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Home My WebLink About197-162 STATE OF ALASKA ALASKA _AND GAS CONSERVATION COMMISSe Rt:CE/VEr JAN 1 9 2006 ons. Comm, aYe WELL COMPLETION OR RECOMPLETION REPORT AND ~n 1a. Well Status: OilU GasD Plugged 0 Abandoned[] SuspendedD WAGD 1b. Well Class: ". ..... lJas 0#' 20AAC 25.105 20AAC 25.110 Development [] Explorat~( , GINJD WINJD WDSPL 0 No. of Completions 1 Other Service 0 Stratigraphic TestD 2. Operator Name: 5. Date Abandoned 12. Permit to Drill Number: Union Oil Company of California 11/5/2003 197-162 3. Address: 6. Date Spudded: 13. API Number: PO Box 196247, Anchorage, AK 99519 nla 50-733-20480-00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1,041' FNL, 463' FWL, S33, T9N, R13W, SM nla M-16 Top of Productive Horizon: 8. KB Elevation (ft): 15. Field/Pool(s): nla 160' above MSL McArthur River Field Total Depth: 9. Plug Back Depth(MD+ TVD): Grayling Gas Sands 776' FSL, 1330' FWL, Sec. 28-T9N-R13W, SM nla 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 214,078 y- 2,499,462 3,625'/2,667' Steel head Platform TPI: x- nla y- nla 11. Depth Where SSSV Set: 17. Land Use Permit: Total Depth: x- 214,989 y- 2,501,257 448' nla 18. Directional Survey: Yes [] No 0 19. Water Depth, if Offshore: 20. Thickness of Permafrost: 187' feet MSL nla 21. Logs Run: nla 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 28" 82' 488' 81' 487' Driven 13-3/8" 68# K-55 82' 840' 81' 836' 17-1/2" See Schematic Attached 9-518" 47# L-80 81' 1,506' 80' 1 ,435' 12-1/4" 7" 29# L-80 1,295' 3,623' 1,260' 2,666' 8-1/2" 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) SZ- 12, Opened 5/7/01, 1,751'-1,808' MD; 1,614-1,652' TVD nla SZ-14, Opened 5/7/01, 1,959'-2,004' MD; 1,747-1,774' TVD SZ-15, Opened 5/7/01,2,092'-2,130' MD; 1,826-1,848' TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. SZ-17, Cmt Isolated on 9/23/02, 2,485'-2,559' MD; 2,042-2,081' TVD SZ-18, Cmt Isolated on 9/23/02, 2,612'-2,667' MD; 2,110-2,140' TVD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED SZ-22, Cmt Isolated on 9/23/02, 3,211'-3,239' MD; 2,440-2,455' TVD nla nla SZ-23, Cmt Isolated on 9/23/02, 3,387'-3,408' MD; 2,535-2,546' TVD 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): nla nla Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: I Gas-Oil Ratio: Test Period -+ Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity - API (carr): 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". none '.""'"'~''' I' f· S~- \{', RBDMS BFL JAN 2 5 2DD6 \iP""," '"~ ~;Jc,"'.. Form 1 0-407 Revised 12/2003 o RIG I N ArE 161408 CONTINUED ON REVERSE G NAME GEOLOGIC MARKERS MD 29. ORMATION TESTS 28. TVD Include and briefly sum e test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top MKG Pool SZ12SB SZ13SB SZ16ST SZ19ST SZ21ST SZ22SB SZ23BSB ACT ACB A1ST A1SB A1CT TD none 1,500 1,808 1,916 2,157 2,802 3,025 3,248 3,416 3,479 3,503 3,514 3,537 3,549 3,625 1 ,430 1,652 1,721 1,864 2,214 2,338 2,460 2,551 2,586 2,599 2,605 2,618 2,624 2,667 30. List of Attachments: Directional survey, schematic, daily operations summary 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Larry Buster 263-7853 Title: Drilling Manager Signature: Phone: 907-276-7600 Date: Sundry Number or NIA if C.O. Exempt: / P'-¿;;;fc<~ 303-296 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing 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 be 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 AFE 161408 /' - e Well Name: M-16 Wellbore Schematic: M-16, as abandoned 11/05/03 Operator: Unocal Alaska Field: McArthur River Field API: 50-733-20480-00 Permit: 197-162 Casina Detail Well Type: Gas well Size Wt Grade Type Top (FT) Btm (FT) Length (FT) Well Status: Abandoned 28" Structural 82 488 406 RKB 160' above MSL 13-3/8" 68# K-55 Surface 82 840 758 TD/TVD: 3,958'/2,566' 9-5/8" 47# L-80 Intermediate 81 1,506 1,425 PBTD/PBTVD: nla 7" 29# L-80 Liner 1,295 3,623 2,328 Jewelry Detail No. Type Depth (FT) Baker SC-1 packer, 70A4-40. 3/24/01 RST SIGMA log depicts packer at 1,621', 1,61" 1 Log is 2' high to DIL Model"S" GP ext, 80-40 with sliding sleeve with 16' lower ext 1,620 3 jts blank pipe, with weld on centralizers in middle and pin end 1,644 2 3 jts Bakerweld 140, 4" x 12 gauge screen 1,73c - - 1,82c 5 joints slim pack, 4" x 12 gauge screen with 20-40 Baker bond '" / 7 jts Bakerweld 140,4" x 12 gauge screen 1,92E - I-- Model "S-22" Snap-Latch seal assy, 82-40 with 1.84' of seals 2,13E 3 Baker "SC-1R" packer, size 70-40. with 5' MOE 2,13~ - I-- Landing collar, 5-1/2" with solid aluminum plug. Plug milled out with coil unit on. 2,14E TOCat1,518" Anchor latch seal assy with 1 seal unit. Size 82-40. 2,14~ - '-- '.. ..,...,........ 4 Baker SC-1 packer, 70A4-40 2,15C X I ><"IX 3 Model "S' GP ext, 80-40 with sliding sleeve with 16' lower ext 2,15c 1 ,553' cemel1t Through tubing cement retainer with open hole element pumped 16 bbls of 15.8 2,15~ retainer 5 ppg "G" cement below retainer KOIV size 5" 2,17E 8: ~1 10 joints blank pipe, with weld on centralizers in middle and pin end 2,181 1 6 3 jts Bakerweld 140, 4" x 12 gauge screen 2,481 2 jts slim pack, 4" x 12 gauge screen with 20-40 Baker bond 2,57'1 2 jts Bakerweld 140, 4" x 12 gauge screen 2,61'1 Model "S-22B" Snap-Latch seal assy, 82-40 with 2.02' of seals 2,67011 2 7 Baker SC-1 packer, 70A4-40 2,675 38: ~ Model "S" GP Ext, 80-40 with sliding sleeve with 16' Lower ext 2,68C KOIV size 5" 2,70 1 pup joint blank pipe, with weld on centralizers on pin end 2,70E 4~ ìX 16 joints blank pipe, with weld on centralizers in middle and pin end 2,721. 8 3 jts Bakerweld 140,4" x 12 gauge screen 3,20oll ~18 3 jts slim pack, 4" x 12 gauge screen. with 20-40 Baker bond 3,29'1 10 2 jts Bakerweld 140,4" x 12 gauge screen 3,35c Model "S-22B" Snap-Latch seal assy, 82-40 with 2,82' of seals 3,41c 9 Retainer production packer, size 80-40 3,416 Baker 'FA' packer (Sheared off packer at 2,154' and pushed same downhole to 2,18..: 6 10 2,182'. Packer is partiallv set) tlenoratlon Uetall 78: ~ Zone Status Top (FT) Btm (FT) Length (FT) SZ- 12 Opened 5/7/01 1,751' 1,808' 57.00 SZ-14 Opened 5/7/01 1,959' 2,004' 45,00 SZ-15 Opened 5/7/01 2,092' 2,130' 38.00 SZ-17 Cmt Isolated on 9/23/02 2,485' 2,559' 74,00 SZ-18 Cmt Isolated on 9/23/02 2,612' 2,667' 55,00 8 SZ-22 Cmt Isolated on 9/23/02 3,211' 3,239' 28,00 SZ-23 Cmt Isolated on 9/23/02 3,387' 3,408' 21,00 - - ILast Revised: 1/17/06 I Revised By: DED~ 11/02/03 - e RU Pollard wireline on M-16. 11/03/03 RU and test Pollard lubricator to 500 psi. PJSM on pulling SSSV. RIH with 6.10" GR to 448' POOH. RIH and pull 7" SSSV. RD slickline. RU Schlumberger. RIH with 7" Halliburton EZSV to 1,550'. Set 7" EZSV at 1560' e-line measurements. POOH. RD Schlumberger. Pressure test 7" and retainer to 1,500 psi ( good test.) Switch over to 9 5/8" X 7" annulus and pressure up to 1500 psi for 30 min ( good test). PJSM, RIH 9 - 4 3/4" Drill collars and 3 jts drill pipe make up Halliburton RTTS Storm valve, RIH and SET at 289'. Back out of storm valve. POOH pressure test 7" against storm valve to 3000 psi good test. ND 7" Tree. 11/04/03 Change out upper rams to 5" and bottom rams to 3 1/2". RU test BOP to 250 OSI low and 3,000 PSI high. 11/05/03 Finish testing BOPs. Release RTTS and POOH. Make up cement stinger. Single in hole on 3 1/2" drill pipe. Break circulation with Schlumberger. Test line to 3,000 psi. Mix and pump 20 bbl, 15.8 PPG cement slurry. Cut displacement short by 2 bbl. Pull out of retainer and let cement equalize above retainer, picked up 35'. Circulated two botoms up. POOH with cement stinger RU tongs and unit, to lay down 7" tubing. Make up cross over sub on stand of drill pipe. Screw into hanger. Pull tubing seals out of packer. Circulate and displace well to FIW. Pull and lay down 7" tubing. M-16 Abandonment, 161408 morning report summary, CONFIDENTIAL: last revised 1/17/2006, Page 1. e e Report Name Position Log Well M-16 Date Created 1/10/2006 KB SuñX SuñY Well Name CURRENT STATUS API (ft) (ft) (ft) M-16 GAS 507332048000 160 214,078 2,499,462 MD TVD SSTVD X Off YOff X Y Inc Azimuth (ft) (ft) (ft) (ft) (ft) (ft) (ft) (deg) (deg) 0 0 160 0 0 214,078 2,499,462 0 0 90 89 71 0 0 214,078 2,499,462 0.2 200 180 179 -19 0 0 214,078 2,499,462 0.1 14 270 . 269 -109 0 0 214,078 2,499,462 0.1 260 360 359 -199 0 0 214,078 2,499,462 0.1 28 450 449 -289 0 0 214,078 2,499,462 0.2 93 559 558 -398 0 1 214,078 2,499,463 2.3 334 648 647 -487 -2 8 214,076 2,499,470 6.8 332 701 700 -540 -5 15 214,073 2,499,477 9.8 335 737 735 -575 -7 21 214,071 2,499,483 11.3 338 800 797 -637 -11 33 214,067 2,499,495 13 348 863 858 -698 -13 47 214,065 2,499,509 12.9 351 958 950 -790 -14 71 214,064 2,499,533 15.9 2 1,053 1,041 -881 -11 99 214,067 2,499,561 18.7 6 1,147 1,128 -9.68 -4 132 214,074 2,499,594 23.9 14 1,240 1,212 -1,052 8 170 214,086 2,499,632 27.6 22 1,334 1,294 -1,134 28 212 214,106 2,499,674 31.1 27 1 ,428 1,373 -1,213 52 257 214,130 2,499,719 35.1 26 1,478 1,413 -1 ,253 66 283 214,144 2,499,745 36.3 27 1,601 1,508 -1,348 103 352 214,181 2,499,814 42.2 27 1,696 '1,577 -1,417 133 410 214,211 2,499,872 46.2 25 1,791 1,641 -1 ,481 164 473 214,242 2,499,935 48.6 25 1,884 1,701 -1,541 197 536 214,275 2,499,998 50.6 27 1,979 1,759 -1,599 234 601 214,312 2,500,063 53.6 30 2,074 1,816 -1,656 272 667 214,350 2,500,129 53.8 28 2,168 1,870 -1,710 311 734 214,389 2,500,196 56.1 30 2,262 1,921 -1,761 351 801 214,429 2,500,263 57.2 28 2,356 1,972 -1,812 390 870 214,468 2,500,332 57.5 28 2,450 2,023 -1,863 428 940 214,506 2,500,402 57.6 28 2,542 2,072 -1,912 467 1,007 214,545 2,500,469 57.1 29 2,636 2,123 -1,963 506 1,075 214,584 2,500,537 57 29 2,730 2,175 -2,015 545 1,144 214,623 2,500,606 56.9 28 2,824 2,226 -2,066 583 1,212 214,661 2,500,674 56.4 27 2,918 2,279 -2,119 620 1,281 214,698 2,500,743 56 27 3,010 2,330 -2,170 655 1,349 214,733 2,500,811 55.6 26 3,105 2,383 -2,223 693 1,418 214,771 2,500,880 57.1 28 3,199 2,434 -2,274 732 1,487 214,810 2,500,949 57.7 29 3,293 2,484 -2,324 773 1,555 214,851 2,501,017 57.5 30 3,386 2,534" -2,374 813 1,622 214,891 2,501,084 56.8 29 3,479 2,586 -2,426 851 1,690 214,929 2,501,152 56.6 28 3,572 2,637 -2,477 889 1,757 214,967 2,501,219 56.2 28 3,625 2,667 -2,507 911 1,795 214,989 2,501,257 56 28 Unocal Alaska 909 W 9th Ave Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 Email: oudeand@unocal.com UNOCALi) ""'-Alaska Debra A Oudean G & G Technician ø[lY-{ January 29, ~ DATA TRANSMITTAL To: From: Lisa Weepie Debra Oudean 333 W 7tn Ave, Suite 100 909 W. 9th Avenue Anchorage, AK 99501-3539 Anchorage, AK 99519-6247 AOGCC Unocal Alaska Transmitting as follows: i ;~~~~~:~~r ~~~1I! '~!~r~~1I ~.fl~" }~ft' ~~~" ~Ii~. J Cf5j-ClP L{ TBU G-21 RD. COMPLETION RECORD . : 5 INCH. 9380-9900 .1 1,0 " , BU M-1 ,COMPLETION RECORD OWEN X-SPAN PATCH, '" , 5 INCH " ,12/1212003 4100-42,96, ,:.1 1: 0 I1&rŒ7 TBUM~1 ':fRSTSIGMALOG ,"" , ~j~INCI!.--J~2~~50-4360 , ~~:r- ) ?f1'<JI9 r!BU M- ~~-"~'~I.~O~~!:~!ION ~ECORD 2.5 HSD POWE~~ET~_....______j5 INC~~.~.!.!?!2003'"r.~~~~~l!M!!Lî4r!_.-r~-'I~.--' ) f59-QLIC¡ TBU M-13 : PERFORATING RECORD 2.5 HSD POWERJETS : 5 INCH :1 11/2/2003'12538-2700 l!.licl' 1: 0 ) q'1-IIP TBU. M-16 !cOMPLElmN RECORDEZSV DRILL PACKER,S INCH ,-I W3I20031560-1606, r ß)iJ~-rlH" q.... . TBU M-16RD :CEMENT BOND LOG .15 INCH :111/13/200313859-3958 1 : 1 o.¡ 0 . '1(6- 'f5 TBÜ M~16RD ~COMPLETION RECORD 4.72 HSDPOWERFLOWŠ 7'-~3I2õ0312755-3800 ' 'ì1J9iflfl111'j õ~... 7\ . MODEL FA SUMP PACKER 'I I '1 I .- I ~ q" ; ::> TBU M=5~- . .. .. COMPLËTION REC;ORD VELOCITY STFUNG P Ac'KE'R" 15 INCH - u'-I-ïi2512003ISÕ-33S0 11 J()'iJ~'1 i - ~IO-- J (5 . - /ð .TUBING PUNCHER .' . .I : RECEIVED F~r~.p 2 6 ?f\04 "- ..J ... L! t .i~iaßka Oi! & Gas Cons. Commission An('horage ," '.'.---:- -,....,... . of this transmittal or FAX to 907 263-7828. Date: 8CA.\~NED ~~Å~ 1 5 2004 Unocal Alaska Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519-6247 Telephone (907) 276-7600 UNOCAL Larry Buster Drilling Engineer September 23, 2003 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn' Commission ChairSarah Palin Re: Sundry to Abandon (form 10-403) t%'"~ - \ ~ '~ Steelhead Well M-16 Commissioner Palin' Attached is an Application for Sundry Approvals (form 10-403) for the Steelhead Well M-16 Abandonment. We intend to abandon this well and then utilize the slot to drill the Steelhead Well M-16RD. I will be submitting an Application for Permit to Drill for the M-16RD Well under separate cover. Please call myself at 263-7804 with any questions you may have. Larry Buster Drilling Engineer LWB/s Attachment i" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATIONCdMMISSION APPLICATION FOR SUNDRY APPROVALS , -- 1. Type of Request: Abandon: x Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair ~v'ell: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Unocal Corporation Development: x 160' KB Above MSL feet 3. Address Exploratory: 7. Unit or Property name P.O. Box 196247 Stratigraphic: Anchorage, AK 99519-6247 Service: Trading Bay Unit 4. Location of well at surface ,v/" ,] ,,/" 8. Well number 1,041' FNL, 463' FWL, Sec. 33-9N-R13W, SM (Leg A-1 Conductor #4 Steelhead Platform) M-16 At top of productive interval 9. Permit numbe, r/~ 591' FNL, 603' FWL, Sec. 33-T9N-R13W, SM 97-162 At effective depth 10. APl number v~ 50- 733-20480-00 At total depth 11. Field/Pool 776' FSL, 1330' FWL, Sec. 28-T9N-R13W, SM McArthur River Field/Grayling Gas Sands 12. Present well condition summary Total depth: measured 3,625 feet ~/' Plugs (measured) 2,159' - Cmt. Retainer true vertical 2,667 feet Effective depth: measured 3,446 feet Junk (measured) 2,182'- Baker FA Packer true vertical 2,530 feet Casing Length Size Cemented Measured depth True vertical depth Structural 406' 28" Drive 448' 448' Conductor Surface 768' 13-3/8" 1,350 sx 850' 849' Intermediate 1,419' 9-5/8" 575 sx 1,500' 1,436' Production 2,363' 7" 880 sx 3,624' 2,650' Liner Perforation depth: measured 1,751'-1,808', 1,959'-2,004', 2,092'-2,130' true vertical 1,613'-1,651', 1,748'-1,775', 1,826'-1,848' Tubing (size, grade, and measured depth) 7", 29# L-80 NSCC f/68' to 1,295' Packers and SSSV (type and measured depth) Baker ZXP Liner Top Packer @ 1,295' HES WRSSV 3.5" ID in 5.963" Lock Mandrel @ 448' Baker SC-1 Packer at 1,615' 13. Attachements Description summary of proposal: x Detailed operations program: BOP sketch: x 14. Estimated date for commencing operation 15. Status of well classification as: 11/1/2003 16. If proposal well verbally approved: Oil: Gas: x Suspended: Name of approver ~ Date approved Service: 17. I here~ ~oregoi~.~ ~correct to the best of my knowledge. Sig_~...~ ~._,.~,. ~l,~i~ry Buster Title: Drilling Engineer Date: 9/22/2003 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No. ~,.,~ Plug integrity .. BOP Test "~ Location clearance~ Mechanical Integrity Test. Subsequent form required 10- Approved by order of the Commissioner .~ Commissioner Date Form 10-403 Rev 06/15/88 ORIGINAL ! SUBMIT IN TRIPLICATE UNOCALe Steelheaa Well M-16 Abandonment Procedure 1 Prior to rig arrival, kill well by pumping kill weight fluid down 7" tubing and then lubricating off any gas. 2 R/U lubricator & recover 7" Wireline Retrievable SSSV. 3 If unable to establish injection into the existing perforations, then be prepared to perforate across existing gravel packed zones to be abandoned. 4 RAJ E-Line. RIH and set 7" cement retainer at +/- 1550'. 5 Test retainer and casing to 1500 psi for 10 minutes. 6 IAccept Rig. N/U and Test 16-3/4" BOPE to '3,000/250 psi. 7 IP/U work string and cement stinger. RIH to retainer. 8 Establish injection below the retainer. Mix and pump 10 bbls 15.8 ppg cement below the retainer. 9 Sting out and circulate out excess cement. 10 POOH with work string. 11 R/U and pull 7" tubing from the top of the liner hanger. Circulate well clean. 12 Pull and L/D 7" tubing. 13 Release Rig to M- 16RD operation. 14 'i5 16 17 18 19 20 21 22 23 24 25 Abandonment Procedure M-16 1 9/22/2003 Well M-16 Abandonment Abandonment Cement Volumes Depth Length ff 1550-1615 65 1615-2230 615 Area 7" Csg 4" pipe Capacity bbl/ft 0.0371 0.01223 Volume Notes bbl 2.41 7.52 ~/100' below lowest perforations Total 9.93 "16 3/4" t30P Stack-Up Top of Tbg Spool Tradiag Bay lLJa~ Sttedhead Platform Well # 34-16 Cm'ren~ Completion RKB to TBG Head = 80' Tree connection: 1262' SZ-22 SZ-23 PBTD = 3446' TD = 3625' MAX HOLE ANGLE = 57.T' @ 3199' Currenl Complethm Je*a dry PERFORATION DAT.