n ~. r i n iz. ~. n d ~. n iz. Date 6/~n/R7 Submit in Duplicate EP-]O00 ' OTNA WELL NAME: C41-23 DAILY DRILLING REPORT Shill Oil Company Western E & P Region 10,535' · ' ' 'Depth"Or PBTD DAYS: E:stimeted /. STATUS: Footage Gut / Report Day No. Ahead (+) Behind DIV.: DATE: 1/3/87 RIG: SHELL "C" Junk Ca 10,270' 7 "e 10,593' Size & Depth Last Csg Prog. Depth I I I W.I...c.c. Cl-mg/I. LCM4b/bbl. OI1-% hrs, Conduct Safety Meeting w/all crews - .561 10.8 MUD: / / / Gradient-psi/ft. Wt.-ppg. Vls.-~c. Additional rib)Mt: Crews arri Ye .. Ca 1 ocation @ .08' O0 Logging. torin~ and Orientation w/same! 1/2/87 22 hrs. Mobilize Rig, R/U Mud Pumps, Drawworks, water lines~ Repair Mmenting, Io~s of I~rm~lmtion, repairs*, ~hokin~", f~hing*, Air ~ Lines, Service Controller, R/U Choke BOPE, Clean & Service Accumulator, R/U Divertor Manifold, R/U 6" Gas Buster Line to Pit, Mix CaCl? to 10.8 ppg. · '*show hours Surveys: CC)ORD. LAST STATION: End of Dally Wire T / / / M.D. Drift L I ,I I I Direction T.V.D. V. Sec. N or S E or W ADDITIONAL I I Plastic VIs. 'Yield MUD PROPERTI ES: / / Pm Pr/Nil DR ILL)NG ASSEMBLY: Gel ~10 Sand I I I I pH HY.-HP. FII C~ke ECD / / / Solids Ca/Mg Ppm Bent.-Ib/bbl. liT RUNS , MUD ADDITIONS Run Number Bar- Size-Make Gel - Dbmond ' Ca Cl 2 Type/Size . I:~th Out , . . TIB Gauge JU. ~ ]907 Bit Wt. ~pM ' ' 'Naska 0ii &Gas Cons. C0mmissi~ ........ ' ..... !' ! ,nc;i0i-a~o ....... C~Ft. .... . , n 'Pump Liner 6-1/2 "Stroke 10 ". For Air4;es Show CFM COSTS (As of ) Mud Mud Cost This Date 8144 Time-Date AI.._~.r .Water Total Mud Cost - wa. co, t 22,619 This Date Total 2 2,619 Well Co~t · Over (-) Under (+) Target R. L. Anderson Shell Foremen £p.:ooo DTNA WELL NAME: 1'0,535' DAYS: C41-23 Depth or PBTD 11 / Estimated DAILY DRILLING REPORT Shell Oil Coml~ny Western E & P Region RIG: DIV.: /~ i dSKd DATE: 1/4/87 SHELL "C" /. STATUS: Junk Ca Footege Cut 2 / - 7 "e 10~593' · Report Day No. Ahead (+) Behind (--) Size & Depth List Csg Prog. Depth MUD: · 561 / Gradient-psi/ft. 18 hrs. Additional report: 10.8 i / i i / Wt.-ppg. Vls.-sec. W.L..-c.¢. Cl-mg/I. LCM-Ib/bbl. 011-% R/U choke manifold, service BOPE, R/U gas buster line to pits Logging, coring, DST'e, casing, 6 hrs. Mix CaC12 to 10.8 ppg, R/U Arctic Coil Tbg. Unit. Pressure Test Coil Tbg and Lubricator T/2500 psi, RIH w/1¼ oementing, Ios~ of ¢lrculatlon, repairs', choking~, fishing", Coil Tub. T/10005', Attempt to kill well by pumping thru Coil Tubing Ca I BPM Rate Ca 3500 psi, Take Return to Separator 'H2S present Ca Surface, Max 1200 ppm · '*SHOW hours 24 hrs. Surveys: COORD. LAST STATION: End of Dally Wire M.Do / I I I .I I I Drift L Direction T.V.D. V. Sec. N or S E or W ADDITIONAL MUD PROPERTI ES: Plastic Vis. Pm DRILL}NG ASSEMBLY: I / I I I I 'Yield Gel O-10 pH HY.-HP. FII Cake ECD I i I I I Pf/Mf ~and Solids Ce/Mg ppm Bent.-Ib/bbl. )IT RUNS MUD ADDITIONS COSTS (As of Run Number Bar- ,.. Size-Make Gel - , Diamond Type/Size CaCl ,,, Depth Out ,Footage T/B Oeuge J~ iL -- ~, lC~O'7 Bit Wt. ~k~ gll idb bUilb, bgiililll3btU RPM PSI GPM' J J ~Cost/Ft. Mud Cost This Date Total Mud Cost · Mud Time-Date Air I Water Well Cost This Date Total Well Cost Over (-) Under (+} Target R. L. Anderson Shell Foreman 'Pump Liner "Stroke ", For Air-Gas Show CFM [P.]OOO DTNA · · C41-23 10,535' Depth or PBTD DAYS: 11 i Estimated DAILY DRILLING REPORT Shell Oil Coml~ny · We~ern E & P Region DIV.: 1/5/87 DATE: RIG: SHELL "C" Junk Ca 10,270' · _ STATUS: "/ Footage Cut 3 / - 7 ..e~ 10,5:g3' · Report Day No. Ahead (+) Behind (--) Size & Depth List Cig ProB. Depth MUD: .561 Additional report: Logging, coring, DST'a, easing, cementing, loss of circulation, rapairs*, ~hoking*, flshing*, Oradlent*pslZft. 13 / 10.8 / / / / / Wt.-ppg. Vis.-lec. W.L.-c.c. Cl-mg/1. LCM-Ib/bbh OI1-% hrs. Displace Annulus of 10.8 ppg Ca,C12 , Take returns to separator, fluid out to 10.2 ppg 80-400 ppm H2S shot in well for volume. hrs. Take on 500 bbls. fresh water, Hix CaC12 to build wt to 10.8 ppg 'eShow hours 24 hrs. Surveys: COORD. LAST STATION: End of Dally Wire ! I I I ,I I / M.D. Drift L Direction T.V.D. V. Sec. N or S E or W ADDITIONAL I / MUD Plastic Vis. 'Yield PROPERTIES: / / Pm Pr/Mr DRILL}NG ASSEMBLY: I / / I Gel O-10 pH HY.-HP. FII Cake ECD I I I Sand Solids Ca/IVlg ppm Bent.-Ib/bbl. BIT RUNS . MUD ADDITIONS Run Number Bar- Size-Make Gel - 'Diamond Type/~ize ~,aC1 2 540 , D.pth Out Footage ...... Ho~rs RECEIVED TIB G~uge JUL 6 1.9~'/ Bit Wt. ;RPM Alaska Oil & Ga,, Cons. Commission PSI GPM" Cost/Ft. COSTS (As of Mud Cost This Date Time-Date .,Mud AI....~r Water Total Mud Cost · Well Cost This Date Total Well Cost Over (--) Under (+) Target R. L. Anderson Shell Foreman 'Pump Liner "Stroke ", For Air-Gas Show CFM EP-1000 (l-TS) DTNA WELL NAME: 10,535' DAYS: MUD: C 41-23 DAILY DRILLING REPORT ~hell Oil Company Western E & P Region D~pth or PBTD Estimated .572 G radlent-psU'ft. . Report Day No. Wt.-ppg. STATUS: Footage Cut DIV.: DATE: ALASKA , 1/6./87 RIG: SHELL "C" Junk @ 10,270' 7 "e10,593' Ahead (+) Behind (--} Size & Depth List Cig Prog. DePth I I I I I VJs.4ec. W.L_-~.c. Cl-mg/I. LCM-Ib/bbl. 011-% Additiorml report: Log~lr~, goring, DST's, ~=sing, eernenting, loss of circulation, rapalr~, ehoklng~, fishing*, 4½ hrs. 8½ hrs. Build CaCl2 Volume to Wt up same to 10.8 PP9 Circ. thru Coil tbg. @ I BPM Rate @ 3600 psi, take returns thru 7" Csg CaC12 Fluidcut to 10.1 ppg. 125 ppm H2S~ Shut in well (375 psi Tbg) (300 psi csg) 1½ hrs. Wt up Surface System to 11.0 ppg 9½ hrs. C~rc. 11.0 ppg down CT Return @ I BPM Rate w/3650 psi, Fluid cut ·'*show hours to 10.5 ppg. up on Tbg. & No H?S @ surface. Stop circulation, Open well csg. Vacuum on well. Hole take 8 bbls/hr rate. Surveys: COORD. LAST STATION: End of Dally Wire M,D, Drift L I I .I I Direction T.V.D. V, Sec. N or S I EorW ADDITIONAL I Plastic Vis. 'Yield MUD PROPERTIES: / Pm Pf/Mf DRILLING ASSEMBLY: I I I I Gel O-10 pH HY.-HP. FII / / Sand Solids Ca/Mg ppm Ca ka / ECD Bent.db/bbl. 3IT RUNS . MUD ADDITIONS COSTS (As of . . . Run Number Bar- ,. Size-Make Gel - Diamond Ca Cl 2 Type/~ize Depth Out Footage T/B w,. J U L - RPM ~,,,u~ nil & R~.~ Co ~s. Commissiorl / :PSI GPM*I Anchora: le CmUFt. ...... Mud Cost This Date ,Mud Time-Date AI._.~r Water Total Mud Cost · Wall Cost This Date Total Well Cost Over 1--) Under (+) Target R. L. Anderson Shall Foreman EP.]000 · DTNA WELL NAME: 10 ~'535 ' DAYS: MUD: C 41-23 Depth or PBTD 11 Estimated .572 Ora dlent-pslZft. Report Day No. / 11.0 wt.*ppg. Additional r~mrt: DAILY DRILLING REPORT Shell Oil Company Western E & P Region - - STATUS: Footage Cut Ahead (+) Behind (--) RIG:. .. DIV.:L ALASKA DATE: 1/7/87 SHELL "C" Junk @ 10~270' 7 "p 10,593' Size & Depth Last Csg Prog. Depth 1 hr. I I I Vls.-r~c. W.l..-c.c. Observe well,HOLE Taking 8bbl/Hr Rate 258,000 CI-mg/I. L. CM-Ib/bbl. OI1-% Logging, ~orinli, 4 hrs. POH W/Cai 1 Tbg. DST'i, c~sing, oementing, loss of ctrcubtion, repairS', 1½ hr. Displace CaC12 w/Diesel ½ hr. R/D CTU in Coil Tbg. choking", fishing", 2½ hrs. N/D Tree, Inspect Tbg. Flanger (bad threads) N/U Tree 2 hrs. llon'itor uell, well stabilized (static) '·show hours 2½ hrs. Circ. Thru 3~"' Tbg, Return to 7" Casing, Lost 11 bbls I hr R/U APR, RIH, Cut 3 1/2"@ 2009', POH R/D Same 6 hr N/D Tree, i,l/U BOPE, Surveys: I hr 2 hr M./U Tri-State Spear, RIH, Latch Hanger, Pull Same POH L/D 3½" Tbg. COORD. LAST STATION: End of Dally Wire I I / ,I I I M.D. Drift L Direction T.V,D. V. Sec. N or S E or W ADDITIONAL I I Plastl~ Vis. 'YMId MUD PROPERTIES: / / Pm Pf/Mf DRILLING ASSEMBLY: I I I I Gel O-10 pH H¥.-HP. FII Cake ECD I I I Sand Solids Ca/Mg ppm Bent.-Ib/bbl. BIT RUNS . MUD ADDITIONS COSTS (As of Run Number Bar- Size-Make Gel - Diamond ' :a C Type/Size 2 · Depth Out Footage I<LLEiVLL iTIB Gouge Bit Wt. Alaska 0il & (as Cons. Commission ~RPM ~ mllora2e PSI GPM' Cost/Ft. Mud Cost This Date Time-Date ,Mud, Air, Water Total Mud Gost· Well Cost This Date Total Well Cost Over (--) Under {+) T0r~t R. L. Anderson 5hell Foreman *Pump Liner "Stroke ", For Air-Gas Show CFM DTNA WELl. NAME: C 41-23 10,535' ~ Depth o~PBTD DAYS: 11 I 6 Estimated MUD: Additional report: Logging, coring, DST'i, casing, cementing, loss of circulation, repairS", choking~, fishing*, Report Day No. hours ~hell' Oil Company Western E & P Region G ,a~JFe!~-psl[ft. / 3 Footage' Cut STATUS: Ahead (+) Behind (--) DATE: 1/8/87 RIG: Shel 1 "C" Junk @ 10,270' 7'm 10,593' Size & Depth LAst Csg Prog. Depth ._ 1111 I I I I W[.:p-pg. Vls.-iec. W.L.-c.c. Cl-mg/I. LCM-Ib/bbl. 011-% ~*~n~ch I/Il q~," TI~C M/U Tri-state Spe. ar, RIH T/2009', Attempt to latch top of ~Dg., Could not L IDg. split 3' down from cutting) , PO~ 6 6 L/D Spear. iq/U Tri-state Overshot Rill, Work down over top .of'Fish I/D . Ov~r.~hnt: £irc rlnwn Thg POH L/D 3½" Tbg., R/D Tbg. Tongs I";/U Bi L & Scrdp~r, Rill WiD.P. Ti2000' RIH: P/U 31" D.P. T/gO(lO' .(2~' Fill po~_~ihl~ Present OPeration Circ. Mix HEC pill! ~0H Surveys: COORD. LAST STATION: End of Dally Wire / I I ,I M.D. Drift L Direction T.V.D. V. Sec. / Nors I EorW ADDITIONAL I / Plastic Vis. 'Yield MUD PROPERTIES: / / Pm Pf/Mf DRILLING ASSEMBLY: I I I I Gel O-10 pH H¥.-HP. FII / / Sand Solids Ca/Mg ppm Cake I ECD Bent.-Ib/bbl. BIT RUNS . MUD ADDITIONS COSTS (As of Run Number Bar- ,,, Size-Make Gel ..... '" 'Diamond Type/Size , , , ~h Out Footage TIB G~u~ _ JUL- 6 1987 Bit W~. ... " NaSka 0il & Ga~ C'0ns] Commission ,,. 'Pump Liner "Stroke "For Air-Gas Show CFM · Mud Cost This Date Mud Time-Date Air Water Total Mud Cost - Wall Cost This Date Total Well Cost Over (-) Under (+) Target R: ,L ....Anderson Shell Foreman DTNA WELL NAME: C 41-23 8,881'T0C I. Depth or PBTD DAYS: 11 ! 7 Estlmatad Report Day No. MUD: 5 9 I "0 ra¢llenT-~sl/fl. ~.1-1~0~. Additional rq)ort: shell Oil Compiny Western E & P Region STATUS: Footage Cut Ahead (+) Behind (--) DATE: 1/9/87 RIG: Shel 1 "C" ~ 10,.,593' SIze & Depth Last Csg Prog. Depth I I I I I Vts.-~c. W.L.~.c. Cl-mg/I. LC M-I b/bbl. OI1-% Lofting, coring, DST's, casing, eernentlng, loss of eircubtion, repairs', ebbing', fishing', · '*show hours S u r vey ·: 3 hrs 3 nrs 6 h_~s 3~ hrs 2½ hrs ....... L ½ iii' 2~ hrs 3 hrs Circ .Hole clean FOOH, L/U Bit & Scraper M/Il Mnrl~l 'mKIi' 14nl~k,,v,+nn DRp, I~TI-I Cc~+ ]~p,D /~1 .qoQ~' D/Il B.J., Test Lines T/2500 psi, Pump 700 lbs sand, Well Fiow Back, P/U .Pump Dnwn n=P_~ Tag ~an~ e 8972' (24') Circ Repair Suction Valves on B.J. Pumps, Test Liner to "2550 psi, Pump 25 bbis water ahe6d, Pump i4 sx class "G:: cement followed by 7.5 hhl~ watpr= displaced W/BR hhl~ CaClz ruun, T/8866', Reverse out (No CMT) Mix and PU~D Barack A & Para Formaldehyde inhibitor L/D 3,1/2" D.P. COORD. LAST STATION: End of Dally Wire ! I I / ,I I M.D. Drift L Direction T.V.D. V. Sec. N or S I EorW ADDITIONAL I I MUD Plastic Vis. 'Yield PROPERTI ES: i i Pm PfZMf DRILL)NG ASSEMBLY: I I I I Gel 0-10 pH H¥.-HP. FII / I Sand Solids Ca/Mg ppm Cake / ECD Bent.db/bbl. BIT RUNS . MUD ADDITIONS Run Number Bar- .... . Size-Make Gel - Diamond Tv~ize Baracor-A ,2 drr D~pth Out Para Formaldeh' ,,, r~ 5 ~X TIB G~ .,,w,. RECEIVED RPM ~S~, GPM' " J L - 1987 c~Ft. j Nas~ Oil & Gas ',OHS. Commission · --~ , , , ~lgllg ~UU 'de *Pump Liner "Strolm ", For Air-Gas Show CFM COSTS (As of Mud Cost This Date Mu__.¢ Time-Date AI.._L I Water Total Mud Cost - Well Cost This Date Total Well Cost Over (-) Under {+) Target , ,, . _r_ L: Anderson Shell Foreman EP-]000 D'tNA WE L-~. NAME: L//'~IL! IJrtlI. LII11~.