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178-057
STATE OF ALASKA ~~ ~ ~ 1/ AL~ OIL AND GAS CONSERVATION COM• ION WELL COMPLETION OR RECOMPLETION REPORT AN[~~C~(~ 2008 1 a. Well Status: Oil ^ Gas ^ Plugged Q Abandoned Q Suspended ^ 20nnC 25.105 20nnC 25.,,0 GINJ^ WINJ^ WDSPL^ WAG^ Other^ No. of Completions: 1 b. WQ I r~+I ~r. ~+ P~Ii~~~,~~ ' & Gas Cons. C r Development L~J xploratory~ Service ^ Str~{~i7iT~Test^ 2. Operator Name: Union Oil Company of California 5. Date Comp., Susp., or Aband.: 7/25/2008 12. Permit to Drill Number: , 178-057 ~ ~ 3 Q~- (~'~"" 3. Address: PO Box 196247, Anchorage, AK 99519 6. Date Spudded: 8/12/1978 13. API Number: 50-733-20156-01-00 4a. Location of Well (Governmental Section): Surface: 735!'i~& 140~of SE Cr. Sec 17, T9N, R13W SM 7. Date TD Reached: 10/28/1978 14. Well Name and Number: King Salmon K-12RD - Top of Productive HlTzon: ~ 532'N & 392' W of SE Cr. Sec 18, T9N, R13W SM 8. KB (ft above MSL): 33.8' Ground (ft MSL): 15. Field/Pool(s): McArthur River Field Total Depth: 607'N & 780' W of SE Cr. Sec 18, T9N, R13W SM 9. Plug Back Depth(MD+TVD): 10,886'MD (9,099TVD) Hemlock Oil Pool , Middle Kenai G Oil Pool ~ 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 213758 y- 2511809.1 Zone- 4 10. Total Depth (MD + TVD): , 11,775'MD (9,850'TVD) 16. Property Designation: ADL0018777 (King Salmon Platform] TPI: x- 208345. y- 2511950 Zone- 4 Total Depth: x- 207855 y- 2512083 Zone- 4 11. SSSV Depth (MD + TVD): N/A 17. Land Use Permit: N/A 18. Directional Survey: Yes No ~ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: 100' (ft MSL) 20. Thickness of Permafrost (TVD}: N/A 21. Logs Obtained (list all logs here and submit electronic and printed information per 20 AAC 25.071): N/A 22. CASING, L INER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING D EPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT TOP BOTTOM TOP BOTTOM PULLED 24" Surface 394' Surface 393' 13-3/8" 61 J-55 38' 2,510' 38' 2,437' 18" 1500 sxs class G cement 9-5/8" 47 N80/S9 38' 10,747' 38' 8,981' 12-1l4" 1000 sxs class G cement 7" 38 P-110 10,487' 11,765' 8,762' 9,842' 8-1/2" 350 sxs cement 23. Open to production or injection? YesQ No^ If Yes, list each 24. TUBING RECORD interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) G-5 interval (10,826'-10,910'MD) was left open to be part of K-12RD2 N/A N/A N/A ::~,,d~1~E SEA ~ ~ 200$ 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A N/A 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity -API (corr): Press. 24-Hour Rate ~ 27. CORE DATA Conventional Core(s) Acquired? Yes LJ No U Sidewall Cores Acquired? Yes LJ No U If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. .- i;OMFLcTiO~k .af ~,,;•>~ Ba~t~ 1~T'eL_ ;,r~' ~.r ~ LUUiJ f Form 10-407 Revised 2/2007, - y e t CONTINUED ON REVERSE [a~ V • • 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ~ No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Top needed, and submit detailed test information per 20 AAC 25.071. Permafrost -Base Formation at total depth: 30. List of Attachments: Daily Operations Summary, Well Schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Tyler 263-7649 Printed Name: Timothy C. Brandenburg Title: Drilling Manager Signature: Phone: 907-276-7600 Date: 8/25/2008 INSTRUCTIONS ~~~ 2~ 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 1 a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for 1 njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 Chevron • Trading Bay Unit King Salmon Well No. K-12RU Abandonment t',t,ti1NG A~ID'1'IInING DF.'rAll. 24" @ 394' 13318" ~ 2,510' TOC X9300' Bad csg 10,328' i 7" Liner 1o,4sr s s/s" @ 1o,7ar T' Casing Whipstock ~ 10,886' Bridge Plug ~ 1o,s3a Fish 11,077' To 11,241' RKB to TBG Head = 33.80' asi-Set Plug ~ 11,429' / TOC ~ 11,419' PBTD = 11,641' TD =11,775' MAX HOLE ANGLE = 42° @ 5800' SIl.F; WT GRADE CONN ID TOP 13'1'M. 24" Surf 394' 13-3/8" 6L0 J-55 12.515 38' 2,5IO' 9-5/8" 47 N-80 & S95 BTC/LTC 8.681 38' 10,747' 7" Liner 38 P-1 l0 LTC 5.920 10,487' 11,765' Tubin Fish Details Item OD ID Len th Junk Mill 5'/4" 1-''/z" 2.75 Junk Basket 4-'/8" 1-'/2" 3.64 Junk Basket 4?/8" 1-'h" 3.63 Bit sub 4 3/4" 1-'/~" 2.81 Double Pin Sub 4'/0" 1-'h" 0.86 Strin mill 5 '/4" 2" 5.53 Bum er Sub 4'/4" 2" 7.86 Oil Jar 4 3/4" 2" 11.05 Drill Collars 4 5/8 2-'/8" 30.64 Drill Collars 4 5/8 2-'/Z" 30.82 Drill Collars 4 3/4 2-''/z" 31.01 Drill Collars 4 5/8 2-'h" 30.98 Screw-in sub 4-3/4" 2-11/16" 3.36 PERFORATION DATA Zone Top Btm Amount Condition G-5 10,826' 10,910' 84 Open in'95. Reperfd 1/02 HB-1 11,037' 11,057' 20 Open in'78. Reperfd 1/02 HB-2 11,070' 11,175' 105 Open in'78. Reperfd 1/02 HB-3 11,175' 11,200' 25 Open in'78. Reperfd 1/02 HB-4 11,216' 11,236' 20 Open in'78. Reperfd 1/02 HB-5 11,310' 11,330' 20 Open in'78. Reperfd 1/02 HB-6 11,372' 11,402' 30 Open in'78. Reperf'd 1/02 HB-6 11 424' 11 444' 20 Open in'78. , , Attempt isolation 1/02 Rotating Hours: 24" Casing - 17.5 hrs 13-3/8" Casing - 755 hrs 9-5/8" Casing - 126 hrs 7" Casing - 19 hrs 08/25/08 CVK ~Lhevron Chevron -Alaska Daily Operations Summary Well Name K-12RD Field Name MCARTHUR RIVER, API/UWI 507332015601 Lease/Serial ADL0018777 CHEVNO AR4374 License No./Prope... 1780570 Orig KB Elev (ftKB) 33.8 Water Depth (ft) - Jobs _ --- Job Cat Type AFE No. OC Eng Abandon Abandon Well UWDAK-R8042 -- -- Daily Operations __ ---_ _ 6/27/2008 00:00 - 6/28/2008 00:00 Operations Summary Skid Cudd to K12RD, Kill well w 304 bbls KCL/Bleach water at 1.5 bpm, followed by 450 bbls filtered inlet water. NU Riser. AOGCC Notified of upcoming BOP test. 6/28/2008 00:00 - 6/29/2008 00:00 Operations Summary Cont RU, Perform 250/3000 psi Hi-Lo test on choke manifold, erform BOPE test 250/3000 psi, witnessed by AOGCC Chuck Scheve. 6/29/2008 00:00 - 6/30/2008 00:00 Operations Summary Pull BPV, Test BOPE Blinds 250/3000 psi. POOH w/ 2-7/8" kill string, Run WL gauge ring to 10943'. POOH w/ gauge ring, RIH, set CIBP at 10930'. POOH w/ setting tool. 6/30/2008 00:00 - 7/1/2008 00:00 Operations Summary RD Wireline, RIH w/ 8-1/2" mill & scraper assembly to TOL at 10,500' DP measurement. 7/1/2008 00:00 - 7/2/2008 00:00 Operations Summary Make torque test at 36 rpm, up/down wt check. Circ 10 bpm at 2000 psi. POOH w/ Bit and scraper. 7/2/2008 00:00 - 7/3/2008 00:00 Operations Summary POOH w/Bit & 9-5/8" scraper, TIH w w/ 9-5/8" RTTS packer. 7/3/2008 00:00 - 7/4/2008 00:00 Operations Summary Set 9 5/8" RTTS at 10095' pres. tst casin to 250/1000 si hi-lo tst 30 min, POOH w/ RTTS 7/4/2008 00:00 - 7/5/2008 00:00 Operations Summary Mix 9 PPG water base mud, Rigging up CUDD torque tube equipment for drilling operations 7/5/2008 00:00 - 7/6/2008 00:00 Operations Summary Complete CUDD torque tube rig up & mud mixing 680bb1s, Prep CUDD power pak 5. AOGCC Notified of upcoming BOP test. 7/6/2008 00:00 - 7/7/2008 00:00 Operations Summary Perform scheduled BOPE test, witness waived by AOGCC Bob Noble, replace rams, maintain mud, wait on air permit 7/7/2008 00:00 - 7/8/2008 00:00 Operations Summary Continue to wait on air permit, change out hoses on CUDD power pak 7/8/2008 00:00 - 7/9/2008 00:00 Operations Summary Receive air permit, mobe service crews on beach (BOT & MWD personnel), unload BHA & strap 3-1 /2 DP, prep to run whipstock assembly 7/9/2008 00:00 - 7/10/2008 00:00 Operations Summary pull out of hole with RTTS. MU 7" whipstock &RIH. Set down on liner top @ 10,508' 7/10/2008 00:00 - 7/11 /2008 00:00 Operations Summary Attempt to run 7" whipstock into 7" liner without success. POOH. Left 7" whi stock at liner to . 7/11/2008 00:00 - 7/12/2008 00:00 Operations Summary RU slickline. Run LIB to 10,558' Test ROPE, witness waived b AOGCC Jim Re 7/12/2008 00:00.7/13/2008 00:00 Operations Summary Continue w/ BOPE test. P/U liner hanger hook retrieving tool. RIH to 10,061' 7/13/2008 00:00 - 7/14/2008 00:00 Operations Summary RIH to 10,537'. Engage hook and shear bottom anchor on 7" whipstock w/ 60K over pull. POOH. 7/14/2008 00:00 - 7/15/2008 00:00 Operations Summary Finish out of hole wL no recove . MU overshot fishing BHA and RIH to 5,272' 7/15/2008 00:00 - 7/16/2008 00:00 Operations Summary RIH to 10,529'. Work overshot over fish. POOH. No recovery. r. Chevron Chevron -Alaska Daily Operations Summary Well Name K-12RD Field Name MCARTHUR RIVER, API/UWI 507332015601 Lease/Serial ADL0018777 CHEVNO AR4374 License No./Props... 1780570 Orig KB Elev (ftK6) 33.8 Water Depth (ft) Dail Operations _: 7/16/2008 00:00 - 7/17/2008 00:00 Operations Summary MU smaller grapple overshot assembly. RIH. Drop slip dies down hole. POOH w/slip dies on top of fishing BHA. Unable to pass BHA thru well headdue to slip dies. Attempt to recover slip dies w/dry rod. 7/17/2008 00:00 - 7/18/2008 00:00 Operations Summary Continue attem is to recover sli dies. 7/18/2008 00:00 - 7/19/2008 00:00 Operations Summary Fished slip dies and start clean up.Contacted AOGCC Jim Regg regarding fishing operations. Extension given for BOP test until fished out of hole. Contacted AOGCC Chuck Scevie who waived witness to BOP test. 7/19/2008 00:00 - 7/20/2008 00:00 Operations Summary Finish testing BOP stack Changed Shear rams to blind rams. Test BOPs 250 low. 3000 high. AOGCC witness waived, Test was good. Start in hole w/ Overshot. 7/20/2008 00:00 - 7/21 /2008 00:00 Operations Summary RIH with overshot, work fish @ 10,490' - 10,497' POOH with fish (whipstock). 7/21/2008 00:00 - 7/22/2008 00:00 Operations Summary POOH and la~down _fish (whipstock missing 2 dies) RIH with clean out assembly, work top 7" liner no problems, RIH Tag CIBP 10,886' jack rail measurement' 7/22/2008 00:00 - 7/23/2008 00:00 Operations Summary Tag CIBP @ 10,886' jack rail measurement Displace well from Flw to 9.0 ppg mud, POOH with clean out assembly, Start installing torque tube 7/23/2008 00:00 - 7/24/2008 00:00 Operations Summary POOH with clean out BHA, LD same. Changed bolt on carrier of blind rams. Contact AOGCC Lou Grimaldi about repair and BOP test. Witness waived by Lou Grimaldi. Test BOP 250/3000gsi, good. 7/24/2008 00:00 - 7/25/2008 00:00 Operations Summary Make MWD on whipstock & test, RIH to 10,526' at time of report. 7/25/2008 00:00 - 7/26/2008 00:00 Operations Summary Rih w/ whipstock passing thru 7" liner - no problems. At 10,778' make up kelly & work to orient whipstock. Work down to CIBP and set whipstock at 10,886' Adjust KB tool face 38 degrees left. Shear bolt. P/U 216,000# S/D 98,000#. • ~,„ °„J ~~ ~ 4 ~~~.~ ,. ~ ~ ~ ~° ~w ~ ~ SARAH PAL/N, GOVERNOR ~"`~~~~ OII/ t~i`L ~ 333 W. 7th AVENUE, SUITE 100 COI~SER~A'rIO1~T COl-il-iIS5I0IQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager UNOCAL PO Box 196247 ~,~~~~~~~ JUN ~ ~ 2008 Anchorage, AK 99519-6247 n ~ ,,, n S 1 Re: McArthur River Field, Hemlock/Middle Kenai G Oil Pool, K 12RD Sundry Number: 308-190 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this3 aday of May, 2008 Encl. • Chevron May 19, 2008 Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Sundry for Abandonment (Form 10-403) McArthur River Field King Salmon Platform, Well K-12RD Dear Commissioner, Timothy C Brandenburg Drilling Manager • Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com ~~~~~, `~ V A! SAY 2 ~ 10~g ~ska 4r! ~ Gas fans Gom Anchara~e mr~ipn ~~~~.os7 Enclosed is an Application for Abandonment (Form 10-403) for King Salmon Well # K- 12RD. This well went off production when a fish was left in the hole across the productive ~ intervals during a workover in July, 2007. f The intention is to prepare this well for aside-track, to be commenced immediately upon the proposed abandonment. This proposed re-drill will be submitted for sundry approval under a separate cover. If you have any questions in regards to this sundry, please contact Mr. Steve Alexander at (907) 263-7880. Sincerely, ~, _-, ; , ~~..w ~.