~, Zone Top Btm Amount Condition SZ-18 2,612' 2,66T 55 Cmt Isolated on 9/23/02 M 16 Actual Schematic 9-23-02.doc Updated by SLT l 0/02A)2 Trading Bay Un~ ,qteethead Pl~dbrm Well # M-16 PPoP Ab~nd~nment RKB to TBG Head = 80' Tree connection: PBTD: 3446' TD = MAX HOLE ANGLE = 57,7° @ 3199' CASING AND T~ BING DETAIL Curren~ (~mplelion ,Ie~ dry PERFORATION DATA Zone -- Top Btm Amount Condition SZ- 12 1751 1808 57 Opened 5/7/01 SZ-14 1,959' 2,004' -- 45 Opened 5/7/01 SZ-15 2,092' 2,130' 38 Opened 5/~/01 SZ-17 2,485' 2,559' 74 Cmt Isolated on 9/23/02 SZ-18 2,612' 2,66T 55 Cmt isolated on 9/23/0~- SZ-22 3,211' 3,239' 28 Crnt Isolated on 9/23/02 SZ-23 3,387' 3,408' 21 Cmt Isolated on 9/23/02 M16 Abandonment Proposed Schematic,doc Updated by LWB 9/t 8/'02 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 ACC 25.280 1. Type of request Abandon [] Suspend [] Operation Shutdown [] Perforate [] Variance ~ Annular Disposal ~1 Alter Casing [] Repair Well [] Plug Perforations [] Stimulate [] Time Extension [] Other X Change Approved Program r~ Pull Tubing [3 Perforate New Pool [] Re-enter Suspended Well [] 2. Operator Name: 4. Current Well Class 5. Permit to Drill Number: Union Oil Company of California/Unocal 97-162 3. Address: Development X Exploratory [] 6. APl Number: PO Box 19-0247, Anchorage, AK 99519 Statigraphic [] Service [] 50-733-20480-00 7. KB Elevation (ft): 9. Well Name and Number 160' KB above MSL M-16 8. Property Designation: Steelhead Platform, Cook Inlet 10. Field/Pool(s): Trading Bay/Grayling Gas Sands Pool 11. Present well condition summary Total depth: measured 3,625 Feet Plugs (measured) true vertical 2,667 Feet Effective depth: measured 3,446 Feet Junk (measured) true vertical 2,530 Feet Casing Length Size MD 'I'VD Burst Collapse Structural 488' 28" 488' 487' Conductor Surface 840' 13-3/8" 840' 836' 3,450 psi 1,950 psi Intermediate 1,506' 9-5/8" 1,506' 1,435' 6,780 psi 4,760 psi Liner 1,845' 7" 3,623' 2,666' 8,160 psi 1,720 psi Liner 483' 7" 1,778' 1,632' 8,160 psi 1,720 psi Perforation depth: measured 1,751-1,808, 1,959-2,004', 2,092-2,130', 2,485-2,559', 2,612-2,667', 3,211-3,239', 3,387-3,409' true vertical 1,613-1,651', 1,748-1,775', 1,826-1,848', 2,041-2,081', 2,110-2,197', 2,535-2,547', 2,440-2,455' Tubing (size, grade, and measured depth) 7" 29# L-80 NSCC Tubing from 68-1,778' Packers and SSSV (type and measured depth) Baker SC-1R pkr @ 1,615', Baker SC-1R Pkr@ 2,138', Baker SC-1L Packer @ 2,149' Baker SC-1R Pkr @ 2,675, Baker DA Sump Pkr@ 3,416 12. Stimulation or cement squeeze summary Intervals treated (measured) Cement zones 17, 18, 22, 23 Grayling Gas Sands Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure .Prior to well operation 0 8,000 63 0 406 Subsequent to operation 0 9,000 4 0. 426 Daily Report of Well Operations: X 16. Well Status after proposed work: Oil ~ Gas X WAG ~ GINJ [] WINJ [] WDSLP [] 17. I hearby certify that the foregoing is true to the best of my knowledge. Sundry Number: Contact: L ¥-'~ ~..~'~" Printed Name ~ ~.) ~L..~ Title: ~'~ ~ [ t i: ,, <~ ~ ~"'. Signature: ,, .... Phone: '7-~'~-"~ i(~-, Form 10-404 Revised 2,2003 N0~R/GINAL BFL JU 2003 MAY 2 2 2003 Alaska Oil & Gas ConS. Commission Anchorage STEELHEAD PLATFORM WELL # M-16 TRADING BAY UNIT COMPLETION AS OF 9/24/02 COMPLETION DESCRIPTION 1) 7" 29# L-80 NSCC Tubing f/1778' - 68' 2) HES 5.963" ID SSSV Landing Nipple F/ Safety Valve ~ +/-448'. (Min. ID = 3.50") 3) Baker SC-1R Packer ~ +/-1615'. 4) 4" 9.5# SSWW Screen & Blank Packed w/ 20/40 Carbolite F/2137' - 1620'. 5) Baker SC-1RPacker ~2138'. 6) Baker SC-1L Packer ~ 2149' 7) 4" 9.5# SSWW Screen & Blank Packed w/ 20/40 Carbolite F/2674'-2154'. 8) Baker SC-iR Packer ~ 2675'. 9) 4" 9.5# SSWW Screen & Blank Packed w/ 20/40 Carbolite F/3415'-2679'. i0) Baker DA Sump Packer @ +/-3416' 11) 4" Baker 'FA' pkr (min. ID = 1.875") (Note: Sheared offpacker at 2154' & pushed same downhole to 2182'. Packer is partially set) 12) Cement retainer at 2159' (cement to perfs) TD ~ 3625' JUN 0 20i]3 RKB = 160' 7" TBG Hanagr McEvoy 1 I" x 7" NSCC bottom Type J BPV 1 l"x 7" 28" Structural Casing @ 488' RKB (141 'BML) 13-3/8" cement to surface 13-3/8" 68# K-55 BTC Surface Casing @ 840' 7" 29# L-80 NSCC 1295-68' 7" Liner Top ~ +/- 1262' w/ ZXP Liner Top Packer ITOC inside 7" x 9-5/8" liner lap I 9-5/8" 47# L-80 BTC Intermediate Casing @ 1506' 9-5/8" cement to surface I 1751-1808' MD 1959-2004' MD 2092-2130'MD 2485-2559'MD 2612-2667'MD 3211-3239'MD 3387-3409'MD 7" 29# L-80 KC Butt Liner from 3623' - 1778' 7" 29# L-80 NSCC Liner from 1778'- 1295' Operations Summary M-16 CT 9/19~02 Lay out equipment. R/up Braid line unit & test RS t/4200# (ok). Pressure test lubricator t/1000 psi (ok). Rih w/6.03" GR t/452' RKB POOH (ok). Rih w/7" GS & 9' prong t/452' rkb & pulled SSSV. POOH bump up short tools across tree. RIH w/SSSV t/452' rkb & sheered GS. POOH removed 4' (pump in sub) & re-pinned GS. RIH t/452' rkb latch SSSV POOH hit tight spot in lubricator. Rih t/452' rkb & sheer GS pooh. Remove 11' section of Lubricator. Rih t/452' rkb latch SSSV POOH & I/dn 7" MBR SSSV. Start r/dn braid line unit 9~20~02 Continue r/dn braided line unit. R/up slickline unit & test. Rih w/5.85" OD X 5' dummy pkr drift t/ 1621' RKB & POOH w/no problems. Rih w/3" GR falling slow, stopped falling @ 1533' RKB pooh. Added more stem to tool string. Rih w/2.00" DD bailer w/mule shoe t/2155' RKB stopped falling, POOH & bailer MT. Chg tool string to roller stem. Rih w/3.25" swage tools falling slow & finally stopped @ 2150' RKB POOH & I/dn lubricator to work boat. Stand-by for crane. Finish ddn & move to M-5. Rig Prep. Repaired driller side hyd pump. Hanging chain bsk on bop chain falls 9/21/02 Finish cleaning & draining coil tank to platform pits & clean & prep south pipe rack for coil equipment. Assist Unload boat #3 & ~4 of coil equipment, Spot & dup same. Fill coil tank & test NTU's. FIW straight from production - 1.3 NTU's. FIW circ thru hopper in coil tank = 5.7 NTU's. FIW w/6% KCL circ thru hopper in coil tank = 14.7 NTU's. Spot shaker on coil tank for mounting & r/up transfer line to Dowell tank start building 6% kcl volume. Continue to spot & r/up coil & cmt equipment & unload boat #5. Wire line foreman finished M-5 slickline work & moved to M-1. Production shot fluid level @ 39 collar dn +- 1634'. 9~22~02 Wire line Foreman finished braided line work on M-l; finish hanging chain buckets on bop chain falls. Assist ddn of braided line & move well bay working hatch cover to M-16, build 6% kcl volume & chk NTU's. avg 12-14 units. Finish building 350 bbls of 6% KCL & chk NTU's, finish mounting shaker on coil tank & wire in same. Finish hand rails on coil tank & R/up portable hand sets @ coil tank, CTU & cmt shack, Finish dup of coil & cmt. equipment & stab coil in injector head. Test bops load coil w/Fluid & chg out O ring on lubricator & pressure test coil & shell test stack t/4500 psi (ok). Pickle coil w/10% HCL, Pump Hippo Turbo dart & nerf ball. Brk off injector head. M/up BOT coil connector & pull test & pressure test (ok) finish m/up WATCO 2-7/8" ventura bailer. Stab injector head. And riser & shell test 4500 psi (ok). Rih t/1550' rkb bring on pump @ 1.9 bpm w/returns to test separator & circ in hole to tag @ 2182' RKB with a 220 psi increase in circ pressure, POOH t/2000' & rih & 2nd tag @ 2182' rkb & flag pipe POOH & dn pump @ 1600' & shut well to test separator. 9/23/02 Continue POOH t/1600' & dn pump & shut well to test separator & continue pooh. Brk Dn & chk bha, Recovered 3/4" pkr element that was 90% intact stuck in end of bailers mule shoe & Secure well & unit. Shut dn SLB for rest, dress btm deck of coil shaker w/80 mesh screens, Built 100 bbls 6% KCL volume & chk NTUs, mixed 10 sx soda ash into acid pickle in coil shaker tank & let neutralize, Clean & organize drill deck Warm up equipment & p/up injector head & M/up & pressure test BHA #2 & stab lubricator. Shell test stack 4000 psi (ok) & rih t/1550'. Wait on '"'"~"~' p~'uction ~ell to test separator. Rih circ @ 1/2 bpm & wt chk @ 2100' w/no problem & tag prk @ 2182' & chk flag (ok) POOH t/setting depth & get 3600# over pull spike @ 2159' possible trip spotting valve on retainer, discuss options w/anch office load & pump 1/2" setting over goose neck & let fall 10 min & pump 15 bbls no seat. POOH & chg/out setting tool & shell test lubricator. Rih t/1550' rkb bring on pump @ 1/2 bpm w/returns to test separator & circ in hole t/2137' load & launch 1/2" setting ball. Continue rih t/setting depth @ 2159' & pump ball over goose neck & let fall 10 min. Ball on seat Pressure up in 500 psi increments w/5-10 min waiting times ECP retainer blew thru @ 1800 psi & set top of element @ 2159' rkb. Establish injection rate in to SZ-17, 18, 22& 23 GGS @ 2.35 bpm @ 1750 psi. Slow pump to 1.2 bpm @ 700 psi fluid pack well & batch up cmt. Pump 2 bbls fiw ahead test lines t/3160 psi ok pump 16 bbls of 15.8 ppg "G" cmt & displaced w/5 bbls FIW & 21 bbls FIW w/6% KCL final injection rate 1 bpm @ 2110 psi. pressure @ shut dn 2050 psi, 30 sec 934 psi @ three min 390 psi. Unstring from pkr & POOH slowly pumping tbg volume @ max rate continue POOH t/1550 psi. Unload well to production w/N2 @ 550 CFM. Up N2 rate t/800 CFM & POOH t/800' & rih t/1550'. POOH & trap 540 psi on well (total water unloaded +-37 bbls), bleed coil pressure, Brk & L/dn bha. 9/24/02 Pickle Coil w/10% HCL, Pump Hippo turbo dart & nerf ball, R/up to pump 1.90 dart -- got stuck were coil enters core of real reverse circ & recover dart. Hook up hoses to rig jacks, spooled on man rider line, added soda ash to HCL pickle in coil shaker tank Rig to pump 1.9" ball around for drift. 9/25/03 Operations secured - M-16 on test Rate = 8.5, Flowing tubing = 409, water 8bbl since 00:00, Sand report non definite at this time. Rigging down Coil Equipment for Back Load to beach to Respool & Drift Coil - Dowell Pumping equipment stayed on board along with Mis BOP equipment related to Coil operation - 4 NAD to King to center rig package up on well # 22. Final release from M-16 - Nipple Down BOP & Riser- Install Tree cap & gauge Manifold. Operations secured JUN, 0 2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: X Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: X Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) UNOCAL Development: X 160' KB above MSL feet 3. Address Exploratory: 7. Unit or Property name P.O. Box 19-0247 Anchorage, AK. 99519-0247 Stratigraphic: McAuthur River Field Service: 4. Location of well at surface v'" .,~ ~/' 8. Well number 1,041' FNL. 463 FWL. Sec. 33, T9N, R13W, SM M-16 At top of productive interval 9. Permit num/ber 591' FNL. 603' FWL. Sec. 33, T9N, R13W, SM 97-162 At effective depth 10. APl number 50- 733-20480-00 Field/Pool !~ 1~ ~ ? I ~, At total depth 11' Trading Bay~/"~G~yI1flg!~a~s ~n~ ~OI 776' FSL. 1330' FWL. Sec. 28, T9N, R13W, SM 12. Present well condition summary ./ Total depth: measured 3,625' feet v~ Plugs (measured) Ii !i F",. '~ ~.~!),~'.,; true vertical 2,667' feet ,~-L..':.. U i Effective depth: measured 3,446' feet Junk (measured) true vertical 2,530' feet'~ ~ ~"nr:"°raye Casing Length Size Cemented Measured depth True vertical depth Structural 406' 28" Driven 488' Conductor Surface 758' 13-3/8" Lead 1430 sx + 350 sx Tail 840' Intermediate Production 9-5/8" 47# Lead 712 sx + 162 sx Tail 1506' Liner 7" 460 sx 3623' Perforation depth: measured See Attachment "A" true vertical See Attachment "A" Tubing (size, grade, and measured depth) 7" 29# L-80, from 67' to 3623' Packers and SSSV (type and measured depth) 1615', 2138', 2149', 2675' & 3416' 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: July 18, 2002 16. If proposal well verbally approved: Oil: Gas: X Suspended: Name of approver Date approved Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. "' Signedi"'~-'~ /~ ]~'A/V'~FoRTitle:cOMMISSION~f'[//"''L~E ONLY/V)~ "~'~ e"r' Date: Conditions ifil'approval:Plug integrity__.____N°tify CommissiOnBopSO representatiVeTest ~ may witneSSLocation'~)r...~clea~ance ~' t.-~, Cx~"~,,~ ~.'~. C,.,C::~t,~ ~:>(~r~.~pproval No~_~,~__ Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commissioner ~"~mm~ ~ ~41~' SCAN N E[J~o.~lr~lssCjn~ ~ I~ r,~ Date /' Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment "A" M-16 Existing Perforated Interval Zone MD TVD Comments SZ~,t2 1751' 1808' 1613' 1651' Open SZ-t4 1959' 2004' 1748' 1775' Open ~ ~ 2092' 2130' 1826' 1848' Open SZ-17 2485' 2559' 2014' 2081' Open SZ-18 2612' 2667' 2110' 2197' Open SZ-22 3211' 3239' 2535' 2547' Open SZ-23 3387' 3408' 2440' 2455' Open Proposed Perforated Interval Zone MD TVD Comments SZ-11 1597 1613 1505 1517 NEW ~.12 ~ 1751' 1808' 1613' 1651' iOpen SZ~14,, 1959' 2004' 1748' 1775' Open SZ-15 2092' 2130' 1826' 1848' Open SZ-17 2485' 2559' 2014' 2081' Cmt Isolated SZ-18 2612' 2667' 2110' 2197' Cmt Isolated SZ-22 3211' 3239' 2535' 2547' Cmt Isolated SZ-23 3387' 3408' 2440' 2455' Cmt Isolated ~GANNE~ JUL 2 1 20 D2 No 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 2O Steelhead M-16 Proposal Summary Preliminary Proposed Procedure RU Slickline. Retrieve SSSV @ 448'. RIH w/3.00" GR. Tag BOT Model "FA" pkr @ 2182'. POOH RD slickline. Mob CTU w/2" coil, Nitrogen, Cement/GP equip. RU CTU. Test BOPE, MU CTC. Test same. PU/MU 2-1/2" Through Tbg ECP Cement Retainer, packer assy. RIH & set Through Tubing ECP cmt retainer @ 2150'. Sqz cal. vol. of cmt below ret to P&A SZ 17, 18, 22 & 23 ~.~\c_,.~\c.r~_~> ~ ~-\..~, ~-~\ PU displace well w/N2. POOH. Wait On Cmt for 24 hrs. Flow well to test separator to evaluate production. ( If well will flow above 7 MMCFPD then RD and De-Mobe CTU. ) PU Through Tbg Retrievable Bridge Plug assy. RIH set isolation in 4" blank, below SC-1R Pkr @ 1615', to isolate SZ-12, 14 & 15. Release f/TTBP. PU circulate gas out w/FIW. Pressure test isolation assy to 500 psi. POOH. PU w/4-1/2" CT/TCP guns w/"SB" Pkr Plug on btm of gun assy. RIH. Latch "SB" Pkr Plug into SC-1R @ 1615'. PU place gun on depth. Displace w/ N2. Perf SZ-11. POOH. Secure CT. Test SZ-11 sands. RIH w/venturi bailer. Clean-out perf debris to pkr plug. POOH. RIH latch & retrieve SB Pkr Plug. POOH. PU/MU GP Assy. RI latch into iso assy @ 1613'. Set pkr. Frac-Pack SZ-11 sand w/ 20-40 Gravel. Reverse circulate CT. Test pack. POOH. RIH w/coil tubing. Displace well w/N2. POOH. Turn well over to production. RD De-Mobe CTU, N2, Cmt/GP equip. $C&NNED JUL ~ 1_ ?_l~O?. UHOCAL RKB to TBG Head = 80' Tree connection: 1506' B C PBTD = 3446' TD = 3625' MAX HOLE ANGLE = 57.7 @ 3199 Trading Bay Unit Steelhead Platform Well # M-16 Proposed 06/19/02 CASING .&ND TUBING DETAIL SIZE WT GRADE CONN ID TOP I~TM. NO. Depth Len~ A. 28 E. 2150 80 I. 448 2. 1615 471 1620 _3..7 1644 9062 3. 1735 9041 1825 I00 95 1926 211.24 2138 0.88 4, 2139 979 2148 086 2149 073 5. 2150 471 2155 2349 2178 I73 218I 30219 6. 2483 9042 2574 4040 2614 6026 2674 088 7. 2675 471 2680 2352 2703 173 2705 1511 2722 48220 8, 3204 9047 3294 6065 3355 60.27 3415 092 9. 3416 305 10. 