~ nLrv~l Shell Oil Company ~' ~Western E & P Region C 41-23 DAYS: 8,881 ' T0C i STATUS: he,th'or PBTD Footaga Cut 11 / 8 i +3 Estimated Report Day No. Ahead (+) Bahlnd (--) RIG: DATE: 1/10/87 Shel 1 "C" ?"e 10,593' Size & Depth Last Csg Pr~. Depth MUD: .572 I 11 _fl I I G radlent-psllft~ Wt.-pPg. Vis.-sec. I I I W.L.<.c. Cl-mg/I. LCM-Ib/bbl. 011-% Additional report: POOH L/D 3½" D.P. R/D Choke Manifold P/U 'Diu-Lu9 C~9 Cailper Log;" Log F/8875' 'to Surface Loggers N/D BOPE & N/U Production Tree Clean Rig-'& De,,,ubil ize Ri9 · '*show hours c.vv hi~$ I/ Surveys: COORD. LAST STATION: End of Dally Wire I I I ,I I M.D. Drift L Direction T.V.D. V. Sec. N ors / EorW ADDITIONAL I I Plastic Vis. 'Yield MUD PROPERTI ES: / / Pm Pr/Mr DRILLING ASSEMBLY: I I I I Gel O-lO pH HY.-HP. FII / I Sand Solids Ca/Mg ppm Cake / ECD Bent.-I b/bbl. tiT RUNS . MUD ADDITIONS COSTS (As of . , Run Number Bar - ,. Size-Make Gel - Diamond .' Type/Size Baracor-A i drl Depth Out .. Footage , Hours 1 ! REqEI\ ED - ,T/B Gauge :Bit Wt. jUL '6 1,987 RRM I ~aska Oil ~'GasCo ts. Commission PS1 GPM' I C~t/Ft. .... *Pump Liner "Stroke ", For Air.as Show CFM Mud Cost This Date Time-Date Mud_ Air Water Total Mud Cost - Wall Cost This Date Total · Wall Cost ' Over (-) Under (+) Target · R.L. Anderson Shall Foreman December 12, 1986 Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 Gentlemen: SUBJECT: PROPOSED SHUTDOWN OF MIDDLE GROUND SHOAL WELL C41-23 Enclosed is an Application for Sundry Approval for the Middle Ground Shoal Well C41-23. The application is submitted in triplicate. The work is estimated to commence December 18, 1986. .If you have any questions, please contact Susan Brown at (907) 263-9613. Very truly yours, M~na~/'r~ ~ ~ 1 a~ory Affai AlasRa Division ~ rs SBB/kma Enclosures RECEIVED Alaska Oil & Gas Cons, Commission Anchorage SBBD/1210a , ~""~ STATE OF ALASKA ALASNi, OIL AND GAS CONSERVATION COMrv,._.SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon r'~i Suspend [] Operation Shutdown J~ Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) Shell West,ern E&P ];nc. 105' DF feet 3. Address 6. Unit or Property name 601 West Fifth Avenue, Suite 810, ~chorage, Alaska 99501 Middle Ground SHoal 4. Location of well at surface Platform 'lCll, Leg 4, Conductor 28. Center of Leg 1 @ 541.65'N & 1596.41 'W from SE corner of Sec. 23, T8N, R13W, S.M. 7. Well number C 41-23 At top of productive interval 3827'N & 567'E of surface location At effective depth 4193'N & 337'E of surface location At total depth 4270'N & 289'E of surface location 8. Permit number 68-112 9. APl number 50--733-20163 10. Pool "G" PO01 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10,712' 10,147' 10,535' feet Plugs (measured) feet feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 1653 ' 10,593' Size Cemented 10-3/4", 40.5#, J-55 7", 26-29#, N-80 measured 9087-10,477' true vertical (8 intervals) Tubing (size, grade and measured depth) p3a-.1/2" 9 '~ N-80 EUE @ 10,810' cKers and ~'~] (type and measured depth) packers set. @ 9029', 9651', 9781' , 10001', & 10148' Measured depth True Vertical depth 1350 sx 1653' 10,593' RECEIVED 1 2 1986 Oil & G~s Con, s. Com, n~ission 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation December 18. 1986 14. If proposal was verbally approved Name of app,~, r Date approved 15. I hereb~ert f~hat~he//u/.4 ~,/ foreg~jj~i.is true and correct to the best of my knowledge Signed /! Title Division 0perat.ions Manager Date 12/1 1/86 Conditions of approval Approved by Commission Use Only Notify commission so representative may witness [] Plug integrity I Approval No. [] BOP Test [] Location clearance ~'~ g ' ....... Dy order of ~ ~ } Commi one comm . o. / E- Form 10-403 Rev 12-1-85 Submit in triplicate JUSTIFICATION FOR SHUTDOWN OPERATION MIDDLE GROUND SHOAL FIELD C41-23 The current economic climate dictates that C41-23 be temporarily shutdown. It is currently shut-in with pressure on the injection and surface casing. Properly shuting in this well will eliminate a potentially hazardous situation and will allow for a future economic recompletion. The well is located in a good structural position to recover over 600 MBO of additional reserves when it is returned to service. Permanently abandoning it and redrilling a new well at this location at a future date is not justified. Approval of this shutdown and the future return to service of this well will help maximize reserve recovery in this area of the field and correct a potentially hazardous situation. JHFA/1211b SHUTDOWN OPERATION MGS C 41-23 12/11/86 STATUS: Shut-in 6/13/86 with hole in tubing at 376' and pressure on 10-3/4" x 7" annulus. 10-3/4" casing pressure = 425 psi 7" casing pressure = 850 psi tubing pressure : 850 psi KILL WEIGHT: lO.8#/gal with 100 psi margin (assume pressure from HC-HD) WELL DATA: TD : PBTD = 10,712' (F.C.) 10,535' (Baker RBP junk @ 10,270') maximum hole angle is 31.4° at 4,090' TUBULARS: 10-3/4", 40.5#/ft, J-55 @ 1653' with 1350 sx 7", 26#/ft, N-80 @ 8450' · 29#/ft, N-80 8450-10,593' W/900 sx MECHANICAL: see attached Tubing Detail sheet PERFORATIONS: Zone TOp (TVD) GN-GO 8088 GR-GS 8423 HC-HD 8648 HC-HD 8648 HE-HF 8766 HI-HK 8863 HK-HN 8910 HN-HR 9026 HR-HZ 9169 HR-HZ 9169 Interval (M~) 9087-108 9450-495 9706-720 9733-764 9842-886 sqz cemented 9954-993" " 10003-147 10180-316 10340-438 10462-477 RECEIVED 1 2 1986 Alaska Oil & Gas Cons. Commission Anchorage JHFA/1211b OPERATION' le 2. 3. 4. 5. Page 2 Make tubing cuts between packers. Mobilize rig. Kill well with coiled tubing unit. Pull tubing above top packer. Set RBP above pay intervals capped with 30' of sand and 75' of cement. REFERENCE LOG' SOS Tracer Survey 2/12/79 NOTE' HeS up to 1600 ppm is present in theAinjection water. D~tection equipment and emergency air pack will be located on the rig floor. PROCEDURE le RU E-line with 2.70" Jet Cutter. Pressure test lubricator using 1" line from offsetting injection well to 2500 psi. RIH and tie into REFERENCE LOG and make cut at following depths' RUN NO. CUT DEPTH PACKER DEPTH I 9997 10001 2 9774 9781 3 9646 9651 4 9024 9029 Report condition bf each spent cutter on Morning Report. ECE VE5 1 2 1986 0il & Gas~,Cons-,,on Com,~iss[on JHFA/1211b NOTE' NOTE' Page 3 Monitor all returns closely for H2S and crude oil. Take returns to on-deck tank if H2S or crude is present. 2. Mobilize rig. RU 1-1/4" CTU with bull-nosed jetting nozzle and test lubricator to 2500 psi. RIH at 80 ft/min. With EOT at 10,100', kill well by circulating down CT, taking returns from 7" annulus with lO.8#/gal CaCle brine (143# CaCl per BBL,; Brine is to be mixed in f~'esh water. When ~ull weig..~ brine returns are achieved, shut in annulus and take returns up tubing. Monitor well. Increase weight if necessary. POH, keeping hole full. RD CTU. 3. Set BPV in tubing hanger. ND tree. NU BOP and test. Pul 1 BPV. 4. Screw into dough nut. RU E-line and make tubing cut with 2.7" cutter at 2000'+. Pull and lay down tubing. RIH with 3-1/2" 13.3#/ft drill pipe with overshot and jars. RD E-1 ine. 5. Fish tubing to tubing cut at 9024'. 6. RIH with 6" bit and scraper on 3-1/2" drillpipe and clean out to at least 9000'. Use HEC pills as necessary to clean wellbore. POH. 7. RIH with RBP for 7", 29#/ft casing on drillpipe and set 10' above lowest clean out point. After release, test set by slacking off 10,000# weight on top of RBP. Spot 7 sx (30') of sand on top of RBP. 8. RU cementing service. With end of drillpipe on top of sand plug mix and pump the following 75' balanced plug of 15.8#/gal Class "G" cement- Cement mixture will be tested prior to operation for compatibility with lO.8#/gal CaC12 brine. 5 BB1 fresh water 14 SX cement 5 BB1 fresh water To spot a balanced plug, with the end of drillpipe above sand plug, displace tail of cement with 5 BB1 fresh water and 59.1 BB1 of workover fluid. POH 100' and reverse out any excess cement. Circulate inhibited CaCl2 fluid as specified by Anchorage Production Engineer. POH laying down drillpipe. 2 1986 ~.;_~ JHFA/1211b Ancho~'ag~ ® 10. Page 4 RU E-line. Run 5-3/8" 64 finger Dia-Log casing caliper from 8850' to surface. RD E-line. Evaluate log and determine depth of hole(s) in 7" casing. POH laying down drill pipe. ND BOP. NU wellhead. Pickle rig. RECOMMENDED APPROVED: ~- DATE: 12- ~ ~ ~ ..... D',:_"C ! 2 1986 Oil & G~s Cons. '"'~-'~"' JHFA/1211b MIDDLE GROUND SHO~,,''''~ SHUTDOWN OPERATION C41-23 12/11/86 PRESENT CONDITION PROPOSED SHUTDOWN C'ONDITION 9087 10477 --SHALLOW HOLE IN 7' ~10-3/4' AT 1653' 3-1/2' TUBIN~G W/ HOLE BETWEEN 176' - 1900' 'TOC AT 7760' 10.8 ,C/GAL INHIBITED 'CaCI2 TOC AT 8895' -. PACKER AT 9029': PACKER AT 9651' PACKER AT 9781' PACKER AT 10001' 30' SAND RBP AT 9000' TBG CUT ~ AT 9024' TBG CUT AT 9646' TBG 'CUT~ AT 9774' TBG CUT ~ AT 9997' PACKER AT 10148' EOT AT 10180' ,2 ~£C I 2 !986 0il & O3s Cons. Gomml 7' AT 10593' ~ALL TUBING CUTS NECESSARY FOR SUCCESS OF FUTURE PLANNED WORKOVER /¢% STATE OF ALASKA ALASK[i 31L AND GAS CONSERVATION COMk lION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown '- Re-enter suspended well ~,' Alter casing -' Time extension ~ Change approved program ~ Plugging ~ StimUlate-_ Pull tubing ~ Amend order ~ Perforate [-_' Other 2. Name of Operator , Shell Wes, i;ern E&P In¢, 3. Address 601 West, Fifth Avenue, 5uit,e 810, Anchoracje, Alaska 99501 4. Location of well at surface Platform "C", Leg 4, Conduct,or 28. Center of Leg 1 @ 541.65'N & 1596.41'W from SE corner of Sec 5. Datum elevation (DF or KB) 105' DF 6. Unit or Property name Middle Ground Shoa] 7. Well number C 41-23 feet 'At top ot productive in'te~'val 123, T8N, R13W, S.M. 3827'N & 567'E of surface ]ocation At effective depth 4193'N & 337'E of surface location At total depth 4270'N & 289'E of surface locqtion 11. Present well condition summary Total depth: 8. Permit number 68-112 9. APl number 50- 73,3-20163 10. Pool "G" Pool measured 10,712 ' feet Plugs (measured) true vertical feet Effective depth: measured 10,535' feet Junk (measured) true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth 1653' 10-3/4", 40.5#, J-55 BTC, 1350 sx @ 1653' 10,593', 7", 26-29#, N-80 BTC,@ 10,593' True Vertical depth measured 9,087' - 10,477' true vertical Tubing (size, grade and measured depth) 3-1/2", 9.3#, N-80 EUE @ 10,180' Packers and SSSV (type and measured depth) packers set. @ 9029', 9651', 9781'. 12.Attachments Description summary of proposal 10001' & 10148' Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation Nnv~mhc_r 1'4, l_qR6 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge S.ignedy ¢/¢,/~. F '/~~,,-,. Title Production Super :i ntendent Commission Use Only Date 11/07/86 Conditions of approval Approved by Notify commission so representative may witness ~ Plug integrity ~ BOP Test ~ Location clearance ¢~,~ ~ ~ ~~-~o~'~ssioner Approval No. by order of the commission Date Form 10-403 Rev 124-85 Submit in triplicate MGS C 41-23 11/5/86 OPERATION: STATUS' KILL WEIGHT' 1. Run Tubing inspection log and find holes in tubing e All holes are shallow (<1000'), kill well by placing a weighted viscous pill across perforations and in tubing using a coiled tubing unit. Shut-in 6/13/86 with hole in tubing at 376' and pressure on 10-3/4" x 7" annulus. 