~ ..~ ~! ~~:~..~- Timothy C. Brandenburg Drilling Manager Attachments Union Oil Company of California / A Chevron Company Page i of i 3a ~ STATE OF ALASKA ~~ ALA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ~j~ 20 AAC 25.280 1. Type of Request: Abandon Q Suspend ^ Operational shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing epair well [,~~~ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program Pull Tubing ^~ - Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ^ Exploratory ^ 78-57 3. Address: Stratigraphic ^ Service ^ 6. API Number: ~"p- '7 33' PO Box 196247, Anchorage, AK, 99519-6247 50-733- ~6 ,aA/S6 'b~-L~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: 5~ Z,$. property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No Q K-12RD ' 9. Property Designation: 10. KB Elevation (ft): ' 11. Field/Pool(s): il d`~ ~~ Q ADL 18777 100 AMSL y . McArthur River Field, Hemlock / 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,775' 9,867' r 11,641' 9,737' 11,419' Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,472' 13 3/8" 2,510' 2,436' 3,090 1,540 Intermediate Production 10,709' 9 5/8" 10,747' 8,981' 6,870 4,760 Liner 1,288' 7" 11,775' 9,867' 10,800 11,390 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,826'-11,402' 9,052' - 9,535' 2-7/8" , 6.5 ppf N-80 4,505 Packers and SSSV Type: NA Packers and SSSV MD (ft): NA 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch Q Exploratory ^ Development ^~ Service ^ 15. Estimated Date for 6/25/2008 er proposed work: ~ pyj !A i^~' O 16. Well Statu aft / ~ Commencing Operations: ~ dd Oil , ~o~Gas ^ Plugged Abandone d [t~ ~ 17. Verbal Approval: Date: WAG ^ ~'~ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certity that the foregoing is true and correct to the best of my knowledge. Contact Steve Alexander 907 276-7600 Printed Name Timothy Brandenburg Title Drilling Manager Signature ,/ =~ Pho --+ Date ~ ,. . ~--''" COMMISSION USE ONLY Conditions of approval: Notity Commission so that a representative may witness Sundry Number: ~ g " ~~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^~~p"~~~~ ll,,,,,,~~ Other: MAY ~ ~ 2008 Alaska art ~ G as cans. ~ammissian Subsequent Form Required: ~ Anchoraga APPROVED BY ~ ~ ~ ©~ () Approved b : COMMISSIONER THE COMMISSION Date: vx y •~$ ORIGINAL ~~-~:~;l~l~~-~~QO~ ~4~:~'.~~ Form 10-403 Revised 06/20 6 Submit in D plicate . Chevron • • King Salmon K-12RD Proposed Abandonment Revision #0 5/19/08 OBJECTIVE: • Abandon the current completion and set the well up for a side-track as deep as possible. • Set a bridge plug at -11,010' just above fish at 11,077' and the Hemlock Bench 1 perfs at 11,037' and below the G-5 open perfs at 10,826'-10,910'. • Don't pump any cement to isolate the current completion due to the close proximity of the proposed Re-Drill well path. • Set Whip stock at -11,000'. PROCEDURE SUMMARY: • Circulate well, displace well to inlet water + LCM (Kill well), ensure standing column of fluid in well. (Displace returns to production). • Set BPV, Pull tree. • Nipple up BOPE and test to 250/3000 psi. (AOGCC will be notified 24hrs to witness test) • Pull Completion consisting of 4505' 2 7/8" kill string with GLM. • Gauge 7" liner with Eline GR, Scrape 9 5/8 csg, test casing with RTTS pkr. • Run upper 7" liner scab ifrepuired from csg test (FIT from 10100'-TOL) • RIH w/ bridge plug and set in 7" casing at _11,010'. • Run an set 7" whip stock at 11,000'. K-12RD Abandonment REVISED BY: LWB 5/19/08 Chevron • Trading Bay Unit King Salmon Well No. K-12RD Completion CASING .AND TUBING DET AIL ' SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head = 33.80 24•• Surf 394' T ree connecti on: 13-3/8" 61.0 K-55 12.515 38' 2,510' 9-5/8" 47 N-80 & S95 BTC/LTC 8.681 38' 10,747' 24" 394' 7" L;n~r 38 P-110 LTC 5.920 10,487' 11,765' @ ' Tubin 13 3/8" GLM @2289 - 2-7/8" Kill Strin 6.5 N-80 BTC 2.441 35 4505' @ 2,510' GLM @3825' J M S @4505' TOC @9300' , Bad csg 10,328' ~ 7" Liner M 10,487' ~~ 9 5/8" @ 10,747 ~ G-5 Fish 11, 077' To 11, 241' osfSetPlug @ 11,429' /TOC@ 11,419' B-1 B-2 B-3 B-4 B-5 B-6 PBTD =11,641' TD = 11,775' MAX HOLE ANGLE = 42° @ 5800' Fish Details Item OD ID Len th Junk Mill 5 3/" 1-%z" 2.75 Junk Basket 4-'/8" 1-%2" 3.64 Junk Basket 4-'/g" 1-%z" 3.63 Bit sub 4'/" 1-''/Z" 2.81 Double Pin Sub 4 '/" 1-''/z" 0.86 Strin mill 5 3/" 2" 5.53 Bum er Sub 4 3/" 2" 7.86 Oil Jar 4 3/" 2" 11.05 Drill Collars 4 5/8 2-'/8" 30.64 Drill Collars 4 5/8 2-%z" 30.82 Drill Collars 4 3/4 2-%z" 31.01 Drill Collars 4 5/8 2-''/Z" 30.98 Screw-in sub 4-'/" 2-11/16" 3.36 PERFORATION DATA Zone Top Btm Amount Condition G-5 10,826' 10,910' 84 Open in '95. Reperfd 1/02 HB-1 11,037' 11,057' 20 Open in'78. Reperf'd 1/02 HB-2 11,070' 11,175' 105 Open in'78. Reperfd 1/02 HB-3 11,175' 11,200' 25 Open in '78. Reperf'd 1 /02 HB-4 11,216' 11,236' 20 Open in'78. Reperfd 1/02 HB-5 11,310' 11,330' 20 Open in'78. Reperfd 1/02 HB-6 11,372' 11,402' 30 Open in'78. Reperfd 1/02 HB-6 11,424' 11,444' 20 Open in'78. Attempt isolation 1/02 Rotating Honrs: 24" Casing - 17.5 hrs 13-3/8" Casing - 755 hrs 9-S/8" Casing - 126 hrs 7" Casing - 19 hrs 09/13/07 CRW - Chevron . Trading Bay Unit King Salmon Well No. K-12RD Proposed Abandonment reclvn nnn TtIRlrun n~Tnn 24" @ 394' RKB to TBG Head = 33.80' Tree connection: 13 3/8" @ 2,510' TOC @9300' , Bad csg ' 10,328' 7" Liner ~ 10,487' i 9 518" @ 10,747' ~ 7" Casing W hipstock @ - 11,000' Bridge Plug @ -11,010' Fish 11, 077' To 11,241' G-5 B-1 B-2 B-3 B-4 B-5 os~SetPlug @ 11,429' /TOC@ 11,419' B-6 PBTD =11,641' TD = 11,775' MAX HOLE ANGLE = 42° @ 5800' SIZE WT GRADE CONN ID TOP BTM. 24" Surf 394' 13-3/8" 61.0 K-55 12.515 38' 2,510' 9-5/8" 47 N-80 & S95 BTC/LTC 8.681 38' 10,747' 7" [.~~ 38 P-110 LTC 5.920 10,487' 11,765' Tubin Fish Details Item OD ID Length Junk Mill 5 '/" 1-%z" 2.75 Junk Basket 4-'/8" 1-%z" 3.64 Junk Basket 4?/8" 1-%z" 3.63 Bit sub 4'/" 1-%i" 2.81 Double Pin Sub 4 3/" 1-%z" 0.86 Strin mill 5 3/" 2" 5.53 Bum er Sub 4 3/" 2" 7.86 Oil Jar 4 3/" 2" 11.05 Drill Collars 4 5/8 2-'/8" 30.64 Drill Collars 4 5/8 2-''/z" 30.82 Drill Collars 4 3/4 2-%z" 31.01 Drill Collars 4 5/8 2-%z" 30.98 Screw-in sub 4-3/" 2-11/16" 3.36 Zone Top PERFORATION DATA Btm Amount Condition G-5 10,826' 10,910' 84 Open in'95. Reperfd 1/02 HB-1 11,037' 11,057' 20 Open in'78. Reperfd 1/02 HB-2 11, 070' 11,175' 105 Open in '78. Reperf'd 1 /02 HB-3 11,175' 11,200' 25 Open in'78. Repelfd 1/02 HB-4 11,216' 11,236' 20 Open in'78. Reperfd 1/02 HB-5 11,310' 11,330' 20 Open in'78. Reperf'd 1/02 HB-6 11,372' 11,402' 30 Open in'78. Reperfd 1/02 HB-6 11,424' 11,444' 20 Open in'78. Attempt isolation 1/02 Rotating Hours: 24" Casing - 17.5 hrs 13-3/8" Casing - 755 hrs 9-5/8" Casing - 126 hrs 7" Casing - 19 hrs 09/13/07 CRW • • 5!1 AR King Salmon K12RD BOP Stack C~ C~ Page 1 of 3 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, May 29, 2008 11:43 AM To: 'Buster, Larry W Cc: Alexander, Steve [TWT]; Walsh, Chantal [Petrotechnical]; Hammons, Darrell Subject: RE: K-12RD (178-057) Larry, et al, Thanks much. Tom Maunder, PE AOGCC ~~~,,~~~~E~ JUN ~~ ~ 200 From: Buster, Larry W [mailto:LBuster@chevron.com] Sent: Thursday, May 29, 2008 11:38 AM To: Maunder, Thomas E (DOA) Cc: Alexander, Steve [TWf ]; Walsh, Chantal [Petrotechnical]; Hammons, Darrell Subject: RE: K-12RD (178-057) Tom, Thanks. Also, on the current King Salmon work, we are running 2-7/8" x 5-1/2" VBR's in the top and blind/shears in the bottom of our double gate. Regards, Larry Larry W. Buster Drilling Engineering Manager MidContinent/Alaska Business Unit Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501-3322 Tel: (907) 263-7853 Cell: (907) 250-0374 Fax: (907)263-7884 Ibuster@chevron.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, May 28, 2008 5:04 PM To: Buster, Larry W Cc: Alexander, Steve ['TWT]; Walsh, Chantal [Petrotechnical]; Hammons, Darrell Subject: RE: K-12RD (178-057) Larry, et al, Thanks much for the reply.. There is no need to resubmit the sundry. When it is returned, the hand changes will be evident. In this case so o the information listed is from K-12, not K-12RD. As this exchange has shown, it is important to keep the paperwork consistent workover to workover on a given platform. On platforms where the rig cannot or will not actually be employed, it is probably best to state upfront if the CUDD • C7 Page 2 of 3 unit or some other piece of equipment. is being employed. One last quesfian, are you. employing VBRs? Call or message with any questions. I will plan to place a copy of your reply in the respective welt files. Tom Maunder, PE AOGCC From: Buster, Larry W [mailto:LBuster@chevron.com] Sent: Wednesday, May 28, 2008 4:51 PM To: Maunder, Thomas E (DOA) Cc: Alexander, Steve ['TINT]; Walsh, Chantal [Petrotechnical]; Hammons, Darrell Subject: RE: K-12RD (178-057) Tom, We are planning to do the abandonment work on the K-12RD with the CUDD 340 unit currently on the King Salmon Platform. Please advise if we need to re-submit the proposed program for the 10-403? Also, we are submitting a 10-401 for the proposed K-12RD2 today. Lastly, We are using the 3K (double gate and annular) on all of the King Salmon Wells using the CUDD 340 unit. Thanks and Regards, Larry W. Buster Drilling Engineering Manager MidContinent/Alaska Business Unit Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501-3322 Tel: (907) 263-7853 Cell: (907) 250-0374 Fax: (907) 263-7884 Ibuster@chevron.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, May 28, 2008 3:37 PM To: Walsh, Chantal [Petrotechnical] Subject: K-12RD (178-057) Chantal, Would you please forward to Steve Alexander. I don't have his email. Steve, I left you a message. The Commission has received the sundry application to plug this well. Will this work be done using the Cudd HWO unit presently on the platform? If so, then the plan should state this. It is also noted in your letter that you will submit the proposed redrill for sundry approval. The redrill will require a new permit to drill. L` • Page 3 of 3 Also, a question for both of you. Which BOP stack arrangement is being used on King? This latest sundry has a 2 ram stack with annular which does meet the 3K requirements. I checked back on the 3 sundries recently approved for other wells and 2 have 3 ram stacks (K-22RD and K-01 RD2) and 1 the 2 ram stack (K-19). I probably should have caught the difference when they came through, but as I remember they got split up due to questions. Thanks in advance. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Wednesday, May 28, 2008 5:04 PM To: 'Buster, Larry W' Cc: Alexander, Steve [lWf]; Walsh, Chantal [Petrotechnical]; Hammons, Darrell Subject: RE: K-12RD (178-057) Larry, et al, Thanks much for the reply. There is no need to resubmit the sundry. When it is returned, the hand changes will be evident. In this case some of the information listed is from K-12, not K-12RD. As this exchange has shown, it is important to keep the paperwork consistent workover to workover on a given platform. On platforms where the rig cannot or will not actually be employed, it is probably best to state upfront if the CUDD unit or some other piece of equipment is being employed. One last question, are you employing VBRs? Call or message with any questions. I will plan to place a copy of your reply in the respective well files. Tom Maunder, PE AOGCC From: Buster, Larry W [mailto:LBuster@chevron.com] Sent: Wednesday, May 28, 2008 4:51 PM To: Maunder, Thomas E (DOA) Cc: Alexander, Steve [lWr]; Walsh, Chantal [Petrotechnical]; Hammons, Darrell Subject: RE: K-12RD (178-057) Tom, We are planning to do the abandonment work on the K-12RD with the CURD 340 unit currently on the King Salmon Platform. Please advise if we need to re-submit the proposed program for the 10-403? Also, we are submitting a 10-401 for the proposed K-12RD2 today. Lastly, We are using the 3K (double gate and annular) on all of the King Salmon Wells using the CUDD 340 unit. Thanks and Regards, JUN ~ 4 2008 Larry W. Buster Drilling Engineering Manager MidContinent/Alaska Business Unit + ~.. -----._ . Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501-3322 Tel: (907) 263-7853 Cell: (907) 250-0374 Fax: (907) 263-7884 (buster@chevron.com °-~ From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, May 28, 2008 3:37 PM To: Walsh, Chanta! [Petrotechnical] Subject: K-12RD (178-057) Chantal, Would you please forward to Steve Alexander. I don't have his email. Steve, I left you a message. The Commission has received the sundry application to plug this well. Will this work be done using the Cudd HWO unit presently on the platform? If so, then the plan should state this. It is also noted in your letter that you will submit the proposed redrill for sundry approval. The redrill will require a new permit to drill. Also, a question for both of you. Which BOP stack arrangement is being used on King? This latest sundry has a 2 ram stack with annular which does meet the 3K requirements. i checked back on the 3 sundries recently approved for other wells and 2 have 3 ram stacks (K-22RD and K-01 RD2) and 1 the 2 ram stack (K-19). I probably should have caught the difference when they came through, but as I remember they got split up due to questions. Thanks in advance. Tom Maunder, PE AOGCC Chevron ~.,. ~; ~.;~~-~. ;:... December 4, 2007 To: AOGCC Christine Mahnken 333 W. 7t" Ave. Ste#100 Anchorage, AK 99501 P a"Ea"E IT# APB fJi .~5ER~ELL ~~_)G 7`i PE i SCF~LE ~ LOG ~ DATE ~ !NTEP,`J,4L P ~N~ LOGGED # B- F~L~ C~ LIfJE ~ IJOTES - I LAS, PDS. CLIS 1.56" POWERJET 6 SPF 60 1 85- DEGREE 12-Jul- 10700 - 0 507332015601 K-12RD2 PHASED 5" 07 11165 1 1 1 1 PDS ~~~-os~ ~ i J~~~ ~~ Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received By: Date: il>~S ; z .~ n~~,. Francisco Castro Technical Assistant Chevron North A•ica Exploration and Production 909 W. 9th Avenue Anchorage, AK 99501 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com ~~~ DEC ~. ~ 2U~7 • • Maunder, Thomas E (DOA) From: Tyler, Steve L {tylersl@chevron.com] Sent: Friday, September 28, 2007 5:49 PM To: Maunder, Thomas E (DOA) Subject: RE: K-12RD {178-057) This is correct. Page 1 of 1 From: Maunder, Thomas E (DOA) [mailtoaom.maunder@alaska.gov) Sent: Friday, September 28, 2007 12:15 PM To: Tyler, Steve L Subject: K-12RD {178-057) Steve, Further to our conversation on K-12RD. It would appear that reporting an operational SD is not correct. The email trail indicates that originally it was planned to suspend the well, however that changed to running a GL string that would aNow some production of the well. As no#ed in the message trail, the well passed a no-flow some time ago and no work was performed to enhance any of the perforations. Please respond and confirm if my understanding is con'ect. Tom Maunder, PE AOGCC ~~.~~~~ N0~ ~. ~ 207 lam- 05~ loni2oo~ • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Repair Well . lug Perforations Stimulate Other illGliQi"8 j~£ Performed: Alter Casing ^ Pull Tubing [[]~ Perforate New Pool ^ Waiver ^ Time Extension ^ , Change Approved Program ^ Operat. Shutdow rl ~ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: pp Name: `~1 Development Q ~ Exploratory ^ 78-57 3. Address: PO Box 196247, Anchorage, Stratigraphic^ Service^ 6. API Number: AK 99519-6247 50-733-20156-01 ~ 7. KB Elevation (ft): 9. Well Name and Number: 100' AMSL - K-12RD i 8. Property Designation: 10. Field/Pool(s): ADL 18777 McArthur River Field, Hemlock ~ 11. Present Well Condition Summary: Total Depth measured 11,775' y feet Plugs (measured) true vertical g 867 feet Junk (measured) 11,077 Effective Depth measured 11,077' feet true vertical 9,260' feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,472' 13-3i8" 2,510' 2,436' 3,090 1,540 Intermediate Production 10,709' 9-5l8" 10,747' 8,981' 6,870 4,760 Liner _ 1,288' 7" 11,775' 9,867' 10,800 11,390 Perforation depth: Measured depth: 10,826'-11,402' True Vertical depth: 9,052'-9,535' Tubing: (size, grade, and measured depth) 2-718" L-80 4,505' Packers and SSSV (type and measured depth) None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: ~ ~~~ $ ~D~~ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 410 % 178 6750 120 120 Subsequent to operation: NA 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development Q Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-114 Contact Chantal Walsh - 263-7627 Printed Name Timothy Brandenburg Title Drilling Manager Signature -' ~ '~"'~~ Phone 907 276-7600 Date 13-Sep-07 ~~~~~ ,`~~P 7 4 ~qq7 Alaska ~ {~ ~x~lw Inns. Cammissiort Form 10-404 Revised 04/200 ~~~ `~ ~ ~ ~"`i, ~~t; Submit Original O ,y Chevron ~ • Trading Bay Unit King Salmon Well No. K-12RD Completion C~+,SING A\D TUBING DET :UL SILE N'"C GRADE CO\\ ID TOP BTYI. RKB to TBG Head = 33.80' 24" Surf 394' T ree connecti on: 13-3/8" 61.0 K-55 12.515 38' 2,510' 9-5/8" 47 N-80 & S95 BTC/LTC 8.681 38' 10,747' " ' 7" Liner 38 P-110 LTC 5.920 10,487' 11,765' 24 ~ 394 ,~; Tubin 13 3/8" GLM X2289' - 2-7/8°° Kill Stfln 6.5 N-80 BTC 2.441 35 4505' ~ 2,510' TOC @9300' Bad csg 10,328' 7" Liner G~ 1 o,aa7' 9 5/8" ~ 10,747' @3825' MS @4505' ISSUES d' • 13 '/s" pressure communication to 24" • 13 '/8" has high rotating hrs. • Bad csg with penetration • Fish covering most of HB-3 • HB-4 thru HB-6 is not accessible. Fish Details G-5 J Fish 11,077' To 11,241' B-1 B-2 B-3 B-4 B-5 B-6 Posi-Set Plug @ 11,429' /TOC ~ 11,419' PBTD = 11,641' TD = 11,775' MAX HOLE ANGLE = 42° @ 5800' Item OD ID Len th Junk Mill 5 '/a" 1-'/z" 2.75 Junk Basket 4-'/g" 1-'/z" 3.64 Junk Basket 4>/8" 1-'/z" 3.63 Bit sub 4'/<" 1-'h" 2.81 Double Pin Sub 4'/<" 1-'/z" 0.86 Strin mill 5'/<" 2" 5.53 Bum er Sub 4'/<" 2" 7.86 Oil Jar 4'/4" 2" 11.05 Drill Collars 4 5/8 2-'/a" 30.64 Drill Collars 4 5/8 2-''/z" 30.82 Drill Collars 4 3/4 2-''/2" 31.01 Drill Collars 4 5/8 2-''h" 30.98 Screw-in sub 4-'/0" 2-11/16" 3.36 PERFORATIO\ DATA Zone Top Btm Amount Condition G-5 10,826' 10,910' 84 Open in'95. Reperfd 1/02 HB-1 11,037' 11,057' 20 Open in'78. Reperf'd 1/02 HB-2 11,070' 11,175' 105 Open in'78. Reperf'd 1/02 HB-3 11,175' 11,200' 25 Open in'78. Reperfd 1/02 HB-4 11,216' 11,236' 20 Open in'78. Reperfd 1/02 HB-5 11,310' 11,330' 20 Open in'78. Reperfd 1/02 HB-6 11,372' 11,402' 30 Open in'78. Reperf'd 1/02 HB-6 11,424' 11,444' 20 Open in'78. Attempt isolation 1/02 Rotating Hours: 24" Casing - 17.5 hrs 13-3/8" Casing - 755 hrs 9-5/8" Casing - 126 hrs 7" Casing - 19 hrs 09/13/07 CRW • • King Salmon K-12RD Workover Change out of ESP -Operations Summary ~ ` 5-12-07 Circulate well to production to displace wellbore w/ 3%KCL water. Spot saturated size salt pill (15 bbl salt spacer + 30 bbl size salt pill + 15 bbl spacer). Bullhead with 3% KCL into formation. Monitor well. 5-13-07 Continue to monitor well. ND tree, plug chem. control lines, pull and blind prod. Lines, pull tree. NU riser spools, mud cross and BOPS. Dress BOP rams w/blinds. 5-22-07 Prep location. Establish circulation in well. Well losses at 14 bbl/hr. Set BPV. Continue to prep location. 5-23-07 Install test dart. ND wellhead. NU mudcross, NU double gate with 2-7/8" x 5-1/2" variable rams in bottom, blind in top. NU Annular. Mobe rig. 5-24-07 Mobe rig. Contact State for upcoming BOP test. 5-25-07 Mobe rig. 5-26-07 Mobe rig. 5-27-07 Prep location, continue to mobe rig. Pump into and circulate well. AOGCC waived BOP test. Test blind rams, IBOP, & choke manifold valves, 2501ow / 3000 high. Test VBRs on choke manifold &TIW valve. No success. 5-28-07 Test BOP to 2501ow / 3000 high. Good test. VBRs, choke manifold valve, kill valve, HCR valve, annualar, manual kill line valve, manual choke, TIW valves, and accumulator test good. LD test joint. Close blind rams. Pull BPV. Well losses @ 25-30 bbUhr. Pull/LD tbg. TOOH. -------, 5-29-07 Continue to LD tbg. Losses @ 5 bbl/hr. Pull/cut cable. Inspect tbg. Continue POOH, LD 4-112" IBT tbg w/ gas lift mandrels. 5-30-07 Continue to POOH and LD tbg. Losses @ 1-2 bbls/hr. Pull ESP BHA. Found Flat Motor Lead short to ground with in 1' of pot head clamp. Top pump locked. Other 2 pumps, motor and seals had good rotation. Junk left in hole: 4 protectolizer doors, 9 super bands, 2 cannon clamps and 3.5 sections of flat guard. • King Salmon K-12RD Workover Change out of ESP -Operations Summary 5-31-07 MU, install test plug and joints. Test VBRs 250psi low / 3000 psi high. Test Annular, same. Tests good. Pull test plug. PU wear bushing and set. PU BHA #1 with 8-1/8" overshot grapple and mill, bumper sub and drill collars. PU 4" HT-38 DP. Fluid losses at 33 bbls/day. 6-1-07 Continue to PU DP. RIH and tag @ 10175' (very close to setting depth of old completion). Work BHA down to 10193'. Prep to POOH. 6-2-07 TOOH. Rack back 4" DP. LD BHA. Avg losses while tripping at 2.7 bbls/hr, 1.5 bbls/hr while static. 6-3-07 Finished LD BHA. Recovered 6.3' flat guard, and 2 super bands. MU/PU BHA #2, shoe with finger basket and wash pipe. Hydraulic power pack catches on fire. Shut in on well. Secure operations. File reports and make contacts. Current losses on well at 1.5 bbUhr. 6-4-07 Continue clean up. Well is secure. No operations. 34 bbllday losses. 6-5-07 Continue to clean location. AOGCC rep on site. Monitor wellbore. 6-6-07 Continue to monitor well. Loss rate at 1.5 bbl/hr. Replacing equipment. 6-7-07 Continue to monitor well. Cleaning location. Skid rig and prep for wireline work. Wellbore loss rate at 1.5 bph. 6-8-07 Continue to monitor well losses. RU lubricator on tree. RU eline for tubing punch run. Load guns. RIH with 6' of 1-9/16" OD tubing punch guns. Work tool string to 11092'. Pump 1 bpm of 3% KCL. Returns after pump equa128 bbls. Getting returns from 9-5/8" annulus with less than 50 psi tbg pressure. Worked guns to 11,280'. Shot top shot at 11,272' and bottom shot at 11,278'. 