2182 JEWELRY DETAIL 3~25 Baker SC-I Packer, 70A4-32 w/Model "S" GP Ext. 80-32 w/ SZ- 12 1751 1808 57 Opened 5/7/01 SZ-14 1,959' 2,004' 45 Opened 5/7/01 SZ-15 2,092' 2,130' 38 Opened 5/7/01 SZ-17 2,485' 2,559' 74 Cmt Isolated SZ-18 2,612' 2,667' 55 Cmt Isolated SZ-22 3,211' 3,239' 28 Cmt Isolated SZ-23 3,387' 3,408' 21 Cmt Isolated UNOCAL Trading Bay Unit Steelhead Platform Well # M-16 Proposed 06/19/02 Baker SB Pkr Plug Thru Tbg Pkr, 2-112" ~ SZ-11 Thru Tbg Pkr, 2-112" SZ-11 SZ- 12 SZ- 14 SZ- 15 SZ-12 SZ-14 SZ-15 SZ-12 SZ-14 SZ-15 SZ-17 SZ-18 SZ-17 SZ-18 SZ-17 SZ-18 SZ-22 SZ-23 SZ-22 SZ-23 SZ-22 SZ-23 Set ECP Retainer. Cmt/Abandon Iwr intervals Isolate SZ 12,14 & 15 Perforate & test SZ-11 Gravel Pack SZ-11 .SCANNED JUL 3 Re: FW: M- 16 Perforation Subject: Re: FW: M-16 Perforation Date: Tue, 23 Jul 2002 09:00:06 -0800 From: Robert Crandall <Bob_Crandall~admin.state.ak.us> Organization: DOA-AOGCC To: "Martin, Shannon W" <martins@unocal.com>, "Hartz, John" <jack_hartz@admin.state.ak.us> CC: "Seamount, Dan" <dan_seamount~admin.state.ak.us> Martin: We have reviewed the correlations between TBU K-2 and TBU M-16 and we agree with Eric Graven that the subject perforations are within the Middle Kenai Gas Pool. Statewide regulations do not control spacin9 for the proposed recompletion. Bob Crandall "Martin, Shannon W" wrote: Bob: I would usually inquire with Steve and don't know if Jack is the right guy. Can you offer any advice? Please see below. Thanks for your help, Shannon W. Martin Project Landman Union Oil Company of California (907) 263-7882 ..... Original Message ..... From: Martin, Shannon W Sent: Monday, July 08, 2002 3:24 PM To: Hartz, John D -Vendor Subject: M-16 Perforation Hi Jack: In Steve's absence I wanted to ask for your advice on the following issue: We are trying to fast-track a coil tubing workover project on the M16 well. The job will involve abandoning a portion of the completion and adding perforations in the SZll sand (1597' - 1613' MD or 1505' - 1517' TVD). The problem is, CO 228.2 defines the McArthur River Middle Kenai Gas Pool as the interval in TBU K-2 between 1780' - 10128'). Our proposed perforations are outside the delineated pool yet we do not necessarily wish to apply for vertical expansion. Thus, are we okay to apply to the AOGCC for Administrative Approval under Rule 3, CO 228, so long as we can demonstrate that sound engineering practices are maintained and the amendment will not result in physical waste? We appreciate your advice. Regards, Shannon W. Martin Project Landman Union Oil Company of California (907) 263-7882 8G/-iNNF... JUL It 1 2002 Re: M-I(~ Fgrtoratlon ~~ubject: Re: M-16 Perforation Date: Wed, I0 Jul 2002 17:16:29 -0800 From: Jack Hartz <jack_hartz admin. state. . To: "Martin, Shannon W" <martins~unocal,com> CC: Robert Crandall <bob_crandall~admimstate.ak.us>, Stephen F Davies <steve_davies~admin. state.ak.us> Shannon, We've briefly looked into some of the features Conservation Order governing development of the Middle Kenai Gas Pool. If a gas well is perforated above the top of the defined MKG pool, it will be subject to statewide regs and production reported to an undefined pool. That would entail allocating production between defined and undefined pools on some reasonable basis. Another complication is that statewide spacing is 640 acres (20 AAC 25.055) in undefined gas pools. If there are other wells within the section completed above the pool, then a spacing issue may arise. The MKG pool rules address the differential pressures notable across the column in the MKG sand sequences. There is a limitation on the vertical footage allowed to be open concurrently in a MKG pool well, 1000' tvd I think. Spacing is nominal for the MKG pool - 10 acres I think to give the operator lattitude in placing offiake points in the shallow as well as deeper sands. Generally, we prefer to go through the process to redefine the pool at some poim in the near future. We can either do this based on an application from Unocal or we can do it on our own motion. Any loose ends can be cleaned up and then orders are up to date for your development needs. We would need some input from Unocal to make sure the geologic and engineering bases are covered (as per CO 228). I am unsure if we would be required to notice it for public hearing or not. If a hearing was not requested or required, then the AOGCC can go ahead and amend the CO to bring it up to date. The work you propose on M-16 can be done under the statewidc regs in the meantime with production allocated to an undefined pool or allocated between pools depending on whether the MKG pool is open to production also. We probably should meet (you and a geologist or engineer) sometime soon to ensure you are clear on some of the issues I mentioned and make sure there is no confusion as to how you can procede. Let me or Bob Crandall know if you have any questions. Jack Hartz "Martin, Shannon W" wrote: Hi Jack: In Steve's absence I wanted to ask for your advice on the following issue: We are trying to fast-track a coil tubing workover project on the M16 well. The job will involve abandoning a portion of the completion and adding perforations in the SZ11 sand (1597'- 1613' MD or 1505'- 1517' TVD). The problem is, CO 228.2 defines the McArthur River Middle Kenai Gas Pool as the interval in TBU K-2 between 1780' - 10128'). Our proposed perforations are outside the delineated pool yet we do not necessarily wish to SCANNED 1 of 2 7/12/2002 11:34 AM ,., apply for vertical expansion. Thus, are we okay to apply to the AOGCC for Administrative Approval under Rule 3, CO 228, so long as we can demonstrate that sound engineering practices are maintained and the amendment will not result in physical waste? We appreciate your advice. Regards, Shannon W. Martin Project Landman Union Oil Company of California (907) 263-7882 i JackHartz <jack hartz~admin, state, ak.us> ] ] Sr. Reservoir Engineer Alaska Oil & Gas Conservation Commission ,SCANNED JUL 1 200Z, 2 of 2 7/12/2002 11:34 AM [Fwd: Steelhead M-16] Subject: [Fwd: Steelhead M-16] Date: Wed, 03 Jul 2002 14:40:30-0800 From: Tom Maunder <tom_maunder~admin. state.ak.us> To: Jody J Colombie <jody_colombie~admin.state.ak.us> CC: Bob Crandall <bob_crandall~admin.state.ak.us> Jody, It appears that there could be a pool limits issue with this sundry (302-203). Bob and I sent the attached note to Unocal. They will have to sort out the issues before we could possibly approve this sundry. How long it may take to resolve this is not well known. Tom Subject: Steelhead M-16 Date: Tue, 02 Jul 2002 09:09:59 -0800 From: Tom Maunder <tom maunder@admin.state.ak.us> To: Steve Tyler <tylersl~unocal.com> CC: Bob Crandall <bob_crandall~admin.state.ak.us> Steve, You are likely to get a message from Jerry Bowen on this as well. I have looked at the application for the subject well and discussed the intervals with Bob Crandall. It appears that the zone you wish to add is not within the pool and it is possible that some of the zones.you plan to keep are not in the pool as well. I don't know all the issues here, but would you get with your reservoir engineer and land person and see what you can determine. I have copied this not to Bob Crandall, so please keep him in the loop as well. Thanks. Tom Tom Maunder <torn_maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission ~;~n~::Maunder<tom maunder adrnin.state.ak~~'~'~:~ sr. petroleum Engineer I~.,~,_~l...~]~a Oil and Gas Conservation Commission ~GANNED JUL ~ 1 2002: 1 of 2 7/9/2002 8:07 AM Steelhead M-16 Subject: Steelhead M-16 Date: Tue, 02 Jul 2002 09:09:59 -0800 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: Steve Tyler <tylersl@unocal.com> CC: Bob Crandall <bob_crandall@admin.state.ak. us> Steve, You are likely to get a message from Jerry Bowen on this as well. I have looked at the application for the subject well and discussed the intervals with Bob Crandall. It appears that the zone you wish to add is not within the pool and it is possible that some of the zones you plan to keep are not in the pool as well. I don't know all the issues here, but would you get with your reservoir engineer and land person and see what you can determine. I have copied this not to Bob Crandall, so please keep him in the loop as well. Thanks. Tom Tom Maunder<tom maunder@admin.state.ak, us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 5CANNED JUL ;8 :[ 1 of 1 7/3/2002 2:30 PM Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOEAL Dan Williamson Drilling Manager 10/05/O 1 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Commissioner Julie Heusser Report of Sundry Operations (Form 10-404) Steelhead, Well M-16 McArthur River Field Commissioner Heusser: Enclosed for your review is a Report of Sundry Well Operations (Form 10-404) for the recent concentric workover of Steelhead Well #M-16. Efforts to install a 2 7/8" isolation liner using coil tubing were unsuccessful, although we were successful in washing sand fill out of the well and returning it to production. No further work is planned for the well at this time. If there are any questions, please contact Jerry Bowen at 263-7640. Drilling Manager RECEIVED OCT 1 0 Oil & Gas Cons, Commi~sio~ Anchor~e AOGCC cover letter404.doc ORIGINAL Tim Billingsley STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Attempt to shut-off water Pull tubing: Alter casing: Repair well: Obher: X with 2 7/8" isolation liner 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 160' KB ABOVE MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247, Anchorage, AK 99519 Service: Trading Bay Unit 4. LocalJon of well at surface Leg A-l, Slot #4 Steelhead Platform 8. Well number 1041' FNL & 463' FWL of Sec.33, T9N, R13W, SM M-16 At top of productive interval 1600' TVD 9. Permit number/approval number 591' FNL & 603' FWL of Sec.33, T9N, R13W, SM 97-162/301-226 At total depth 2650' TVD 10. APl number 776' FSL & 1330' FWL of Sec.28, T9N, R13W, SM 50- 733-20480-00 11. Field/Pool McArthur River Field Grayling gas Sands 12. Present well condition summary Total depth: measured 3,625' feet Plugs (measured) None true vertical 2,667' feet Effective depth: measured 3,446' feet Junk (measured) None true vertical 2,530' feet Casing Length Size Cemented Measured depth True vertical depth Structural 406' 28" Driven 448' 448' Conductor Surface 768' 13-3/8" 1350 sx 850' 849' Intermediate 1419' 9-5/8" 575 sx 1500' 1436' Production Liner 2362' 7" 880 sx 3624' 2650' Perforation depth: MD: TVD: MD: TVD: SZ-12 1751-1808' 1613-1651' SZ-18 2612-2667' 2110-2197' SZ-14 1959-2004' 1748-1775' SZ-23 3211-3239' 2535-2547' SZ-15 2092-2130' 1826-1848' SZ-24 3387-3408' 2440-2455' SZ-17 2484-2559' 2014-2081' Tubing (size, grade, and measured depth) 7" 29# L-80 NSCO @ 1,295' to 68' Packers and SSSV (type and measured depth) Baker ZXP Liner Top Packer @ 1,295' HES WRSSV 3.50" ID in 5.963" Lock Mandrel @ 448' MD/VD NOTE: Left Baker 4" FA packer (junk} inside gravel pack assembly at 218.2.1, could not install isolation liner!asplanned. 4" Gravel Pack screen & blank pipe from 1615' to 3416' w/five (5) packers @ 1615', 2138', 2149', 2675' & 3416' 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Injection Data ~8 OiI-BBL Gas-Mcr Water-Bbl Oasin9 Pressure ~-fich0ra~l'ubing Pressure Prior to well operation 8-12-01 0 0 0 0 495 SlTP Subsequent to operation 9-20-01 0 8000 -: .~(55- ' 0 405 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: Gas: X Suspended: Service: 17. I hereby certify that the foregoin9 is true and correct to the best of my knowledge: Sign n Williamson Title: Drilling Manager Date: .~'"" -- Form 10-404 Rev 06/15/88 ORIGINAL SUBMIT IN DUPLICATE STEELHEAD PLATFORM WELL # M-16 TRADING BAY UNIT COMPLETION AO 9/13/01 COMPLETION DESCRIPTION 1) 7" 29# L-80 NSCC Tubing f/1778' - 68' 2) HES 5.963" ID SSSV Landing Nipple F/ Safety Valve @ +/-448'. (Min. ID = 3.50") 3) Baker SC-IR Packer @ +/-1615'. 4) 4" 9.5# SSWW Screen & Blank Packed w/ 20/40 Carbolite F/2137' - 1620'. 5) Baker SC-IR Packer @ 2138'. 6) Baker SC-IL Packer @ 2149' 7) 4" 9.5# SSWW Screen & Blank Packed w/ 20/40 Carbolite F/2674'-2154'. 8) Baker SC-IR Packer @ 2675'. 9) 4" 9.5# SSWW Screen & Blank Packed w/ 20/40 Carbolite F/3415'-2679'. 10) Baker DA Sump Packer @ +/-3416' 11) 4" Baker 'FA' pkr (min. ID = 1.875") (Note: Sheared offpacker at 2154' & pushed same downhole to 2182'. Packer is partially set) Jetted fill out of well with coil tbg to 3250' on 9l 12/01. TD @ 3625' RKB = 160' 7" TBG Hanagr McEvoy 11" x 7" NSCC bottom Type J BPV 1 l"x 7" 28" Structural Casing @ 488' RKB (141'BML) 13-3/8" cement to surface I 13-3/8" 68# K-55 BTC Surface Casing @ 840' 0 7" 29# L-80 NSCC 1295-68' 7" Liner Top @ +/- 1262' w/ ZXP Liner Top Packer TOC inside 7" x 9-5/8" liner lap 9-5/8" 47# L-80 BTC Intermediate Casing @ 1506' -5/8" cement to surface I 1751-1808'MD 1959-2004'MD 2092-2130'MD 2485-2559'MD 2612-2667'MD 3211-3239'MD 3387-3409'MD 7" 29# L-80 KC Butt Liner from 3623' - 1778' 7" 29# L-80 NSCC Liner from 1778'- 1295' Date 8/13/01 8/14/01 8/15/01 8/16/01 9/10/01 9/11/01 9/12/01 9/13/01 Daily Report of Well Operations Steelhead Well M-16 Slickline & Coil Tubing Workover to Install 2 7/8" Isolation Liner AFE #150878 Summary Rigged up slickline unit (while rig over well M-31). Tested lubricator. RIH w/3.1" GR, set down @ 2138'. RIH w/3.187" x 3' dummy packer, set down @ 2493'. RIH w/ 1.75" bailer to 2493', recovered ½ cup of fine sand. SWFN. RIH w/2.50" DD bailer to 2499', recovered ½ cup fine sand. RIH w/2.50" pump bailer to 2499', recovered bailer full of fine sand. RIH w/2.50" bailer to 2501', recovered 2 cups fine sand. RIH w/2.50" pump bailer to 2501', fell through to 2892', recovered bailer full of fine sand. SWFN. RIH w/3.187" x 3' dummy packer, set down at 2686', could not work deeper. RIH w/ 2.65" star bit, set down at 2686', beat down & fell through to 2882'. RIH w/3.187" x 3' dummy packer, set down at 2686', could not work deeper. RIH w/2.50" pump bailer, set down @ 2162', worked through tight spot @ 2162' & fell through to 2879', no recovery. RIH w/2.50" pump bailer to 2885', recovered bailer 3A full of sand. RIH w/2.50" pump bailer to 2886', work through to 2895', recovered bailer ½ full of sand. RIH w/2.50" pump bailer to 2895", work through to 2918', recovered 1 cup of sand. RIH w/2.50" pump bailer to 2923', bailed to 2924', recovered 1 cup of sand. RIH w/3.05" star bit, set down at 2925', beat down, no progress. RIH w/2.50" pump bailer to 2925', no progress, no recovery. SWFN. RIH w/1.75" star bit to 2925', no progress. RIH w/2.00" DD bailer to 2925', no progress. RIH w/3.187" x 3' dummy packer, set down at 2691', worked & fell through suspected but hole was sticky, POH. RD Slickline unit. OPERATIONS SUSPENDED UNTIL RIG AVAILABLE Skidded rig over M-16. Installed V-door. Start NU of coil tbg riser & BOPE. Finished RU coil tbg riser & BOPE. Tested BOPE. Installed manual choke on M-16 flowline. Held PJSM. RIH w/2 1/8" rotating wash tip on 1.75" coil tbg, pumping N2 and taking returns down flowline. Tagged hard fill at 3119'. Increased to maximum N2 pump rate & jet out fill to 3250' as per plan (producing perfs at 3211' to 3239'). Encountered tight spots while POH @ 2050' & 2070'. Note: Gas production rate increased to 8 MMCFD after jetting to 3250'. Ran back in hole jetting w/N2 to 3250' and worked coil through tight spots until no longer tight. Make up 4" Baker FA packer (3.187" OD). RIH, could not pass SSSV @ 440'. POH & rotate packer muleshoe. RIH & set down on top of gravel pack assembly at 1620', could not work past. POH. Bent coil above BHA. RIH w/4" Baker FA packer (3.187" OD) to 2709', worked packer three hours, could not get past KOIV (the final restriction). Attempted to POH w/packer, pulled tight at 2154'. Packer sheared off while attempting to POH. POH w/setting tool, setting tool had stroked, packer partially set. RIH w/2 1/16" wash tip. Tageed packer (fish) at 2154' pushed downhole to 2182', no further progress. POH. SWFN. Rig down coil tbg, BOPE & riser. Prep to skid rig. Returned well to production @ 8 MMCFD. FINAL REPORT: RE: Tentative plan for M-16 Subject: Date: From: To: CC: RE: Tentative plan for M-16 Thu, 16 Aug 2001 11:08:55 -0700 "Bowen, Jerry-Alaska" <jbowen@unocal.com> "'keytl@kenai.oilfield.slb.com'" <keytl@kenai.oilfield.slb.com>, '"Bob. Harris@bakeroiltools.com'" <Bob. Harris@bakeroiltools.com>, burton4@anchorage.oilfield.slb.com, mward@anchorage.oilfield.slb.com, "'Dewees, Lee'" <ldewees@midf. com>, "BROWN, TED" <TED.BROWN@fmcti.com>, '"HITE, KEVIN'" <KEVIN.HITE@fmcti.com> "Nienhaus, Doug R" <nienhausd@unocai.com>, "Tom Maunder- AOGC (E-mail)" <tom_maunder@admin.state.ak. us> M-I, Dowell, Baker, FMC; Please be advised that the workover for well Steelhead M-16 has just been postponed (+/- 1 1/2 - 2 weeks) until after M-14RD due to a stubborn sand bridge at 2925' which we could not bail out. We're evaluating clean-out options at this time. Bob; please note that the liner hangers and completion equipment for M-14RD are suddenly moved up a few days. We should be running the whipstock in a very few days. Possibly by Monday. Also, I hope the planned upper packer, the 'FAL', is retrievable? Can you please e-mail a good completion diagram with a brief setting procedure, pressures, etc., for the liner hanger/packer and each production packer? John, we need to finalize the BHA's today, can you please e-mail your recommendations? Current plan, as you know requires 7°/100' BURs in the 8 1/2" hole. Would prefer full LWD, real-time, with slick ADN in both holes. Concerning bits, I mainly want to be certain we can successfully steer the 8 I/2" hole to the landing point in one run. Let me know what you think about bit selection. As you know we're using WBM, so need to get it drilled in one run and get the 7" in the ground ASAP. !'11 be in the office this evening (after moving our furniture from overseas into our house) trying to finalize the procedure. You can reach me on the cell phone anytime today if I can be of service. Thanks. Jerry F. Bowen, P.E. Sr. Advising Drilling Engineer Office: 907-263-7640 Cell: 907-360-2490 Home: 907-688-2278 Fax: 907-263-7884 > .... Original Message ..... > From: Bowen, Jerry -Alaska > Sent: Wednesday, August 15, 2001 2:33 PM > To: Byrne, Don S; Williamson, Dan R; Smetanka, Jeff W; Orr, Gary A; > Benson, Jim (Brazil); Byrne, Don S; Fahrlender, Harold F-Contract; > Nienhaus, Doug R > Cc: 'keytl@kenai. oilfieid, slb.com'; 'Bob. Harris@bakeroiltools. com' > Subject: Tentative plan for M- 16 > > Gentlemen; > Update: The star bit (previously reported to be 3. I0" OD) was run 1 of 3 8/17/0! 