10-3/4" casing pressure = 7" casing pressure = tubing pressure = 425 ps i 850 ps i 850 ps i lO.8#/gal with 100 psi margin (assume pressure from HC-HD) WELL DATA' TUBULARS' MECHANICAL' TD = 10,712' PBTD = 10,270' (Baker RBP junk) maximum hole angle is 31.4© at 4,090' 10-3/4", 40.5#/ft, J-55 @ 1653' with 1350 sx 7" 26#/ft N-80 @ 8450' 29#/ft, N-80 8450-10,593' see attached Tubing Detail sheet JHFA/1110 PROCEDURE 1.RU SLICKLINE UNIT WITH LUBRICATOR. TEST LUBRICATOR TO 2000 PSI USING A ]" LINE FROM AN OFFSETTING INJECTION WELL. MAKE A 2.75" DRIFT RUN TO ]0]80'. CARE MUST BE TAKEN WHILE RUNNING PAST HOLE IN TUBING AT 376'. POH. 2. IF TUBING DRIFTED TO ]0]80'. RIH WITH "PX" PLUG AND SET IN "X" NIPPLE AT 10165' OR ]0173'. RD SLICKLINE UNIT. 3. RU COILED TUBING UNIT WITH LUBRICATOR. PRESSURE TEST LUBRICATOR TO 2000 PSI. RIH 2.5" ROUNDED JETTING NOZZLE ATTACHED TO CT WITH SWEDGE-LOCK OR SIMILAR CONNECTION WHILE MAINTAINING A PRESSURE OF AT LEAST 500 PSI GREATER ON THE INSIDE OF THE CT THAN CT-TUBING ANNULUS. CARE MUST BE TAKEN WHILE PASSING THRU ANY SLICKLINE IDENTIFIED TUBINO HOLES. TAG PBTD. MOVE EOT UP ]0' AND CIRCULATE A ]00 BBL ]0.8~/GAL NaC1/CaC1VISCOSIFIED WITH HEC (60#/]000 GAL) PILL TAKING RETURNS TO CT-TUBING ANNULUS AND DOWN J-TUBE. VOLUME OF CASING BELOW EOT AND OF $ ]/2" TUBING IS 92 BBL. MONITOR RETURNS FOR H2S. IF RETURNS CONTAI~ UNSAFE AMOUNTS OF H2S, TAKE RETURNS OVERBOARD. MONITOR RETURNS FOR BRINE DENSITY. WHEN FULL WEIGHT BRINE RETURNS ARE ACHIEVED, STOP CIRCULATING AND MONITOR WELL FOR PRESSURE. WEIGHT UP AS NECESSARY TO KILL WELL. IF UNABLE TO KILL WELL WITH WEIGHTED PILL, CONTACT ANCHORAGE PRODUCTION ENGINEER. IF WELL IS DEAD,BEGIN POH. 4.WHILE POH CT, CONTINUALLY DISPLACE CT VOLUME WITH WEIGHTED PILL. MONITOR TUBING FOR PRESSURE. RD CTU. ~_~IR I~NDREL$ II MD. ~ i 1. ~995' DuIy 9688' Du~y 4. ~819° Dun~ny 10038' Dummy ~" 40.511 Buttress, 0-1653' 2511 #-80 Buttress, 0-8450' 2911 N-80 Buttress, 8450-10593' ~9.3t N-80 EU£ 0-~0~80' (336 aT) Perfs ~- 9108' GN-GO 9450- 9495' GR-GS 9706- 9720' HC-ND 9733- 9764' 9842- 9886' HE-HF sqz. 9954- 9993' H]-HK sqz. 10009-10147' HK-HN 10180-10235' HN-HR 10256-10316' " 10340-10370' HR-HZ 10396-10438' " 10445-10454' " 10462-10477' " .--NOTE***NOTE--- "Fish" in casing, Top 10,269'. (Baker retrievable plug less center rod ass'y) Page 89 C 41-23 PR£S£~ COMT'L£TI 0): Ia11 Valve e I ,s3" KBM 111 ~ 8995' ~. PBTD 10535' TD 10593' Unipacker VII e 9029' KBM 112 e 9066' Unipacker V!I e 9651' KBH ~3 e 9688' Unipac~er Vi I e Unipacker V11 ~ lOOOl' KBM 115 ~ 10038' Baker F-1 Packer & Seal g 10148' X-Nipple ~ 10165' X-Nipple 0 10173' Mule-Shoe Pup ~ 10180 (EOT) "Fish' Baker retrievable plug, less centr' rod assembly ~ 10269' ~ · Analysis of injection rate vs. pressures: As of 4/1/86 the injection pressure and annulus pressure were the same indicating tubing-to-annulus communication. 'About 5/1/86, while continuing at a constant injection pressure of about 3500 psi, the rate increased from approximately 3400 B/D to 4000 B/D on 5/10/86.. '. Subsequent operations: The well was shut in 6/13/86 with holes in the tubing at 376' and pressure in the 10 3/4' x 7" annulus. Workover 1/5/87 to · . 1/10/88. Set plug over top of perfs. Workover 9/12/87 to .·!0/12/87. Squeezed holes in casing at 2147. Ran packer and then 3~ tubing -- tested annulus to 1000 psig okay. Acid stimulated well returned to injection on 10/17/87. '0 00~- .! ood~- O00~- 00gg- 0008- OOg~- 000~- i OZ ~g :'6 OL/g 986L -0~/I~ 98~6~9- 9811.1:1' Ol./k . I ~ I I iI::IOISIH NOilO3rNI-IVOIHdVl::lO , 'i'" ,:'~_L~,:O : ,-' -000I, SCHLUMBERGER OFFSHORE SERVICES A Division of Schlumberger Limited .:~ HOUSTON. TEXAS 77OO1 SEPTEMBER' 19,1985 ,-~^., ,,P-Y To 500 ANCHORAGE, ALASKA 99558. ATTN: BETH CUZZORT SHELL WESTERN E&P INC. P.O. BOX 527 HOUSTON, TX. 77001 Attention: LOG FILES, WCK 4147 Gentlemen: Enclosed are 1BL printsof the PRODUCTION LOG Company SHELL WESTERN E&P INC. ,Well MGS C 41-23 Field. MIDDLE GROUND SHOAL ., County KENAI State ALASKA on: Additional prints are being sent to: 1BL nrints SHELL WESTERN E&P INC. P.O. BOX 527 HOUSTON, TX. 77001 ATTN: 'R.J.'-VALLEJO, WCK 11.3-/~ 1RFOLD_F.,D.~I~ /STATE'OF ALASKA / ALASKA OIL & GAS CONSERVA~ION'""COMM~ [ 3001 PORCUPINE DR. k~ANCHORAGE, ALASKA 9950~'" ~N: H.W. KUGLE~_ 2BL mrints SHELL WESTERN E&P INC. 601 W.FiFTi: AVE~SUITE ANCHORAGE, ALASKA 99501 ATTN' jOE FRAM 1MYLAR 1BL nrints' ARCO ALASKA INC. P.O. BOX 100360 ANCHORAGE, ALASKA 99501 ATTN' JOHN C. HAVARD 1BL nrints SHELL' PLATFORM "A" OR "C" -C/O SHELL KErf OFFICE NORTH STAR ROUTE #1 P.O. BOX 485 WIK RD. KENAI, ALASKA 99611 ~prints 1RROLLED SEPIA P.O. BOX 1078~9 ANCHORAGE, ALASKA 99510 ATTN: J.L. WEAVER prints The film is RETURNED TO SHELL (HOUSTON) We appreciate the privilege of serving you. . .C .XVED FGFIV f DATE~---~ ocr ~ 0 ~oo ~ Alaska Oil & Gas Cons. Commission Anchorage Very truly yours, SCHLUMBERGER OFFSHORE SERVICES DAVID RE_mOL DISTRICT MANAGER SOS--1565-A ~ STATE OF ALASKA ALASKA 0IL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE L LX[~ 2. Name of Operator 7. Permit No. Shel 10i 1 ComPany 68-112 3. Address 8. APl Number John Douglas, P.O. Box 4500, Kenai, AK 99611 5o_733-20163-00 OTHER [] 4. Location of Well Conductor 28, Leg 4, Sec. 23, T8N, R13W. 5. Elevation in feet (indiCate KB, DF, etc.) 106' K.B. 12. I 6 . Lease Designation and Serial No. ADL 18756 9. Unit or Lease Name HGS 10. Well Number C41-23 1 1. Field and Pool Middle Ground Shoal Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). PROPOSAL' Determine injection profile. 10/14/83 - Rigged up Dresser Atl~.~s. Ran spinner survey. 10/15/83- Ran radioactive tracer injeCtion survey. R.D. Al3ska Oit ,~ Gas" , 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,.ned The space below for Commission use Date 10/27/83 Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS COMPLETED WE LL ;1~( 1. DRILLING WELL [] Injector OTHER [] 2. Name of Operator Shell Oil Company 3. Address John Douqlas, P.O. Box 4500, Ke.nai, AK 99611 4. Location of Well Conductor 28; Leg 4, Sec. 23, T8N, R13W 5. Elevation in feet (indicate KB, DF, etc.) 106 :' K.B. 12. I 6 . Lease Designation and Serial No. ^DL 18756 7. Permit No. 68-112 8. APl Number 50- 733-.20163-00 9. Unit or Lease Name MGS 10. Well Number C 41-23 11. Field and Pool Middle Ground Shoal Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] . Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). See Attached. 14. I hereby certify that.the foregoing is true and correct to the best of my knowledge. signed ~(~,~/~ Title .Mgr. Pr0d. Admn. The space below for Commission use Date 10/4/83 Conditions of Approval, if any: Approved Copy Returned ORIGINAL SIGNED By Order of Approved by. BY ~.0N~I'[ ~, ~IT~ COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate AUTHORITY FOR EXPENDITU~ ,, PRODUCTION PACl FIC DIVISION HOUSTON P1 atform C - o,'a .,,,,. Middle Ground Shoal Field 9/22/83 Cook Inlet, ^laska ~r. LOCATION NUMBER ~RK SHELL'S 33 % SHARE ORDER ~PE DESCRIPTION ' ' NUMBER 1~ C~ BU~ N~-BU~ I~ i ii i i R&R 0b~a~n Prof~e [n~ec~on $]5,000 $5,000 $5,000 Survey ~n ~e~ C4~-23 Non 0pedagogs Approval ~o~ Eequ~ ~ed Requested by' ~. ~. Douglas T. S. Burns ~. Sus-~o~ $~ 5,000 $5,000 $5,000 i i i i i ~ I' LESS ' ~ 5 ~ 000 POSITION ' ' NEW CAPITAL FUNDS REQUIRED BY BUDGET REVISION TOTAL COST , 'I ' I I JUSTIFtCATION: See ~eched , , OCT Alaska Oil & Gas Cons. · Anchorage ~3m~issio CONTINUED i i ' ~ -RECOM M EHOED APPROV ALS Justification Injection Survey C41-23 Middle Ground Shoal Field Funds totalling $15,000 ($5,000 Shell's 1/3 share) are requested to obtain an injection survey in well C41-23. Platform "C", Middle Ground Shoal Field, Cook Inlet, Alaska. Well C41-23 was drilled and completed in January 1969 and was converted to injection in October 1969 with an initial rate of 5,000 BDW. As can be seen from the attached well history, C41-23 has been acidized several times to improve the'injection profile. The last injection survey run in February 1979 indicated a poor lower zone profile. The HK/HN(U) was taking 26% of the water and the HN/HR(U) was taking 28% of the water. No other zones below the HK was taking water. In October 1982, an adjacent injector A34-14 Rd2 was pulled and the HN/HR(U) thief zone was isolated. Since that time, the injection rate in C41-23 has steadily increased from 1300 BDW to 2100 BDW. An injection survey is necessary at this time to determine if the additional water noted since October 1982 is going into the HN/HR(U). The injection survey will also determine if a poor profile exists as it did in the last survey. It is likely that R&R action may result from one of the above-mentioned items if confirmed by the survey. Your approval is recommended TSB:mh Prognos i s Injection Profile Survey C41-23 Status: Injection 2100 BDW at 3500 psi. See attached completion details for perforations, sliding sleeves, packers, gas lift mandrel depths, etc. Objective: Determine injection profile. Procedure: le Rig up wireline and lubricator. Test lubricator to 3500 psi. Make drift run to bottom. Record on log heading. Rig down wirel ine. e Maintain constant injection rate of 3500 psi pressure for 3 days prior to and during the survey. Record on log heading. 0 Rig up service company's lubricator (high pressure - wireline), stuffing box, collar locator, continuous flow meter, and radioactive tracer with ejector and two radioactive detectors. e Tie into depths with collar locator in casing. Log perforated interval (9087'-10477') with CFM and determine profile for water leaving tubing or casing. e Use R.A.T. to determine profile behind tubing and vertical fluid movement behind casing. Ge Log tubing to surface with CFM to determine tubing leaks and/or fluid leaving tubing and re-entering at a lower location. If casing leaks are suspected, confirm and locate using R.A.T. 7. Rig down service company, continue injection T~~3h Appro~ ~ Date I<~Z) -- ~5 - ~S ~ M3 OF JU~f 29~ '5978 '~ 26// N-80 BUTRESS; o-~fo' ?' 2~// N-SO BUTTi~ESS 3-~~,' ~.3// N-SO O-:LO~80" (336 '~.) 087-9 ~ 108 ' ~O-9~ ~9~' GR-OS 7o6-9, ?20' ' 9~733-9~76~' 8142 ~9.~ 886 ' 954~9~993' HI-HK 10~ 009-t0~ ]~7 ' HK~ 105256-!0~316' ~-~ 10 ~ 3 }-$0-10 ~ 370 10~396210~h38' 10, l$62-10~ 477' HR-HZ i"FIS~{" IN CASING~ TOP @ !10 ~ ~69 ~-- ( BAKER RETRZEVABLE PLUG I'Y-SS CENTER ROD ASS'Y.) B]\LL VALVE @ 295 ' I · o · , i · · UNI-PACKER, VII ~ Kt~ J/2. O) 9,066, UNI-PACKER VII @ 9~651' KBM //3 ~ 9~688' . BAYR~R F-1 PACKER &'. 'SEAL @ 10,1[~8 ' X-NIPPLE @ 10~ 165] .. X-NIPPLE @ 10~173~ MU~-SHOE P~ ~ 10~180' (EOT.) '~IS~"BA=R =TEIEVAB~ PLUO~ i~SS ' C~TER ROD ASSemBLY, ~ 10~269~ *'"-,,. . / STATE OF ALASKA " ALASKA .,,C~AND GAS CONSERVATION CO~VllSSION SU[' DRY [ IOTIC S Ik:D WELLS DRILLING WELL I-1 COMPLETED WELL r~x OTHER 2. Name of Operator Shell Oil Company 3. Add,es, Production Superintendent 601 t'l. 5th Ave., #810, Anchorage, AK 99501 4, Location of Well Conductor 28, Leg 4 @ 38.14'S & 64.85'E frOm Center of Leg I @ 541.65'N & 1596.41'W from SE Corner, Sec. 23, T8N, R13W, S.U. , 5. Elevation in feet (indicate KB, DF, etc.) 105' D.F. 6. Le~5~es~.g~ and Serial No. 7. Permit No. 68-112 D. APl Number s0- 733-20163 9. Unit or Lease Name 10. Well Number C 41-23 11. Field and Pool MIDDLE GROUND Sti0AL "G" POOL 12. (Submit in Triplicate) Perforate [] Alter Casing I--J · Perforations Stimulate I-'1 Abandon Fl Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other I'-I Pulling Tubing (NoTe: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Dupl'icate) [] Altering Casing Abandonment Fl Other [] o [] 13. C)escribe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Proposed job cancelled.~~ t ECEIVED DEC I ~ 3982 a/aska 0ii & Gas Cons. Com~nission Anchorage Sig-.,,d ,, T.,o Production Administration The .