23 total shots, .21" diameter. POOH w/ wireline, RD same. 32.5 bpd losses. 6-9-07 Prep/clean location. Test choke manifold, 250psi low/3000psi high. All valves but 1 held. • • King Salmon K-12RD Workover Change out ofESP -Operations Summary 6-10-07 Continue cleaning location. Monitor well, 34.5 bpd losses. 6-11-07 Monitor well, 34.5 bpd losses. 6-12-07 Hook up new power packs. Function test same, OK. Fill with oil. POOH w/ BHA. LD drill collars. 6-13-07 Continue to LD BHA. MU test joint. Pull wear ring. Run test plug. BOP tested 250psi low/ 3000psi high. AOGCC witnessed. Pull test plug, rerun wear ring. Run BHA #3 w/ crane, run DP. 6-14-07 RIH with DP. Circulate wellbore to production (20bbls) - no oil cap. Wash from 10,193' to 10,295'. Difficult at 10,209'. 6-15-07 Worked pipe from 10,295' to 10,359'. TOOH with BHA. Retrieved clamps from inside boot baskets. 6-16-07 Changed out KR valve. RIH with fishing BHA. Well losses at 34 BPD. 6-17-07 Tagged at 10,300'. Washed to 10,364', circulating @ 4bpm. Dress off top of fish. Work down to 10,367'. POOH. Well losses at 2.8bb1lhr. 6-18-07 LD BHA #4. Found wadded up flat guard and bands. PU BHA #4. RIH. 6-19-07 RIH to 10,320'. Work to 10,395'. Top of packer appears not to be going down. Pump/squeeze 15 bbls saturated salt, 40 bbls sized salt, 15 bbls saturated salt spacer. Shut down and monitor losses @ 12 bph. TOOH with shoe. 6-20-07 POOH. Losses at 7 bph. LD accelerator and 3 drill collars. 6-21-07 Finish LD of BHA. PU test jt. BOP tests, 250psi low. PU hanger and subs, land, pressure test void to 5000 psi. Test OK. Back out/ stand back tbg. Remove VBR ram blocks and blind ram blocks. • • King Salmon K-12RD Workover Change out of ESP -Operations Summary 6-22-07 Continue BOP test. 6-23-07 Finish testing BOPS to 250psi low/ 3000psi high. All good. Pull test plug and set wear bushing. PU BHA #5 (overshot assembly, jars, DC, Accelerator). TIH to 10,365'. 6-24-07 Tag fish at 10,377' Swallow fish w/BHA to 10,384'. Latch and jar. Seal assembly free. CBU at 8 bpm with 1600#. POOH to BHA. 6-25-07 Pull out last of BHA. Tubing stub was broken, did not retrieve entire fish. PU BHA #6. RIH to 10,385'. Circulate down DP and up csg. Rotate pipe and ream down to 10,395'. Start burning over packer. 6-26-07 Wash over packer with shoe to 10,399'. Pump and rotate while washing. Pump high vis sweep (15 bbls), while washing over packer. Circ, POOH. 6-27-07 Pull completely out of hole with BHA. Junk basket has small metal cuttings. MU new burn shoe. PU TIH w/ BHA #7 to 10,389' (tag). Pump 15 bbl size salt pill, begin milling on packer. Push packer 3' to 10.402' . 6-28-07 Continue to mill packer. Pump 10 bbl size salt pill. Rotate on packer. Pump 10 bbl sized salt sweep. Continue to work and push packer to 10,471'. CBU. Some gas to surface in gas buster. Cir 705 bbls. POOH. Rackback. 6-29-07 Finish POOH w/ BHA #7. PU MU BHA #8. RIH tag packer @ 10,436'. Push packer to 10,453'. Latch fish. CBU. Pump 640 bbls. Begin POOH w/fish. 6-30-07 POOH w/ packer (seal assembly/tail pipe/no slip body). POOH w14-112" IBT and LD same. Fish at surface. Test BOP. LD testing equipment and reinstall wear bushing. 7-1-07 PU MU BHA for cleanout of 7" liner. PU BHA #9. RIH to top of liner @ 10,487'. Tag at 10,491'. Kick in rotary. Pump 20 bbl sized salt sweep and begin milling/clean out. 7-2-07 Continue milling on bottom. 5-3/4" mill at 10,555'. Have 8-1/2" mill in 9-5/8" csg. TOOH (some drag). r] • King Salmon K-12RD Workover Change out of ESP -Operations Summary 7-3-07 POOH LD BHA #9. Recovered parts of packer slips and scale in junk baskets. MU PU BHA #10. Mill at 9,250'. Continue to mill in tight spot from 9,301' to 9,305'. Reamed from 9289 - 9320' to clean section. Continue to 10,515'. 7-4-07 TIH to 10,515'. Tag at 10,520' (original depth of liner top at 10,487' KB) Corrected for Jack KB. Liner top now at 10,530'. Pumped 2-1/2 x hole volume. CBU. POOH (no excess drag). 7-5-07 LD String mill and junk baskets. Had large pieces of scale and metal from packer. MU ProActive Diagnostic Memory tool. MU spang jars, wt bars and rope socket. RU Slickline. GIH to 10,600'. Multifinger tool opened and POOH @ 50'/min. Retrieve tool, data valid. RD Slickline. MU PU BHA #11. RIH. 7-6-07 Continue to RIH w/ BHA #11 to 10,483'. Pumped down tbg. No tag. CBU. Start in liner top at 10,533'. Rotate/mill to 10,927'. Continue milling to 11,243', string hung up at 11,240'. 7-7-07 Attempt to work string to set free, No joy. Continue to fill hole. PU MU 1"Free Point tool. RU eline. RIH to 10,000'. Felt jars go off. POOH w/tools. RD eline. Attempt to jar with rig. No go. 7-8-07 RU eline. RIH and tag at 11,175' WLM. POOH. RD eline. RU Slickline unit. RIH with bailer to 11,190'. POOH with tools. Recover 1/2 cup of sand. Run back in hole tag at 11,190'. Work tool to bottom, tool stuck. Work to get unstuck. POOH. Recovered 1/2 cup of dry black particles. Change to 1-3/4" bailer. RIH tag at 11,190' WLM. Worked at bottom. POOH. Recovered 2 tablespoons of same material. LD bailer. PU tbg scratcher spear tool. RIH to 11,190'. Repeatedly stick tool. POOH. Recover 3 tablespoons of same material. RD Slickline. RU to circulate and work string. Work string by jarring. 7-9-07 RU eline. MU packoff and tools. MU 7 strips of backoff charge. GIH to 11,142'. Fire f string shot. Put 2-1/4 turns in string. Connection broke. DP free. Top of 358.9' fish at / 11,142'. Pump 555 bbls pre vis pill. Pump 50 bbls vis pill. Continue to pump and saw no noticeable solids at surface. Pumped 2002 bbls behind pill. POOH. 7-10-07 Continued to POOH. No fish. Run BOP test. 250 low/3000 hish. All tests passed. TIH with subpressure control sub. • King Salmon K-12RD Workover Change out of ESP -Operations Summary 7-11-07 RIH to 10,851'. Wash down and tag fish @ 10,881'. Screw into fish. RU eline. MU freepoint tool. RIH to 10,873' WLM. Take reading with tool from 10,873' to 10,924' RD eline. Build perf guns. RU eline. Arm gun and RIH. 7-12-07 RIH, fire 1.56" OD 5' guns from 11,171' to 11,166'. POOH. A1131 shots fired. RD eline. Attempt to break circ. No go. RU eline. RIH fire shots from11,082 - 11,087' POOH. RD eline. RU to pump. Pump with no noticeable freeing of the pipe. Run freepoint tool. Readings form top of first DC to 10~' DC (fill at this point 11,174'). 7-13-07 POOH with free point tool. Pump and work pipe. RIH with string shot. Fired at 11,075'. POOH with wireline. RD wireline. Circulate well and work pipe. Pump 60 bbl viscosity sweep. Good returns with fine sludge. POOH with DP. 7-14-07 POOH with fish. Fish remaining in hole is 161.58'. PU BHA with 4 spiral drill collars. RIH to 11,058'. Wash down and tag fish at 11,078'. Screw into fish and begin pumping. 7-15-07 Continue to work pipe, jarring and pulling. RU wireline. RIH with 1-3/8" tbg punch and spangs. Located top of fish at 11,078', located fill at 11,101'. No sticking. Pooh, RD eline. Continue to jar and pump. RU Slickline bailer. RIH with 1-3/4" drive down bailer. 7-16-07 Bail on fill at 11,133'. Make 5 bailer runs to recover wet sand and pieces of packer slip, to work down to 11,135'. Last run no recovery. POOH. Continue to work new bailer (2"x5') to 11,151'. 7-17-07 Continue bailing. Change bailers periodically. Recover pieces of metal and sand. Worked from 11,153' to 11,176' (14 runs). 7-18-07 RD Slickline. RU eline. RIH with freepoint tools. Tag fill at 11,140' RD eline. RU Slickline continue to bail to 11,197' SLM. RD Slickline. RU eline. RIH with the freepoint tool. 7-19-07 RIH with freepoint tools. Test from 10,968' to 11,119'. POOH. Arm string shot. Torque pipe. Fired shots at 11,140'. POOH w/string shot. Shot rod missing. RD slickline. RU Kelly. PU on pipe, free movement. • King Salmon K-12RD Workover Change out of ESP -Operations Summary 7-20-07 RIH with collar locator. No pipe movement, backed off @ 11,022'. POOH w/CCL. Kelly up on drill pipe. Screw back into bumper sub. RU eline. MU string shot. RIH and fire at bottom of 2°d collar on fish. Work pipe while pumping. RIH with stringshot, fire at bottom of the lst DC in remaining fish. POOH with eline. RD eline. Begin POOH with pipe. 7-21-07 TOOH to DC in BHA. No fish recovered. Test BOPs. 7-22-07 Test BOP ,choke manifold valves, VBR Rams, Blind Rams, and function test Accumulator. Pull test plug, install wear bushing. PU BHA, TIH wBHA and drillpipe to 10,475'. 7-23-07 Establish circulation while in the 9-518" csg. CO to 11,126'. Circulate pressure inside the 7". Pump 20 bbl vis sweep, wash over 1St drill collar of fish, pump another 20 bbl vis sweep. Pump 847 bbls of follow sweep. TOOH. 7-24-07 Continue to TOOH. Recover metal and flat guard from ESP in boot basket. MU/PU BHA #16. TIH. Bring on pumps. Rotate DP. Engage fish at 11,079', made 16 rounds on DP. Jar and pump. Very slight returns. RU wireline to tag fill. 7-25-07 MU CCL tool with 1-5/8"jars and spearbar. MU pack off on DP. Install pump in sub and TIW valve on DP. RIH and tag fill at 11,085' (6' inside top DC of fish). POOH, RD eline. RU slickline. Make 7 runs, recovered sandy slush. RD slickline. RU eline, RIH and tag fill at 11,092' (13' inside top DC of fish), POOH. 7-26-07 MU CCL and string shot tool. RIH and work torque in pipe. Fire shot at 11,076'. Work DP. Broke connection with fish. POOH with eline. RD eline. CBU. TOOH. 7-27-07 MU/PU BHA #17. TIH. Attempt to rotate. 7-28-07 RIH to top of fish at 11,079'. Pump 10 bbls of vis pill, continue to wash over fish. Wash down to blades on string mill, attempting to jet out junk around fish. Pump 20 bbl vis pill. Pump dry pipe pill. Establish circulation. Pump 20 bbl vis sweep followed with 850 bbl fluid. No sign of returns on shakers. No flow from well. Pump 25 bbls dry pipe pill. TOOH. ~~..~: r i King Salmon K-12RD Workover Change out of ESP -Operations Summary 7-29-07 Continue to TOOH. Recovered cups of debris, pieces of metal and metal filings from the junk baskets. RU/PU BHA #18. TIH with DP. 7-30-07 Continue to TIH. Circulate, engage fish. Work torque, jar, pump and pull on fish. Continue pattern, no movement on fish. RU eline. MU CCL tool with 1-5/8" spear and spang jars. RIH tag fill at 11,092'. 7-31-07 POOH with eline. MU/PU stringshot tool. RIH to 11,079' WLM. PU 50'. Work torque in DP, fire shot. DP backed off. POOH. RD eline. Circulate, pump 23 bbl dry job. POOH LD DP. 8-1-07 ~' POOH. LD DP. BHA left screw in sub on top of fish. New top offish at 11,077'. RU to test BOPs. Install 2-7/8" slips and blow in window. BOP test passed. P/IJ 2-7/8" tbg. 8-2-07 Continue to RIH with 2-7/8" tbg with GLMs. 34.5 total stands of 2-7l8", 6.5#, L-80 Buttress thread run in hole. MU landing joint and prep to land. 8-3-07 Land hanger in well head (tbg tail at 4504.73'). ND BOP. Install tree and test void. Pull BPV and install TWC, test tree, pull TWC. Release well to production. Demobe rig. 8-4-07 Demobe rig. 8-5-07 Demobe rig. . Page 1 of6 . Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, August 02,20072:26 PM \ '\ <6- OS" To: 'Tyler, Steve L' Cc: Regg, James B (DOA); Buster, Larry W; Harness, Evan; Cole, David A Subject: RE: King Salmon K-12RD ESP WO Sundry #307-114 Steve, et ai, I have spoken with Commissioner Seamount and you have his oral approval to proceed with the new plans. do not need to file an additional sundry. As you note, cover the changes on the 404. Good luck. Call or message with any questions. Tom Maunder, PE AOGCC You Mr::. r'o AUG 0 6 2007 C. r 1\ M ,~ -.J __;".¡N' ..... . ----~--~~-"---,---"----------_._-----~~---_._"-----~.,_._--_._--~-------- From: Tyler, Steve L [mailto:tylersl@chevron.com] Sent: Thursday, August 02, 2007 11:30 AM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA); Buster, Larry W; Harness, Evan; Cole, David A Subject: RE: King Salmon K-12RD ESP WO Sundry #307-114 The proposed depth was based off of what weight of tubing we could safely pull with the crane at a later date. We have no know communication of the 9-%" production csg to surface csg. We do have indication of communication from the 13-%" to the 24". ,-,-,-_._----------- ---------~-,_._>--- From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, August 02,200711:23 AM To: Tyler, Steve L Cc: Regg, James B (DCA); Buster, Larry W; Harness, Evan; Cole, David A Subject: RE: King Salmon K-12RD ESP WO Sundry #307-114 Steve, This is a change to the planned completion for sure. The proposed packer depth is well above the perforated interval. What has led to this depth selection? Are the original annular communication concerns still in play? Thanks in advance for your reply. Tom Maunder, PE AOGCC _._------~~------_.~--_."--- ~--~----_. From: Tyler, Steve L [mailto:tylersl@chevron.com] Sent: Thursday, August 02,2007 11:11 AM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA); Buster, Larry W; Harness, Evan; Cole, David A Subject: RE: King Salmon K-12RD ESP WO Sundry #307-114 Tom After discussing our options with our Oil Team we are wanting to recomplete K-12RD with 2-%" gas lift completion to ±4500' to produce G-5 and Hemlock Benches 1 & 2. We want to have the option to come back, at a later date, and perform a sidetrack (wI Coil Tubing or HWR) off a flow through whipstock to reestablish production from the Hemlock Benches 3, 4, 5 & 6 sand. The well passed a "No-Flow" test after it was converted to ESP in 2002. 80% of the net oil comes from the HB 3, 4, 5 & 6 which is currently isolated by the fish we left in the 7" csg @ 8/6/2007 . Page 2 of6 . 11,079'. Let me know if I need to send you a 403 or if I can summarize our activities on the 404. Thanks -~-_. -_._----" From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, August 01, 2007 4:04 PM To: Tyler, Steve L Cc: Regg, James B (DOA) Subject: RE: King Salmon K-12RD ESP WO Sundry #307-114 Steve, You need to consult the regulations on suspending wells, 25.112 I think. If the well is to be sidetracked, then it is likely that the present penetration will have to be plugged. Given the multiple issues that prompted the workover in the first place, especially the outward communication, it would seem prudent to consider effecting the plugging while you are in the well. Cement cures a lot of problems and should effectively isolate the producing intervals. Please note, I am not directing you all to cement off the producing intervals. You all know much better the future utility of the well and any other issues. The suspension regulations should provide guidance. Call or message with any questions. Tom Maunder, PE AOGCC -~-------------"----------~- ~----_. From: Tyler, Steve L [mailto:tylersl@chevron.com] Sent: Wednesday, August 01, 2007 3:56 PM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA) Subject: RE: King Salmon K-12RD ESP WO Sundry #307-114 I miss spoke. We will be running 4500' of 2-7/8" tbg. The well is a "No-Flow" well. We wasn't planning on adding a plug. But if we are required to we will. ._-,-----~ < From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, August 01,20072:16 PM To: Tyler, Steve L Cc: Jim Regg Subject: RE: King Salmon K-12RD ESP WO Sundry #307-114 Steve, Planning a kill string is prudent. I note that there are open perforations above the TOF. Was this well considered "no-flow"? Has placing some sort of deep plug been considered? According to the regulations, to be suspended some sort of downhole plugging is in place. I don't believe that just running a shallow kill string will satisfy the requirements. Look forward to your reply. Tom Maunder, PE AOGCC -.----.-.----.-. ~---,-------- From: Tyler, Steve L [mailto:tylersl@chevron.com] Sent: Wednesday, August 01, 2007 2:08 PM To: Maunder, Thomas E (DOA) Cc: Harness, Evan; Brandenburg, Tim C; Buster, Larry W; Applewhite, Billy -APRS [contractor] Subject: King Salmon K-12RD ESP WO Sundry #307-114 Tom We had no joy in being able to retrieve the fish in K-12RD @ 11,079'. Our plan forward is to run a 2-7/8" Kill String to approximately 2500' and suspend the well. 8/6/2007 . Page 3 of6 . The well then becomes a future re-drill candidate. Attached is a copy of our proposed diagram. Let me know if you have any questions. Drilling Engineer, Adviser Union Oil Company of California WOffice: (907) 263-7649 WCell: (907) 350-6295 .Home: (907) 696-1837 .Fax: (866) 730-9392 41Email: tylersl@chevron.com 8/6/2007 1°1 I I I I IJ 24" @ 394' 133t8" @2,510' TOC @9300' Bad csg 10,328' 7" Liner @ 10,487' 95/8" @ 10,747' Fish 11,079' To 11,241' osi-Set Plug @ 11,429' tTOC @ 11,419' . RKB to TBG Head = 33.80' Tree connection: GLM @2300' GLM @3800' MS @4500' '$~~~$~$¡S~S¡S¡S~S~S¡S¡S¡S¡S¡SSS¡S¡S¡ ......... .... ·.·····.·····ó··.·.····· .............. . PBTD = 11,641' TD = 11,775' MAX HOLE ANGLE = 42° @ 5800' SIZE 24" 13-3/8" 9-518" T' Liner Tubin: G-5 HB-1 HB-2 HB-3 HB-4 HB-5 HB-6 HB-6 . Trading Bay Unit King Salmon Well No. K-12RD Proposed Completion WT CASING AND TUBING DETAIL GRAllf: CONN II) BTM. 394' 2,510' 10,747' 11,765' TOI' Surf 38' 38' 10,487' 61.0 47 38 K-55 N-80 & S95 P-110 STC/L TC LTC 12.515 8.681 5.920 ISSUES · 13-%" pressure communication to 24' · 13-%" has high rotating hrs. · Bad csg with penetration · Fish covering most ofHB-3 · HB-4 thru HB-6 is not accessible. Fish Details Item OD ID Len th Junk Mill 5 %" I-Yz" 2.75 Junk Basket 4-Ys" l-Yz" 3.64 Junk Basket 4-/'8" I-Yz" 3.63 Bit sub 4%" I-Yz" 2.81 Double Pin Sub 4%" I-Yz" 0.86 Strin mill 5 %" 2" 5.53 Bum er Sub 4%" 2" 7.86 Oil Jar 4%" 2" 11.05 Drill Collars 4 5/8 2-%" 30.64 Drill Collars 4 5/8 2-Yz" 30.82 Drill Collars 4 3/4 2-Yz" 31.01 Drill Collars 4 5/8 2-Yz" 30.98 Screw-in sub 4-%" 2-11/16" 3.36 Zone PERFORATION DATA Btm Amount Condition 10,910' 84 Open in '95. Reperfd 1/02 11,057' 20 Open in '78. Reperfd 1/02 11,175' 105 Open in '78. Reperfd 1/02 11,200' 25 Open in '78. Reperfd 1/02 11,236' 20 Open in '78. Reperfd 1/02 11,330' 20 Open in '78. Reperfd 1/02 11,402' 30 Open in '78. Reperfd 1/02 11 444' 20 Open in '78. , Attempt isolation 1/02 Top 10,826' 11,037' 11,070' 11,175' 11,216' 11,310' 11,372' 11,424' Rotating Hours: 24" Casing - 17.5 hrs 13-3/8" Casing - 755 hrs 9-5/8" Casing - 126 hrs 7" Casing - 19 hrs C:\ternp\Ternporary Internet Files\OLKF\K12RD Current 7-30-07.doc 01122/07 JAR .~-~ .~, SARAH PALIN, GOVERNOR A.I,ASIiA. OILAlWD GAS CONSERVATION COMMISSION 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 June 19. 2007 Mr. Evan Harness Drilling Superintendent - MCBO Chevron North America Exploration and Production 909 West 9th A venue Anchorage, AK 9950 I sCANNED JUN 2 1 Z007 Dear Mr. Harness, The Alaska Oil and Gas Conservation Commission ("Commission") has completed its review of a fire that occurred on a workover unit located on the King Salmon Platform, Trading Bay Unit, Cook Inlet. That fire occurred on June 3, 2007 and has been attributed to a loose high pressure flange on the discharge pump for the hydraulic system, part of the workover unit's power pack. Hydraulic fluid released from the pump was ignited when the spray came in contact with the hot exhaust manifold of the diesel engine, damaging equipment that provides power to the workover unit. No injuries were sustained, and there was no other signiticant damage to the rig or platform. There was also no enviromnental impact associated with this event. The Commission agrees with the findings of both Chevron North America Exploration and Production ("Chevron"), and workover unit owner Cudd Energy Services ("Cudd") as presented to the Commission. ~ 7g~~,o... 2 Cudd 136 was performing a tubing workover on Trading Bay Unit Well K-12RD (PTD 78- and was making up a bottomhole assembly and running it into the well at the time of the fire. Cudd 136 uses two power packs for its well operations; both were damaged in the fire. In response to this incident, Chevron and Cudd conducted investigations and equipment inspections to determine the root cause. Inspections were also performed to identify any needed equipment and procedural modifications that were necessary to prevent recurrence of this incident. The following information was provided to the Commission on June I 1, 2007 documenting the Chevron and Cudd efforts: - "5 Why" Investigation Report (Chevron); - Summary of Accident Investigation (Cudd); - Summary of proposed moditications to the workover unit power packs; - Restart procedure for the Cudd 136 Unit after installation of replacement power packs, including quality control/quality assurance procedures. A Commission Inspector visited the King Salmon platform on June 5, 2007 tq gather information about the incident and confirmed the well was secure. He returned to the King Salmon platform on June 13, 2007 after replacement power packs were installed on Cudd 136 to witness blowout prevention equipment testing prior to recommencement of operations. Equipment moditìcations ·_~ . Mr. Evan Harness June 19.2007 Page 2 of2 and rig up \\cre also inspected b) the Commission on June 13. Blowout prevention equipment tests passed State of Alaska requirements, Equipment moditications and rig up were found to be satisfactory by the Inspector. clearing the way for Chevron to continue vvorkover operations at Well K-I 2RD, The Commission appreciates Chevron's expeditious eHarts to clearly determine the root cause of the incident and report results of the incident investigation. The Commission considers this incident closed and finds no basis for any punitive actions against Chevron or Cudd. Should you have any questions about the Commission's findings, please contact Jim Regg at 907-793- I 236. · I have attached Chevron's 5 why investigation - Cudd should have me their Investigation along with their Start-up procedure today - I will also get a copy to you when' get it - Looks like we should ship Power Pack's to Platform for Rig up 06-12-07 Evan K. Harness Drilling Superintendent MidContinent Business Unit Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501 Office 907-263-7932 Office Fax 907-263-7884 or 907-263-7392 Cell 907-229-3592 Home 907 333-2228 eharness@chevron.com Content-Description: 5 Why report King CUDD Fire.doc 5 Why report King CUDD Fire.doc Content-Type: application/msword Content-Encoding: base64 1 of 1 6/15/2007 12:59 PM ·, . "FIVE WHY" Investigation Report Incident Number: Business Unit Location: Facility Name: MCBU Alaska KinQ Salmon Incident Date: Type of Process: Type of Equipment: 6/3/07 Hydraulic Dower DumD Team Members: Ken Lucas, Sandy Reynolds, Robert Brister, Brannon Domangue Incident Description: Hydraulic power pack caught on fire. FIVE WHY'S 1. Wh did "above" ha en? Hydraulic oil leak contacted exhaust. Verification Visual and post investi at ion e seal failure. ins ection ins ection ins ection Root cause What OE Tenets were broken? Maintain integrity of designated systems ROOT CAUSE S: What were the root causes of your incident? 