10:09 AM RE: Tentative plan for M~16 successfully to +/-2892'. When POH with the star bit, stopped at 2686' to re-check the interval where the previous obstruction was encountered at the suspected KOIV depth with s/ickline error). Had no drag and felt nothing running in/out through the previous obstruction. However, it later was determined that the star bit O.D. was only +/-2.6" (it was apparently mis/abe/ed). While still believing the star bit OD was 3.10" the decision was made to re-run the 3.187" OD dummy packer. Unfortunate/y, it set down at the same p/ace +/.2686'. Since then a 2.5" pump bailer has been run and it appeared that a bailer full of sand was recovered (without breaking through a bridge), but the bailer is just approaching the surface so the amount of sand recovered is not yet confirmed. Current Slick/ine Strategy: / advised Doug to focus on baiting at +/-2892' for the time being. Otherwise we might end up with a problematic coil tubing clean.out. After evaluating the possible sand bridge at +/- 2892' (whether it's determined to be a bridge or a column of sand), we can try a larger star bit and try to open the obstruction at +/-2686' enough to/et the packer pass through. If we ever get the dummy packer to go to 2800', / would tike to be in a position to shut down immediately after that run, so it's best to bail first and fight the restricted clearance issue second. It's also possible that multiple bailer trips to 2892' wi// help open the obstruction at 2686'. Method of Running the Lower Packer: Doug also confirmed that the dummy packer ran to +/-2686' with no drag, and without having to beat downward or work the tool through tight spots. This tends to confirm that the lower packer potentially can be run on E-line to get the required CCL correlation. However, we have the ability to set both packers with coil tubing if this becomes necessary. No additional tools are required to set both packers with coil tubing according to Bob Harris with Baker. /n my view, the packer should slide downhole on E-line, or it probably won't go with coil pushing it. Plan Moving Forward??: /t's my view that the attached revised procedure still offers our highest chance of success, assuming we can work the dummy packer through the obstruction at 2686' to the packer setting depth of 2736'. << Fi/e: M-16 Workover Procedure. doc >> Depending on which prob/ern we can solve and which we can't, there are several options to be considered: 1. Obviously, if we can't get the dummy packer to pass the KO/V, we would have to consider re-milling through the KOIV with either a longer gauge 3.20" OD mill, or a slightly larger OD mill. Of course, a slightly larger OD mill would probably lead to additional milling uphole, and we do not want to ream out the two SC-1 seal bores (ID = 3.25"). t spoke to Todd Duwe with Baker, they can prepare a mill and mobilize the 2 1/8" motor and related equipment within 3 to 12 hours, depending on the specific mill dimensions requested. I've asked him to see how long it will take to make a 3.200" mill with 6" of gauge length and some cutting material on the OD surface. 2 of 3 8/17/01 10:09 AM RE: Tentative plan for M-16 > 2./f we can get the KOIV obstruction opened up enough for the dummy > packer, but can't break through the sand bridge to expose the perforations > at 3211', the option of a coil tubing clean-out, with or without a > Weatherford Venturi bailer, could be considered. Weatherford has a 2 > 1/16" Venturi bailer available on the s/ope which could be here in 1-3 > days. This tool would recover only 2-3' of sand per run with a normal > configuration (20' bailer barrel). The largest tools in the string would > probably be the 2 1/8" OD connector, BPV, disconnect and bailer shoe. > Considering the expense of bailing a lengthy column of sand with coil > tubing, it might be better to try and wash through the suspected bridge > with only a wash tip, etc.. 3. /f neither problem can be solved with slick/ine, we can run the mi// as discussed in option #1, ream out the obstruction(s)) and attempt to wash through the bridge at 2892' without returns. This is potentially risky, but should work as long as we quickly take sma//bites, keep the pumps going and don't wash any deeper than necessary. We could then POH and confirm the top of sand with slickline. If the top of sand is at the same depth, we expect that we have a column of sand on bottom and not just a bridge. 4. /t should be pointed out that all three of the above coil clean-out options are risky. There is a reasonably good chance that the lower zone might produce out a column of loose sand fines. Perhaps trying to wash out a column of sand is unnecessary. 5. /f additional time is need for more detailed planning, we could skid to M-14 first, etc.. Thanks. Jerry F. Bowen, P.E. Sr. Advising Drilling Engineer Office: 907-263-7640 Ceil: 907-360-2490 Home: 907-688-2278 Fax: 907-263-7884 3 of 3 8/17/01 10:09 AM Applications for Permits for Steelhe...s M-14 Abandonment & M -16 Work over Subject: Applications for Permits for Steelhead Wells M-t4 Abandonment & M -16 Work over Date: Fri, 10 Aug 2001 16:33:42-0700 From: "Bowen, Jerry-Alaska" <jbowen@unocal.com> To: "Tom Maunder- AOGC (E-mail)" <tom_maunder@admin.state.ak. us> Tom; Thanks for your patience. Hopefully, the answers to your questions concerning the M-16 work over and the M-14 abandonment can be found below. Well M~16: 1. When nipping down the 7 1/16" tree & nipping up Bops, we will have three barriers in place; i.e. (1) the Baker inflatable packer at +/-1659' with a partial column of 3%KCL-FIW sufficient confirm well 100% dead, (2) a closed and tested SSSV at 448' and (3) a BPV in the tbg hanger. 2. We can pressure test the 4 1/2" x 7" annulus after running the velocity string. Will have to run dummy gas lift valves in the 4 1/2" velocity string, and would have to fully load the annulus with water to accomplish this. However, we fully expect the seal assembly to seal, and the 7" pipe appears to have pressure integrity at this time. We do not want to end up with a live 4 1/2" x 7" annulus. However, we question the need for the extra cost and time to change out the dummy gas lift valves to live gas lift valves, and we are concerned that the extra load water will result in unnecessary formation damage in this Iow pressure completion. 3. We intend to leave the inflatable packer in place until after the 4 1/2" velocity string is run, the Bops are nippled down and the 4 1/16" tree is installed. At that time we can the recover the inflatable bridge plug and puli it out of the well through the 4 1/2" T(E)-5 TRSSSV and with slickline. Well M-14 Abandonment: 1. The planned cement volumes for the short string and long string in well M-14 will be 136 sx (29 bbls) and 318 sx (67 bbts), respectively, as per the attached calculation. I have not yet gotten the procedure approved, but these are the volumes I will recommend. These volumes assume that we will have adequate injectivity, and it is assumed that we will pump 20 bbls of cement outside each set of perfs (as per the attached calculation). Please note that we intend to wait on cement and pressure test both squeezes along with the 9 5/8" casing. <<Abandonment Cement Volume.xls>> If I have overlooked anything, please call or e-mail and ! wilt be happy to provide whatever additional information is required. Thanks. Jerry F. Bowen, P.E. Sr. Advising Drilling Engineer Office: 907-263-7640 Cell: 907-360-2490 Home: 907-688-2278 Fax: 907-263-7884 1 of 2 8/t5/01 4:22 PM Dan Williamson Drilling Manager Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCALe RECEIVED JUL t 200i 07/23/~ska Oil & Gas Cons. Con,mission Anchorage Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Commissioner Julie Heusser Sundry Application (Form 10-403) Application for Approval to Workover Steelhead, Well M-16 McArthur River Field Commissioner Heusser: Enclosed for your approval is a Sundry Application (Form 10-403) for the planned workover of Steelhead Well #M-16. The subject well produces gas with excessive amounts of water and formation sand. The purpose of the workover is two-fold; (1) utilize coil tubing to install a 2 7/8" isolation liner to shut-off production from the water producing SZ-17 and SZ-18 perforations, and (2) run 4 ~" production tubing in the well to alleviate liquid loading problems and improve performance for the remaining life of the completion. The expected date for work to begin is approximately August 15, 2001, so your timely consideration for approval is appreciated. If there are any questions, please contact Dan Williamson at 263-7677 or Jerry Bowen at 263-7640. /8i~cerely,¢. ,,./'!^ Dan Williamson Drilling Manager AOGCC cover letter.doc ORIGINAL. Tim Billingsley STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Isolate middle Alter casing: Repair well: Plugging: Time extension: Stimulate: gravel pack & Change approved pr'ogram: Pull tubing: Variance: Perforate: Other: X run 4 1/2" tubing 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 160' RT above MSL feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Stratigraphic: Anchorage, AK 99519-6247 Service: Trading Bay Unit 4. LocalJon of well at surface Leg ~A-10. ond. #4 Steelhead Platform 8. Well number 1041' FNL & 463' FWL of Sec.33~, T91~, R13¢/, SM Steelhead M-16 At top of productive interval 1600' TVD 9. Permit num~" 591' FNL & 603' FWL of Sec.33, T9N, R13W, SM 97-162 At total depth 2650' TVD 10. APl number ~ 776' FSL & 1330' FWL of Sec.28, T9N, R13W, SM 50- 733-20480-00 11. Field/Pool McArthur River / Grayling Gas Sands 12. Present well condition summary,~' ;::tt Total depth: measured 3,625' Plugs (measured) None true vertical 2,667' Effective depth: measured 3,446' feet Junk (measured) None true vertical 2,530' feet Casing Length Size Cemented Measured depth True vertical depth Structural 406' 28" Driven 448' 448' Conductor Surface 768' 13-3/8" 1350 sx 850' 849' Intermediate 1419' 9-5/8" 575 sx 1500' 1436' Production Liner 2362' 7" 880 sx 3624' 2650' Perforation depth: MD: TVD: MD: TVD: SZ-12 1751-1808' 1613-1651' SZ-18 2612-2667' 2110-2197' SZ-14 1959-2004' 1748-1775' SZ-23 3211-3239' 2535-2547' :. SZ-15 2092-2130' 1826-1848' SZ-24 3387-3408' 2440-2455' SZ-17 2484-2559' 2014-2081' Tubing (size, grade, and measured depth) 7" 29# L-80 NSCC @ 1,295' to 68' RECEIVED Packers and SSSV (type and measured depth) Baker ZXP Liner Top Packer @ 1,295' HES WRSSV 3.50" ~plin 5.~;6~" I.¢j)~'~andrel @448'MD/VD'"'--uu~~J-/ 4" Gravel Pack screen & blank pipe from 1615' to 3416' w/five (5) packers @ 1615', 2138', 2149', 2675' & 3416' Alaska 0il & ~s Cons. Commission 13. Attachments Description summary of proposal: x Detailed operations program: BOP sl~R~lQl(a~9 14. Estimated date for commencing operation 15. Status of well classification as: 8/15/2001 16. If proposal well verbally approved: Oil: Gas: X Suspended: Name of approver . r? N/A Date approved Service: 17. I hereb~tifYsigne" ,~_~ _~'J \.[,thal~ ~ I~J~~;~ing is true andmsonCOrrect to the best ofTitle:mYDrillingknOwledge.Manager Date: ~~h/~ FOR COMMISSION USE ONLY ' Conditions of approval: Notify Commission so representative maywitness,~ c~,.~(,..~t~ ~%',, ~"~(:~>--~-~%..~-- IApproval No,,~O/ (~/ Plug integrity.__ BOP Test .. Location clearance ' .~ Mechanical Integrity Test Subsequent form required 10- ~J~(')~. - ~--~rO~r'~t.~c.~- ~ Cx, c..~-~-._~j,~-.J.~~.~_ tt Commissioner Date ~'i/'~//~) I '~ ,Oril)i~al Signed By Approved by order of the Commissioner Cammy Oech,fli ORIGIF, JA L Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE M-16 Procedure to Isolate Water Producing Perfs & Run 4 1/2" Velocity Tubing Prior to Mobilizing Rig 1 [Verify SSSV functioning correctly (Production personnel) Prior to Skidding Derrick Over Well 2 MIRU Slickline unit 3 Test lubricator & BOPE 4 RIH with dummy packer.& jars ._ 5 RD Slickline Unit Isolation Liner Installation Procedure 6 Skid derrick over well 7 MIRU E-Line Unit 8 Test lubricator & BOPE 9 RIH, set 4" FA packer @ +/- 2736' & POH 10 RD E-Line Unit 11 RU Coil Tbg Riser & BOPE' 12 Test Riser & BOPE 13 Make up 270' x 2 7/8" Isolation Liner (Rig Crew) 14 Attach coil & RU Injection Head 15 Re-test coil tbg riser 16 RIH, set isolation liner w/coil tbg & POH 17 Rig down coil tbg unit & riser 18 Skid derrick to next well & test well M-16 Yelocity String Inst. (after improved performance verified) 19 Skid derrick back over well 20 RU E-line unit. Test lubricator 21 RIH & set 4" inflatable packer @ +/- 1659' MD o,~,~ 22 Partially load well w/3 % KC1 FIW & bleed gas out of well 23 ND x-mas tree & NU 4.5" tbg head & BOPE 24 Test BOPE 25 Recover SSSV w/slickline 26 RIH w/4.5" tbg 27 Recover inflatable packer w/E-line unit. 28 ND BOPE & NU x-mas tree 29 De-mobilize rig STEELHEAD PLATFORM WELL # M-16 TRADING BAY UNIT ACTUAL WELL COMPLETION TBG Hanagr McEvoy 11" x 7" NSCC bottom Type J BPV 1 l"x 7" 28" Structural Casing @ 488' RKB (141'BML) 3-3/8" cement to surface 13-3/8" 68# K-55 BTC Surface Casing @ 840' COMPLETION DESCRIPTION 1) 7" 29# L-80 NSCC Tubing f/1778' - 68' 2) HES 5.963" ID SSSV Landing Nipple F/Safety Valve @ 448' 3) Baker SC-IR Packer @ 1615' 4) 4" 9.5# SSWW Screen & Blank Packed w/20/40 Carbolite F/2137' - 1620'. 5) Baker SC-IR Packer @ 2138'. 6) Baker SC-IL Packer @ 2149' 7) 4" 9.5# SSWW Screen & Blank Packed w/20/40 Carbolite F/2674'-2154'. 8) Baker SC-IR Packer @ 2675'. 9) 4" 9.5# SSWW Screen & Blank Packed w/20/40 Carbolite F/3415'-2679'. 10) Baker DA Sump Packer @ 3416' RKB = 160' TD @ 3625', PBTD @ 3446' 5 6 7" 29# L-80 NSCC 1295-68' 7" Liner Top @ 1295' w/ ZXP Liner Top Packer ITOC inside 7" x 9-5/8" liner lap 9-5/8" 47# L-80 BTC Intermediate Casing @ 1506' 9-5/8" cement to surface 1751-1808' MD 1959-2004' MD 2092-2130'MD 2485-2559'MD 2612-2667'MD 3387-3409'MD 3211-3239'MD 7" 29# L-80 KC Butt Liner from 3623' - 1778' 7" 29# L-80 NSCC Liner from 1778'- 1295' STEELHEAD PLATFORM WELL # M-16 TRADING BAY UNIT PROPOSED COMPLETION COMPLETION DESCRIPTION 1) 7" 29# L-80 NSCC Tie-back casing f/1295' - 68' 2) T(E)-5 3.73" ID TRSSV @ +/-448' 3) Baker SC-1R Packer @ 1615'. 4) 4" 9,5# SSWW Screen & Blank Packed w/ 20~40 Carbolite F/2137' - 1620'. 5) Baker SC-1R Packer @ 2138'. 6) Baker SC-1L Packer @ 2149' 7) 4" 9.5# SSWW Screen & Blank Packed w/ 20~40 Carbolite F/2674'-2154'. 8) Baker SC-IR Packer @ 2675'. 9) 4" 9.5# SSWW Screen & Blank Packed w/ 20/40 Carbolite F/3415'-2679'. 10) Baker DA Sump Packer @ 3416' 11) 4 V2" 11.6# L-80 Improved BTC Spec. Clear. Velocity String 12) Baker locator seal assembly, I.D. = 3.25" 13) 2 7/8" 6.5# L-80 STL isolation liner 14) 4" Baker 'FA' pkrs (two), top pkr @ +/- 2460', bottom pkr @ +/-2736' (min. ID 1.875") 15) Baker 4 l/z" 'CMU' SSD, w/'F' profile (3.688" ID) 4 V2" SFO2 SPM 16) TD @ 3625', PBTD @ 3446' RKB= 160' ll4I 13 14 ! ! 7" TBG Hanagr McEvoy 11" x 7" NSCC bottom Type J BPV 1 l"x 7" 28" Structural Casing @ 488' RKB (141'BML) 13-3/8" cement to surface ~ 13-3/8" 68# K-55 BTC Surface Casing @ 840' 7" 29# L-80 NSCC 1295-68' 7" Liner Top @ +/- 1262' w/ ZXP Liner Top Packer TOC inside 7" x 9-5/8" liner lap 9-5/8" 47# L-80 BTC Intermediate Casing @ 1506' -5/8" cement to surface 1751-1808'MD 1959-2004'MD 2092-2130'MD 2485-2559'MD (Blanked Off) 26 I2-2667 'MD (Blanked Off) 3387-3409'MD 3211-3239'MD 7" 29# L-80 KC Butt Liner from 3623' - 1778' 7" 29# L-80 NSCC Liner from 1778'- 1295' M=16 16 3/4" BOP Stack up Rig Sub Grating 60¸ -CT BOP STACK 2 7/8" Liner BOP Stack SLB Dowell 10K Quad BOP SI.~B 7" 15K Lubricator DSR 7 1/16 Annnlar Bag Shear / Blind Rams Shear / Blind Ranis 1'75' Slip Ranis 1.75" Pipe Rams DSR Dual Stack BOP dressed for 2 7/8" Liner 2 7/8" Pipe Slips 2 7/8'~ Pipe Rams AOGCC Geological Materials Inventory PERMIT 9 7-.162 UNOCAL Log CMT RETAIN. CN/LDT DEPTH DETER. DEPTH DETER. DITE PACKER PERF SRVY CALC ,d~2407 Completion Date Are dry ditch samples required? Was the well cored? Data Sent Recieved Box ~'~3000-3512 ~/'2-~/~t'] 3/17/1998 3/31/1998 ~1~1507-3598 3/17/1998 3/31/1998 '~900-2150 10/5/97 3/17/1998 3/31/1998 1800-2350 10/1/97 3/17/1998 3/31/1998 1507-3621 3/17/1998 3/31/1998 ~2950-3420 l~/'2_~/C~r'] 3/17/1998 3/31/1998 ! yi3H 0-3625 10/27/1997 10/30/1997 [t)/l~[/*'~ Daily well ops ~ yes ~ no And received? ~ no Are tests required? yes ~ no Analysis _description recieved? ~.