~pace below lot Commission use Date 12/6/82 Conditions of Approval. if any; By Order of Approved by COMMISSIONER the Commission ~)ate Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Ouphcale STATE OF ALASKA ALASKA ~AND GAS CONSERVATION CC ,VIISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~X / ~v OTHER 2. Name of Operator SHELL OIL COMPANY 3. Address [']ayne Simpsen 601 W'. 5th Ave..: #810, Anchor. age~ AK 99501. 4. Location of Well Conductor 28, Leg 4 @ 38.14'S ~ 64.85'E 'from Center of Leg I @ 541.65'N & 1596.41'W from SE Corner, Sec. 23, T8N, R13W, S,M. 5. Elevation in feet (indicate KB, DF, etc.) 1051 D. F. 12. J 6 . Lease Designation and Serial No. ADL 18756' 7. Permit No. 68-112 8. APl Number so_ 133-20163 9.r~ or Lease Name 10. Well Number C 41-23 11. Field and Pool MIDDLE GROUND SHOAL "G" Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate r"l Alter Casing [] ~ Perforations [] Altering Casing [] Stimulate ~ Abandon r"l Stimulation [] Abandonment I"1 Repair Well [] Change Plans [] Repairs Made [] Other ["1 Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-40~ for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). SEE ATTACHED RECEIVED NOV 0 4 1982 Alaska 0ii & Gas Cons. C0mffijSsj0D Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed/~~ Title PRODUCTION ADMI'N ISTRATION The space below for Commission use Date 10/21/82 Conditions of Approval, if any: Approved by J Approved :~'~'.y //. £. By Prefer-of'" COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Stimulation Prognosis C41-23 Status: Well injecting 1200 BDW into the HC/HZ zones. Objective: Stimulate the HN/HR(L) and the HR/HZ zones using acid placed with coiled tubing. Procedure: Note: Shut-off injection ±48 hours before rigging up coiled tubing. 1. Rig up slick line, test lubricator to 3500 psi. Run 2" drift tool and tag bottom at ±10,535' Tag and record depth. Place dummies in mandrels at 9688', ~819', 10,038'. Test rate out the end of tubing. 2. M.I.R.U. coiled tubing and Dowell acidizing equipment. Test tree and coiled tubing to 5000 psi. Test hydraulic system. 3. Run tubing in hole slowly (no more than 100 fpm). Circulate (while running in hole) using filtered inlet water with 3500 psi pressure on C.T.U. and +1500 psi back pressure on tubing annulus. 4. Tag bottom at 10,535. If there is fill above bottom perf at 10,477', contact T. S. Burns-Houston (713) 870-4465, ( 713) 980-4393 (home). Make three passes through perforations (10,477'-10,256') while circulating filtered inlet water. Note: Use caution while going through Baker retrievable plug, less center rod assembly @ 10,269'. 5. With coiled tubing at 10,477', spot 380 gal. 7% HC1 with 0.3% W-35 (anti-sludge), 0.2% F-75N (surfactant), and 1.0% A-200 (inhibitor). Slowly move coiled tubing up hole while s,potting acid in order to cover all perforations (10,447'-10,256) with acid. Pump 19 bbls of injection water to clear coiled tubing. 6. Pull up hole to 9500'. Wait 30 minutes after clearing tubing and pump 10 bbls of injection water to displace spent acid. 7. Run coiled tubing to 10,477' and spot 380 gal. of 12%-10% HC1-HF acid with 1.2% A-200. Slowly move coiled tubing uphole while spotting acid in order to cover all perforations (10,477'-10,256') with acid. Pump 19 bbls of injection water to clear coiled tubing. NO~/O419B2 8. Pull up hole with coiled tubing to 9500', wait 30 minutes after clearing tubing of acid. Pump 16 bbls of injection water to Gas G~n~. ~;~mmisr, iq~ispl ace spent acid. Ancho~9~ (Repeat Steps 7 and 8 two times). 9. After repeating 7 and 8 the second time, spot 380 gal. of 7% HC1 with 0.3% W-35, 0.2% F-75N and 1.0% A-200 while moving tubing up hole to displace acid across perfs (10,477'-10,256'). Clear tubing with 19 bbls injection water. Pull up hole to 9500'. Wait 30 minutes and pump 20 bbls of injection water to displace acid. 10. Pump 100 bbls injection water while moving coiled tubing up and down through treated interval. 11. P.O.O.H. and rig down. Put well on strip chart, return well to injection at 3500 psi and test. Report rates to T. S. Burns in Houston. Note: While working on water injectors, do not leave tubing standing in well without fluid movement. Blow coiled tubing with rig air after rigging down. If rig air is not available, cover coiled tubing reel and keep heated or circulate 50% methanol and 50% inlet water. NOV 0 4 1982 Alaska 0il & Gas Cons. cotnmis~ien Anchorage Coiled Tubing Stimulation Cost Estimate C41-23 le 760 gal 2 gal 2 gal 8 gal 2. 1140 gal 14 gal 3. Pump 4. Tanks 5. Lines 6. Personnel 7. Miscellaneous 8. Coiled Tubing Unit HCl @$1.10/gal W-35 @$33/gal F-75N @$36/gal A-200 @$34/gal HCl-HF @$2.4/gal A-200 @$34/gal 1.5 days @$1300/day 1.5 days @$470/day 1.5 days @$924/day @$15,000/day Transportation Total Say $ 836 66 72 272 2,736 476 1,950 705 2,000 1,386 1,000 22,000 1,100 $34,600 $35,ooo WESTERN E&P 'OPERATIONS t iDDLE"GFIOU . D SHOAL FIELD SHELL-ATLANTIC'STANDARD I I ' ..... ~. ~ , ~ ,;:._. ,,,, 1/.. ii.'-" fj ,...,,,.. · J~ ' ......- 'i s.? '1',,.,, , · ',- I / · · · · I · ~ .L .~.~ J /' ,,,-..,,/ 'i . I ' ~: I i . I I I iii , · /Io ~-o, : I IJ I ' I Z4-OI ' · i" ~ ' / "M' /' 'j ' , . - , =.: =-% ~ ,,-,~ / J - · ~...,~ ~..q' Ja.' '. ~ / - , , -i ~ , ,,.,~, - ~ ,,..,,/ -:1:' I ~ / _ j ',t.', j / :L: ' * i · · [ _~ / ~.j _,,.,,,/ . '-. · ~.,, .~.!-~,_3 {.i.4,--- /'. '' ' , , - ct,), .... .~ ' --- ! '-- ' ......... ,. - ...... ___ _ ......... ~_..__...~.r,,.,.,-.,. · ii j . .k / 11 !~'~ll H-lb ,,,~ ,. APL lS751J [ ~ '~/ ~ B,~J, 4~-t4 [~ 512o Ac. ,j K / W /c ~ ' '" J~4 j /; .~ INJECTION WELL , / t ~ /~' ~ ~' ' L , ' , - 3~-14- Ji /, - , j I -~a~ i ~ ' · PRODUCING WELL · I / , $4-N I I_o . · j /~2.~i'~'~' L/" ' ~{~P.~PLUGGED&ABNE · ' ~~--+-~- . : · "~ ~ D~'~ M . I r I t r I · ~E'C IVED ..... ,." - ~ :. ~as~ Oil & Gas Commls3i~B ~cl rage J ~ '~ ~1~ .. Page 3 · 1o 8,995' 2. 9~O66' DL~Y ' 3 · 9,688.' - DU~'~Y. 4. 9,819' DUll'Ff. '.5. 10, O38' DUO,ff. -. . .. : C~SING: 10 3/4" ~0o5~ BUTTRF_.SS, 0-1653 ' ?" 26# N-80 BUTRES~. o-845o' 7" 29# N-80 BUTTRESS 8450-t0,593' .TUBING: 3~" 9~3# N-80 EUE ' '.. 0-10,180" (336 'JT.) '.. - . PERF.: 9~087-9,108 ' GNLGO 9,450-9~ 495 ' GR-GS 9,706~9, 720, · 9,733-9,764' HC-HD 9,842-9., 886 ' HEiHF 9,954-9,993 ' HI-HK 10, OO9-10~ 1~7' HK-HN 10,180'10~ 235' 10~ 256-10,316' HN-HR 10,340-10,370'-7-~ 10,396"10~438' 10, 4~5-10,454' 10,462-10: 477' HR-HZ ---NOTE*~*NOTE-. -- ~"FISH": IN CASING, TOP @ ~10,269 '. ( B~ RETRIEVABLE PLUG IZ~SS CENTER ROD ASS Y. ) 0-41-23'." OF. JULY 29, '1978". Page B-ALL VALVE @ 295' · . .. · . -. . · .. .. . , · :.-. ....'. ::.i '..' ' . .. " .. . . , .. UNI-PACKER. VII @ 9~ 029 ' KBM #2. @ 9,066' UNI-PACKER VII @ 9, ~51' KBM #3 @ 9,688' ..' · . UNI-PACKER VII @ 9,781' KBM #4 @ '9,819' · UNI-pA.C'KER VII @ lO, OOl'. NO.V0.. 4 /~/aska . , · B~.F-1 PACER &~.~L ~ 10,~_~' X-N~P~ $10~ 165"' X-N~P~ ~ 10,173'.. M~~HOE P~ $10,180' (EOT.) '~IS~' BA~R ~T~EVAB~ PLUG, ~SS C~R ROD ASS~4BLY. ~ 10,269 PB~, 10,535' ~.~ 10,593' "--~f 87 F.O. Box 31.g0 i ~ ' Anchorage, Alaska 99.510 re~e£hone (00~) 25S-23~$/338-2019 " Actual O.D. Nominal I.D. Wall thickness · Weight Wall area Flow area 1. 250 in. 1.08/+ in. O. 083 in. 1.034 lbs/ft. 0.304 in.2 0.925 in.2 Tensile: . · Ultimate Yield Max. Operating .22,800 lbs. 21,300 lbs. .7 'ooo Burst: Ultimzte Test press. Max. Operating Collapse: Ultimate Max. Operating 9,960 psi. 6,000 psi. 5,000 psi. 6,100 psi. 1,500 psi. Capacity: 141 Bbl/1,000 ft. 8-75 ft./Bbl. Wall displacement 0.377 Bbl/lO00 ft. Total displacement 1.518 Bbl/1000 ft. CEIVED NOV 0 4 1982 Alaska Oil & Gas Cons. Oo/.nmis:f~n t~nchorage Form 10-403 ' /~ Submit "1 ntentions" in Triplicate REV. 1-10~73 ~ & "Subsequent Reports" in Duplicate STATE OF ALASKA 5. APl NUMERICAL CODE OIL AND GAS CONSERVATION COMMITTEE 50-133-20163 6. LEASE DESIGNATION ANO SERI# SUNDRY NOTICES AND REPORTS ON WELLS :' (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT~' for such proposals.) ADL 18756 ~ GAS ~ .7. IF ,NDIAN, ALLOTTEE OR TRIBE 1. ~L~ WELL~ OTHE~ Water Injector None ~ "NAMEOF OPERATOR 8. UNIT, FARMOR LEASENAME She(( 0~[ C~pa~7 H~dd[e ~ound Shoal 3. ADDRESS OF OPERATOR 9 WELL NO ' . . C-4[-23 1700 Broadway, Denver, Colorado 80290 4. LOCATION OF WELL 10. FIELD AND POOL, ORWILDCAT At surface M~ddle flround Shoal-"( Conductor 28, Leg 4 ~ 38.14'S & 64.85'E fr~ center of ' zz. SEC.,T.,R.,M..(SOTTOMHOLE(~-~ Leg 1 ~ 541.65' N & 1596.41'W fr~ SE Corner, Section 23 13. ELEVATIONS (Show whetherDF, RT, GR, etc.) 12. PERMIT NO. ~05~ D~ 68-~t2 14, CheCk Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF J.__._J FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR AClDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates,.including estimated date of starting any proposed work. See attachment SIGNED TITLE Div. Opers. En8r. DATE OCT 0 9 197~ (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side ACDZ .& REARRANGE 'PKRS . SHELL- CHEVRON-AMOCO-ARCO FROM: 6'/3- '8/23/78 -A~AS~At MIDDLE GROUND ~ SHOAL ..... MIDDLE GROUND S~OAL LEASE MIDDLE GROUND SHOALWELL NO. O-41-9-3 ~'~SzuN u~ .~.~-? ELEV 105' DF COUNTY STATE ALASKA C-41-23 "FR" TD 10,700. PB 10,535. 6/30 AFE provides funds to (Acdz & re-arrange pkrs) acdz & re-arrange pkrs. Skid'd rig & assisted divers. Checked electric wires. RU ~IL; set plug in X-0 sleeve @ 9034'. 7/1 Pulled WL; plug would not set in X-0 sleeve. Ball valve would not go. 7/2 Ran ~ tbg scraper. Ran ball valve; would not w'or~, ~yu line plug'd. ~ trce ~ NU BOP' s. ~'0t 0 B 1978 C-41-23 ......... TD 10,700. PB 10,535. 7/3 Tested pipe & blinds to 7500 (Acdz & re-arrange pkrs) psi, hydril to 1500 for 15 mins, ok. Speared into tbg & .~ried to work pkrs free; would not come free. Retrieved B cup from 200' (WL), & pmp'd 60 bbls 10.8 ppg pill & killed tbg; well flw'g thru annulus. Ran freepoint & shot off @ 9908' retrieving 2 pkrs. Pulled tbg 75' & stuck again. RU die-log. 7/4 Installed rotating head & LD tbg. Pmp'd pill (annulus packed off around pkr, could not kill tbg). Ran WL w/D cup & plug'd tbg. LD tbg & rec'd 3 pup its, ball ~alve, x-o sleeve, mandrel (Res lift) & 317 j ts tbg. ~OL ,5 ~9~78 . C-41-23 ..... :--TD~'10'70O. --P~ 10,535. ~ 7/5-Made-up fish'g tools & trip'd (Acdz & re-arrange pkrs) in to 9695, top of fish. Worked over fish &-jar'd loose, Trip'd out w/fish & LD same. Made up fish'g tools & trip'd in to 9878, top of fish. Worked over fish, jar'd & worked fish loose, (180' tight). Trip'd out slow w/fish, (pkrs drag'g). JO[ ~ 1578 C-41-23 ......................... ID 10,700. PB 10,535. No report. (Acdz & re-arrange pkrs) JUL 7 1978 C%41'23 · TD 10,700. ~B 10,535. 7/7 TOOH w/tools; no rec. TIH to (Acdz & re-arranga-'pkrs) top of fish @ 9900 & jar'd. Released from fish & TOOH. TIH w/spear. 7/8 TIH to top of fish @ 9900 & jar'd. Released from fish & TOOH. PU 3-1/2 tbg w/overshot on btm & RIH; tbg stop'd @ 9721. Ran Dialog. collam locator to verify meas. TOOH w/tbg. 7/9 Made up BHA & tapered mill & TIH to 9085. Milled from 9085-9093 & reamed'from 9706-9714. Ran mill to 9878 (free). TOOH &'LD tools° '. TIH w/tbg & overshot. RU' Dialog & ran tbg them cuter. JUL ! 0 1978 C~41-23 TD 10,700. PB 10,535. Trip's--out for overshot. Tried (Acdz & re-arrange pkr~~?-'~ to get WL in fish; was unable ~ do so. Ran spudder bar on WL. Ran 2-5/8 WL tbg swage & ran impression block. 0gL ].~ 197~ TOOH w/tbg & picked up wash pipe & tools. Trip'd in w/ % wet plug. Washed over fish; drop'd to 9917 after washing ............ over 3' of mandrel. Trip'd out for overshot. C-41-23 ' TD 10,700. PB 10,535. RIH w/overshot & latched onto (Acdz & re-arrange pkrs) fish. POOH; rec'd gas lift mndrl & 16' tbg. Reran overshot w/1 jt WP ext & latched onto fish. Jar'd fish'& POOH. Jar'd mndrl in two & rec'd 21' of fish. ................................................... JUL 1~ 1978 C-41'23 ' ' TD 10,700. PB 10,535. Made up BHA consisting of (Acdz & re-arrange pkrs) 6 x .4-3/4 shoe, 1 jt WP, 6 DC's, jars & bumper sub. Milled 13 hrs & made no hole. POOH. JUL J3 1978 · C-41-23 '" ' TD 10,700. PB'1°,535. Hit & worked thru tight spt @. (Acdz & re-arrange pkrs) 9986. Milled on & washed over pkr 6". TOOH for new washover shoe; mill'g. JUL J4 1978 f C-41-23 ..... TD 10,700. 'PB 10,535. 7/16 Latched onto fish & jarred (Acdz & re-arrange pkrs) fish up hole 1 std & 1 single & lost fish. POOH. Jarred mandrel in two; rec'd 2"'pkr mandrel. RIH w/spear & latched onto fish in tbg jt below pkr. Spot'd jarred pkr to 9050'±. POOH. Rec'd pkr & tbg stinger. RIH w/tapered mill. Milled 9621-9627' & 9903-9909'. Staged in to 10370 & encountered fill. Circ'd & POOH. 7/1~ Ran bit & scraper to-CO fill @ 10370' to 10498'. POOH. Made up Bkr sqz pkr & RIH. Ran . Dresser.Atlas collar log & tied csg back to DP measurements. 7/i51Milled over pkr; 1' total. POOH. Rec'd 9' of pkr body in wash over shoe. RIH w/overshot & hooked onto fish° Jarred pkr up the hole 2 std & 1 single. POOH. Overshot slipped off. RIH w/overshot & latched onto fishOUL 17 1978 . C-41-23 TD 10,700. PB 10,535. No-report. (Acdz & re-arrange pkrs) ~[ ~ Cf4i-23 ......... TD 10,700. PB 101535. Ran Bkr pkr & set @ 10,328'. (Acdz & re-arrange pkrs) Released pkr & pulled up & set @ ].0,164'. Released pkr & pulled up & set @ 10,001'; did not comm. Released pkr & ran to 10,365' & spot'd 15 bbls 15% HC1 acid. Pulled up & set pkr @ 10,001' & acid treated w/120 bbls 15% HCl acid as per WS & broke comm @ 3000 psi after following acid into formation w/25 bbls wtr. Checked blanks @ 9910, 9800 & 9600'I no comm. Pulled out of hole.run'g RBP. SD. Trip'd in & set RBP @ 9800' & spot'd 5 bbls 15% HC1 acid° · ~u~led pkr to 9600' & pmp'd 30 bbls ~C1 acid. Displaced acid w/375-bbls Wtr & g°t'--zone~o--mm,'' SI w/1125 psi initially; 600 final press Circ'd acid out. Latched.onto RBP, would not release. Worked RBP to 9828'; stuck. TOOH leaving RBP @ 9828'. LD pkr & picked up retrieving tool. TIH. Washed on RBP & ~ried to get it to release; would not release ~ji_~i41_L23 ............... ~~ip'goutformillingshoe. JUL]9 1978 10,700. PB 10,53'5.- TOOH & picked-Up 6 DC's. Made (Acdz & re-arrange pkrs) up fishing'tools TIH to 9828' (top of RBP), milled over · ~Ok ~ 0 ~97~ RBP & RBP released. Pushed.to 10,004' & TOOH. LD fishing · tools& picked up RBP retriever. TIH w/RBP retrieving · . C~41-23 (Acdz & re-arrang? krs) TD 10,700. PB 10,535. ~'xt & latched on RBP & TOOH w/ RBP,(left part of RBP ir. ole). Pick. ed up jars, accelerato: & DC's. Pushed & washed RBP to 10,269'. TOOH w/plug'd string containing 20 ppm H2S on rig floor, when checked @ box on DP it was 200 ppm~. C-41-23 TD 10,700. PB 10,535. 7/21 Picked up pkr & RBP & TIH (Acdz & re-arrange pkrs) to 9525'. Tried to get pkr & RBP to test; appeared pkr · was leaking. Pulled 10 stds & tried to seat RBP & pkr; pkr not holding. Trip'd out & tested RBP & pkr @ 8150' & 2575'; would not test. LD tools, reline brakes on DWKS & picked up new RBP & pkr & TIH. 7/22 TIH to 2000' & tested RBP, ok. TIH to 9525 & set RBP. TOOH & picked up pkr. TIH to 2000' & tested pkr, ok. TIH to 9500' & spot'd 5 bbls acid. Pulled to 9305' & set pkr. Let acid set w/3000// acid' did not break.down. TIH to 9500'& spot'd 5 bbls acid across perfs, pulled to 9305'' & reset pkr. Let well stand shut in. Circ'd hole clear of acid & TOOH w/RBP & pkr. 7/23 TOOH w/RBP & pkr, made up pushing tool to push junk @ 10269; could not move junk. TOOH & picked up 7" csg JIJL ~4 1978 scraper & RIH to 10200. RU Dresser to run WL BP. Tied in collar locator w/flag j t @ 10141 - 10162. Set BP @ 10002 w/very little drag. Run'g WL re. tainer. ~TD 10,700 PB 10,535. No report. C-41-23 "- TD 10,700. PB 10,535. 7/24 Set retainer @ 99.70' & TIH (Acdz & re-arrange pkrs) & stung into retainer; initial inj rate was 1 BPM @ 750 psi. Mixed 45 sx Class "G" @ 15.8~/gal. Put 5 bbls wtr ahead & stung into retainer + sqz'd 20 sx cat to formation w/sqz press~@ 1/4 BPM w/500 psi; finishing press was 750 psi Pulled. out of retainer & pmp'd 10 sx cmt on top of ~L 9~B ~9~ retainer,~ T~ip'd in & tag'd cat strings @ 9130'. Sqz'd perfs from 9'954 to 9993'. ' C-41-23 ............... TD 10,700. PB 10,535." 7/26 Set retainer @ 9805' & TIH & (Acdz & re-arrange pkrs) stung into retainer & established inj rate of 4 BPM @ 1500 psi. Released from retainer, mixed & displaced 150 sx Class "G" cat mixed at 15.8~/gal, Yield 1.14 cu ft/sx. Sqz'd 125 sx; initial sqz press 3000 psi. Released from pkr '& spot'd 25 sx on top of the retainer. POOH. Trip'd in & tag'd cat @ 9120 to 9140'; tag'd top of f~rm cat @ 9710'. Sqz'd perfs from 9842-9886 & 9954-9993'.0~/ ~7 1~78 C-41~23 ......... TD 10,700. 'PB'10'535. 7/27' Top of cat @ 9710'. Had (Acdz & re-arrange pkrs) stringers from 9710 to 9760. Had firm cmt from 9760 to retainer @ 9805. Circ'd btms up & milled up retainer @ 9805'; drop'd 1' & started milling hard cmt. Milled hard cat to 9875' & soft cat to BP @ 10,002'; started milling on BP. JUL ~8 1978 C-41-23 ...... (Acdz & re-arrange pkrs) C-41-23 (Acdz & re-arrange ~) JUL 9.1 19"/9 C-41-23 (Acdz & re-arrange pkrs) C-41-23 (Acdz & re-arrange pkrs) TD 10,700. PB 10,535. 7/?~Finished RU Dresser & .ran gauge tool & junk basket. Start in hole w/WL p~; hit tight spot @ 2900' & worked to 9'/~3', could not get deeper. Ran back in hole w/gauge ring & junk basket'; worked thru tight spot @ 8763 (6 times). Re-ran WL pkr; stop'd ~ 9763 but worked thru on 3rd try. Set Bkr Mdl F-1 retainer prod pkr @ 10,150. RU & ran tbg w/4 Guiberson UNI-VII pkrs set @ 10,001, 9781, 9651 & 9029'. Set pkr w/inj wtr. Slack tbg 2' & set tbg hanger. Started tightening locking screws in wellhead. 7/30 Removed BOP equip & installed wellhead, i Tested wellhead to 2000 psi for 30 mins. RU WL unit & pull-! ed dummy valve from mandrel @ 8995'. Inj'd S~ inhibited w/l% Nalco 938 & .1% Nalco 1153 in tbg-csg annulus. Re- install dummy valve @ 8995'. RD o TD 10,700. PB 10,535. 7/31 Tried to pUll plug from x nip- @ 10,175; no success. Ran sample bailer & rec'd some fill. Continued run'g bailer. RD rig, moth balled rig & mud pmps. Rig released 8:30 a.m. 8/1/78.~U~ .1 7978 · TD 10,700. PB 10,535. ~&~-liftimg. ~UG ~'~ T~'~,'t.,G,-. ,2 1978 C-41-23 (Acdz & re-arrange pkrs) TD 10,700. PB 10,535. Gas lifting. ~/0'~ecT~3~ AUG 3 1978 C-41-23 (Acdz & re-arrange pkrs) TD 10,700. PB 10,535. Oas ilfci~. AUG 04 1978 C-41-23 (Acdz & re-arrange pkrs) TD 10,700. PB 10,535. AUG 07 '~978 C-41-23 TD 10,700. PB 10,535. .,' (Acdz & rearrange pkrs) (Report discontinued until test established.). AUG 08 1978 .. _ . C-41-23 ...... -.: -~D- lO,700.-'~B"~0,5-35-. (Pu~D 8/8178). O~ 24-hr test (Aedz & rearrange pkrs) 8/21178, inj'd 1680 bbls w/3300 psi inj press. ~-OG 2 3q978 FINAL RgPORT SHELL OIL COMPANY 1700 BROADWAY DENVER, COLORADO 802.02 August 14, 1978 Subject: Shell-ARCO-Standard Middle Ground Shoal Mr. O. K. Gilbreth, Jr. State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Gilbreth: Attached are two copies of the Monthly Report of Operations for July, 1978. KWL:ts For: R. Planty Division Operations Engineer Rocky Mountain Operations Office Attachments cc w/Attach: Atlantic Richfield Company Standard Oil Company Amoco USGS i97'8 Form Ng. P-4 REV. 3-1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICATE AP1 NUMERICAL CODE 50-133-20163 MONTHLY REPORT OF DRILLING ~. LEASE DESIGNATION AND SERIAL NO. AND WORKOVER OPERATIONS ADL 18756 1. 7. IF INDIAN'ALOTTEE OR TRIBE NAME OIL ~'~ GAS D OTHER Water Injector None WELL WELL 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Shell Oil Company Middle Ground Shoal 3. ADDRESS OF OPERATOR 9. WELL NO. 1700 Broadway, Denver, Colorado 80290 C-41.,.23 4. LOCATION OF WELL 10. FIELD AND POOL, OR WILDCAT Middle Ground Shoal-"G" Pool Conductor 28, Leg 4 @ 38.14'S & 64.85'E from Center u. SEC. T. mM.(BO*rO~HOLE OBIECTIVE) of Leg 1 @ 541.65'N & 1596.41'W from SE Corner, Section 23 Section 23-T8N-R13W SM 12. PERMIT NO. 68-112 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. OPERATIONS FOR JULY 1978 Acidiaed perfs HR/HZ (10,349-10,477) w/120 bbls 15% Acidized perfs MN/HR (10,180-10,316) w/60 bbls 15% Sqz'd~HE/HF & HI/HK~Perfs (9842-9886 & .9954-9993) w/150 sx Class "G" Presently injection testing 14. I hereby cer th nd correct SIGNED ~-~ I ~~d TITLE Div. Opers. Engr~ DATE 8/14/78 NOTE--Report on this form is requn~d for each calendar month, regardless of the statUs f operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. Form 10-403 REV. 1-10-73 Submit "intentions" in Triplicate & "Subsequent Reports" in Duplicate 6. LEASE DESIGNATION A Ag[ 18756 7. IF INDIAN, ALLOTTEE OiR TRIE~AMI~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE 5. APl NUMERICAL CODE 50-133-20163 SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) NAME OF OPERATOR Shell Oil Company 3. ADDRESS OF OPERATOR 1700 Broadway, Denver, Colorado 80290 4. LOCATION OF WELL At surface Conductor 28, Leg 4 @ 38.14'S & 64.85'E from Center of Leg 1 @ 541.65'N & 1596.41'W from SE Corner, Section 23 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 105 ' DF 14. Check Appropriate Box To Indicate Nature of Notice, Re None 8. UNIT, FARM OR LEASE I~lAME ' Middle Ground Sho)al 9. WELL NO~ C-41-23 10. FIELD AND POOL, OR W''ILDCAT Middle Ground Sho,)al-''c ' U P,A FT : i ,,--,. ~-r ,,~. C5;o0i · 11. SEC., T., R., M., (BbTTOIVM._HOLE ;i~.tEC. T-P&~)--- Section 23-T8N-R13W SM 12. PERMIT NO. 68-112 )ort, or Other Data NOTICE OF INTENTION TO'- TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. See attachment RECEIVED JUN '-'" ? !gll SIGNED (This space for State office use) APPROVED BY CONDITIONS OF/~fPRoVAL, IF AN~'= r- - - TITLE Div. Opers. Engr. DATE 5/31/78 See Instructions On Reverse Side Approved Cop~ Returned WORKOVER (SATERBPAP* AND RARP**) PROGNOSIS SAS MGS C-41-23 MIDDLE GR-O'UND 'SHOAL FIELD, ALASKA Status Backflowing +2000 BW/D (out of injection service since 1/15/78) Prior to shut-in/backflow, injected +4000 BW/D Limited profile control...leaking SS~-s Refer to Mechanical Detail Sheet for downhole configuration Objectives . Improve injectivity and injection profile via · *Selective Acid Treating Employing Retrievable Bridge Plug And Packer, and · **R_eplace A_nd R_earrange P_acker for profile control Procedure 1. Close ball valve, set BPV in tubing hanger, ren~ve X-mas tree, nipple up BOPE and riser. Test BOPE to 3000 psi. 2. Open ball valve, remove BPV and pull tubing and packers. 3. Run bit and scraper on 3-1/2" DP workstring and clean out to PBTD .10535' using injection water as circulating fluid. Catch samples off of shaker screen for analyses. 4. Run retrievable bridge plug (RBP) and packer on 3-1/2" DP. Set RBP below bottom perforation 10477'. 5. Spot 5 Bbls 15% HC1 acid on bottom and raise packer to +lO000'. Acid formu- lation (spot-acid as well as stage treatment-acid)' - Component Function Inhibitor Surfactant Sequestering Agent Concentrati on 5 gal/lO00 gal 2 gal/lO00 gal 13#/lO00 gal · Run collar locator log (gamma ray not required) and tie workstring measure- ments to 7" caSing collars;' 'rflA~ j-"6Tnt 21' long, top at 10141' and bottom at 10162' (refer to CBL/GR dated 1/22/69). 