1 Inadequate quality control or inspection, leading to loose bolt on the pump flange housing For categories, see next page) Basic Cause Category: Inspection I Quality Control RECOMMENDATION(S): (List actions that will be taken to eliminate the root cause of the incident) 1 Contractor to review quality control procedures at Due Date: Owner: fabrication shop. (SiteSafe action item assigned to Evan Evan Harness for follow-up with Frank Breaux at CUDD) Harness 2 Contractor to establish a procedure for more thorough Due Date: Owner: inspection when receiving new equipment. (SiteSafe action Evan item assigned to Evan Harness for follow-up with CUDD Harness field supervisors) . ",-", Cudd Information will follow up with another with Cudd's Quality Control/Quality Assurance Plan Evan K. Harness Drilling Superintendent MidContinent Business Unit Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501 Office 907-263-7932 Office Fax 907-263-7884 or 907-263-7392 Cell 907-229-3592 Home 907 333-2228 eharness@chevron,com Content-Description: proposed mods. doc . proposed mods. doc Content-Type: application/msword Content-Encoding: base64 ContentøDescription: fire causes. doc fire causes.doc Contentø Type: application/msword Content-Encoding: base64 ] of I 6115/2007 ]2:59 PM .. ,,--,.' .--./ To Whom It May Concern: The purpose of this letter is to inform Mr. Evan Harness of the results of an accident investigation conducted by myself, Mr. Scott Cunningham, and Mr. Lance Benson. The investigation was initiated to determine the cause of a fire that occurred on the CVX King Salmon platform at 0700 hours June 3, 2007. The power pack was shipped to the shore base and the unit was visually inspected and a portion of the hydraulic system was disassembled. The disassembly of the hydraulic system revealed that one of the high pressure flanges on a 66 gallon per minute pump had blown the o-ring from its groove in the flange. The cap screws on this flange were found to be loose. This resulted in 66 gallons per minute of Environ 32 hydraulic oil being atomized and sprayed onto the engine of the power unit. The exhaust manifold of the diesel engine then served as the ignition source that resulted in the fire. After the first power pack ignited the burning hydraulic oil sprayed onto the second power pack damaging the wiring, electronic system and doing superficial damage to some of the hydraulic hoses and gauges. There were no other discoveries made that lead any of the members of our investigation committee to believe that there were any other contributing factors to this incident. Although this incident is regrettable it should also be noted that no one was injured and no environmental damage was incurred. Kindest Regards, Bobby Bray Regional Manager HWO Cudd Energy Services Office 985-580-1177 Ce11281-687-9753 Email BBray@Cudd.com . ._v . .......-/ To Whom It May Concern: The purpose of this letter is to outline the proposed modification to the hydraulic power packs that Cudd Energy Services currently is using on the King Salmon platform. These modifications have been made to the power units to ensure that there is not a reoccurrence ofthe incident that occurred June 3, 2007. 1- A steel splash guard has been installed isolating the hydraulic system ITom the engine compartment. 2- The wind walls have been notched so that the doors can be closed at all times. This will prevent the spraying of oil from one power pack onto another in the event of a leak. 3- All cap screws in hydraulic system have been removed, coated with loctite, reinstalled and torqued to spec. 4- Additional insulation has been added to the exhaust system. 5- The 10" line that equalizes the level in the two hydraulic tanks has been lengthened from 4' to 1 0'. This allows the two power units to sit further apart on the platform. 6- The diesel fuel lines have been lengthened allowing the fuel tanks to be placed further from the power units. 7- A remote emergency kill manifold has been constructed. This allows the power units to be shut down ITom a remote area on deck. In addition to the above the hydraulic hoses that connect the unit to the power pack have been lengthened by 75', allowing further setback from the well bay. Kindest Regards, Bobby Bray Regional Manager HWO Cudd Energy Services Office 985-580-1177 Cell 281-687-9753 Email BBray@Cudd.com e. ,_.~ Cudd QCQA Plan Evan K. Harness Drilling Superintendent MidContinent Business Unit Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501 Office 907-263-7932 Office Fax 907-263-7884 or 907-263-7392 Cell 907-229-3592 Home 907 333-2228 eharness@chevron.com Content-Description: TestProcedures_5.pdf TestProcedures _ 5.pdf . Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: TestProcedures _l.pdf . TestProcedures _l.pdf .. Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: T estProcedures _2. pdf . TestProcedures_2.pdf . Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: TestProcedures_3.pdf 'TestProcedures _3.pdf . Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: TestProcedures_ 4.pdf > TestProcedures_ 4.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 6/15/2007 1 :53 PM i'\..v. Communication has been good. Thank you and the personnel at King Salmon platform for accomodating our Inspector yesterday. Please provide 2 things: 1) startup plan for the rig; 2) a summary of any investigation/root cause analysis findings. I believe our inspector has made arrangements to witness the next BOPE test. Jim Regg AOGCC Harness, Evan wrote, On 6/6/20076:10 AM: Mr. Regg I am sorry to be communicating by email but it is the best ¡ can do - The contact information below is now correct with a new cell phone - Are you currently OK with the information you have on K12rd _ Do I need to do something additional Evan K. Harness Drilling Superintendent MidContinent Business Unit Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501 Office 907-263-7932 Office Fax 907-263-7884 or 907-263-7392 Cell 907-229-3592 Home 907 333-2228 eharness(â¿chevron .com Jim Regg <¡1m regg(Z~admin.state.ak.us> Petroleum Engineer AOGCC 100 6/6/2007 12:06 PM K\::: We are interested in the results of your investigation. Please keep us informed. Also, we will be sending an inspector to the King Salmon platform to gather some information. Jim Regg AOGCC Mr. Regg On our King Salmon operation (K-12rd PTD # 78-57) - We have had an equipment fire (Sunday AM. 06-03-07) - The fire has damaged Both of the hyd power packs providing power to the Hyd Workover unit _ We currently have no capability to move pipe with the Hyd workover unit (ùiltZ (34) 14w ä Uttei-- t Harness, Evan wrote, On 6/4/20077:36 AM: We were in the process of making up our BHA - Had one stand (62') 4" D. P. made up - DSM's on site have Secured the well- We have the BHA + 1 stand of D.P. made up - We have lowered the BHA to Put 4" D.P. tube across the stack with a safety valve installed - We are currently cir across the top of the well with an AVG loss rate of 1.5Bbl/hr which is about what we have been seeing I will be out of office today but will be available on Mobil - My temp cell phone number = 907-240-1163 Evan K. Harness Drilling Superintendent MidContinent Business Unit Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501 Office 907-263-7932 Office Fax 907-263-7884 or 907-263-7392 Cell 907-229-3592 not working Home 907 333-2228 eharness@chevron.com Jim Regg <jim regg(äiadmin.state.ak.us> Petroleum Engineer AOGCC I of I 6/4/2007 II: 13 AM ..,.,K "alve . '1Bu.. K-J 2-~ Mr.Regg: f7!) j t ß- 067 As per Lou Gramaldi we replaced our annular K.R. valve that was sticky on our BOPE test 6/13/07 on our first trip out of the hole.We also changed out the actuator valve. We successfully functioned the annular several times. THANK YOU BOB FARRELL DRILL SITE MANAGER MIDCONTINENT ALASKA BUSINESS UNIT RIG 907-776-6698 CELL 907-252-8696 FAX 1-866-914-1452 ~~ J1J~ ~ \; 2\)t)1 I of 1 6/18/20078:48 AM . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P. I. Supervisor DATE: June 06,2007 /78-057 FROM: Lou Grimaldi Petroleum Inspector SUBJECT: Platform Inspection King Salmon ,<_ I ~ Chevron June 6. 2007: I made an inspection of the King Salmon platform and CUDD Snubbing unit which had recently had a fire on it's Hydraulic Power Unit (H.P.U.). I traveled out to the platform and met with Floyd Hurt (Chevron) who was on duty at the time of the incident and Ken Lucas who was the night man. The situation is secure out there. They are circulating over the top to keep the hole full and have an active pit watcher at all times, fluid loss is approximately 1.5 bbl/hour. The damaged HPU's are on the beach being repaired (if possible) and Chevron is doing an accident investigation. Chevron immediately initiated an investigation and has taken many pictures of the damaged HPU's that were made available for review. From the pictures I looked at it appears that a flanged hydraulic fitting had an "0" ring failure that allowed the hydraulic fluid to spray on the turbo charger. I looked at the Toolpushers morning reports for that day and the previous day, it was noted that a visual inspection for leaks was made. The new power packs are due to be up here Friday. The situation with the two power packs being side by side was that they were using both at the same time for faster trip times, as I understand it this is common to "marry" the two HPU's to accomplish this. The new power unit's coming up will be of the same design but are supposed to have a "splash shield" incorporated to help keep this type incident from occurring again. I plan on catching their BOP test which is due as soon as they are ready to go. I also asked them to send you a start-up plan by Thursday afternoon. Attachments: Cudd unit King Salmon a 06-05-07 LG.jpg Cudd unit King Salmon b 06-05-07 LG.jpg Cudd unit King Salmon c 06-05-07 LG.jpg Confidential · . ~1r~1rŒ ffiJ~ ~~~~[{~ / / AI,ASIiA. OIL AlVD GAS / CONSERVATION COMMISSION ¡ SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager Chevron Alaska PO Box 196247 Anchorage, AK 99519-6247 Re: McArthur River Field, Hemlock Oil Pool, K-12RD \1 q, - ob7 Sundry Number: 307 -114 Dear Mr. Brandenburg: SG 1NNED APH 2 3 2007 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may me with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this J!i day of April, 2007 Enc!. 1. Type of Request: I?i 1-11d'{i:TEOFAlASKA ~C\'~I. K' RECEIVED ALA Oil AND GAS CONSERVATION COM ION Kr~1 APPLICATION FOR SUNDRY APPROVALS \'( APR 0 4 LOOl 20 MC 25.280 Operational shutdown 0 Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development 0 '" Stratigraphic 0 Suspend 0 Repair well 0 Pull Tubing 0 ./ Perforate 0,' Waiver A h ' Other Stimulate 0 Time Extension 0 nc or age Re-enter Suspended Well 0 5. Permit to Drill Number: Exploratory 0 78-57 V Service 0 6. API Number: 50-733~ Abandon 0 Alter casing 0 Change approved program 0 2. Operator Name: Union Oil Company of California 3. Address: 7. If perforating, closest approach in pool{s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? Yes 0 9. Property Designation: ADl 18777 ./ 12. Total Depth MD (ft): 11,775' 8. Well Name and Number: k~ JO\SÇ, -0 \ PO Box 196247, Anchorage, AK, 99519-6247 Casing Structural Conductor Surface Intermediate Production Liner Total Depth TVD (ft): 9,867' Length No 0 K-12RD 10. KB Elevation (ft): 11. Field/Pool{s): 100' AMSl McArthur River Field, Hemlock PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 11,641' 9,737' Plugs (measured): 11,419' þ{,;¡¿/k-K~~ '/Ø-Þ1 Junk (measured): Size MD TVD Burst Collapse 2,472' 13 3/8" 10,709' 95/8" 1,288' 7" 2,510' 2,436' 3,090 1,540 10,747' 11,775' 8,981' 9,867' 6,870 4,760 10,800 11,390 Tubing MD (ft): 10,074 NA 41/2" , 12.60 ppf Packers and SSSV MD (ft): Tubing Grade: N-80 Perforation Depth MD (ft): 10,826'-11,402' Packers and SSSV Type: Perforation Depth TVD (ft): 9,052' - 9,535' Tubing Size: NA Date: 14. Well Class after proposed work: Exploratory 0 Development 16. Well Status after proposed work: Oil 0 / Gas 0 WAG 0 GINJ 0 0' Service 0 0 Abandoned 0 0 WDSPL 0 13. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 15. Estimated Date for 5/21/2007 Commencing Operations: 17. Verbal Approval: Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Timothy Brandenburg Title Drilling Manager Plugged WINJ Jim Rose, 907-263-7637 Signature Date L/ - .3 -D'-:::;- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ Plug Integrity 0 BOP Test ~ Mechanical Integrity Test 0 Location Clearance 0 Other: '3>0C:ö~, \6.(:§? ~">~ \-JO~\<N::> -\-<::"":>-\--~~U\~~ 'V--ih~ \,-\ ~~'\ So O~ ~\~<:"\'f'~ \Ñf(. \\ ~(..\_\~ct.~~ t~e-A Subsequent Form Required: 4()L\ APPROVED BY THE COMMISSION APR 2 0 2007 -/6'·7 SUbmit~~~/07 Date: Re: TBU K-13RD2 . . ~ l$..-oS Thanks Jim. As I looked at the file for K-12RD, I found the choke drawing you have included. It appears that a lot of the approvals to employ the hydraulic equipment were done for work in that well. Plan on having your Company Man contact the Inspectors for the BOP test. Since this is the first rig up in a while we will likely be out for a witness. It would be appreciated if a shell test could be conducted on the equipment prior to calling the Inspector out. Call or message with any questions. Tom Maunder, PE AOGCC Rose, Jim -Contractor wrote, On 4/17/2007 4: 11 PM: Tom see below for answers., Jim Jim, I am reviewing the proposed workover application. Sorry for the application getting misplaced. Is 4/21 still the proposed start date? nope...looks like we wjJ] be delayed until May 3 to start rigging up. Has the equipment started moving to the platform? Not yet. 1. Will the rig up largely be similar to what has been used before and the line diagram dated Dee 7, 2004 (attached)? To IllY knowledge, the configuration is genera!]y the same (I wasn't here at that time). I think we wiH use a different brand BOP stack and maybe a couple other small differences. In any case. it wiH meet AOGCC requireruents. 2. You do not propose a BOP test pressure. Looking into the file 3000 psi was the test pressure used last time. 3000 psi is what I propose as a test pressure. Although the stack is shown in a "3000 psi configuration", I i-ailed to mention it. '['hanks for pointing that out. 3. On your choke diagram, there is a "new line". It appears to be a bypass line located at the top ofthe drawing. Would you comment please? According to my understanding, this is the same manif()ld that is always used on the kíngESP workovers and the ]ine is a pank line that vents straight up. 10f2 4/18/20077:33 AM Re: TBU K-13RD2 . . 4. Will the operations be conducted according the general ESP workover procedure developed after the workover incident a few years back? Same genera] procedure. Chevron continues to make effÖrls to improve procedures that'Nill minimize exposure to problems. Thanks in advance. I look forward to your reply. Tom Maunder, PE AOGCC 20f2 4/18/20077:33 AM . . Chevron === Timothy C Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com March 30, 2007 Commissioner Alaska Oil & Gas Conservation Commission 333 W. ih Avenue Anchorage, Alaska 99501 Re: King Salmon, Well K-12RD, APD 78-57 RECEIVED APR 0 4 2007 Alaska Oil & Gas Cons. Commission Anchorage Dear Commissioner, / Chevron intends to work over the above referenced well to replace a failed ESP and re- perforate. Attached is a Planned Operations Summary, BOP equipment layout, current well sketch, and form 10-403 in duplicate. Please review and approve the Application for Sundry Approvals at your earliest convenience. Please contact Jim Rose at 907-263-7637 or myself at 907-276-7600 if you have any questions. Sincerely, _ .¿~¡ 2 -6 c jS_~.q Timothy C. Brandenburg ß Drilling Manager Attachments: K-12 RD Summary of Planned Operations BOPE layout drawings Form 10-403, Application for Sundry Approval in duplicate Current Well Sketch Cc: File Union Oil Company of California I A Chevron Company Page 1 of 1 Chevron === . . King Salmon Platform Well K-12RD ESP Replacement Program 2007 K-12RD Planned Operations Summary March 30, 2007 Objective: Remove failed ESP. Remove abandoned packer. Reperforate. Install new ESP. 1. Blow down gas lift system and prepare well for arrival of rig. 2. MIRU HWOU over K-12RD. Commission and test all systems. 3. Install and test BOPE 4. TOOH with failed ESP. 5. TIH with DP and mill / recover abandoned packer assembly. 6. Clean out well bore to PBTD at 11,419' 7. Re-perforate existing perforations in Hemlock Bench 2. 8. Run new ESP assembly 9. Land tubing, remove BOPE, tree up, and test equipment. 10. Release HWOU. Top of drill deck A 2 1/16" 5M HCR Valve B :2 1/16" 5M Manual gate valve C 2 1/16" 5M Manual gate Kill line D 21/16" 5M Manual gate Kill line E 3 118" 5M Target Tee F 21/16" 5M Target Tee G 135/8" 5M x 11" 5M DSA H 11" 5M x 13 5/8" 3M CIW DCB TH I 135/8 3M x 13 5/8 5M DSA J 13 5/8" 5M x 13 5/8" 5M 1# 13 Hub Gra lock Hub 3/3 WÆI'lð!109ntshare1 \Groups\DRILLlNG\Platforms\King_ Salmon\K-12RD\K-12RD ESP _2007_ AFE R7010\Regulatory\King BOP Stack .xlsJAR K-12RD 3 1/8" 5000 PSI Choke Manifold 2" to Production Separator or Gas Buster Bypass 3" 5M National Ball Valves II 2", 5M, Flanged, Hose From Choke Line Side of Drilling Spool RKB to TBG Head::: 33.80' T ee con nee 13 3/8" @2,510' 2 3 10,350' 7" Liner @ 10,487' 95/8" @ 10,747' CASING ANI) TUlUNGI)ETAIL T' Liner BTC/L TC LTC Tubing: 4-1/2" 3.958 N-SO BTC 12.6 JEWELRY I)ET AIL 2281' 4089' 5321 ' 6113' 6660' 7210' 7702' 8198' 9178' 4-112" FSO-2 GLM C/W IV:." 4-1/2" FSO,2 GLM C/W 1112" VALVE 4-1/2" FSO-2 GLM CIW 1112" VALVE 4-112" FSO-2 GLM CIW 1 112" VALVE 4-112" FSO-2 GLM C/W 1 112" 4-1/2" FSO-2 GLM CIW 1 W' 4-1/2" FSO-2 GLM C/W 1 112" VALVE 4,1/2" FSO-2 GLM C/W 1 112" 4-1/2" FSO,2 GLM C/W 32/64 ORIFICE 2 Centrilift ESP Pump & MQtor ERA Length=86.21' 10,074' 3 4.875 15' 4,1/2" tbg stub, LocatotSeaJ Assy w/20' of seals. Spaced out 3' above pkr Baker Model "FE-I" Pern:¡Pk:r, size 192-60 wI! 0' SBE. Set on E/line. PT t/2000 psi 10,331' 4 6.00 10,350 4 FISH: l-W' Orifice Valve E/liine work: Fill tagged at 11458' with 1-11/16" OR/CCL 1/15/02 Set Posi-Set plug @ 11,429'. Dump bail TOC @ 1 Post job production results indicates plugfailed. Zone HB-1 HB-2 HB-3 HB-4 HB-5 HB-6 HB-6 20 Open in '78. Repe~d 105 Open in '78. Repe~d 1/02 25 Open in 1/02 20 Open in '78. Repe~d1/02 20 Open.in '78.Repe~d1/0:2 30 Open in '78, Reperf'd 1/02 20 Open in '78. Attemptisolation 1/02 11,424' 11,444' PBTD::: 11,641' TD::: 11,715' MAX HOLE ANGLE::: 42° @ 5800' C:\Documents and Settings\roseji\Desktop\K-12RD\K-12RD wen Program 012207\K12RD WSketch Actual 012207.doc JAR 1. Operations Abandon U Repair Well U Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator Union Oil Company of California Name: 3. Address: PO Box 196247, Anchorage, AK 99519 Plug Perforations U Perforate New Pool 0 Perforate 0 4. Current Well Class: Development 0 Stratigraphic 0 " 'c:CS MAR 2 ll/~D N.'k, Oil.tl ;] 2005 \I Ga, C 4.. on,. CtJ . StimulateU Other l.:J R../Iii'ed ~1J"Jon Waiver 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: Exploratory 0 78-57 Service 0 6. API Number: 50-133-20156-01 9. Well Name and Number: K-12RD 10. Field/Pool(s): TBU/Hemlock Pool STATE OF ALASKA ALA5. )OIL AND GAS CONSERVATION COMM, JION REPORT OF SUNDRY WELL OPERATIONS 7. KB Elevation (ft): 100' AMSL 8. Property Designation: King Salmon Platform 11. Present Well Condition Summary: Total Depth measured 12,250 feet true vertical_10, 151 feet Effective Depth measured 12,170 feet true vertical 10,100 feet Casing Length Size MD Structural Conductor 393' 24" 393' Surface 2510' 13-3/8" 2510' I ntermed iate Production 10747' 9-5/8" 10747' Liner 1278' 7" 11765 Plugs (measured) 11 ,429 Junk (measured) n/a TVD Burst Collapse 393' 2429' N/A 3090 psi N/A 1540 psi 8973' 6330 psi 9859' . ,~) ItI '2 08t60 psi SCANNE.D MAR r..~ ti .. OJ 3810 psi 7020 psi Perforation depth: Measured depth: 10,826 to 11,444' True Vertical depth: 9,048 to 9,570' Tubing: (size, grade, and measured depth) 4-1/2", 12.6 ppf L-80 IBTC @1 0,114' Packers and SSSV (type and measured depth) Baker Model FB-1 Perm Pkr @ 10,350' 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 64 2137 1205 311 5353 105 15. Well Class after proposed work: Exploratory n Development I-Il 16. Well Status after proposed work: Oil0 Gas 0 WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl Tubing Pressure 280 85 Prior to well operation: 162 Subsequent to operation: 240 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Service n x GINJ 0 WINJ 0 WDSPL 0 Sundry Number or N/A if C.O. Exempt: 304-482 Contact Larry Buster 263-7853 Printed Name Timothy C. Brandenburg --7' Signature?' ~) C- !< // /- J (/' Title Drilling Manager ----- - '-=-'".