~. no yes j;~no Received? ~ yo~ ~-~,, no Well is in compliance Comments Initial Friday, October 08, 1999 Page 1 of 1 Dear Mr. Hartz: Unocal Alaska Resourc~ Unocal Corporation 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907)276-7600 April 7, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Attn: Jack Hartz Steelhead Platform WeI[M-16_~_~ APl # 50-733-20480-00 Form 10-421, Gas Well Open Flow Potential Test Report Attached is Form 10-421 for the modified isochronal flow test on Steelhead Platform Well M-16 conducted on March 24, 1998. Please d rect any questions to Sam Darkwah at 263-7864. Sincerely, :-\l~:tSl';a, U!: i;~. ;;..i;,'..:!; ~.;0ilS, ' ........ -:¢-r_,i Ai~ch0r~ge Attachment: Log-Log Plot of Test Data Sam A. Darkwah Reservoir Engineering Technician I I ,_., ' " STATE OF ALASKA ALASKA O'IL AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTEHTIAL TEST REPORT I I I I I I 1 a. TEST: INITIAL ~l lb. TYPE TEST ANNUAL{~ I MULTIPOINT [] SPECIAL OTHER J~ 0D t F~r ~ STABILIZED NON STABILIZED CONSTANT TIME ISOCHRONAL 2. Name of Operator UN~o~l 0~L- co~Pa~JY 5. Elevation in feet (indicate KB, DF etc.) IGo' 14~ ftG~uF_.. M SI_ 12. Completion Date 7. Permit No. q~ 162. 8. APl Number ~o- ~/~5-2oH2o- 9. Unit or Lease Name 10. Well Number 11. Field and Pool Lease Designation and Serial A-DL- 13. Total D~pth'rl)/M~l 14, Plugback T,O.~'V~/M~ 115. Type Completion (Describe) 6. Csg. Size_ Weight p~r foot, lb. ~ I.D. in inches Set at ft. ~,, S,'~' 6~M. K-? 12. z/~6 17. Tbg. Size Weigh[ per foo~, lb. I.D, in inches Set at 18. Packer set at ft. (~) ~19. GOR cf/bbl. 120-APl Liquid Hydrocarbons 22. Producing thru: ~ ~1~" Reservoir Temp. °F. r~. ¢ C~. G ~ O 23. Length of flow channel (L) Vertical Depth IH) ~ Go. ~ o~ CO2 Fh}w Data Prover Choke Pressure Diff. Temp. Line X Orifice Size (in.) Size (in.) psig hw ~ F. ~' N2 Mean Annual Temp. o F. Barometric Pressure (Pa), psia o 24. ~f x t zf. x 61o 1~4.6 Tubing Data Pressure psig Temp. °F. Casing Data Pressure psig Temp. °F. Duration of Flow Hr. z. 2. Basic Coefficient (24-Hour) Fb or Fp Pressure Pm Flow Temp. Factor Ft Gravity Factor Fg t-).65 Super Comp. Factor Fpv Rate of Flow Q, Mcfd I~'~ O~) 0 No. Form 10.421 Rev. 7-1,80 I-2..O 1.0~ Temperature T Tr 1-61 o.'1o5 O' flip.. Critical Pressure Critical Temperature for Separator Gas Gg for Flowing Fluid G D- O- CONTINUED ON REVERSE SIDE Submit ~n duplicate .. :',-': ..' L Pc No. l4. 25. AOF (Mcfd) Remarks: Pw2 i I pc2 . pw2 0,00o I hereby certify that the foregoing is true and correct to the best of my knowledge Signed AOF Fb Fp Fg Fpv Ft G Gg GOR hw H L n Pa Pc Pf Pm Pr Ps Pt Pw Q Tr T Z DEFINITIONS OF SYMBOLS Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia. Basic orifice factor Mcfd/-v hwPm Basic critical flow prover or positive choke factor Mcfd/psia Specific gravity factor, dimensionless Super compressibility factor=-%' l/Z dimensionless Flowing temperature factor, dimensionless Specific gravity of flowing fluid (air=1.000), dimensionless Specific Gravity of separator gas (air=l.00), dimensionless Gas-oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F.) per barrel oil (60 degrees F.) Meter differential pressure, inches of water Vertical depth corresponding to L, feet (TVD) Length of flow channel, feet (MD) Exponent (slope) of back-pressure equation, dimensionless Field barometric pressure, psia Shut-in wellhead pressure, psia Shut-in pressure at vertical depth H, psia Static pressure at point of gas measurement, psia Reduced pressure, dimensionless Flowing pressure at vertical depth H, psia Flowing wellhead pressure, psia Static column wellhead pressure corresponding to Pt, psia Rate of flow, Mcfd (14.65 psia and 60 degrees F,) Reduced temperature, dimensionless Absolute temperature, degrees Rankin Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual Of Back-Pressure Testing Of Gas Wells, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. ,t Form 10-421 - 60 - Steelhead Platform Well M-16 -- Modified Isochronal Test Analysis (03/24/98) 1,000,000 100,000 10 Gas Flow Rate, Qg, MMCFD 1 O0 O:/Gas CFT/M16_fourpt.xls/M 16plot Unocal Agricultural Products Diversified Business Group 909 West 9th Ave, Anchorage, AK 99501 Te/e: (907) 263-7889 Fax: (907) 263-7828 E-mai/: chi/dersd @ unoca/.com UNOCAL Debra Childers Geotech Assistant DATA TRANSMITTAL March 17, 1998 To: Laurie Taylor 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From: Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Transmitting the following items: WELL NAME PRINT FILM SCALE DESCRIPTION RUN# DATE TBU M-1 1 1 5" Completion Record 1 10/12/97 TBU M-16 1 1 2' Phasor Induction- SFL 1 9/24/97 TBU M-16 1 1 5' Packer 1 9/28/97 TBU M-16 1 1 5' Squeeze Perf 1 9/25/97 TBU M-16 1 1 5" Cement Retainer 1 9/25/97 TBU M-16 1 1 5" Depth Determination Log 1 10/5/97 TBU M-16 1 1 2" Compensated Neutron Lithology Density 1 9/24/97 TBU M-16 1 1 5" Depth Determination 1 10/1/97 P/L-~se acknowledge rec, e~t by signing and returning one copy of this transmittal or FAX to (907) 263-7828. I Received by.(~'~'~~ ]Date: STATE OF ALASKA ALASKA OtL.- ND GAS CONSERVATION C, MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: GAS: X SUSPENDED: ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number UNOCAL 97-162 3. Address 8. APl Number P.O. Box 19-0247 Anchorage, AK. 99519-0247 50- 733-20480-00 4. Location of well at surface Leg A1 Slot # 4 Steelhead Platform,---_~! 9. Unit or Lease Name 1,041' FNL. 463 FWL. Sec. 33, T9N, R13W, SM -~ .................. ~ ; ,..~.~,-¢,)~L~.¢~.~?~ ! Trading Bay Unit At Top Producing Interval @ 1,751' MD i/(~ 7~/i~,_~/_ .~.~ i~ j 10. Well Number 591' FNL. 603' FWL. Sec. 33, T9N, R13W, SM .~ _ M-16 AtTotal Depth ' ~.E~'Fi~; ~ ~'~~ 11. Field and Pool 776' FSL. 1330' FWL. Sec. 28, TeN, R13W, SM i.~/~ ..... ! .:_,~-,-~,~,..;_--&7.~ McAuthur River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designab~)'¢i' a'~h'~r~b~i~rNb. Grayling Gas Sands Pool 160' KB above MSLI ADL 18730 12. Date Spudded 13. Date T.D. Reached I 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore I 16. No. of Completions 9/14/1997 9/23/97I 10/14/97 187' feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 3,625' MD & 2,667' TVD 3,446' MD & 2,530' TVD Yes: X No:I 448' feet MD N/A 22. Type Electric or Other Logs Run DIL/LDT/CNL/Gamma Ray 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 28" 82' 488' Driven 13-3/8" 68# K-55 82' 840' 17-1/2" Lead 1430 sx + 350 sx Tail 9-5/8" 47# L-80 81' 1506' 12-1/4" Lead 712 sx + 162 sx Tail 7" 29# L-80 80' 3623' 8-1/2" 460 sx 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7" 29# L-80 67' - 3623' 1615', 2138', 2149', 2675', MD TVD MD TVD & 3416' SZ-12 1751'-1808' 1613-1651' SZ-23 3211'-3239' 2535'-2547' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. SZ-14 1959'-2004' 1748'-1775' SZ-24 3387'-3408' 2440'-2455' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED SZ-15 2092'-2130' 1826'-1848' SZ-12, 14 & 15 HRWP w/24,600 lb 20/40 CarboLite SZ-17 2485'-2559' 2014'-2081' SZ-17 & 18 HRWP w/16,630 lb 20/40 CarboLite SZ-18 2612'-2667' 2110'-2197' All perforations 12 SPF SZ-23 &24 HRWP w/7,950 lb 20/40 CarboLite 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 10/21/1997I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 10/21/1997 6 TEST PERIOD => 0 9,925 0 N/AI 0 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 500 psi 0 24-HOUR RATE => 0 39,700 0 N/A 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate GEOLOGIC MARKERS FORMATION TESTS NAME Inciude interval tested, pressure data, ail fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T. Tyonek Shallow Zone 1,751' 1,514' 31. LIST OF A'I-I'ACHMENTS 32. I hereby certify that the foregoing is true and con'ect to the best of my knowledge Signed ,~ ~ ~- (~, ~ Title Ddllin.qMana.qer Date October27, 1997 Dale Haines INSTRUCTIONS Generai: This I'orm is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas Injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given In other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the preductin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersble, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: I! no cores taken, indicate 'none'. Form 10-407 1997 9/14- 9/23 9/24 9/25 SUMMARY WELL HISTORY STEELHEAD M-16 DAY 1-12 Skid rig to SW leg. Center up over well M-16 and commence rig up operations. Make up diverter and diverter risers. Function test same from Driller's station and remote panels. Install drilling nipple flow line and fill up lines. Held Abandon Platform Drills for aH crew members. Pick up HWDP and fill up conductor and diverter with sea water. Function test operation on diverter lines. Make up Kick-off motor assembly. RIH and clean out conductor from 381 to 480'. Rotary drill from conductor shoe at 480' to 500', Circulate and clean up returning fill. Make up gyro and run 90' stations from surface to conductor shoe. (Conductor straight). Orient motor and kick-off well and drill 17-1/2" hole building at 4deg/100' to 783'. Lay LCM pill at 783' due to loss circulation (60 BPH). Continue drilling to section TD at 852'. Make short trip to lay down side entry sub and RIH with no problems. POOH and rig up to run 13-3/8" casing. Run 18 joints of casing to 842. Cement casing with full returns to surface. Lay out casing landing joints and nipple down diverter system. Install Furmanite pack-off and NU 16- 3/4" 10M BOP's. Test BOP's to 250/5000 psi and annular to 250/5000 psi. Make up 12- 1/4" steerable motor assembly. RIH and drill 12-1/4" hole from 852' to 1520'. POOH and prepare to mn 9-5/8" casing. Run 9-5/8" casing to 1506'. Cement casing with intermittent returns to surface. Set pack-off and install and test casing spool. RAN HES temperature survey to determine estimated top of cement. Make up 8-1/2" steerable motor assembly and drill ahead to TD at 3625'. Raise mud weight to 9.5 ppg due to excessive BG gas. Make wiper trip to shoe without problems. RIH and circulate hole clean. POOH and lay down BHA. DAY 13 Rig up to mn wireline logs. Run triple combo from 3525 to 1506'. Rig down Schlumberger and change out top casing rams to 7". Prepare to run T' liner. Rrm 44jts 7" 29"lb/ft BTC with KC couplings and 12 joints 7" 291b/ft NSCC casing. Make up liner hangar and continue RIH. DAY 14 Continue RIH to TD at 3630'. Circulate and condition mud. Set liner hangar with 1800 psi and release from hangar with 2500 psi. Attempt to shear out ball seat with 6000 psi without success. (Should have sheared at 3900 psi). Rig up HES slickline and RIH to confirm position of liner wiper plug. Found liner wiper plug had sheared and gone down hole to landing collar (no possibility of pumping cement through shoe track). POOH with liner running tool and layed down. Rigged up Schlumberger and RIH and perforated 3510-3512 with 3-3/8" 6spf 60 deg phasing casing guns. POOH and made up Baker Model D wireline set packer with integral float collar. RIH and set at 3446'. POOH and rig down Schlumberger. 9/26-10/1 DAY 20 Make up Baker seal assembly and RIH to top of liner to complete cementation of liner. Tag top of liner, sting in and make up plug drop head. Cement liner with 10 bbls Chemwash, 28 bbls 10.5ppg Mudpush followed by 118 bbls (460 sx) G cement with 1% D020, .lgps D47, .1 gps D135, 2.6gps D600 and .5 gps PAKS002. Drop top plugs and displace with 9.7ppg mud. Unstung from liner and circulated out. POOH and PU 8-1/2" bit and clean out assy. RIH to and clean out to top of liner. Make up 6" clean out assy and clean out liner to ETD at 3446'. RU Schlumberger and mn CET/CBT/GR. RIH with Baker polishing mill and dress tie back area. MU and RIH with Baker ZXP tieback packer and set on top of liner tie-back extension. Pressure test to 3500 psi. RIH and displace wellbore from ETD at 3446' to 6% KCL. POOH Make up model D sump packer and ROIH and set on wireline at 3416'. MU TCP assy and RIH to sump packer at 3416'. STEELHEAD PLATFORM WELL it M-16 TRADING BAY UNIT ACTUAL WELL COMPLETION COMPLETION DESCRIPTION 1) 7" 29# L-80 NSCC Tubing f/1778' - 68' 2) HES 5.963" ID SSSV Landing Nipple F/Safety Valve ~ 448' 3) Baker SC-1R Packer ~ +/-1615'. 4) 4" 9.5# SSWW Screen & Blank Packed w/20/40 Carbolite F/2137' - 1620'. 5) Baker SC- 1R Packer ~ 2138'. 6) Baker SC-1L Packer ~ 2149' 7) 4" 9.5# SSWW Screen & Blank Packed w/20/40 Carbolite F/2674'-2154'. 8) Baker SC-1R Packer ~ 2675'. 9) 4" 9.5# SSWW Screen & Blank Packed w/20/40 Carbolite F/3415'-2679'. 10) Baker DA Sump Packer ~ +/-3416' RKB = 160' TD ~ 3625' TBG Hanagr~ McEvoy 11" x 7" NSCC bottom Type J BPV 1 l"x 7" 28" Structural Casing ~ 488' RKB (141'BML) I13-3/8" cement to surface 13-3/8" 68# K-55 BTC Surface Casing ~ 840' 7" 29# L-80 NSCC 1295-68' 7" Liner Top ~ +/- 1262' w/ ZXP Liner Top Packer TOC inside 7" x 9-5/8" liner lap 9-5/8" 47# L-80 BTC Intermediate Casing (D~ 1506' 9-5/8" cement to surface I 1751-1808'MD 1959-2004'MD 2092-2130'MD 2485-2559'MD 2612-2667'MD 3387-3409'MD ~211-~2~9MD 10 7" 29//L-80 KC Butt Liner from 3623' - 1778' 7" 29# L-80 NSCC Liner from 1778'- 1295' 9/26-10/1 Cont'd 10/2-14 Tag sump packer. Space out and TCP perforate 3211-3239' and 3387- 3408' with 500 psi underbalance. Strong blow to surface. POOH and lay down gun assy. All shots fired. RIH with ~avel pack assy. Space out and set top Baker SC-1 packer at 2675'. Pump pickling solution and prepare for frac-pac operations. Pump 20/40 Carbolite sand at 14BPM. Final sand concentration through perforations was 113 lb/ft. (34' of blank pipe covered). Monitor well and weight up to 9.0ppg. POOH. PU SB packer plug and set in SC-1 packer at 2675'. Test to 1500 psi. POOH and RU to mn TCP assy No.2. RIH with TCP assy. And perforate well from 2667-2612' and 2559'- 2485' with 500 psi underbalance. Strong blow to surface. POOH with TCP assy. DAY 32 CONN'T POOH AND LAY DOWN PERFORATION GUNS. (ALL SHOTS F3RED. RIH WITH BOWEN 150 OVERSHOT AND RECOVER BAKER SB PACKER PLUG AT 2677'. RIGGED UP TO RUN BAKER GRAVEL PACK NO.2 HAD DIFFICULTY STABBING MULE SHOE INTO LOWER LINER PACKER. WORKED 1/4 LH TURN IN ORDER TO STAB MULESHOE INTO PACKER TO WITH NEGATIVE RESULTS. WELL STARTED FLOWING. RAISED ACTIVE SYSTEM TO 9.2 PPG. POOH AND DISCOVERED THAT 8 JOINTS BLANK PIPE, 7 JOINTS SCREEN AND TAIL PIPE ASSY LEFT IN HOLE. MADE UP FISHING ASSY AN RIH. ENGAGED FISH AND RECOVERED 100%. RIH WITH MULUE SHOE GUIDE · ON 2-7/8" STINGER ON 3-1/2" DP. WEIGHTED UP ACTIVE SYSTEM TO 9.5PPG. WORKED MULE SHOE INTO SC-1 PACKER. SPOT 1.3 CUFT SAND ON KOIV FLAPPER VALVE AND POOH WITH ASSY. RE-RAN GP ASSY. SNAPPED INTO SC-1 PACKER AND SPACED OUT. RIGGED UP SURFACE LINES AND DROPPED SETYING BALL OR SC-1 PACKER. PERFORMED STEP RATE TEST AND PERFORMED FRAC PAC, INJECTING 112LBS/FT OF 20/40 CARBOLITE INTO PERFORATIONS. APPROXIMATELT 33' OF BLANK PIPE COVERED WlH SAND. POOH WITH WASH PIPE AND SLACKED BACK DOWN TO BREAK THE KOIV. MADE UP AND RIH WITH BAKER ZONE ISOLATION PACKER. SET PACKER AT 2150'. POOH WITH PACKER SETTING TOOLS. MADE UP TCP ASSEMBLY AND RIH. ATTEMPTED TO SHOOT GUNS WITHOUT SUCCESS. NO INDICATION OF FIRING. POOH TO INSPECT GUNS. FOUND ANNULAR PRESSURE TRANSFER LINE BROCKEN BELOW BOTTOM OF PACKER. (NO SHOTS FIRED) MADE UP TCP ASSEMBLY AND RE-RAN IN HOLE. SPACED OUT GUNS AND RIGGED UP SURFACE CON'I~OL LINES. PERFORATED 2130- 2092', 2004-1959' AND 1808-1751' WITH 12 SFF 25GR CHARGES. GOOD INDICATION OF GUNS FIRING. REVERSE OUT AND POOH. ( ALL SHOTS FIRED) MAKE UP CLEAN OUT ASSY AND RIH TO 2147. REVERSE OUT FILL AND CIRCULATE CLEAN. RIG AND RUN GP ASSY NO 3. SNAP IN AND OUT OFSC-1 AT 2142'. SPACE OUT AND RIG UP SURFACE LINES. SET PACKER AND COMMENCE GP OPERATIONS. PLACED 146LBS/Fl' 20/40 CARBOLITE SAND INTO PERFORATIONS. POOH WITH GP ASSY. MAKE UP BAKER 2-1/2' THRU TBG INFALATABLE BRIDGE PLUG AND RUN ON DP. SET IN CENTER OF 4' BLANK OF TOP GRAVEL PACK ASSEMBLY. ATTEMPTED TO SET WITHOUT SUCCESS. POOH AND FOUND PLUG HAD SHEARED OFF. MADE UP AND RIH WITH BAKER HYDRAULIC RELEASE TOOL AND ATTEMPT TO RECOVER BRIDGE PLUG. (NO SUCCESS)) RIH WITH SLICKLINE AND RECOVER PLUG. MAKE UP BAKER S PLUG AND SET IN TOP SC-1 PACKER AT 1620'. POOH LAYING DOWN EXCESS DP AND DC'S. INSTAIJ. 