7. Lower packer to 10328' and set at that depth. Acid treat (AT) HR/HZ per- forations 10340-10477' (122', 488 holes) with 60 Bbls of 15% HC1 acid in ten stages- a· b~ Test packer settings (seal and cement integrity) by pumping into workstring and Observing returns (if any) from annulus. Pump 5 Bbls of acid followed by 1 Bbl of acid containing 200# of benzoic acid flakes plus 4# of HEC. C~ Repeat Step 7.b. ~ine times (however, leave out benzoic acid flakes from last barrel of acid of tenth stage). SAS MGS C-41-23 d, ee If diversion is not obvious from pressure performance, repeat the ten-stage acid treatment using 400# of benzoic acid flakes per Bbl (stage) rather than 200#. Displace acid with 400 Bbls (workstring volume plus 325 Bbls) of injection water; use injection system rather than treating pumps if practical. fe If well backflows after treatment, take returns through tubing (and over the side of platform) before unseating packer. If volume of backflow is great enough to return spent acid to surface, backflow (over the side) until spent acid is clear of well bore. 8. Release packer, wash down to and pick up RBP. Reset RBP at 10328'. 9. Spot 5 Bbls of 15% HC1 acid on bottom and raise packer to 10164'. 10. Set packer at 10164' and AT HN/HR perfs 10180-10316' (136,, 544 holes) with 60 Bbls of 15% HC1 in ten stages as outlined in Step 7 employin§ benzoic acid flake concentrations in diversion slugs as dictated by results in Step 7. Il. Displace acid with 400 Bbls of injection water. 12. Release packer, wash down to and pick up RBP. Reset RBP at 10164'. 13. Spot 5 Bbls of 15% HC1 acid on bottom and raise packer to lO001'. 14. Set packer at lO001' and AT HK/HN perfs 10009-10147' (138', 552 holes) with 60 Bbls of 15% HC1 in ten stages as outlined in Step 7. 15. DiSplace acid with 400 Bbls of injection water. 16. Release packer, wash down to and pick up RBP. Reset RBP at 9800'. 17. Spot 5 Bbls of 15% HCl on bottom and raise packer to 9600'. 18. Set packer at 9600' and AT HC/HD perfs'9706-9764' (45', 180 holes) with 30 Bbls of 15% HC1 in five stages as outlined in Step 7. 19. Displace acid with 400 Bbls of injection water. 20. Release packer, wash down to and pick up RBP. Reset RBP at 9525'. 21. Spot 5 Bbls of 15% HCl on bottom and raise packer to 9300'. 22. Set packer at 9300' and AT GR/GS perfs 9450-9495' (45', 180 holes) with 30 Bbls of 15% HC1 in five stages as outlined in Step 7. 23 Displace acid with 400 Bbls of injection water. 24. Pull RBP and packer. 25. Run bit on workstring to bottom and clean out any excess benzoic acid flakes or other fill to PBTD 10535'. SAS MGS C-41-23 26. Pull workstring. 27. Run Baker Model F-1 retainer production packer on wire line and set at lO150' MD (perfs from 10147' upward, casing collars at 10141' and 10162' and perfs from 10180' downward). 28. Run 3-1/2" injection tubing with packers and ancillary equipment (refer to detail equipment sheet). ~.e~..~;k~. ~1~ ~.~r.~,z ~'~ (~~ ~ ~,/~'~,~ 29. Space out, set packers, retrieve plug from X-nipple, close ball valve, set BPV in tubing, remove BOPE and nipple up X-mas tree. 30. Remove BPV, open ball valve and commence injection into zones below lowest packer (HN/HR and HfyHZ). 31. Release rig. 32. After settled injection rate has been established, open HK/HN, HC/HD, GR/GS and GN/GO to injection (pulling dummies from GL mandrels). 33. Assuming that SATERBPAP has been successful, run injection profile survey after 30 days of injection into all zones opened. Adjustments to profile (installing orificies or dummies) will be made thereafter. E DM: KW 5/11/78 Prepared,nd,:~ Recommended: ~~~~_~ Concur.- Con c u r .~jf~~ ------- App roved~..- · 'WELL SHELL OIL COMPANY' RECOMPLETI'ON REPORT ,~,,~,~D,~. /'_~/ .Y~._Y' ~rker Horizons Z Production Data Manne~ of Pzoductn; ..... Gm~ Fluid-S/D, Clean OLI-B/D, Gravtty-°A. P. I. i Stlinity, ppm N~Cl(t or r) ~ G~s-M, C. F:,, Gas Oil l~atio ! Initial Production ~,.~ g/~.~/~. ..... iml i i i i .. i ii i · i ii ii · P, em~rks: Location ii · [11 11 I "casins "casin~[ "casin~ ",c~sin~ ~tcuinS "liner . W. $. 0.~ ! I ! i i m Adotl. Prod. Data Calculated Potential Date Date mil I Im · Il I I I I I J I Jl I I m I IIl I · II PD298 (Rev-* ;).~r~) Prm~eo m u.o.~. ,I,...%. ~,HELI.. OIL. C~OMPANY /,~ WBkk NO,. - ' /q,~.~,~~ RECONDITIONING ~~COUN'I'Y ' PERIOD ' . · .~.^.Ks (..ow.,a ..o WP. T~OL. . . . -,F~n'[shed. , put~lng Cubl~g. Rigged up and ran .8chltmberge. r, . ' .Located top 'of tt~ fill ac 10~63 R~ (72~ over PB~D). Per[orated 10,~45 ~ ~0,~56; [0,370-' 10,396; 10,235 -~[0,256; 9,~50 - 9,~95.~t~h hypsr Jecs/foo~. ~t'll pe. rfora~e interval [0,~62 - 10,~77 ag~ar blt and acraper run. NalnCained 250. B/D 5~ [n~ec~on dogie8 operaC[ona and durln~ ntgh~ ~hu~ do~ period. . , ', Ran cleanout assembly consisting ot 6" bit, Ba~r s. creper, 2 --~ 3/~" x 30' drill collars, I'~- ~ 3/~" x 2 1/8" x 16" stroke, bumper sub, X over '3 1/2 IF mod. x 3 fY2" EUR' and 3 1/2" tubin8 to surface. Cleaned out hard bridge i0,463 - i0,478, Lost returns, ~orked p/po end increased iuj~ction race gr~ 3500 c° 5000 B/D rate. ic~in~i returns. Reverse .circulated up hea~ f1~ of sand ~ith flecks et ~ha~ looks like coal. Revet-se circulated.ires ~ich full return~ aC ~000 B/D rate and ~ith 700 psi annular pressure. Lost and re~ained returns several times while cleaning - out to lO,SIS'RT. Could not regain ~eturu~ (tubini pluiied). Pulitni , tubing ~et. Shut d~n for night vith 2000 B/D 8~ /nJeccin8 d~ anuuiue'z . . - Continued pulling tubing vet. Bigged up and ran Schl~berger. Using ~o hyperjetm pet foe: perforated inte. rval 10,a62 - i0,~77. ~nced running peckers, eLc., per worksheet. SD ~ernt&ht rich 250 B/D ~ ; .. · . . ~/~ ~y ~/'~*~ .... ,,. CONDITION AT ~ OF PERIOD CONDITION ~$TARTINe WORK HOLE ~ CASING SIZE ~ DEPTH S~ - , (CROSS OU~ AL~ BU~ ~PROPRIATE ITEHI) /d~O~ /~F~/~ ~TION OF PU~PING EQUIPMENT (UNLES~ WELL WAS ORIGIN- ' ~ ALLY COMPLETED ON THE PUMP). BAD CASING, FISH , ,, ,, , , ~ ~,- · i _.1 iij..i i 11 i Il ! i i i nrll I ~ ,_ I Continued romping completion .aCting per worksheet, rabbttint~ al 1 .~ ray.CDC-Car [ocat°r to tie tn packers. Tool shorted. PuLled, ~epat~ed ,tool and reran.. LocaL'ed packer~ and alI'Je~eiry. ~htIe correla~lng.ga~n ray with CB~-colLar logs lC-was discovered rha'~ on bhe original CBL ~he log memory was ia error-by.~-~feet. This uss 'caused by.no~ insert, tag the proper gtgure (22*) planned, Pulled Schl~beraer. R~n and aec q plu~ on wire lire, Flttld level' 1600 .Filled Cubing and pressure :ee~ .packers. 8ott~ .pa~ker sec a~ 900 pit. Slacked -- .of:~i .1 fooc and ~se.t ascend packer aC 1000 p~l. -Third packer sec ac 1250 psi,. o~f 4 1/2 ~ee_c and landed dontl~ ~lth 32,000 ti C.~preaslon. on. Cop packer, .Increased pressure to 2000 psi for 15 minutes.. Held OK, R~ed riser, B~ and sec tree. Tested ~ree Lo 3000 psi ~.' SD operations at 8 ~, , .... . . ~[-[h ,piano ~ira to°ls~ opened/sliding sleeve at 9900*. Vacuum.on tubtnt. ' ~e[~ed l'5.minute~ and ope~led sliding sleeve at 9600'. Vacuum again ~ tubing. ~aited 1~ minutes-and opened, sleeve a~ 9998'. Very st tshc vacu~ on Re~le~d. q plug aC 10,020+. Fluid Caret inside tubing 1600~ a~cer openinK al[ [h~ee sle.e~e, Returned ~ell co injection ~tth IO00 B/D rate at O pet d~n. , , . . . . . ~a ,., ~ ;.~ , , , CONDITION AT W OF PERIOD GONDITION~TARTING WORK HOLE I CASING SIZE I DE~H S~ .... (CROSS OUT Akk BUT APPROPRIATE ITEMS) , *1~ I , rHo" I TO, = bEPTH (ORIGINAL) , , ,, WP P~UG (PI OR BRIDGK (BI D~ ~8T (ND. OR DE.) ~P FIIH (FI OR 3UNK (~) - "~ DEPTH PRESENT EFFEC~VF ~. . BAD ~iG. (~) ORLINER ,. , , NOTE--IH ADDITION TO REPORTING ROUTINE RECONDITIONING OPER- ATIONS, U$~ THIS FORM FOR REPORTING THE FIRST INSTA~ ~TION OF PUMPING EQUIPMENT (UNLESS WELE WAS " ' ALLY COMPLETED ON THE PUMP)· BAD CASING. FISH LE~ DRILL PIP~ HOLE, ~C.. THAT MAY OCCUR AS A REGULT OF PRODUCING OR SHUT DOWN OPERATIONS .... . ,, SIGNED SHELL OIL COMPANY 430 7TH AVENUE ANCHORAGE, ALASKA 99501 February 25, 1969 Confidential Material STATE OF ALASKA Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska DiVISiON O~ O~L AND GAB Attention Mr. Homer L. Burrell Gentlemen: Attached are two copies of the Well Completion Report for our SAS Middle Ground Shoal C-41-23. Included with the report are the follow- ing data: Composite Log (Sepia and Print) Directional Survey (2) Well History (2) Very truly yours, R.D. Allen Division Exploitation Engineer Attachments CO F DENTliJL Form P--7 b, SUBMIT .IN DUPLICATi_~ ~'- -STATE fOF ALASKA ,, see ot~r ~,~- - -. ' structions on · OIL AND GAS CONSERVATION coMMITTEE, reverse side) ~ ~WELL cOMPLETION OR RECO~PLETIQ~ ~ORT A~ND LOG * ~. ~ 0~~ Wz~L: ~ , .~ ~. , WELL WeLL ~~ ~ ~ FIL~ ~.b. TYPE OF COMPLE~ON: - ~ ' ~O~ WELL OVgR EN BACK . - ngSva. Ot[her ~ ~ a <CtC:q 8. U~T,F~OR~SEN~E ~ ~ b. ~P'-'~ Middle Ground Shoal ~2.NAM~ OF OP~RATOR ; ~ 11. ~%1 aompany .................................................. . mwmo~ o~ oil ~Nv ~s 0. w~ ~o. - ~ 430 Seventh Avenue, Anchorage, Alaska 99501 ; : .'] !4.LOCATION Or WELL ~keport location elearl~ and m accoraanoe with a,p State rZquire~sat,)* ' ~; Midd~le Ground- Shoal at su~aee Conductor 28, leg 4 at 38;. 147. S &'. .64. 85ai~ from the center[n, s=c.. o ~ leo I a~ 541 65'~ a 1596 41'~ ~om~the SE co~n~r'; Sec 23';T8N,gg3~ ~ it gu prod. tuterva~'reported below 9687 ' (Sff92'~D)1164~ S-&: 8&8'~ from ~ corner, Section 2~ 8~ g13 ;~H , ' ~ . ~ At ,otaldep~ 10,712 t9t99 ~)~5-S & 1278 W~froy ,he ~E corner;[. _Sec,_ 23, TSN, R13W, Section 23, T8N, R13W, SM .~ ~ ~ ' ' ' - ~ .....r~-~-- ~lq ......... - ....... ,1 i'1 D~ ~DD~ ~.DA~ T.D. ~C~ ~i' ~- ~7-es ~-a0-e [ ~-~-~9 [ -10s' ~s' (~nnw)., . l, ' .... 18; T~ D~H ~ & TVD~9. pLUG ~ ' MD & ~D~. ~ ~'~'~ ~L., / [ 11 T~RT INTERVALS DRIL~D 10,712' (9499'T~} 10~35' (9346'~D~ ..... ~ ~ ~ ....... ~.~PaODUC~N~ ~VA~(S), O~ ~a ~TXON~. ~M, N~ (~ A~ ~)' . ; Top 9087' ~(809~2'~) E Pool - . Yes Bottom 10,370" (9Z04'~) G Pool ' ~4.i ~fPE wrr,~,~C AND OTHER i DIL, BHC, FDC and 'CBL_ ~. C~ ~ (Re~ all strings set ~ w~ll) C~G S~z~ WEIG~ D~ ~T (~) HO~ S~E ' 10 3 ; 7" 900 Sacks -, c~~G xmcom) HtB ~ OKG~ t-i x/ \ 5. AP1 NDEW_F_~CAL CODE .... HWK 50-133-20163 6. ~E D~IGN~ON ~D SE~ NO. ~ ~L 18756 - ~ AMOUNT PULJ~g~ LINER 1RIIC O,1~, ~ BOTTOM (MD) SAC~S ~ .f i 28.:'PEl~FORATIONS OPEN TO PROD~0H (Inte~al, si~ ~d number) Four - 1/2" Jets per foot. 9087k9108 9450L9495'; 970~%~'20'; 9733%9764'; 984f-9886'; 995~ ~:99~93 ; 10,009k10,147'; 10,180t 10,235' ;~ 1~;256kl0, 316'; 10,340k 10~370' ~'-10~3967+L0~;438' SCREEN (1VID) - SIZI~ D~-,~ (MD) [ PACI~ S~ (~) 1/2 .-., 9016 ., ' 8948 i , ~ D~'I'~V~ '(D) I ~O~T.. /~ raND OF ~~ U~ i ' PRODUCTION f ' FIRST PI~ODUCTION ! ' [ shut-in) _ . ; 1-26-69 [ ~. Gas Lifting ' ' ' ] .Producing } DATI~ OF TIIIST, Iz~otras T~T~) '-:~ 'I~OKE SIZE I~OD'N FOR O~B~ "'~~CF. · WA~~ .[ G~.Om ~O ~ 2.2-69, [ 24': :-'~'i 128/64" I ~ I' 14~60 [ 724 I -48 I 920' ~W ~BING ~SmG ~msa ic~~ O~BBL. G~~. WA~B~. [OIL GRAV~Y-~ (C~.) ~ 80 I s20 ~..I ; t 1460 I 7'24 I 48 I 34.6° ~ 31'. DISPOSITION OF GAS (8old, dsed yo¢~uel, vented, etc.) ]TZST WZTNrSS=D S~ Vented~. ~ - .... . Well History (2), Directional Survey (2), DIL 2" (Sepia and Print) c~ the ~ln~n t~ched information ts eomplet~ and correct as determined from allVavailable reeoras :~ a~. I here~ SIGNED ~~ ~' ~ TIT~DiV' Exp1Oitat' n Eng' DATE INSTRUCTIONS .. . . C_~neral: This form is designed for submitting a complete and correct well completion report 'and log on all tyl. pes of lan.ds and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in ether spaces on this form and in any attachments. 