7" CASING RAMS AND TEST BONNET SEALS. RU AND RUN 7' NSCC 29 LB L-80 TIE- BACK STRING. MAKE UP SVLN WITH BLANKING SLEEVE INSTALLED. RUN DUAL CONTROL LINES.DISPLACED ANNULUS WITH 65KCL BRINE + 1% TRETOLITE CRW132 CORROSION INHIBITOR AND DEFOAMER. STAB INTO TIE-BACK SEALS AND TEST. TEST 7" X 9-5/8" ANNULUS TO 2500 PSI. NIPPLE DOWN BOP STACK AND NU TREE. PULL BPV AND RUN TWC VALVE. RIG RELEASED FROM M-16 AT 0600 HRS 10/10/97. DEACTIVATE RIG AND PREPARE TO SKID FROM SW LEG TO SE LEG FOR STORAGE. RU DOWELL CT EQUIPMENT. RECOVER SVLN BLANKING SLEEVE ON WIRELINE AND RECOVER S PLUG AT 1618'. MU MILL. ON CT AND RIH AND MILL ON ALUMNIUM PLUG AT 2148'. MII.I. THROUGH KOW AT 2185' AND 2798 CTM. RIH TO ETD AND PUMP NITROGEN TO UNLOAD W]::.LL. RIG DOWN CTU AND RELEASE WELL AT 1600 HRS 14 OCTOBER 1997 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-90733 Sidetrack No. Page 1 of 2' ~ Company UNOCAL Rig Contractor & No. Pool Arctic Alaska- Steelhead ?'7"'~/~ ~ Field MCARTHUR RIVER FIELD Well Name & No. STEELHEAD PLATFORM/M-16/TRADING BAY UNIT Sun/ay Section Name Definitive Survey BHI Rep. MILLER,HAMBURG let TVD (F'r) Target Coord. N/S Slot Coord. N/S -1041.23 Grid Correction 0.000 Depths Measured From: RKB ~ MSL[~ SS0 let Description Target Coord. E/W Slot Coord. EJW 462.99 Magn. Declination 21.870 Calculation Method MINIMUM CURVATURE ]et Direction {OD~ Build~Walk\DL per: 100ft[~ 30m~ 10m0 Vert. Sec. Azlm. 26.76 Magn. to Map Corr. 21.870 Map North to: OTHER SURVEY DATA · Survey Sun/ay Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length 'I'VD Section N(+) I S(-) E(+) I W(-) DL Build (+) Right (+) Comment ifPO (FT) {OD) {DO) {FT) ~ {Fl') (IT) (Per leo F'r)Drop (-) Left (-) 0,00 0,00 0,00 0,00 0.00 0,00 0,OO TIE IN POINT -SEP-97 RGSS 90,00 0,16 200,25 90,00 90,00 ..0,12 -0,12 -0,04 0,18 0,18 -SEP-97 RGSS 180.00 0.11 14.12 90.00 180.00 -0.17 -0.15 -0.07 0.30 -0.06 .-SEP-97 RGSS 270.00 0.11 260.20 90.00 270.00 -0.13 -0.08 -0.13 0.20 0.00 i-SEP-97 RGSS 360.00 0.07 27.60 90.00 360.00 -0.13 -0.05 -0.19 0.18 -O.04 ~-SEP-97 RGSS 450.00 0.15 92.69 90.00 450.00 -0.03 -0.01 -0.05 0.15 0.09 r'~ J'~ ~/,~ I 5-SEP-97 RGSS 648.00 6.80 331.53 89.00 647.66 5.48 8.25 -4.19 5.01 5.01 -2.73 5-SEP-97 RGSS 701.00 9.75 334.82 53.00 700,11 10.04 15.08 -7.60 5,64 5.57 6.21 ,, 5-SEP-97 RGSS 737.00 11.28 337.88 36.00 735,50 14.24 21.10 -10.22 4.52 4.25 8.50 ,,, 5-SEP-97 RGSS 800.00 13.00 348.01 63.00 797.10 23.82 33.74 -14.01 4.34 2.73 16,08 ._~ 19-SEP-97 RGSS 863.00 12.85 350.93 63,00 858.50 35.02 47.59 -16.59 1.06 -0.24 4.63 ,,. 19-SEP-97 RGSS 958.00 15.94 2.45 95.00 950.53 55.48 71.06 -17.70 4.42 3,25 12.13 .. 19.SEP-97 RGSS 1053.00 18,69 6.30 95.00 1041.22 81.64 99.23 .15.47 3.13 2.89 4.05 / 19-SEP-97 RGSS 1147.00 23.89 13.72 94.00 1128.79 114.32 132.72 -9.30 6.22 5.53 7.89 ,, 19-SEP-97 RGSS 1240.00 27.65 22.48 93.00 1212.55 154.22 170.98 3.43 5.75 4.04 9,42 19-SEP-97 MWD 1334.00 31.15 26.77 94.00 1294.44 200.30 212.86 22.73 4.34 3.72 4,56 19-SEP-97 MWD 1428.00 35.09 26.48 94.00 1373.16 251.65 258.77 45.73 4.19 4.19 -0.31. ,. 19-SEP-97 MWD 1478,00 36.33 26.81 50.00 1413.75 280.83 284.85 58.82 2.51 2.48 0.66 , , 22-SEP-97 MWD 1601.00 42.15 26.70 123,00 1508.98 358.60 354.30 93.83 4.73 4.73 -0.09 22-SEP-97 MWD 1696.00 46.18 24.95 95.00 1577.11 424.77 413.88 122.62 4.43 4.24 -1.84 ,, 22-SEP-97 MWD 1791.00 48.56 24.99 95.00 1641.45 494.62. 477.24 152.13 2.51 2.51 0.04 ,. 22-~EP-97 MWD 1884.00 50.59 26.77 93.00 1701.75 565.40 540.92 183.04 2.62 2,18 1.91 , i-~2-SEP-97 MWD 1979.00 53.63 29.61 95.00 1760.10 640.33 606.96 218.48 3.98 3.20 2.99 SURVEY CALCULATIONAND FIELD WORKSHEET JobNo. 0450-90733 Sidetrack No. Page 2 of 2 1 Company UNOCAL Rig Contractor & No, Pool Arctic Alaska- Steelhead Field MCARTHUR RIVER FIELD Well Name & No. STEELHEAD PLATFORM/M-16/TRADING BAY UNIT Survey Section Name Definitive Survey BHI Rep, MILLER,HAMBURG I~ i ~'~a~ WELL DATA let TVD {F~ Target Coord. NIS Slot Coord. N/S -1041.23 Grid Correction 0.000 · Depths Measured From: RKB ~ MSL 0 SS~ let Description Target Coord, EAN Slgt. Coord, E/W 462.99 Magn, Declination 21.870 ,' Calculation Method MINIMUM CURVATURE let Direction IpD) Build~Walk\DL per: 100tt[~ 3Omni 10m~ Vert, Sec, Azim, 26,76 Magn, to Map Corr, 21.870 Map North to: OTHER SUhVEY DATA , Survey Survey Incl, Hole Course Vertical Total Coordinate Build Rate Walk Rate Dote Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right.(+) Comment Typo ~ (OD) ~ ~ miT) (F'I) (F'D (Per loo Iq) Drop (-) Left (-) .'~1~i~---9~MWD 2074,00 53,79 28.27 95,OO 1 at 6,33 716.84 673.97 255.53 1,15 0.17 -1,41 ; .. SEP-97 MWD 2168,00 56.13 29.67 94,00 1870,30 793,74 741,29 292.82 2.77 2,49 1,49 .sEP-97 MWD 2282.00 57,16 28.07 94,00 1921,98 872,20 810,05 330,72 1,79 1,10 -1,70 -SEP-97 MWD 2356.00 57,51 27,88 94.00 1972,72 951,31 879,93 367,84 0,41 0,37 -0.20 -SEP-97 MWD 2450.00 57,63 ' 27,98 94,00 2023,12 1030,64 950,03 405,00 0,16 0,13 0,11 :-SEP-97 MWD 2542,00 57,08 28,75 92,00 2072,75 1108,07 1018,20 441,80 0,92 -0,60 0,84 !-SEP-97 MWD 2636,00 56,97 28,59 94,00 2123.91 1186,88 1087,39 479,63 0,18 -0,12 -0,17 !-SEP-97 MWD 2730.00 56,86 27,58 94,00 2175,23 1265,62 1156.87 516,71 0,91 -0,12 -1,07 !-SEP-97 MWD 2824,00 56,39 27,00 94.00 2226,94 1344,11 1226,63 552,70 0,72 -0,50 -0,62 .)-SEP-97 MWD 2918.00 56.04 26,54 94.00 2279.21 1422,24 1296.38 587,89 0.55 -0.37 -0,49 ;?-SE P-97 MWD 3010.00 55,59 26,12 92.00 2330,90 1498.34 1364,59 621,65 0,62 -0,49 -0.46 3-SEP-97 MWD 3105,00 57,10 27,87 95.00 2383,55 1577,41 1435,04 657.55 2,21 1,59 1,84 '"'*?;, . ~i ' 3-SEP-97 MWD 3199.00 57,66 28,84 94,00 2434.23 1656,55 1504,71 695.15 1,05 0.60 1,03 ....... ~';.L ?; ........ .'., ..... 3-SEP-97 MWD 3293.00 57,47 29,98 94.00 2484.64 1735.80 1573,82 734,11 1.04 -0.20 1,21 ...... 3-SEP-97 MWD 3386.00 56.83 28,63 93,00 2535.09 1813,85 1641,95 I 772,35 1,40 -0,69 -1,45 ;~;; .?;' ............ 3-S EP-97 MWD 3479,00 56.59 28,00 93,00 2586,14 1891,56 1710,38 809,22 0,62 -O.26 -0.68 ~: ,, . :3-SEP-97 MWD 3572.00 56,15 28,39 93,00 2637,64 1968.97 1778,63 845.81 0,59 -0,47 0,42 '.3-SEP-97 MWD 3625.00 55.97 28.38 53.00 2667.23 2012.92 1817.31 866,71 0,34 -0.34 -0.02 ProJ~bted Data - N° Survey , , - TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 September 11, 1997 Dales Haines Drilling Manager UNOCAL P O Box 190247 Anchorage, AK 99519-0247 Re: Trading Bav Unit M-I 6 UNOCAL Permit No: 97-162 Sur. Loc' !041'FNL. 463'FWL. Sec. 33, TgN. RI3W. SM Btmhole Loc.760'FSL. 1371 'FWL. Sec. 28. TgN. R13W. SM Dear Mr. Haines: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law t¥om other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance xvith 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test pertbrmed before drilling below the surface casino= shoe must be ~-°iven so that a representative of the Commission may. witness the test. Notice may be =iven by contactinz the Commission at 279-1433. David W. J~ Chairman BY ORDER OF THE COMMISSION / die Enclosures CC' Department or' Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 September 11. 1997 ADMINISTRATIVE APPROVAL NO. 228.04 Re' The application of Union Oil Company of California. operator of the Trading Bay [)nit (TBU). to drill and complete the TBU M-16 Middle Kenai Gas Pool production well. .¥1r. Rick D. Cross. Sr. Landman Unocal Alaska Resources b%'OCAL Corporation P O Box 196247 ,Anchorage, AK 99519-6247 Dear Mr. Cross' Your application of August 12. 1997. for a permit to drill and complete the TBU M-16 well requires exception to spacing requirements set forth in Conservation Order No. 228. The drilling and completion of the TBU M-16 well is expected to provide additional gas recovery from the Middle Kenai Gas Pool in the TBU. The ,~\laska Oil and Gas Conservation Commission hereby authorizes the drilling and '~8 completion of the TBU M-16 well pursuant to rule 3 of Conservation Order No. ;, . .. ~d dated September 11, 1997. CD. ~idrmWa~Xtoxhnst°n / CRo°bmem~i~sioCneh~r'stens°n' P'E' STATE OF ALASKA ALASKA OI,_AND GAS CONSERVATION L-: MMISSION PERMIT TO DRILL 20 AAC 25.005 I la. Type of work Drill: X Redrill: I lb. Type of well Exploratory: Stratigraphic Test: Development Oil: Re-Entry: Deepen:I Service: Developement Gas: X Single Zone: Multiple Zone: 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool UNOCAL 160' RKB feet McAuthur River Field 3. Address 6. Property Designation Grayling Gas Sands Pool P.O. Box 19-0247 Anchorage, AK. 99519-0247 ADL 18730 4. Location of well at surface Leg A1 Slot # 4 Steelhead Platform 7. Unit or property Name 11. Type Bone (see 20 AAC 25.025) 1041' FNL. 463 FWL. Sec. 33, TDN, R13W, SM Trading Bay Unit At top of productive interval 1600' TVD 8. Well number Number U62-9269 701' FNL. 564' FWL. Sec. 33, TDN, R13W, SM M-16 At total depth 2650' TVD 9. Approximate spud date Amount 200000 760' FSL. 1371' FWL. Sec. 28, TDN, R13W, SM 9/15/97 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD) property line M-31 @ 1050' MD 564 feet 48' feet 3840 3624' MD & 2650' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure(see 20 AAC 25.035 (e)(2)) Kickoff depth: 500 feet Maximum hole angle: 60 Maximum surface 192 psig At total depth (TVD) 1166 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD 'I-VD MD 'I'VD (include stage data) 17-1/2" 13-3/8" 68# K-55 Butt 768' 82' 82' 850' 849' Lead 975 sx + 375 sx Tail 12-1/4" 9-5/8" 47# L-80 Butt 1419' 81' 81' 1500' 1436' Lead 175 sx + 400 sx Tail 8-1/2" 7" 29# L-80 Butt KC 3464' 80' 80' 3624' 2650' 880 sx 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True vertical depth Structural 406' 28" Driven 488' 488' Surface ~' ~ ~: ~ ; ~ = ' ~t' ~ ~ · ::~' Intermediate Production ~'!!~ i.! 'i~' ~i ~:.: Liner Perforation depth: measured ~i~;~!~'~.bd'~' ;~ .v~. .... ~_'_!i~5'"' ~t~!~, L~ ~?.._~ ~r~";?''"~ .......... ~' ~''-~'~ true vertical 20. Attachments: Filing fee: X Property Plat: X BOP Sketch: X Diverter Sketch: X Drilling program: X Drilling fluid program: X Time vs. depth plot: X Refraction analysis: Seabed report: 20/LAC 25.050 requirements: X 21. I herby certity that the foregoing is true and correct to the best of my knowledge: ORIGINAL Signed: ,~(~ (~[ r,.,L,,,.~ Title: Drilling Manager Date: 8/8/97 Commission Use Only Permit Number [ APl number I Approval date ? ~-/~',~_._, 50-7~'--"' Z<~' ~ ~"~ ¢-~//-~ for other requirements Conditions of approval Samples required: [ ] Yes ;[~ No Mud log required: [ ] Yes ,,[x~'No Hydrogen sulfide measures [ ] Yes [;K] No Directional survey required ~ Yes [ ] No Required working pressure for DOPE ~2M; [ ]3M; [ ISM; [ ] 10M; [ ] 15M Other: .jnglnal Signed By by order of Approved by David W. Johnston Commissioner the Commission Date: ~' Form 10-401 Rev. 12-1-85 Submit in triplicate Unocal Alaska Resour Unocal Corporation ~_ r 909 West 9th Avenue, P. Oi 'Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL August 12, 1997 Mr. Bob Crandall Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 STEELHEAD PLATFORM PERMIT TO DRILL AND SPACING EXCEPTION Dear Mr. Crandall' Union Oil Company of California (Unocal), as Operator of the Trading Bay Unit (TBU), requests your approval to drill TBU M-16, ADL 18730, from the Steelhead Platform and further requests Administrative Approval for a well spacing exception to Rule 1, pursuant to Rule 3, Conservation Order No. 228. Additionally, in triplicate, is our application for Permit to Drill M-16 (form 10-401) pursuant to 20 AAC 25.005 and our check No. in the amount of $100.00 as required under 20 AAC 25.005 (c) (1). TBU M-16: The specific location, interval, and depth are as follows: Surface Location: 1,041' FNL, 463' FWL, Sec.33, T9N, R13W, SM Top Productive Interval: 701' FNL, 564' FWL, Sec 33, T9N, 13W, SM ~ 1,600' TVD Total Depth: 760' FSL, 1,371' FWL, Sec 28, T9N, R13W, SM ~ 2,650' TVD If you require additional information, please contact the undersigned at (907) 263-7882 or Neal Macgee, Drilling Department at (907) 263-7671. Enclosures UNION OIL COMPANY CALIFORNIA, d.b.a. UNOCal, Sincerely, Rick D.'Cross - / Sr. Landman ORIGINAL VERIFICATION OF APPLICATION FOR SPACING EXCEPTION McARTHUR RIVER, COOK INLET, ALASKA STATE OF ALASKA ADL #18730 STEELHEAD PLATFORM I, RICK D. CROSS, Sr. Landman, Union Oil Company of California, do hereby verify the following: I am acquainted with the application submitted for the drilling of the McArthur River Field, Steelhead Platform TBU M-16 Well. I have reviewed the application submitted for the exception to Rule 1, Conservation Order No. 228 and all facts therein are tree. I have reviewed the plat attached to said application, and it correctly portrays pertinent and required data. DATED at Anchorage, Alaska this 12th day of August, 1997. Sr. Landman STATE OF ALASKA ) )ss THIRI) 3UDICIAL DISTRICT ) ORIGINAL SUBSCRIBED TO AND SWORN before me this 12th day of August, 1997. NOTARY PU~ILIC IN AND FOR THE STATE OF ALASKA ~ Cx>mm~u~lon fixpir~ I:)~member 8, 1998 My Commission expires: Unocal Corporation 909 W. 9th Avenue Anchorage, AK 99501 907-263-7660 UNOCAL Dale Haines Ddlling Manager Wednesday, July 30, 1997 Mr. David Johnston Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Ak 99501-3192 Dear Mr. Johnston: Enclosed, please find the application for the Permit to Drill (Form 10-401) for the Steelhead Platform Well M-16. The intent of this well is to provide a high structural location in the Shallow Zone (SZ) Grayling Gas Sands to maximize gas recovery. UNOCAL plans to spud this well approximately 10 September 1997. The surface and intermediate casing program planned for this well is similar to the previous well (M-9) drilled in August of last year well, however is reduced in size as compared to the other gas wells drilled from Steelhead. The proposed casing setting depths for M-16 are per the regulations in particular Conservation Order 228 as ammended. Unocal will employ the existing diverter and BOP system presently on board Steelhead. For well control purposes, a fracture gradient of .8 psi/ft has been used at both the 13- 3/8" and 9-5/8" shoe depths. UNOCAI_'S recent drilling experience in the Cook Inlet has demonstrated true shallow fracture gradients ranging from 0.75 - 0.94 psi/ft (see Leak Off Test Data). For the kick conditions analyzed, the maximum bottom hole pressure remains well below the anticipated fracture pressure. UNOCAL plans to complete M-16 as a flowing gas well. Due to the shallow depth of the targeted reservoirs, sand control using screens and gravel packs will be employed to complete the well. The 7" liner will be tied back to surface giving a monobore completion. The tie back will include a 7" WL retrievable SSSV. Please contact the undersigned with any questions regarding this application. Sincerely, Dale Haines Drilling Manager Steelhead Platform Well # M- 16 Trading Bay Unit July 30, 1997 Hole Section 1 Depth Interval: 0'-850' 17-1/2" hole size 13-3/8" casing to 850' Mud weight: Shoe depth (13-3/8"): Est. fracture gradient of 13-3/8" shoe: Depth of next hole section (12-1/4"): BHP gradient: Gas gradient (assume worst case): 9.4 ppg=0.49 psi/f~ 850' MD/850' TVD 0.80 psi/ft 1500' MD/1456' TVD 0.44 psi/ft ,~- 0.0 psi/ft Gas kick situation in wellbore. Assume 3/4 mud & 1/4 gas. MSP=BHP - Hydrostatic Pressure MSP=BHP - (3/4 mud + 1/4 gas) MSP=(1436'x.44 psi/R) - ((.75(1436'x0.49 psi/fO) + (.25(1436'x0.0 psi/ft))) MSP= 104 psi Therefore, the hydrostatic pressure at the 13-3/8" shoe (Hpsh) is the greatest when the gas (kick) bubble reaches the 13-3/8" shoe, if a constant BHP is applied. A conservative estimate would be the MSP plus the hydrostatic pressure at the 13-3/8" casing depth (Hpcsg). Hpsh= MSP + Hpcsg Hpsh= 104 + (850'x0.49 psi/R) Hpsh= 520 psi This (Hpsh = 520 psi) is less than the fracture pressure at the same shoe (Fpsh) and thus adequate to handle the well kick scenario. Hpsh = 523 psi < Fpsh = 0.80 psi/ft x 850' = 680 psi. Steelhead Platform Well # M-16 Pressure Calculations Hole Section 2 Depth Interval: 850'-1500' 12-1/4" hole size 9-5/8" casing to 1500' Mud weight: Shoe depth (9-5/8"): Est. fracture gradient of 9-5/8" shoe: Depth of next hole section (8-1/2"): BHP gradient: Gas gradient (assume worst case): 9.4 ppg=0.49 psi/it 1500' MD/1436' TVD 0.80 psi/it 3623' MD/2650' TVD 0.44 psi/ff 0.0 psi/ff Gas kick situation in wellbore. Assume 3/4 mud & 1/4 gas. MSP=BHP - Hydrostatic Pressure MSP=BHP - (3/4 mud + 1/4 gas) MSP=(2650'x.44 psi/fo - ((.75(2650'x0.49 psi/it)) + (.25(2650'x0.0 psi/it))) MSP= 192psi Therefore, the hydrostatic pressure at the 9-5/8" shoe (Hpsh) is the greatest when the gas (kick) bubble reaches the 9-5/8" shoe, if a constant BHP is applied. A conservative estimate would be the MSP plus the hydrostatic pressure at the 9-5/8" casing depth (Hpcsg). Hpsh= MSP + Hpcsg Hpsh= 192 + (1436'x0.49 psi/fi) Hpsh= 895 psi This (Hpsh = 895 psi) is less than the fracture pressure at the same shoe (Fpsh) and thus adequate to handle the well kick scenario. Hpsh = 895 psi < Fpsh = 0.80 psi/it x 1436' = 1149 psi. Leak Off Test (LOT) Data Cook Inlet. Alaska Revised March 15, 19% Unocal Ener~' Resources A~aska Well # Baker Platform Csg Size Shoe Depth Frac Grad. EMW (TVD) (psv'ft.) (vpg) Ba 28 Ba 30 Ba 30 Ba 28 Ba 29 Ba 29 Ba 30 Ba 28 Ba31 Ba31 Ba31 liS-10-93 24" 802' 0.94 18.10 i G24-93 24" 803' 0.83 15.90 1G28-93 18-5/8" 2011' 0.94 18.10 1 ~-17-93 18-5/8" 2135' 0.75 14.50 12-17-94 18-5/8" 2054' 0.76 14.61 12-29-93 13-3/8" 5869' 0.85 16.33 0 i -27-94 13-3/8" 5467' 0.93 17.96 034) 1-94 13-3/8" 3509' 0.75 14.40 G34)4-96 18-5/8" 801' 0.82 15.68 ©_~ 4)9-96 13-3/8" 2076' 0.80 15.40 ©3-15-96 9-5/8" 5937' 1.02 19.70 (FIT) Grayling Platform G-40 G-40 0 ! -24-90 16" 1926' 0.96 18.46 13-3/8" 4977' 0.86 16.54 Monopod Platfom A-lrd 0-14~-91 A-8rd 07-01-89 A-20rd 03-30-90 A-20rd 04-13-90 A-28rd 1 ]-20-89 A-28rd 1~-27-89 9-5/8" 1132' 1.07 20.57 9-5/8" 3760' 1.02 19.61 13-3/8" 755' 0.95 18.20 9-5/8" 1931' 0.85 16.30 20" 240' 0.75 14.42 13-3/8" 1140' 0.97 18.65 Granite Point Platform · 11-13rd 02-14-92 51 08-07-92 51 07-28-92 51 08-25-92 50 05-27-92 50 O6-04-92 50 06-27-92 9-5/8" 9966' 0.96 18.40 13-3/8" 3803' 1.00 19.20 18-5/8" 1010' 0.87 16.80 9-5/8" 9592' 1.05 20.20 18-5/8" 982' 0.91 17.50 13-3/8" 4208' 0.84 16.20 9-5/8" 9877' 0.93 17.90 Dillon Platform 16 04-22-94 18-5/8" 1131' 16 06-16-94 13-3/8" 3640' 16 07-134-94 9-5/8" 9469' 17 04-27-94 18-5/8" 1142' 17 054) 1-94 13-3/8" 3560' 17 05- 9-5/8" 9213' 18 07-26-94 18-5/8" 1132' 18 084)1-94 13-3/8" 3988' 1.12 21.72 0.82 15.80 NA 14.2 (FIT) 1.01 19.47 0.83 15.90 NA 16.5 (FIT) 1.02 19.63 0.80 15.3 Leak Off Test (LOT) Dam Page 2 Anna Platform 11 rd 10-23-34 : 3-3/8" 2976' 1 lrd 11-11-~ 9-5/8" 8750' 3rd 12/10/~ ~-5/8" 7839' 50 2/8/95 : 8-5/8" 1160' 50 2/13/95 : 3-3/8" 4251 50 3/8/95 9-5/8" 9844' 51 1/29/95 : 8-5/8" 1130' 51 5/15/95 :. 3-3/8" 3796' 51 6/3/95 9-5/8" 9842' 52 2/3/95 ~ 8-5/8" 1153' 52 3/27/95 : 3-3/8" 3940' 52 4/15/95 9-5/8" 9470' 7rd2 8/25/95 ~-5/8" 4439' Notes: All fracture gradients r .eported have been corrected for air and water gaps. (FIT)-Formation Integnt2,.' Test 0.89 0.92 0.75 1.38 1.01 .86 1.36 .71 .88 1.41 .84 .91 .96 17.2 17.7 (FIT) 14.5 26.6 19.5 16.5 26.2 13.6 17.0 (FIT) 27.0 16.15 17.6 (FIT) 18.5 Filename Lotdata.doc Drilling Hazards: Lost Circulation from 483'-1500' Shallow Gas Zones from 950'-3624' STEELHEAD M-16 PRELIMINARY PROCEDURE 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 Skid rig Connect service lines, install catwalk,v-door N/U diverter and overboard lines Function test diverter from all stations Finish preparing rig floor P/U directional assembly, RIH to tag fill Function pumps and test entire circ system Gyro survey pile at 100' intervals Spud well and drill 17-1/2" hole to 850' CBU Short trip to shoe backreaming RIH POOH with BHA. R/U to run casing Run 13-3/8" casing to 850' R/U and P/T cementing lines Circulate and cement casing WOC N/D 30" diverter riser Dress wellhead and install Fermanite pac-off. N/U 16-3/4" BOP's and riser P/T BOP's M/U 12-1/4" directional assy and RIH Drill out cement to shoe P/T casing to 2000psi Drill out casing and 10' new hole Circulate well prior to LOT Perform LOT Drill 12-1/4" hole with MWD to 1500' CBU Short trip to 13-3/8" shoe CBU and POOH 33 34 35 36 37 38 39 4O 41 42 43 44 45 46 47 48 49 5O 51 52 53 54 55 56 57 58 59 60 61 62 63 64 65 66 67 68 69 70 71 72 73 74 Change over rams to 9-5/8" and test seals R/U casing gear and run 13-3/8" casing R/U cementers and P/T lines Circulate well and reciprocate casing Cement 9-5/8" casing Monitor well for flow Lift riser and install slips Run temp survey Install tubing spool Test Bop's M/U 8-1/2" directional assy and RIH P/T casing to 2500 psi Clean out cement and float collar Drill out casing and 10' new hole Circulate well Perform LOT Displace hole to polymer mud Drill 8-1/2" hole to TD at 3624' CBU Short trip to shoe backreaming CBU POOH for wireline logs Run triple combo logs from 3624-1500'. Change rams to 7" and test door seals to 2000 psi -~ R/U casing tools and run 7" liner ~o~'~ 't'.~.~,. @ I1~o~ Make up liner hanger and RIH on drill pipe Cement 7" liner Set 7" liner hanger POOH and L/D liner setting tool Change rams to 3-1/2" and P/T BOP's L/D 8-1/2" BHA POOH and P/U 6" clean out assy. RIH P/U remaining 3-1/2" DP Clean out 7" liner to L/C, run scrapper CBU and P/T to 2500 psi POOH R/U Schlumberger and run CET/CBT/GR/CCL Install liner top packer RIH with changeover assy. Circulate and displace well to 6% KCL POOH Run sump packer on wireline and set 75 76 77 78 79 8O 81 82 83 84 85 86 87 88 89 90 91 92 93 94 95 96 97 98 99 100 101 102 103 104 105 106 107 108 109 110 111 112 113 114 115 116 P/U TCP gun assy and RIH Tag sump packer and space out, set champ packer Fire TCP guns and reverse out POOH and L/D guns RIH with casing scrapper and scrape interval Circulate and filter brine POOH M/U gravel pack assy RIH with assy, drop ball and set packer Gravel pack with 20/40 carbolite POOH RIH with stinger on DP and break KOIV Run TDTY log POOH with drill pipe RIH with packer [plug and set in sump packer Place 2 sx sand on plug and POOH P/U TCP gun assy and RIH GR correlate, space out and set champ packer Fire TCP guns and reverse out POOH, L/D spent guns M/U plug catch overshot RIH with 3-1/2" DP and retreiving tool Reverse circulate debris and retrieve plug Circulate and filter brine POOH M/U gravel pack assy and RIH Gravel pack with 20/40 sand POOH to close KOIV POOH RIH with gravel pack plug and set Place 2 sx sand on top of plug and POOH Test Bop's P/U TCP guns and RIH GR correlate, space out and set champ packer Fire TCP guns and reverse out Reverse out and circulate filterd brine POOH M/U gravel pack assy and RIH Gravel pack with 20/40 sand Reverse out and test pack, close sliding sleeve and test POOH Change rams to 7" and P/T door seals 117 118 119 120 121 122 123 124 125 126 127 128 R/U casing crew and mn 7" tieback RIH and M/U 7" SSSV M/U hanger and and test control lines to 4500 psi Hang off above tie-back and circulate packer fluid Drain stack and engage landing hanger N/D BOP's and riser NAd tree with two wing valves R/U Dowell coiled tubing unit RIH with 2" nozzle to break KOIV RIH and unload well with nitrogen R/D CTU Hand well to Production M-I Drilling Fluids L.L.C. UNOCAL STEELHEAD PLATFORM WELL M-16 DEPTH INTERVAL MUD TYPE MUD ADDITIVES PO-I-ENTIAL PROBLEMS 0 - + 850' TMD 17-1/2" HOLE 13-3/8" CASING GENERIC MUD #2 M-I GEL / M-I BAR / SODA ASH / CAUSTIC SODA/LIME / NUT PLUG / KVVIK SEAL HOLE CLEANING / GRAVEL / GAS KICK / LOST CIRCULATION TREA TM E N TS/P R OCEDU RES 1, Build spud mud system with prehydrated bentonite in fresh water and filtered inlet water. Build mud weight to 8.8 ppg with Barite. 2. Lost circulation is a potential problem. An LCM pill made with nut plug mica, and Kwik-.Seal should be available if required. Drill hole. Adjust viscosity as required. K O.P. @ 5OO'. 3. Drill to + 850'. Use all solids control equipment. Raise viscosity if gravel sections are encountered. Spot LCM pill prior to running 13-3/8" casing. 4. Recycle mud for 12-1/4" interval. Mud Density Funnel Viscosity Plastic Viscosity Yield Point Gels Fluid Loss (APl) pH 8.8- 9.2 ppg 44 - 100 sec/qt 10- 15 cps 10 - 30 #/100 ft2 8- 20 No Control 8.5-9.5 NOTE: DO NOT EXCEED M.A.C. of products or use products not approved in the discharge permit. See letter requesting authorization for list of approved products and M.A.C, DM-.231 (7/2~/97bm) M1-377 $ NOTE: SEE REVERSE SIDE FOR UABILITY CLAUSE M-I Drilling Fluids L.L.C. UNOCAL STEELHEAD PLATFORM WELL M-16 DEPTH INTERVAL + 850' - +1500' 12-1/4" HOLE 9-5/8" LINER MUD TYPE GENERIC MUD #2 MUD ADDITIVES POTENTIAL PROBLEMS M-I GEL / M-I BAR / SODA ASH / POLY- PAC / SPERSENE / SODIUM BICARBONATE / CAUSTIC SODA / FLO-VIS HOLE CLEANING / TIGHT HOLE / BIT BALLLING / GUMBO CLAYS / HOLE ENLARGEMENT / GAS KICKS / COAL SLOUGHING TREATMENTS/PROCEDURES 1. Drill the 13-3/8" collar, cement and shoe. Treat this fluid as required to avoid excessive cement contamination. Maintain mud weiqht at minimum 9.2 pp,q. 2. Build additional volume as required with prehydrated bentonite in fresh water and filtered inlet water. 3. Pump viscous sweeps if required by hole conditions. 4. Control density with barite, F.I.W., and solids control equipment. Dump all sand traps as required. 5. Report drill solids analysis on mud check sheet. 7. Use Defoam-X if foaming becomes a problem. 8. Prehydrate all bentonite in fresh water. 9. Drill to T.D. If hole conditions warrant, spot a viscous pill on bottom. Spot LCM pill prior to running 9-5/8" liner. DM-231 (7/24/97bm) M1-377 s NOTE: SEE REVERSE SIDE FOR LIABILITY CLAUSE gRILLINCi FLUIDS M-I Drilling Fluids L.L.C. Mud Density Funnel Viscosity Plastic Viscosity Yield Point Gels Fluid Loss (APl) pH MBT Drilled Solids 9.2- 9.6 ppg 40 - 70 sec/qt 10- 15 cps 10 - 20 #/100 ft2 6/12/18 No Control to 8cc 8.5 - 11.0 < 30 ppb < 75 ppb NOTE: This mud program is a guideline only. Hole conditions should dictate actual mud properties. DO NOT exceed M.A.C. of products Or use products not approved in the discharge permit. See letter requesting authorization of list of approved products and M.A.C. DIVI-231 (7/24/97bm) M1-,177 S NOTE: SEE REVERSE SIDE FOR UABILITY CLAUSE STEELHEAD PLATFORM WELL # M-16 TRADING BAY UNIT PROPOSED COMPLETION COMPLETION DESCRIPTION 1) 7" 29# L-80 BTCKC Tubing f/1000' - 72' 2) HES 5.963" ID SSSV Landing Nipple F/WL Ret. Safety Valve @ +/- 500' 3) Baker SC-IR Packer ~ +/-1619'. 4) 4" 9.5# SSWW Screen & Blank Packed w/20/40 Carbolite F/2147' - 1619'. 5) Baker SC-IL Packer ~ 2147'. 6) 4" 9.5# SSWW Screen & Blank Packed w/20/40 Carbolite F/2660'-2147'. 7) Baker SC-IR Packer ~ 2660'. 8) 4" 9.5# SSWW Screen & Blank Packed w/20/40 Carbolite F/3416'-2660'. 9) Baker N-1 Bridge Plug ~ +/-3416' RKB = 160' TD @ 3624' 28" Structural Casing ~ 488' RKB (141 'BML) h. 13-3/8" 68# K-55 BTC Surface Casing ~ 850' 7" 29# L-80 BTCKC TBE f/1000 - 72' 7" Liner Top ~ +/-yw/Liner Top / \ Packer ~ _ _d~ ~ ~' 9-5/8" 47# L-80 BTC Intermediate Casing ~ 1500' 7" 29# L-80 NSCC Liner F/3622' - 1000' 0.0 -500.0 -1000.0 -1500.0 -2000.0 -2500.0 -3000.0 -3500.0 -4000.0 -4500.0 -5000.0 STEELHEAD M-16 AFE DAYS vs DEPTH Days 20 25 Creoted by sutherlo Dote plotted : 28-Jul-97 Plot Reference ;s M-16 Version Coordinates ore ;n fee[ reference sial t~A1-4. True Vertical Depths ore re(erence wellhead, UNOCAL Structure: STEELHEAO Platform Field : McArfhur River Field Well : M- 16 Location : TBU, Cook Inlet, Alaska UNOCALI WELL PROFILE DATA K~P 500.GO Be~n Turn to Target 675330 End of Build/Turn 202g.76 F.O. & Tar(~et UnOCal 17 .3623.g8 Inc O;r T~O North 0.00 5.30.00 0.00 0.0(] 0.00 5JO.O0 500.00 0.00 7.00 530.00 67~'.56 9.25 57.56 2g.20 179.5.06 626.47 57.5§ 29.20 2650.25 18oo. g2 ra~, V. Sect O.OO 0.00 0.00 O.O0 O.O0 0.00 -5.3( 5.85 4-.00 251.7( 672.72 9~,1 ~- 2016.g~- 0.00 200 0 I I i 400 t 600 800 1000 1200 1400 1600 1800 2OOO 2200 2400 2600 2800 KOP 4.00 7.50 Begin Turn to Target 10.26 15 .3/8 Casing x15'64 17.29 DLS: 4.00 deg per 100 ft 21.06 24.90 28.78 52.69 ~"~ .36.61 9 5/8 Casing ~,~ 40.55 ~x. 44.S0 % ~ 48.46 ~ ~ 52.41 ~ 7 Liner ~_ Unocal 17-Jun-97- 1 i i i i i i i i i i i i i i i i i i i 200 400 600 800 1000 1200 1400 1600 1800 2000 Vertical Section (feet) -> Azimuth 26.76 with reference 0.00 N, 0.00 E from slot #A1-4. East (feet) -> 200 400 600 800 1000 I I I I I I I I I 7 Liner TARGET Unocal 17-Jun-g7 EOC 9 5/8 Casing 13 5/8 Casing Begin Turn to Target · I 2000 t1800 ~ 1600 ~1400 t1200 !1000 I800 F 600 I 400 i I i i200 i i 2200 A I Z O Created ~y finch For: N MAGEE Date plotted : 1-Aug-g7 Plot Reference is ~-oordinotes are in feet reference slot ~A1-4.. True Vertical 0epths are reference wellhead. I, UNOCAL Field : M ~l Cook Inlet, Alaska East (feet) -> 320 300 280 260 240 22O 200 180 160 w- 140 120 ,,',1-- 0 Z 700 80 60 40 2o1 120 100 80 60 40 20 0 20 40 60 80 1 O0 1 I I I I r I I I f f I I I I t I I f I / / 2200 2100 / / / ,, / ,, ~' 1 400 2000 ,' / /' 2300 2100 6000 6100 2400 6000 2300 6300 / 1300 / / / , / / / / / / / 1 200 J 1 600 / , / / / ,' 1800, 1500 / / / / 1100j / ! / 1600 / / / ; I 1400 1000/ 120 ,/ 9OO 2800 8O0 '~ 700 1900 4OO 3400 1900 1800 450( 52OO )0 ¢000 200( 1200 UNOCAL ) 1200 1100 9OO 140 160 180 200 2OOO 0 5400 1600 I I I I I 120 1 O0 80 60 4C 6400 1 400 1200 320 3OO 2100 i900 2100 28O 26O 240 220 2OO 180 1500 24O0 1700 1900 000 0 160 A I Z 140 0 ! 20 ,--I- 1 O0 80 60 20 O0 3400 1100 1800 000 20 90C 1700 1100 ~00 [ 6040 .-~, . I I ! I I I ' I I I I I I 0 20 40 60 80 100 120 140 160 180 200 East (feet) -> Created by finch For: N MAGEE Date plotted : 1-^ug-§7 Plot Reference is M-16 Version ~2, Coordlnotes ore in feet reference slot ~A1-4., True Verticol Depths are reference wellheod. 620 6OO 58O 560 54O 520 500 48O ¢60 440 420 400 38O 36O 540 320 300 280 260 240 f' UNOCAL ruciureSTEELHEADPoffor Well : bi-16 / UNOCAL ) 62O 6OO 2600 250O 2400 2300 2200 27OO / /' 1500 / / / / / 2200 1600;/ / / / / / / / / / / / ~_600 / / / / I 1700 ,'/ / / / ,, / ,, / / / / / 580 // t 2000 - 480 J 460 A ~ I Z 440 0 5500 ,[- 420 400 1800 4~600 ! 360 ! t ~- 340 i 320 ! 6700 i 280 t ,L 260 240 200 220 24-0 260 2100. 5600 / I I I / ~ 400 2000 /' 2300 / / 2100 2000 i i i i t ,4 ~'o o ~'o ' ;o ~o ~o ,oo ,2o E(~sf (feel) -> 160 180 E~sf (feel) -> 40 20 0 20 40 60 80 1 O0 120 140 160 180 200 220 240 260 I I I I I I I I I I I t I I I I I I I I I I I } t ~ C~eote~ ~y ~inch For: N MAGEE {)ate plotted : l-Aug-g7 Plot Reference is M-16 Version ~2. Coordinotes ore in feet reference slot ~A1-4-. True Verticol Depths ore reference wellheod. I UNOCAL :ZTi;';'2 ;L Field : M I Cook Inlef, Alas 9OO 88O 84O 82O 8OO UNOC&L ) 780 East (feet) -> 140 160 180 200 220 240 260 280 300 320 340 360 380 400 420 440 460 6300 ," 2900 I 900 ,," 880 ,,' 7900 ," ,' 860 ,' ,, /' / / ~- 840 / / / 82O 8000 3400 A 740 I 720 7OO 680 760 810C 660 640 62O 6O0 580 560 4900 3300 1900 / / / / / / O0 / / / / · / · / 2400/ / ,,,t 5200 5000 5100 540 51 O0 2500 000 8500 6100 2400 i i 140 160 180 200 220 240 260 280 300 320 340 360 Easf (feel) -> 3800 2700 6400 6200 i 380 800 520 1 , Z 720 0 700 78O 760 740 A I -660 ? 6300 .! 640 '-620 I 5000 k 600 !- .,I- 520 400 420 440 460 Jcreated by finch For: N MAGEE Date plotted : 1-Aug-g7 Plat Reference is M-16 Version '~aordinotes ore in feet reference slot ~A1-4-. True Vertical Depths are reference wellhead. 520 540 360 I I I I 1220 12oo 1180 1160 1140 1120 ! 100 1080 A lO6O I 1040 1020 -I.-- 0 2800 1000 98O 960 940 920 900 880 860 840 UNOCAL r u ¢' u r e : cSATr fE~Y ERAi~. ~ I~f~;rm Location TW~; Field : M I Cook Inlet, Alosk UNOCAL ) East (feet) -> 400 420 440 460 480 500 520 540 560 580 600 620 640 I I f I i I I I I ? I I I I I I I I I [ I I 1 ,100 k 1220 8800 3000 8900 9000 200 22OO 66O0 ~500 290O 5700 3600 5400 6500 9400 9500 / ............. _9.600 / ............ 9700 / / / ,, 5200 ; / / 6700 2100,/ ,... / " 3100 / / / I I I I / / / I / ;/2000 ,.' / / / , · / 680O 5400 5500 / ,, i 58O 1200 1180 1160 t1140 1120 1100 !080 1040 1020 1000 t980 I I i I ~ I i I I I 340 360 380 400 420 440 460 480 500 520 540 560 East (feet) -> F88O 880 f 840 600 620 640 I 980 940 920 gO0 Creoted 0¥ finch For: N MAGEE Dote plotted : 1-Aug-97 Plot Eeference is M-16 Version Coordinotes ore ~n feet reference slot ~A1-4. True Verticol Depths ore reference wellheod. UNOCALe East (feet) -> 560 400 440 480 520 560 ]0 640 680 720 ,760 800 840 880 920 960 1000 1840 I I ~ I I I ~ i ~ ~ I I ~ ~ ~ ~ ~ ~ I i 1840 1800 1760 1720 1680 1640 1600 1560 1520 I 1480 w-- 1440 -,I--- ~ 1400 o Z 1560 1520 1280 1240 1200 1160 1120 6600 ~800 3700 6800 4800 4900 4400 7500 6900 7200 7100 3600 7400 1080 7500 / 100 ,, // / / / / ,/2600 5000 ' 4800 70OO ~-900 tO00 ,' / / / / / /, / , /, /'2500 i900 ,, / ,, / .,., / / /, /. /, / 7 3800 ,,' 1800 1760 1720 1680 fl 640 k 1600 1560 1520 1040 , 360 3300 3200 4900 89OO 9100 4300 4200 6700 6600 6900 5800 5OOO 3600 / / /2400 370£ ,' /, /- / // / i1 · / /2300 3500 ," / , 5200 3400 60( 2200 5900 9500 ·' ............ 9700 ........... ~ 99( 5200 lOO 5700 7200 72oo 7300 54OO 1480 I o 1 ~40 1400 2500 .-..- 1360 I L 1520 7600[ i 1280 ~!240 k 1200 55oo k I 1160 70O 2300 120 ...... 10500/ ~1080 L I : ~ ~ ~ , , , , ~ ~ ~ ~ I 1040 440 480 520 560 600 640 680 720 760 800 840 880 920 960 1000 East (feet) -> Created by Sutherlond For: N. ~GEE Dote plotted : 1-Aug-g7 Plat Reference is M-16 Version ~2. Coord notes ore in feet reference slot ~A1-4.. JTrue Vertical Depths ore reference wellhead. Structure : STEELHEAD Platform UNOCAL Well : M-16 Field : McArthur River Field Location : TBU, Cook Inlet, Alaska WELL PROFILE DATA UNOCAL ) T~ an 0.O0 0.00 I~e~n Turn t~ To',get 675.0~ 7.~ ~ oF ~um 2029.7657.56 ~TD. · Ta~ U~ 17 3623.~ 57.56 o,-r ~0 North 350.00 O.00 a.oo 330.00 500.00 o.cx3 33~.00 674.56 g.25 29.201795.06626.47 29.20265o.25 £a~ V. Sect [3eg./I O~3 0.