'Items 20, and 22:: If this well is completed for separate production from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the prc. Jucing interval, or intervals, 'top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report' (page) on this form, adequately identified, far each adctitional inte~ vel to be seperately produced., show- ing the additional data pertinent to such interval. I~m26: "Sacks Cement": Attached supplemental records for this well shoulci show the details of any mul- tiple stage cementing anti the location of the cementing tool. " Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). ~,' ::~ .;iTMMA.RY OF' I~'~)~IV[ATION 'I']B,~'I'S INC~L. UDIN¢~ INTI~HVAI.. 'I'F_~TED, ~I~I~SSURI~- DA'FA. ~ '~'OV]~P,.IES OF OIL, OAS, ', . · ,. WA'I'li~ AND MUD · : MEAS. DE~TH. ~U~ VERT. D~{ , ' "E" Pool 9058' ' 8066 , (] ~ ; ~ "F", "Pool 9450' 8415' , . ~ :, ~ ,,G,, Pool . 9707' 8640~,. .. ~ . .. . , , ~ ~' ~ ~,~ : ~' :::: .... ~ , , : . ~& CO~E :D~T~, ~CII B~IE~ D~RIPI~O~S O~ L'ITHO~OGY. POROSITY. ,, ~ND ~D~T~C~'~I) SIIOWS OF OIB, G~ OR WA~I. , L i iii i ~ i i mi i l .. . .. . .'. . ,. ~-. :, . : ~ '~ '~ "' I /:~' PD 4A~(Rev. 5-63) Printed ;n U.S.A. / · o /. · M±ddle Ground Shoal (FIE. I.D) · (COUNTY) C-41-23 Section 23 (S"CTIO~ on TSN, R!3W, S.M. (ToWN~Hm oR ~NCHO) .... , : :, _~.,. ~ ,,- ~, TO 2519 1384 1670 2519 3345 4-31 3345 7116 Surface Location: REMARKS Conductor 28, Leg 4 at 38.14'S and 64.85' E from the center of Leg i at 541.65' N and ~596.41'W from the SE Corner SeCtion 23, T8N, R13W, S.M. Elevation 105' D.F. (MLLW) Spudded C-41-23 at 2200 hrs. 12-17-68. Drilled 15" hole to 1384'. Mud 72 pcf Turbodrill #1, 400-937' Faced East CEMENTED 10 3/4" CASING AT 1653' WITH 1350 SACKS. Drilled 15" hole to 1670'. Ran 38 jts, 10 3/4", 40.5 # per fo~ot, Buttress thread casing with guide shoe at 1653'. Cemented casing with 200 cu. ft. water ahead of 1150 sacks class "G" cement (96 pcf. slurry) containing 28 sacks jel and mixed with 306 bbls. inlet water. Followed jel cement with 200 sacks class "G" neat cement (118 pcf. slurry). Displaced cement with 900 cu. ft. inlet water. Bumped plug with 1500 psi. Tested Hydril to 1000 psi and pipe rams to 1500 psi. Drilled 9 7/8" hole to 2519'. Lost two cones off of 9 7/8" bit #1'. Ran bit #2 and junk basket, drilled two hours and recovered one cone. Jumped pin on drill pipe while drilling at 3073. Top of fish 1720'. Ran 6 3/8" overshot, could not get over fish. Ran 7 1/4" overshot, no success. Ran 8 1/8" Shell overshot and recovered entire fish. Drilled 9 7/8" hole to 7116'. At 5314', mud pump pressure dropped 500 psi; Located split tool joint one stand above heavy wall drill pipe. Turbodrill #2, 6047-6095', Faced N78W. Turbodrill #3, 6489-6515', Faced NS8W. Turbodrill #4, 6553-6625'. Faced West. Mud 71-73 pcf. CONDITION AT ~N~ OF PERIOD CASINO s~zg DEPTH SZT -- Io 9 7/S~I 1670 1711.6 DRILL I~iPE ~,, 10 5 10 3/4' 1653' D/VISIoN OF © ~7 ,/. ,.~, .PD. .~,:~'~ (Rei,. 5-63) PJints~ !a d.S.A. Middle Ground Shoal (FIELD) Kena i (COUNTY) FROM 25 PBTD TO 9948 9948 10712 10712 10)12 107.12 10535 10535 DP~LLIHG tLBPORT ~OR P~OD ~D~G January 25, 1969 C-41-23 Section 23 REMARKS Drilled 9 7/8" hole to 9948', Mud 72-75 pcfo Turbodrill {~5, 7116-7176'. Faced S60W. Stuck bit while R. I. H. at 9857'. Worked stuck Pipe 5 1/2 hrs. Ran Dia. Log free point and backed off at 9785'. Ran in screwed into fish and jarred fish free in 1/2 hr. Tripped out with fish. Drilled 9 7/8" hole to 10,712'. Mud 74-75 pcf. Conditioned hole for logging. Ran DUAL INDUCTION LATEROLOG~ RUN 1~ 1658 t° 10,695'. FORMATION COMPENSATED DENSITY~ RUN 1~7250 to 10~704'.. and '~0~HOLE COMPENSATED SONIC LOG~ RUN 1~ 7250 to 10~7~' Conditioned hole for casing. CEMENTED 7" CASING AT 10~593' WITH 900 SACKS. Ran 250 joints, 7" N-80 Buttress Thread casing (26¢f, 36-8450'; 29~, 8450-10,593') with guide shoe at 10,593' and fillup collar at 10,504'. Cemented casing with 400 cu. ft. water ahead of 900 sacks cIass "G" cement (118 pcf. slurry) containing 1% CFR-2 and mixed with inlet water. Displaced cement with 2278 cu. ft. inlet water. Bumped plug with 2000 psi. Ran SPERRY SUN GRYO SURVEY ~ 0- 3000 ' and SCHLUMBERGER GAMMA RAY- COLLAR- CEMENT BOND LOG~ RUN 1~ 7300 to 10~367' , · , Picked up' 6" bit on end of 3 1/2" tubing and cleaned out to 10~535'. Displaced inlet water with diesel. Ran tubing. Dropped bar down tubing but could not break circulation. Pulled bar and on inspection it indicated to have been seated properly. Dropped bar again but still had communications. Pulled tubing found split collar at 5822'. Ran and landed 3 1/2", EUE, 8rd tubing at 9016' with packer at 8948' Tested tubing to 1000 psi. Set packer with 1550 psi and sheared sub with 2600 psi. Gas Lifted 250 bbls. diesel. CONDITION AT~N'It~IO-~OF PERIOD HOLE CASINO mlZg DEPTH 10,593' FEB g 6 'i9 9 DIVISION OF C il i/AD CAS .,. _/ ~/~ (Rev. 5-63) Print~c h~ U.S.A, · · Middle Ground Shoal (FIELD) (COUNTY) Dlt/ G REPORT EOIt PEIIlOD IINDLNG ~n~-y 26, 1969 C-41-23 Section 23 PBTD ]10535 C()NDITION A'C:~ .I~ ~ PERIOD D£PTH SET R;MARK$ Perforated the following intervals with four-i/2" jets'per foot'.' 9087-9108', 9450-9495', 9706-9720', 9732-9764', 9842-9886', 9954- 9993', 10,009-10,147', 10,180-10,235', 10,256-10,316', 10,340-10,370'. 10,396-10'438'. Ran bottom hol'e pressure survey. Placed well on gas lift. Released rig 1600 hrs. 1-26-69. 1653' 10'593 DIVISION OF ©;L/:,bid OA3 ANCO: ..... 3~ :LL NO, 1, D, 438. /+70. 503, 533. 565, 598, 631. 663, 696, 727. 758. 788. 820, 651 · 1 980. 1 273. 1 199, 2 290 · 2 955 · 2 ~84. 2 ~.73. 2 570 · 2 ?67. 2 ;19, 2 LO8, 2 !96. 2 ~84, 2 C-41-23 CONDUCTOR 28 OBJ N 7 E DEV O DIR COUR DTVD TVD 1.25 SE 72. 78, 77,98 437,98 2.2'5 NE 79, 32e 31,97 469,95 3,25 NE 59, 33, 32.94 502,90 4.50 NE 51. 30, 29.90 532.81 6.00 NE ~5. 32. 31,82 564,63 5.50 NE 6~, 33. 32,84 597,48 5,50 NE 74, 33, 32.8~ 630.33 6,25 NE 67, 32, 31e80 662.1~ 7,25 NE 64e 33, 32.73 69~.87 8,00 NE 60, 31. 30,69 725.57 8.75 NE 55, 31, 30,63 756,21 9.00 NE 45. 30, 29.63 785.84 9,00 NE 38, 32. ' 31,60 817,45 OeO0 NE 34, 31, 30.52 847.98 2.75 NE 28, 129. - 125.8~ 973.80 6.00 NE 29, 93, 89.39 1063.19 1,50 NE 33, 126. 117.23 1180.~3 6.00 NE 32. 91. 81,79 1262.22 9.00 NE 34. 65. 56.85 1319,07 9,50 NE 33, 29. ~ 25.24 134~.31 9,50 NE 32. 89, 77.45 1421.77 8,25 NE 32, 197. 173.53 1595,~0 8,00 NE-36, 97, .85.64 1680.95 8,25 NE 36, 152, 133.89 1814.8~ 8,00 NE 3/+, 189, 156.87 1981,72 7.50 NE 34, 188. 166.75 2148.48 7.25 NE 30, 188, 167,1~ 2315,62 JAN, 22 1969 N 0,00 0.00 0.00 0,00 0.00 0.00 0.00 0.00 0,00 0,00 0,00 0,00 0.00 0.00 15.44 ~7.86 76.59 136.54 148e52 185.69 26~.76 301.60 ~59e81 ~33,37 505,94 .579,88 i: D~¥1$ION Of C~L ~qD GAS A~.Cy~ L ~.. 74! S E W DOG LE~ ~0.77 6~,70 0,00 0.00 ~6,53 65.9~ 0,00 35.57 67,5~ 0,00 3~.09 69,~7 0,00 31e72 71,73 0,00 ~,99 30,33 7~,58 0,00 5,93 29,46 77,62 0,00 2,90 28,10 80,82 0,00 3',24 26~,z8 8~.'57 0,00 ~*Z 1 2~.12 88,30 0.00 2.96 21.41 92,17 0,00 ~.37 1'8.10 95.49 0.00 5,20 l~e15 98.57 0,00 9,~9 101.98 0,00 0,00 11~.9~ 0.00 2,32 0,00 127.37 0.00 0.00 15Z,52 0,00 0.00 17~.6~ 0.00 ~.95 0.00 191.28 0.00 ~.~ 0.00 222.28 ~ 0,00 0.55 0.00 271,70 O,OU 0.00 298,46 0.00 i.96 0,00 ~0.75 0,00 0'00 390e37 0,00 0,52 0,00 438,9~ 0,00 0,27 0,00 ~8~,9~ ~ 0,00 SEC, DIST -28,61 -28,22 -Z7'.07 '25.38 -22.74 -21.02 -19,78 --18e04 '15,77 '13,1~ -10,02 -6.32 -2,03 2.75 29,33 53,1U 94,61 130,76 171,67 211,~9 Z99egO 335.73 398e65 ~77,7~ 555,r') 2519, 27,00 NE 28, 2614, 26,50 N~ 28, 2695, 26,50 NE 27, 2851. 26.50 Nc 25. 300~, 25.50 NE 25. 3150, 26,75 NE 23, 3345. 28,75 NE 23, 3533. 31,75 NE 22, 3691. 31,50 NE 23. 3850. 31,50 NE 22. 4005. 31.75 NE 21, 4165. 31.75 NE 20. 4352. 31,50 NE 20, 4541. 30,25 NE 20, 4727, 29.50 NE 19. 4819, 29,50 NE 19. 4912, 29,25 NE 18, 5100. 29.75 NE 18, 5285. 30,00 NE 19, 5486. 30.00 NE 17. 5651, 29,50 NE 16, 5861, 30,25 NE 16, 604.7. 30.00 NE 16. 6065, 29.50 NE 14, 6095, 29.00 NE 13, 6137. 27,75 NE 12, 6169, 27,50 NE 10, 6197, 28e00 NE 35. 31.18 95. 85,01 81. 72,48 155, 139.50 153. 138,09 156. 139,~0 185. 162,19 188, 159,86 158, 134,71 159.. 135'56 156, 132,65 159. 135,20 187, 159,44 189e 163,26 186, 161,88 92. 80,07 93, 188. 163.22' 186. 161.08 200. 173.20 175. 152,31 200. 172.76 186, 161,08 18, 15.56 30.' 26.23 42. 37.16 32. 28.38 28.' 24.72 2346.80' 2431.82 2504"31 2643,92 27@2.01 2921 .~2 3083,51 3243.38 33.78,10 3513 3646.32 3781,~3 ~940,97 4104.24 4266,12 4346,19 4.427,34 4590,~6 4751,64 4924.84 5077.16 5249.92 5411.00 5426.67 5452.9~ 5490.0~ 55~.46 59~.91 631,34 663,5~ 726,63 786'33 850'96 932,87 1024,59 1100,59 1177.61 125~.25 1332.~7 1424.69 1600.76 16~3,59 1686.81 1775.53 1863.47 1959,10 2041.93 2138.79 2228.18 2236,78 2250.96 227'0.08 2284.64 2297'62 0.00 0.00 0,00 0.00 0.00 0.00 0..00 0,00 0,00 0,00 0.00 0.00 O,O0 0,00 0,00 0,00 0,00 0.00 0,00 0,00 0,00 0,00 0,00 0,00 0,00 0,00 0,00 0,00 489.41 509.31 525.72 555.14 582.97 610.41 645,18 % 682.24 714,49 745.62 775,03 803.65 ~ 837,07 869,~3 914,20 928.24- 957,07 ~ 987,35 1016,59 1040.34 1093,7~ 1095,89 1099,16 ll03,ZS 110~,79 1107,~5 0,00 0,00 0,00 0,00 0,00 0,00 0,00 O,O0 0.00 0,00 0,00 0,00 0.00 0,00 O,OO 0,00 0,00 0.00 0.00 0,00 0,00 0,00 0.00 O.O0 0,00 0,-00 0,00 0,00 2.70 0,53 0.55 0,65 0.98 ,' 1,08 1.62 0,37 0.33 0.37 0.33 0,13 0,66 0,48 O,OO 0.59 0.27 0.30 0.50 0.40 0,38 0,13 6.17 2,33 3.18 3.00 2.44 688.71 722,6' 919.0~ 10.04 · llO0.1~ 117~.4~ 1259.7( 1'339'3~ 1~0.~ 1~16.0~ 1~08.8~ 1698 174, 1787.3.~ 1878.9~ 196~ ,9] Z068.3~ 219~.5( 2253.0~ 2353.6~ 2368'1~ 2387'6~ 2~02.3~ ,,%?:..-.- . 229, 292. 342. 393. 514. 5z+2. 566. 5'90 · .636. ~667. ,699, ,731, ,762, ,800e ,825. ~891. ,95~+. ,980. '045, fl08. Fl41, ~176, ~2B7, ~298, Z42Be ~483, 7575, 76B8~ '1 28,2'5 NE 8, 32, 28,18 5571,37 29,25 NE 6. 63, 54,96 56'26,34 31o00 NE 6, 50, 42,85 5669,20 31,25 NE 7, 51. 43°60 5712.80 31.25 NE 7. 94. 80,36 5793,16 31,25 NE 6. 27, 23,08 5815,24 31,.25 NE 5, 28, 23,93 5840,18 31,00 NE 4, 24, 20.57 5860,75 30,75 NE 2, 24, 20,62 5881,38 30,25 NW 1, 46, 39,73 5921,12 29,75 NW 3, 31, 26,91 5948.03 30,00 NW ~, 32, 27,71 5975,74 30°75 NW 5, 32, 27.50 6003,24 31,75 NW 6, 31, 26,36 60Z9.61 32.25 NW 6, 38, 32,13 6061,74 32,75 NW 6, 25, 21,02 6082,77 32.00 NW' 5, 66, 55,97 6138,74 31.75 NW 6, 63, 53,57 6192.31 31,25 NW 7, 31.00 NW 7, 65, 55,71 6270,26 31,00 NW 7, 63. 54,00 6324,26 31,00 NW 7, 8, 6,85 6331,11 30.75 NW 10, 25. 21,48 6352,60 30,25 NW 12. 35, 30,23 6382.83 28,75 NW 15, 61, 53,48 6436,31 28.00 NW.',iT. 61, 53,85 6490,17 27.50 NW 19, 125, 110,87 6601.05 27.25 NW 21. 60, 53,34 6654,39 27,25 NW 21, 92, 81,78 6736,18 26,50 NW 22, 93,' B3,22 6819,41 ,) 2312,62 2343,23 2368.84 2395,10 2457,43 2471,90 2484'24 2496.50 2519,67 2535.03 2550,99 2567,29 2583,51 2603,68 2617,13 2651,97 2684,94 2698,33 2731,56 2763.76 2767.85 2780,44 2797.69 2826,03 2853,41 2907'99 2933,64 2972,96 3011.44 0,00 i109,96 0,00 0,00 1113,17 0,00 0.00 1115,87 0,00 0,00 1119,09 0,00 0,00 1125.03 . 0,00 0,00 1126.50 0,00 0,00 1127.76 0.00 0,00 1128,63 0,00 ., 0,00 1129.05 O,O0 0.00 1128,65 0,00 0,00 1127.84 0,00 0,00 1126,73 0,00 0.00 1125.30 0,00 112~,60T-- 0,00 0,00 1121,~8 0,00 0.00 1120,06 0,00 0,00 1117,02 0.00 0,00 111~,55 0,00 0,00 1111,91 0,00 0,00 1107,8~ 0,00 0,00 110~,87 0,00 0,00 1103.37 0.00 0,00 1101.15 0,00 0,00 1097e4~ 0.00 0.00 1089,89 0,00 0,00 1081,52 0.00 0,00 1062,7~ 0,00 0,00 1052,88 O,O0 0.00 10~7,79 ~ OeO0 0,00 1022,24 0,00 1,67 2,20 3.50 1,13 0,00 1,92 1.85 2.39 ~'+,40 3,48 1,74 2,83 3.63 1,32 2,00 1,40 0.93 2,78 0,38 0,00 0,00 6,2~+ 3.23 3,45 1,98 0.85 1,59 OeO0 0,9~+ 2430,65 2461,43 2.487,18 2562. 