~3 0.0(30.0(3 O.(X3 0.00 0.03 -5.3~ 5.55 4.~~ ~1.7+ 672.~ ~.~ g~.l~2a16.g+ 0.~ 32O 330 540 350 TRUE NORTH 0 10 2O 5O 4O 310 5O 300 6O 29O 7O 28O 3O 8O 270 9O 26O !00 250 240 25O 1300 ! i0 1500 120 220 21 ~ 200 Normal Plane Travelling Cylinder - Feet 140 1300 ~ 1 0 160 ~ 180 70 All depths shown are Measured depths on Reference Well UNOCAL STEELHEAD Platform M-16 slot #A1-4 McArthur River Field TBU, Cook Inlet, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : M-16 Version #2 Our ref : prop2288 License : Date printed : 4-Aug-97 Date created : 17-Jun-97 Last revised : 28-Jul-97 Field is centred on n60 50 4.803,w151 36 18.018 Structure is centred on n60 50 4.803,w151 36 18.018 Slot location is n60 49 54.550,w151 36 8.678 Slot Grid coordinates are N 2499461.839, E 214078.085 Slot local coordinates are 1041.23 S 462.99 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North UNOCAL S T~-ELHEAD Platform, M- 16 McArthur River Field,TBU, Cook Inlet, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 00 R D I N A T E S 0.00 0.00 330.00 0.00 0.00 N 0.00 500.00 0.00 330.00 500.00 0.00 N 0.00 600.00 4.00 330.00 599.92 3.02 N 1.74 675.00 7.00 330.00 674.56 9.25 N 5.34 700.00 7.50 336.86 699.37 12.07 N 6.?4 800.00 10.26 355.94 798.18 26.96 N 9.94 900.00 13.64 6.36 896.01 47.57 N 9.26 1000.00 17.29 12.58 992.38 73.81 N 4.72 1100.00 21.06 16.66 1086.82 105.54 N 3.67 1200.00 24.90 19.54 1178.87 142.60 N 15.87 1300.00 28.78 21.69 1268.08 184.83 N 31.81 1400.00 32.69 23.36 1354.02 232.01 N 51.42 1500.00 36.61 24.71 1436.26 283.91 N 74.61 1600.00 40.55 25.84 1514.42 340.28 N 101.25 1700.00 44.50 26.79 1588.10 400.85 N 131.23 1800.00 48.46 27.62 1656.95 465.31 N 164.39 1900.00 52.41 28.36 1720.63 533.37 N 200.58 2000.00 56.38 29.02 1778.84 604.67 N 239.61 2029.76 57.56 29.20 1795.06 626.47 N 251.74 2500.00 57.56 29.20 2047.31 972.89 N 445.36 3000.00 57.56 29.20 2315.53 1341.24 N 651.23 3500.00 57.56 29.20 2583.74 1709.59 N 857.09 3623.98 57.56 29.20 2650.25 1800.92 N 908.14 PROPOSAL LISTING Page 1 Your ref : M-16 Version #2 Last revised : 28-Jul-97 Dogleg Vert Deg/100ft Sect E 0.00 E 0.00 W 4.00 W 4.00 W 4.00 0.00 0.00 KOP 1.91 5.85 Begin Turn to Target 7.74 4.00 19.60 4.00 38.31 4.00 63.78 4.00 95.89 4.00 134.48 4.00 179.36 4.00 230.31 4.00 287.10 4.00 349.43 4.00 417.00 4.00 489.50 4.00 566.55 4.00 647.80 4.00 672.72 0.00 1069.22 E 0.00 1490.81 E 0.00 1912.40 E 0.00 2016.94 E0C Unocal 17-Jun-97 All data is in feet unless otherwise stated. Coordinates from slot #A1-4 and TVD from wellhead (160.25 Ft above mean sea level). Bottom hole distance is 2016.94 on azimmath 26.76 degrees from wellhead. Total Dogleg for wellpath is 61.19 degrees. Vertical section is from wellhead on azimuth 26.76 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL STEELWRAD Platform, M-16 McArthur River Field, TBU, Cook Inlet, Alaska PROPOSAL LISTING Page 2 Your ref = M-16 Version #2 Last revised = 28-Jul-97 Comments in wellpath mmmmmmmmmmmmmmmmmmmm KD TVD Rectangular Coords. Comment 500.00 500.00 0.00 N 0.00 E KOP 675.00 674.56 9.25 N 5.34 W Begin Turn to Target 2029.76 1795.06 626.47 N 251.74 E EOC 3623.98 2650.25 1800.92 N 908.14 E Unocal 17-Jun-97 Casing positions in string 'A' Top KD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 850.00 847.25 36.56N 10.09W 13 3/8" Casing 0.00 0.00 0.00N 0.00E 1500.00 1436.26 283.91N 74.61E 9 5/8" Casing 0.00 0.00 0.00N 0.00E 3623.00 2649.72 1800.20N 907.74E 7" Liner Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised Unocal 17-Jun-97 215030.000,2501240.000,0.0000 2650.25 1800.92N 908.14E 17-Jun-97 UNOCAL STEELHEAD Platform,M-16 McArthur River Field, TBU, Cook Inlet, Alaska Measured Inclin. Azimuth True Vert R E C T A M G U ~ A R Depth Degrees Degrees Depth C O 0 R D I N A T E S 0.00 0.00 330.00 0.00 1041.23 S 462.99 500.00 0.00 330.00 500.00 1041.23 S 462.99 600.00 4.00 330.00 599.92 1038.21 S 461.25 675.00 7.00 330.00 674.56 1031.98 S 457.65 700.00 7.50 336.86 699.37 1029.16 S 456.25 800.00 10.26 355.94 798.18 1014.27 S 453.05 900.00 13.64 6.36 896.01 993.66 S 453.73 1000.00 17.29 12.58 992.38 967.42 S 458.27 1100.00 21.06 16.66 1086.82 935.69 S 466.66 1200.00 24.90 19.54 1178.87 898.63 S 478.86 1300.00 28.78 21.69 1268.08 856.40 S 494.80 1400.00 32.69 23.36 1354.02 809.22 S 514.41 1500.00 36.61 24.71 1436.26 757.32 S 537.60 1600.00 40.55 25.84 1514.42 700.95 S 564.24 1700.00 44.50 26.79 1588.10 640.38 S 594.22 1800.00 48.46 27.62 1656.95 575.92 S 627.38 1900.00 52.41 28.36 1720.63 507.86 S 663.57 2000.00 56.38 29.02 1778.84 436.56 S 702.60 2029.76 57.56 29.20 1795.06 414.76 S 714.73 2500.00 57.56 29.20 2047.31 68.34 S 908.35 3000.00 57.56 29.20 2315.53 300.01 N 1114.22 3500.00 57.56 29.20 2583.74 668.36 N 1320.08 3623.98 57.56 29.20 2650.25 759.69 N 1371.13 PROPOSAL LISTING Page 1 Your ref : M-16 Version #2 Last revised : 28-Jul-97 Dogleg Vert Deg/100ft Sect E 0.00 0.00 E 0.00 0.00 KOP E 4.00 1.91 E 4.00 5.85 Begin Turn to Target E 4.00 7.74 E 4.00 19.60 E 4.00 38.31 E 4.00 63.78 E 4.00 95.89 E 4.00 134.48 E 4.00 179.36 E 4.00 230.31 E 4.00 287.10 E 4.00 349.43 E 4.00 417.00 E 4.00 489.50 E 4.00 566.55 E 4.00 647.80 E 4.00 672.72 E 0.00 1069.22 E 0.00 1490.81 E 0.00 1912.40 E 0.00 2016.94 E0C Unocal 17-J~n-97 All data is in feet unless otherwise stated. Coordinates from NW Corner of Sec. 33, TgN, R13W SM and TVD from wellhead (160.25 Ft above mean sea level). Bottom hole distance is 2016.94 on azimuth 26.76 degrees from wellhead. Total Dogleg for wellpath is 61.19 degrees. Vertical section is from wellhead on azimuth 26.76 degrees. Calculation uses the m/nimum curvature method. Presented by Baker Hughes INTEQ UNOCAL S TEEI~HEAD Plat form,M- 16 McArthur River Field,TBU, Cook Inlet, Alaska PROPOSAh hISTING Page 2 Your ref : M-16 Version #2 Last revised : 28-Jul-97 Comments in we11path MD TVD Rectangular Coords. Comment 500.00 500.00 1041.23 S 462.99 E KOP 675.00 674.56 1031.98 S 457.65 E Begin Turn to Target 2029.76 1795.06 414.76 S 714.73 E EOC 3623.98 2650.25 759.69 N 1371.13 E Unocal 17-Jun-97 Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 1041.23S 462.99E 850.00 847.25 1004.67S 452.90E 13 3/8" Casing 0.00 0.00 1041.23S 462.99E 1500.00 1436.26 757.32S 537.60E 9 5/8" Casing 0.00 0.00 1041.23S 462.99E 3623.00 2649.72 758.97N 1370.73E 7" Liner Targets associated with this we11path ===================================== Target n~me Geographic Location T.V.D. Rectangular Coordinates Revised Unocal 17-Jun~97 215030.000,2501240.000,0.0000 2650.25 759.69N 1371.13E 17-Jun-97 UNOCAl. S TEE ~=~EAD Platform, M- 16 McArthur River Field,TBU, Cook Inlet, Alaska Measured Inclin Azimuth True Vert Depth Degrees Degrees Depth 0.00 0.00 330.00 0.00 500.00 0.00 330.00 500.00 600.00 4.00 330.00 599.92 675.00 7.00 330.00 674.56 700.00 7.50 336.86 699.37 RECTANGULAR COORDINATES 0.00N 0.00E 0.00N 0.00E 3.02N 1.74W 9.25N 5.34W 12.07N 6.74W 800.00 10.26 355.94 798.18 900.00 13.64 6.36 896.01 1000.00 17.29 12.58 992.38 1100.00 21.06 16.66 1086.82 1200.00 24.90 19.54 1178.87 26.96N 9.94W 47.57N 9.26W 73.81N 4.72W 105.54N 3.67E 142.60N 15.87E 1300.00 28.78 21.69 1268.08 1400.00 32.69 23.36 1354.02 1500.00 36.61 24.71 1436.26 1600.00 40.55 25.84 1514.42 1700.00 44.50 26.79 1588.10 184.83N 31.81E 232.01N 51.42E 283.91N 74.61E 340.28N 101.25E 400.85N 131.23E 1800.00 48.46 27.62 1656.95 1900.00 52.41 28.36 1720.63 2000.00 56.38 29.02 1778.84 2029.76 57.56 29.20 1795.06 2500.00 57.56 29.20 2047.31 3000.00 57.56 29.20 2315.53 3500.00 57.56 29.20 2583.74 3623.98 57.56 29.20 2650.25 465.31N 164.39E 533.37N 200.58E 604.67N 239.61E 626.47N 251.74E 972.89N 445.36E 1341.24N 651.23E 1709.59N 857.09E 1800.92N 908.14E PROPOSAL LISTING Page 1 Your ref : M-16 Version #2 Last revised : 28-Jul-97 Dogleg Vert G R i D C O 0 R D S Deg/100ft Sect Easting Northing 0.00 0.00 214078.08 2499461.84 0.00 0.00 214078.08 2499461.84 4.00 1.91 214076.41 2499464.90 4.00 5.85 214072.97 2499471.21 4.00 7.74 214071.64 2499474.07 4.00 19.60 214068.81 2499489.03 4.00 38.31 214069.99 2499509.62 4.00 63.78 214075.17 2499535.74 4.00 95.89 214084.34 2499567.25 4.00 134.48 214097.44 2499604.01 4.00 179.36 214114.41 2499645.84 4.00 230.31 214135.17 2499692.52 4.00 287.10 214159.62 2499743.84 4.00 349.43 214187.63 2499799.54 4.00 417.00 214219.08 2499859.35 4.00 489.50 214253.81 2499922.99 4.00 566.55 214291.65 2499990.14 4.00 647.80 214332.41 2500060.47 4.00 672.72 214345.07 2500081.96 0.00 1069.22 214547.10 2500423.54 0.00 1490.81 214761.92 2500786.74 0.00 1912.40 214976.73 2501149.94 0.00 2016.94 215030.00 2501240.00 All data in feet unless otherwise stated. Calculation uses m~nimum curvature method. Coordinates from slot #A1-4 and TVD from wellhead (160.25 Ft above mean sea level). Bottom hole distance is 2016.94 on azimuth 26.76 degrees from wellhead. Total Dogleg for wellpath is 61.19 degrees. Vertical section is from wellhead on azimuth 26.76 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ UNOCAL STEEI,H]~AD Platform, M- 16 McArthur River Field,TBU, Cook Inlet, Alaska PROPOSAL LISTING Page 2 Your ref : M-16 Version #2 Last revised : 28-Jul-97 Comments in we11path MD TVD Rectangular Coords. Comment 500.00 500.00 0.00N 0.00E KOP 675.00 674.56 9.25N 5.34W Begin Turn tO Target 2029.76 1795.06 626.47N 251.74E EOC 3623.98 2650.25 1800.92N 908.14E U~ocal 17-Jun-97 Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 850.00 847.25 36.56N 10.09W 13 3/8" Casing 0.00 0.00 0.00N 0.00E 1500.00 1436.26 283.91N 74.61E 9 5/8" Casing 0.00 0.00 0.00N 0.00E 3623.00 2649.72 1800.20N 907.74E 7" Liner Targets associated with this we11path Target n~me Geographic Location T.V.D. Rectangular Coordinates Revised Unocal 17-Jun-9? 215030.000,25012{0.000,0.0000 2650.25 1800.92N 908.14E 17-Jun-9? UNOCAL STEEL. KE~tD Platform M-16 slot #A1~4 McArthur River Field TBU, Cook Inlet, Alaska 3-D MINIMUM DISTANCE CLEARANCE by Baker Hughes INTEQ REPORT Your ref = M-16 Version Our ref = prop2288 License = Date printed = 22-Jul-97 Date created = 17-Jun-97 Last revised = 22-Jul-97 Field is centred on n60 50 4.803,w151 36 18.018 Structure is centred on n60 50 4.803,w151 36 18.018 Slot location is n60 49 54.550,w151 36 8.678 Slot Grid coordinates are N 2499461.839, E 214078.085 Slot local coordinates are 1041.23 S 462.99 E Projection ty~e= alaska - Zone 4, Spheroid= Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 ~eet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object we11path PMSS <1535-4500~>,,M-9,STEELHEAD Platform GSS <O-1421~>,,*M-4*,STEELHEAD Platform M-32 Version #5,,M-32,STEELdg~AD Platform PMSS <8988 - 12583'>,,M32St#2,STEELHEAD Platfo PMSS <12281 - 12660'),,M32St#3,STEELHEAD Platf PMSS <1386 - 9833~>,,M-32,STEELHEAD Platform PMSS <9365 - 10588~>,,M32ST#1,STEELHEAD Platfo PG~S <O-927~>,,Bl-10,STEELHEAD Platform M-31 Version #12,,M-31,STEELHEAD Platform PMSS <10741-12018~>,,M-31St#1,STEELHEAD Platfo PMSS <10247-10355~>,,M-31,STEELHEAD Platform PGMS <0-7250~>,,M-3,STEELHEAD Platform M-7 Version #7,,M-7,STEE~HEAD Platform PGMS <O-6440~>,,M-7,STEELHEAD Platform PGMS <O-7419~),,M-2,STEELHEAD Platform PGMS <O-7250'),,M~1St#1,STEELHEAD Platform PMSS <6595-6988'>,,M-1,STEELHEAD Platform PGMS <O~5600~>,,M-5,STEELHEAD Platform PGMS <500-928~>,,B1-2,STEELHEAD Platform PGMS <O-7434~>,,M-13,STEELHEAD Platform PGMS <O~785~>,,B1-6,STEELHEAD Platform PGMS <O~857~>,,B1-8,STEELHEAD Platform M~30 Version #11,,M-30,STEELHEAD Platform PGMS <O-l%575~>,,M-30,STEELHEAD Platform MSS <0-735~>,,0B #2,STEELHEAD Platform Closest approach with 3-D Minimum Distance method Last revised Distance M.D. 26-Aug-96 145.0 160.0 29-Jul-96 142.7 460.0 29-Jul-96 73.9 1008.0 29-Jul-96 74.1 1008.0 29-Jul-96 74.1 1008.0 29-Jul-96 74.1 1008.0 29-Jul-96 74.1 1008.0 29-Jul-96 77.0 925.0 29-Jul-96 47.7 1050.0 29-Jul-96 48.5 1050.0 29-Jul-96 48.5 1050.0 29-Jul-96 137'.9 525.0 29~Jul-96 134.4 480.0 29~Jul-96 133.1 500.0 29~Jul-96 139.7 0.0 29~Jul-96 137.1 360.0 29~Jul-96 137.1 360.0 29-Jul-96 134.3 525.0 29~Jul-96 95.0 950.0 29-Jul-96 12.1 20.0 29-Jul-96 74.6 800.0 29-Jul-96 61.3 875.0 29-Jul-96 %8.0 1100.0 29-Jul-96 48.0 1100.0 29-Ju1~96 682.9 80.0 Diverging from M.D. 360.0 460.0 1008.0 1008.0 1008.0 1008.0 1008.0 925.0 1050.0 1050.0 1050.0 525.0 3620.0 360.0 260.0 950.0 .._ 1100.0 1100.0 80.0 PMSS <808-1165'>,,RLF #2,STE1 %D Platform PGMS <0-2310'>,,RLF #1,STEELYarD Platform MSS <1363-1859'>,,RLF #2,STEELH]~AD Platform M-19 Version #6,,M-19,STEELWR~D Platform PGM$ <0-5185'>,,M-19,STEE~HEAD Platform PMSS <1006-1449'>,,M-15,STEEL~EAD Platform PMSS <1006-7952'>,,M-15 St, STEEI~,%D Platform PGMS <2700-9101'>,,M-14,STEELHEAD Platform D-48 Replacement Vets. #1,,M-14,STEEL/{EAD Plat MSS <1103-2265'>,,M-26,STEELHEAD Platform PGMS <12486~15276'>,,M-27,STEELHEAD Platform GSS <975-2660'>,,M-29,STEELHEAD Platform PGMS <0-10938'>,,M-29,STEELHEAD Platform PGMS <3700-11700'>,,M-25,STEET.W~D Platform PGMS <0-12930'>,,M-28,STEELR~D Platform Slot A2-3 Version #1,,M-28,STEELHEAD Platform 29-Jul-96 29-Jk~1-96 29-Jul-96 29-J~1-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 623.1 394.2 1750.0 200.1 1550.0 272.1 1325.0 9.0 0.0 13.8 0.0 13.8 0.0 7.8 20.0 103.3 500.0 63.1 1075.0 91.5 975.0 57.1 975.0 57. i 975.0 67.6 1025.0 90 · 0 1025.0 98.2 500.0 1150.0 1750.0 1550.0 1325.0 0.0 0.0 0.0 20.0 500.0 1075.0 975.0 975.0 975.0 1025.0 1025.0 500.0 G-25 K-; -25 M-3 + + G-6 G- 344~ -,o +~ ~ D-1D-~28'~-42 G-3t -30 33 G-14ARD + McArthur River Field Proposed Iocetlon M-16 8/97 PIC. N VIE'W RI~ ~UI~TRUCTUP~ SUBSTRUCTURE SI~CTION Vl~ 16' DIVIIRTgR LINg 16" ~MOTIg 0PF, RATgI) VAL~ CONDUCTOR 16' RRMO~ 0PI~?.AT]~D VAL~ S~'~.I~.~ PI~TFORM DI~RTt~R SYS~M 8/97 lO,O00psi DOUBLEGATE CHECK VALVE ~ G AT~ VALV~ FLOW HYDRIIJ, ~ a/4" ~ooopsi TYPE GK ANNUL~ 10,000psi SING~GATE I 16 3/4' 5000psi RISER I BALL~Li~AD VALVE STEELHEAD PLATFORM PREVENTER SCHEMATIC 8/9? CENTRIFUGE - tfllD - DESANDER DF, SANDER- ~*JD - CENTRIFUGE PIT CLEANER PIT PIT CLEANER PIT 1oo m3~s c~P. PIT RESERVE PIT PIT loo ~mLS CAP. /.~ lis HBL9 CAP.~ ~ 118 BBL9 CAP. O. Og BBLS~ 0.09 BBI, S/IN 105 ~ CAP. Ltl BliP/IN ! , LI! BIff, S/IN 106 BBLS CAP. ' LO~ imLs/mOi 50~ m~LS cAP./0 to~ m~ts/m o o _~ ~.,, ,~/,, ~ o ~ o 82 lmLS CAP. 8O BBLS CAP. ~:, 0 0 0 0 RETURN DITCH ~.~ EQUA~JZER AGITATOR 0 IdUD GUN N STEE HEAD PLA'I'I~)RII FOP-.J'NQUIRIES CONTACT LOCATION WHERE INVOICES WERr- e'JBMITTED . VENDr~q N0. CHECK. N ' .... 1~-~ 1548 08-11-97 2002327 D. ATE ,,, INVOICe'CREDIT,ME, MO NO. ~ voUCHER No: ~co~ : 05-AUG-9' DRILLPE~ITM16 0897300045;~ 100.0) 100.00 DETACH STUB · WELL PERMIT CHECKLIST COMPANY¢'/',~,'o~c,// WELL NAME 7"z~C---f' ,/~'/~ PROGRAM: exp [] dev/,~'redrll [] serv [] wellbore seg U ann. disposal para re_qD FIELD&POOL ~'"~..2-O ,.~'_~""4::::~ INIT CLASS Z¢?~,'/,../ /-7~r,.¢ GEOL AREA ~' ~_.-c~ UNIT# /2_.O-2 4:~ ON/OFFSHORE ¢,~)c/'~-~ ADMINISTRATION ,~ DATE / , 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. ENGINEERING APPR DATE GEOLOGY Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Y N - Well located proper distance from drilling unit boundary .... Y N Well located proper distance from other wells .......... Y N - Sufficient acreage available in drilling unit ............ Y N If deviated, is wellbore plat included ............... Y N - Operator only affected party ................... N _ Operator has appropriate bond in force ............. N Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... ,~Yf~ Can permit be approved before 15-day wait ........... C. N /// , / REMARKS 14. Conductor string provided ................... N 15. Surface casing protects all known USDWs N 16. CMT vol adequate to circulate on conductor & surf csg ..... /~ ~ ;'~" ' "- ~'-' %-~ - _ '% .~ '--7~7 ~'~"~"'/""-' --/ tl * ~J//r- 17. CMTvol adequate to tie-in long string to surf cs.g ........ N ,lA.L/ .... ~ /,, _, ,,.,_~,.--.,..~,~ ~. ~ __ '., /~ ...... ~ t 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... -~Y N ~g,~-' 22. N 23. N 24. N 25. N 26. N 27. N .r/~ 28. 29. Adequate wellbore separation proposed ............. If diverter required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation ................ BOPE press rating appropriate; test to ~~ psig. Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. Y 30. Permitcan be issued w/o hydrogen sulfide measures ..... Y~, N~.,//~X, v ,i~ 31. Data presented on potential overpressure zones ' 32. Seismic analysis of shallow gas zones ............. /Y/' N 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone for we.ekly progress repqrts ..... .~./Y N Y N lexptora~oty ontyj GEOLOGY: ENGINEERING: COMMISSION: B EW~/:~? DWJ JDH ? ~'~./'?..~ RNC~ V HOW/lit - A:\FORMS\cheklist rev 07~97