2576,~0 2990,92 2603,2b 2638,44 2653.59 2669.29 2685.30 2701.19 2720,95 27~4,13 Z768,3~ 2800,6~ 2813,72 2877... 28~1,69 2893,91 2910.58 2937,79 29~3,95 3015,~3 3077.28 k '792. 26'00 NW 22. 124. 111.45 ~887. 25.00 NW 24. 95. 86.09 t985. 25.50 NW 23. 98. 88*4..5 ~077. 25.50 NW 23. 92. 83.03 ~148. 26.00 NW 24, 71. 63.81 ~267. 26.00 NW 25. 119. 106.95 1357. 26.00 NW 26. 90. 80.89 1520. 26.25 NW 27. 163. 146.19 1665. 26e75 NW 27e 145. 129.48 1796. 27e25 NW 29e 131. 116.46 $911. 26.75 NW 28. 115. 102.69 ;104. 26.50 NW 29. 193. 172~72 ;225. 26.75 NW 30. 121. 108.05 ;305. 27.00 NW 30. 80. 71.28 ;565. 27.'75 NW 32. 260.. 230.09 ;759e 30.00 NW 32. 19'4e 168;'00 ;863. 30.25 NW 32. 104. 89.83 ;948. 31.00 NW 31. 85. 72.85 )036. 32.00 NW 32. 88. 74.62 )250. 32e50 NW 34e 214. 180e48 )347. 32.25 NW 31. 97* 82.03 )513. 31e50 NW 32. 166. 141.53 )712. 30.00 NW 32. 199. 172.33 6930.86 7016.96 7105e41 7188.45 7252.27 7359.22 7440.11 7586.30 7719.79 7832.25 7934*94 8107.66 8215.71 8286.99 8517.09 8685110 8774*94 8847.80 8922.42 9102.91 9184.95 9326e48 9498.82 3061.84 3098.52 3137.35 3173.81 3202.24 3249.52 3284.98 33~9,22 3407,37 3~59'83 3628,02 3659,47 3762,13 38~8,~3 3926,35 3965,90 406~,22 4179.1~ 0.00 0.00 0.00 0'00 0.00 0.00 0 .'00 0.00 0.00 0.00 0.00 0,-00 0.00 0,00 0.00 0.00 0,00 0.00 0,00 0.00 0,00 0.00 0,00 1001,88 0.00 0,40 985.55 0,00 969.06 0,00 953,59 0.00 940.9~ ~ 0.00 ' ~ 918,68 0,00 0,~7 901.59 0,00 0*~9 868,86 OeO0 0.31 839e23 0.00 0.34 810.15 0.00 0.79 785.89 O*OO 7~4,10 ~' 0,00 0,27 716.87 0.00 0.42 698.71 0.00 0.31 6~4.55 O.OO 0.4~ .583,15 0,00 1,16 599,39~'.' 0.00 532.84 0.00 1.07 508 · 13 0,00 ~3,83 0,00 0,5~ 417.17 0.00 371.21 0.00 0"55 318 ,~8 3195,53 32~,37 3293,05 3337,2~ 3370.~7 3532,77 3575.~7 3811,~3 38..86,81 3~27,53 ~125.83 SHELL OIL COMPANY 430 '7'tH AVENUE ANCHORAGE, ALASKA 99501 February 3, 1969 Confidential Material STATE OF ALASKA 3001 Por~cupine Drive Anchor age, Alaska Attention To R. Marshall, Jr° Gent lemen: Enclosed is the Monthly Report~~~tions ( copies) for January, 1969, for our Middle Ground Shoal We.~ C-41-23 ~nd the2"C'' Line Well No. 1. Very truly yours, R. Do Allen Division Exploitation Engineer WC~/db Enclosures DIVISION fbi: F~¢~ No. ~--~ STATE O'F ALASKA REV. 9-30-67 SUBMIT IN D~PLICAT~ OIL AND GAS CONSERVATION COMMITTEE MONTHLY REiPORT OF :DRILLING AND WORKOVER OPERATIONS AP1 NI/MERICAL CODE 50-133-20163 LEASE DESIGNATION AN'D SEEIAL NO. ADL 18756 1~-' ' 7. IF INDIAN, ALO'I tEE OR TRIBE NAME O~L ~ o*s '~ o~,~ER None WELL WELL 2. NAME OF OPIgR-ATOR 8. LrNIT,FA_R~M OR LEASE NAAIE Shell 0il Co. Middle Ground Shoal 3~ ADDRESS OF OPERATOR 9. %VELL NO. 430 Seventh Avenue, Anchorage, Alaska C-41-23 10. FieLD A_ND POOL, OR WILDCAT Middle Ground Shoal 4. LOCAl/ON OF WELL Conductor 28, Leg 4 at 38.14' S and 64.85' E from the center of Leg 1 at 541.65' N and 1596.41' W from the SE Corner of Section 23, T8N, Rt3W, S.M. 11. SEC., T., R., M., (BOT'TOM HOLE OBJECTIVE) Section 23, T8N, R13W, S.M. 12. PEI~MIT N'O. 68-112 13, REPORT TOTAL DEPTH AT END OF MONTH, CH.A-NGES IN HOLE SI~-,E, CASING AND CEMENTING JOBS INCLUDING DEPTH SET ANI) VOLI/MES USED, PF2RFORATIONS, TESTS A1VD I~ESULTS. FISHING JOBS, JUAIK IN HOLE A-~D SIDE-T1R~CKED HOLE ANT) A_NY OTI-IER SIGNIFICANT CI--IAN~ES IN HOL]~ CONDITIONS. Drilled 9 7/8" hole to 10,712'. Ran LOgs. Cemented 7" casing at 10,593' with 900 sacks. Ran LOg. Landed 3 1/2" tubing at 9016' with packer at 8948'. Perforated with four- 1/2" jets per foot. 9087 - 9108'~ 9450- 9495', 9706- 9720', 9733- 9764', 9842- 9886', 9954- 9993', 10,009- 10,147', 10,180- 10,235', 10,256- 10,316', 10,340- 10,370', 10,396- 10,438'. Ran bottom hole pressure survey. Placed well on Gas Lift Relased rig 1600 hrs. 1-26-69. DIVISION OF r- _ A;':,;) OAS NOTE~Report on this form is required for each calendar month, regardless of the status of operations, and must be filel~ in i:luplicate with the Division of Mines & Minerals bythe 15th of the succeeding month, unless °therwise direct~i~t~l~it~~t~l%'~"~" ~ ~ ICU~ ~ ' ?'~:''~ ~ ~ ~''~' SHELL OIL COMPANY 430 7TH AVENUE ANCHORAGE. ALASKA 9~01 January 3, 1969 CONFIDENTIAL MATERIAL STATE OF ALASKA 3001 Porcupine Drive Anchorage, Alaska 99501 Attention Homer L. Burrell Gent lemen: Enclosed is the Monthly Report of Operations (2 copies) for D~m~~968, for our Middle Ground Shoal wells G-24-23 Very truly yours, R. D. Allen Division Exploitation Engineer WCHfbr Enclosures ,API NUA~ERICAL CODE Form No. P--4 STATE OF ALASKA suB~rr x~T DEPLICkTE OIL AND GAS CONSERVATION COMMITTEE ~VIONT'HLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1, O,L o*, [] WELL WELL OTHER 2. N,~ME OF OPER2~TOR Shell 0il Company 3, ADDRESS OF OPERATOR 430 Seventh Avenue, Anchorag%~ A%aska 9950]_ 4. LOCA~ON OF WELL Conductor 28, Leg 4 @ 38.14'S and 64.85'E from the center of Leg 1 at 541.65'N and 1596.41'W from the SE corner Section23, T8N, R13W, S.M. 50-133-20163 6. LE~SE DESIGNATION AID SERIAL NO. ADL 18756 7. IF INDIAN, ALO 1 1 EL O,~ TI{IBE NASIE None 8. I/NIT,F.~R~M OR LEASE N.~ME Middle Ground Shoal WELL NO. C-41-23 10. FIF_J. JD AND POOL, OR WILDCAT 11. SEC., T., R., M.. tBO/'TOM HOLE OBJECTIVE~ Sec. 23, T8N, R13W, S.M. 12. PER/VIIT NO, 68-112 13. REPORT TOTAL DEPTH AT END OF MONTH, CI-L~NGES IN HOLE SI~E, CASING AND CE1VIENTING JOBS INCLUDING DEPTH SET AND VOLU1ViES USED, PERFORATIONS, TESTS ANT) RESULTS. FISHING JOBS, JUNK IN HOLE A_ND SIDE-TRACKED HOLE AND ANY OTI-IEI{ SIGNIFICANT CHANGES IN I-IOLJ/I CONDITIONS. Spudded C-41-23 at 2200 hrs. 12-17-68. Drilled 15" hole to 1670'. Cemented 10-3/4" casing at 1653' with 1350 sacks. Drilled. 9-7/8" hole to 7116'. DI¥1$1ON OF OiL AND GAS CO tFIDENTIAL SIGNED TITJ-~ · Div. Exploitation En~r.,. nA..~-S _January 3, 1969 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. SHELL OIL COMPANY 430 7TH AVENUE ANCHORAGE. ALASKA 99501 December 18, 1968 Re: Middle Ground Si~oal Field Well C-41-23 ADL 18756 STATE OF ALASKA Division of Land 394 Sixth Avenue Anchorage, Alaska 99501 A~tention Pedro Denton Gentlemen: Please be advised that on December 17~ 1968, Shell. Oil Com- pany, as operator~ spudded development well C-41-23 o:} State lease ADL 18756. The well will be directionally drilled to a location in the NE/& NE/4 of Section 23~ T8N, R13W, S.M. ~vtsto~ o~ o~ ,~o o~ Very truly yours, .' >"" . R.D. A1]e~ Division Exploitation Engineer 1~ 12. 19~ ~ll Otl ~m~y please find ~ aplMMmd d~pl~~ for referememl ~o11. bll ompb aid core Homer L. Barrel! ~lomaze SHELL OIL COM'PANY 430 7TH AVENUE ANCHORAGE, ALASKA 99501 December 10, 1968 Priyate and Confidential STATE OF ALASKA Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska Attention T.R. Marshall, Jr. Ge ntlemen: Enclosed for your approval is our Application for Permit to Drill well S.A.S.M.G.S. C-41-23 from our Platform "C". Also enclosed is our check in the amount of $50.00 for the filing fee. Enclosure~: Filing Fee Check (1) Application to Drill (3) Location Plat (3) Blowout Prevention Program (3) yours, R.D. Allen Division Exploitation Engineer RECEIVEE) DEC 1 1 1968 DIVISION OF OIL AND GAS ANCHOt~AGE FORM 'SA - I ,B 125.5M 8/6? MEMO-RANDUM TO:r- FROM: State. of Alaska DATE : SUBJECT: FORM 'SA - 18 125.5M 8/67 ~ MEMORANDUM TO: I- FROM: State of AI-aska DATE : SUBJECTJ SUBMIT IN TRI~ ~TE (Other instructions ~.~ Form 1~--1 reverse side) REV. 9~30-6~ STATE O'F ALASKA OIL AND GAS CONSERVATION ,COMMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK la. TYPE OF WORK DRILL IMI WELL WELL 2. NAME OF OPERATOR Shell 0±1 Company 3. ADDRESS O~ OPERATOR OTHER DEEPEN [-] PLUG BACK zo N E ZO N E 430 Seventh Avenue. Anchorage= A]~sk~ 9950] 4. LOCATION O~F WELL ' ~tsurface Conductor 28, 38.14'S and 64o85'E from center Leg 1 @ 541.65'N and 1596.41'W from SE corner, Sec. 23, T8N, R13W, S.M. At proposed prod. zone *See below. ~-' ' '' -~ : .... :' 13. DISTANCE IN MILES AND DIRECTION FXOM NEAREST TOWN OR.POST OFFICE* 17 Miles NW of Kenai~Alaska -~ ' i 14. BOND INFO1R2VIATION: State Wide 0il and Gas TYPE Surety and/or NO. TIC 136503 1§. DISTANCE FROM PROPOSED'~' ..... "- LOCATION TO NEAREST PROPERTY OR LEASE LINE~':FT ..... (A~ to nearest drig unit, if any) ~,,, ' -:: T :,-~ -'~ L~~ .... '~ ;. - ~ :~'~j .... 18. DISTANCE FRO~ PROPOSED LOCA~ON TO NEAREST WELL DRILLING, COMpLE~ OR APPLI~ FOR, FT. -' ............ ~0 7 00 I 21. ELEVATIONS (Show whether DF, RT. CR, etc.) 105' D.F. (MLLW). 23. - ~" : : PII(~PosED CASING AND CEMENTING PROGRAM API 50-133-20163 6. LEA~E DESIGNATION AZN~ SERIAL NO, ADL 18756 None '8. ~IT, FA~ OR LE~E N~E Middle Ground Shoal 9. WELL NO. C-41-23 10. FIELD AND POOL, OR WILDCAT Middle Ground Shoal 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 23, T8N, R13W, S.M. 12. .~o,,~.: $~00,000.00 NO. ACRES ASSIGNED TO THiS WELL 80 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START* Dec. 17; 1968 , SIZE OF HOLE SIZE OF ~slNG/ "~VEIGH~, pER FOo~ : GRAD~ i r;~ SET~FmG~ DEPTH ' ~U*NTiT, OF 15 10-3/4" 40.5~) J 1650'~ ' 'i350 Sacks 9-g/8" 7"-~ · ~- 26~).?& Z9~)-~. · N . 11,700,+., _ . . . , .1290 Sacks ?'~~. ¢ ,,. ..... *Top of productive zone :" -"9000~+ (8100'+ -TVD)1150'-+ S and 850'+ W from NE corner section. Bottom hole location: 11,700'+ (10,500'+ TVD) 140'-+ S.and 1770'+ ~rom NE corner~ Sec. 23 RECEIVED DEC 1 1 1968 Di¥1$1ON OF Oil AND 6&$ ANCMORA~ IN ABOVE SP~CE DESCRIBE PROPOSED PROGRA1Vi: If proposal is to deepen or plug back, give data on present productive zone and proposed new productive zof~e. If Pr(~posal is to drill, or deepen directLonally, give pertinent data on s~bsurface locations and measuma(l and true vertical de?..~. ~wo~tt ~.venter prograph. S?GNI~-~D ~~----t~d COrrect' hereby Division -- ' --.,---.,--- DATE.DEC ~. O 1968 TI~ Expqm~nn ~ngr. (This space for State office use) CONDITIONS OF APPROVAL, IF ANY: [] YES XNo DIRECTIONAL~URVEY REQ~ A.P.I. ~CAL CODE ~.~.TES [] ~o ~ ~'~ ~ I ~ '~ ~ 2. ~ / ~'.~ ~' *See Inmuctions On Reveme Side 17-19-6_a I A. 34-14 i p · 1~ 14 i 14 13 I T. 8 ~.~._~_a_W., S.M C'23'2i3 C.43-23 ADL 18756 22 23 I 23 24 27 26 ! ~6- 2~ i LO(~ATIOII OF CONDUCTOR 28, LEG#4 BOTTOM HOLE LOCATION WELL C.41.23 PUBLIC LAND DESCRIPTION CONDUCTOR 28, LEG No 4 LOCATED 38,14~$ 140'$ AND I??0~E AND 64.8S~E FROM CENTER OF LEO No ! FROM THE NE COR. OF THE SOUTH LINE AND 1596.41' WEST OF THE. EAST LINE. m~' I i I II DRAWN BY: N.L.B. SCALE: 1". 1,000, ~.,~-~,~: ~'.~.'~. SHELL OIL COMPANY I I lOCATION OF SHELL-ATLANTIC-STANDARD WELL C.41-23 IN SEC. 23 T. 8N., R,13W.,S.M.- COOK INLET - STATE OF ALASKA I DRILLING~ CASING: AND BLOWOUT PREVENTION PROGRAM WELL C-41-23 MIDDLE GROUND SHOAL - PLATFORM "C" COOK INLET, ALASKA... 1. Move rig over 24" conductor 28, Leg 4. Install 20", 2000 psi Hydril preventer and riser. 2. Directionally drill 15" hole to 1650'±. Run 1650'± of 10-3/4", 40.5~ J-55 Buttress casing. Cement with 1350 sacks API cement (1150 sacks gel cement and 200 sacks neat cement). 3. Land casing and flange up 12" 3000 psi preventer stack consisting of Double Shaffer Gate and G.K. Hydril, riser, and Cameron compact wellhead. 4. Directionally drill 9-7/8" hole to 11,700'±. Run logs at TO. Run 11,700'± of 7" 26# and 29# N-80 Buttress casing. Cement with 1290 sacks API cement. 5. Run 3-1/2" 9.3# J-55 and N-80 EUE tubing string equipped with packer. Dis- place Inlet water from casing and tubing with diesel oilo Set packer. 6. Perforate productive zone with 4 shots per foot at selected intervals. Place well on production. .PRJ 12/9/68