¿¿ - /-1' - L/ Phone 907-276-7600 Date 3/16/2005 RBDMS BFL;;MI 2 2 2005 OR\G\NAL Form 10-404 Revised 04/2004 Submit Original Only UNOCALti: L 2,510' 13 10,350' 10,487' 10,747¿_ 2 3 7 8 9 10 11 12 ~ G-5 -- 8-1 8-2 8-3 8-4 ...,__.............._ n. ._. ,¡". ',""M""'" ·..._;;··:;·;;;;·:;;r·~ 8-5 A ßtll'j'~ "':lIID'l :]" m[( ··I·IIIII·'····~~" PBTD @ 12,170' TD @ 12,250' Hole Angle = 42 degrees @ 5800' T'thnical Schematic Trading Bay Unit, K-12RD Actual Completion 2/12/05 last revised 03/15/05 (DED) Unocal Alaska Casing and Tubing Detail SIZE WT GRADE CONN ID TOP 13-3/8" 61 K-55 12.515 38' 9-5/8" 47 N-80 & S95 STC/L TC 8.681 38' 7" Liner 38 P-11 0 LTC 5.92 10,487' ~ Tubina: 4-1/2" 12.6 Jewelry No. Death 34.75' 1 2,287' 2 4,089' 3 5,321' 4 6,113 5 6,660 6 7,210' 7 7,702' 8 8,198' 9 8,7231 10 9,187' 11 10,074 12 10,075' 13 10,331' 14 10,350' 8TM. 2,510' 10,747' 11,765' N-80 SC ISTC 3.958 35 10,074' ID Item Description 4-1/2" CIW Tubing Hanger 3.833 GLM FSQ-2 W/ 1-1/2" Valve #1 3.833 GLM FSO-2 W/ 1-1/2" Valve #2 3.833 GLM FSO-2 W/ 1-1/2" Valve #3 3.833 GLM FSO-2 W/ 1-1/2" Valve #4 3.833 GLM FSO-2 W/ 1-1/2" Valve #5 3.833 GLM FSQ-2 W/ 1-1/2" Valve #6 3.833 GLM FSO-2 W/ 1-1/2" Valve #7 3.833 GLM FSO-2 W/ 1-1/2" Valve #8 3.833 GLM FSO-2 W/ 1-1/2" Valve #9 3.833 GLM FSO-2 W/ 1-1/2" Valve #10 5-1/2" EUE Pin x 4-1/2" IBTC Box Discharge Pressure Sub Centrilift ESP Pump & Motor BHA. Length = 86.21' 15' 4-1/2" cut tbg stub, locator seal assy w/ 201 4.875 of seals. Spaced out 3' above packer. Baker Model FB-l Perm Pkr, size 192-60 w/ 10' 6 SBE. Set on E/line. PT t/ 2000 psi FISH: 1-%" Orifice Valve Fill tagged at 11458' with 1-11/16" GR/CCL 1115/02 Set Posi-Set plug ~ 11,429'. Dump bail TOC @ 11,419' Post job production results indicates plug failed. Perforations Zone Top Btm Amount Condition G-5 10,826' 10,910' 84 Open in '95. Reperfd 1/02 HB-1 11,037' 11,057' 20 Open in '78. Reperfd 1/02 HB-2 11,070' 11,175' 105 Open in '78. Reperfd 1/02 HB-3 11,175' 11 ,200' 25 Open in '78. Reperfd 1/02 HB-4 11,216' 11,236' 20 Open in '78. Reperfd 1/02 HB-5 11,310' 11,330' 20 Open in '78. Reperfd 1/02 HB-6 11,372' 11,402' 30 Open in '78. Reperfd 1/02 HB-6 11 ,424' 11,444' 20 Open in '78. Attempt isolation 1/02 1/31/05 ,) Spotted pill in well K-12 while working orf'.K-1. Pumped 10 bbls·saturated salt spacer, 30 bbls sized salt pill and 10 bbls saturated salt spacer. Closed annulus as pill calculated to be across perforations. Closed annulus and squeezed pill into perforations. Maximum pressure was 1900 # and 1400 # right after shutting down. Set BPV in hanger. NU riser, BOPE, kill line and choke line. Ready to pick up test joint at crew change. 2/1/05 Finish testing Koomey. PU and make up 4-1/2" test joint, TIW valve and Kelly hose. Closed variable pipe rams and test. Test valves. Pulled landing joint and 2-way check valve. Installed BPV. Installed landing joint. 2/2/05 Continue to try and to attain a high pressure test with no luck. 2/3/05 Pull test plug up to window. Broke out test joint and set back. Cut ESP cable just above cannon clamp. Added two super bands to hold cable. Pick up RTTS packer and run through jack. Slack off and set packer at 144' below tubing head. Close pipe rams and test RTTS to 500 # for 15 minutes. Release from RTTS packer. POOH with running tool. ND BOPs. ND riser. Inspect tubing spool hanger profile and find bad vertical scarring to severe to repair. 2/4/05 MU new tubing head with DSA on deck. Lower tubing head spool and riser XO into well bay and torque up. NU BOPE. Test blinds, inner choke valve and RTTS to 300 psi low. Test annular, pipe rams and inner and outer choke valves. 2/5/05 Test kill line valves and floor valves. Released RTTS and set in slips. With annulus open to production pump 5.5 BPM 3% KCL with Cudd pump the long way. Break out Kelly. POOH with RTTS and LD same. POH standing back ESP completion, pipe condition good. 2/6/05 POOH to first slice. POOH standing back 4 1/2" completion. No exterior corrosion noted and no scale inside noted. No Norm above background noted. 2/7/05 POOH laying down ESP assembly. Prepare ESP equipment for backload. 2/8/05 Cleaned tools out of work areas. Spotted gas lift mandrels and strapped. Pulled ESP cable through sheave. PJSM on ESP pump pick up. PU ESP pump assembly, run chemical injection and Phoenix sensor lines. 2/9/05 RIH with ESP assembly, no weight loss noted as pump and protectolizers entered in 9-5/8" casing. RIH with 4-1/2 tubing and ESP cable. 2/10/05 Continue RIH with ESP cable. K-12RD (AFE 163357) morning report summary, CONFIDENTIAL: last revised 3/16/2005, Page 1. 2/11/05 ) ) Continue RIH with ESP assembly. PU hanger, MU and orient to land in wellhead. Splice pig tail connector to intruder plug in. Install chemical injection check valves under hanger. Test ESP cable, center above BOP stack for ru nning hanger. 2/12/05 Run and land tubing hanger. Run in lock downs. Test tubing hanger seals to 3000 psi for 10 min. Remove hydril and double gate from cellar and unbolt on drill deck, ND mud cross, riser and XO spools. NU tree, new flow lines. Test void and neck seals 5000 psi (OK). Test tree 250 psi low and 5000 psi high. Cudd crew continuing cleaning and getting tools out of window, basket and sub. Loading boat with equipment to go to beach. 2/13/05 Cleaning and prepping equipment for RD. 2/14/05 Continue to RD Cudd unit. 2/15/05 Continue to clean platform. 2/16/05 Continue clean up of King. SIMOPS walk around with production foreman. K-12RD (AFE 163357) morning report summary, CONFIDENTIAL: last revised 3/16/2005, Page 2. Re: K-12RD workover ) ) Subject: Re: K-12RD workover From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Wed, 02 Feb 2005 07:29:36 -0900 To: "Harness, Evan" <eharness@unocal.com> f7,@~Q57 Morning Evan, Thanks for keeping me in the loop. Sounds like there are some interesting issues with the wellhead on K-12RD. It looks like you and your colleagues are pursuing the various options that will allow you to get a test. RTTS with storm valve is a logical next choice. Did Donnie forward my email from last night?? Call or message with any questions/comments. Tom Maunder, PE AOGCC Harness, Evan wrote: Tom we have been unsuccessful in getting a good BOP test on King K12rd - Looks like we are leaking past the Test Plug - We are currently Mobilizing a Storm valve & Packer from HOWCO - Planning to set Storm Valve + Pick up stack and check out Seal area in wellhead - After evaluation of the Seal Area and Lock Down pins our plan will either be to Test against the RTTS & Storm valve or if we can identify & fix issue with Seal area in wellhead re-Iand the test plug & pressure test against the test plug - Currently the annulus is on a very slight vacuum - I am in Office this A.M. (if you do not get me at desk call cell phone) - PIs call if any questions - I will also try and tag base with you Thanks Evan K. Harness Drilling Superintendent Unocal Alaska Office 907-263-7932 Office Fax 907-263-7884 Cell 907-229-3592 Home 907 333-2228 SCANNED FES 0 220GS 1 of 1 2/2/2005 8:09 AM Re: King Salmon K-12 BOP test ) ) l\'!'rþ- 0.5 q Subject: Re: King Salmon K-12 BOP test From: STMaunder@aol.com Date: Wed, 02 Feb 2005 01 :46:45 -0500 (EST) To: fowlerd@unocal.com CC: tom - maunder@admin.state.ak.us Don, Sorry for the confusion on the eddress. What you propose is acceptable. Plan on testing the blind rams when you get out of the hole. With regard to the damage to the tubing hanger you mentioned, please keep myself and Jim Regg informed as to how the remainder of the tubulars look. Please call or message me tomorrow with any questions. Tom Maunder, PE AOGCC 1 of 1 2/2/2005 8:09 AM Re: K-12RD BOP Test Procedure ') ) Subject: Re: K-12RD BOP Test Procedure From: Thomas Maunder <tom - maunder@admin.state.ak.us> Date: Tue, 01 Feb 2005 09:38:08 -0900 To: "Buster, Larry W" <lbuster@unocal.com> CC: "Harness, Evan" <eharness@unocal.com>, "Brandenburg, Tim C" <brandenburgt@unocal.com>, Jim Regg <j im _regg@admin.state.ak.us> \1)~, - 0&1: \ Larry, Evan and Tim, Your proposal is acceptable given what you have accomplished in preparation to pull the tubing. Although you have identified some leak path through the hanger system, your BOP is obviously holding the 800 psi. Since the well is no-flow and you have spotted a pill and circulated oil from the wellbore, I concur with your plan forward. Tom Maunder, PE AOGCC Buster, Larry W wrote: Tom, As per our discussion of this morning, we are unable to pressure up on top of the K-12RD (Sundry Number 304-482) tubing hanger to test our BOP. We are pumping fluid past the hanger at approximately 1.5 bpm and 800 psi. We feel the leak is either past the hanger seals or thru one of two chemical injection ports. The well is a no-flow status well and is taking fluid slowly (3% KCL) to keep full. The well has been circulated clean with 3% KCL fluid and a 30 bbl sized salt LCM pill has been bullheaded across the open perforations. In order to exact a BOP test and not R/D the BOP riser on a leakingtub!ng hanger, we propose the following: Pull the ESP hanger off seat and lay it out. Make up a test plug onto the 4-1/2" tubing string and re-Iand the same. Test the BOPE as per procedure. Thank You for your advise and consideration in this matter. Regards, *Larry Buster* Drilling Engineer Unocal Corporation 909 West 9th Avenue Anchorage, AK 99501 Tel: ( 907 ) 263 - 7853 Cell: (907) 250-0374 Fax: ( 90 7 ) 2 6 3 - 7 8 84 Ibuster@unocal.com 1 of 1 2/1/20052:25 PM Re: HOPE Proposal ) 'é ._-')\t \) :J 'dO \ - 0 <.) <:; '"" \{- \ ~,Q.. \) \ \ % -O~( Cx¿"e. \û.. \ ç.:-, \ <è \1 w. () Subject: Re: BOPE Proposal From: Thomas Maunder <tom- maunder@admin.state.alcus> Date: Thu, 16 Dee 2004 07:50:09 -0900 To: "Buster, Larry W" <lbuster@unoea1.com> CC: "Harness, Evan" <ehamess@unoea1.com>, Jim Regg <jim_regg@admin.state.ak.us> Larry, Sorry I did not get back to you sooner with regard to the proposed diagram for the HWO rig up on King. Your proposal does greatly reduce the number of connections and potential leak spots. I had done some research on workovers with HWO done in late 2002 and the proposed rig up is similar. 20 AAC 25.285(e) (6) stipulates that kill and choke lines be assembled without hammer unions. (h) of that regulation allows the commission to approve a variance if an equally effective means of well control is provided. The wells proposed for workover are artificially lifted and K1RD2 has been determined to be "no flow". Well pressures that the equipment would likely see should be low and prior to work being performed the equipment wilL be function pressure tested accQrding to the regulations. Your proposed equipment is acceptable. Please advise how the schedule is looking. The initial BOP test will likely be witnessed, so please have your Company Rep stay in touch with the Inspectors (907-659-2714) . Tom Maunder, PE AOGCC Buster, Larry W wrote: Tom, We have worked up a proposed BOPE diagram for the CUDD HWO on the King Salmon Platform. I have attached the diagram for your review. As you can see, the proposal eliminates chicksan hard line in the critical flow paths and uses rotary and circulating hoses. Also, the Choke Manifold in the system is a unocal owned skid mounted unit. I have attached a diagram of this manifold. «unocal king salmon circdrawing one mud pumps rev1.jpg» «KS manifold. xIs» Regards, Larry Buster Drilling Engineer Unocal Alaska SCANNED DEC 1 6 2004 1 of 1 12/16/20047:51 AM -'t. ( , 1M ~ '., ! ' ~ -'1. ' 1f¡¡ I ~ " I' I. '~Ui~,'~~,-.~r~ ..- ",'-' ~"t" ". ~ ~ . r,r.ir~ HIMP ' ' .". ....~.. :r, 1Sm W~ "0 -, -~ 1 .~ , . -", ! ;. ' " ~; f : \. t ' , ; ~ ~ I ~ I ' ~ -4" 1¡~ 1 OCt Hf/III! i 10 bht Trip Tri" ~ .. fiF 'oP ' "" ~ ..-". r CutnJIICk W'mis Hdum '-'''' ~ H~( \~ Y.. RJr""" 1)c1WR trtl.M"! ' I , Hkcd Otf'l.íw .~.. I To d.. no.,r Z. 5!1'R2 Wcw , ¡ X1"~' -¡. , ~ ,"~øUry Ie en,. Cflœf¡m HOan ~,1,~ I~W- \, , ,n,~ -.'- :1,11 Cntnlr.cl:' W¡IY 4":)..:-/ t.MN'I fl' I.P :'1,- "1-- .Þ~::~~ ' -- , T,;"'............. "01 \ 2~ Camw Ryll " """rèr,~, , _.;;-- ~';'~F'" C1!Þke U... ." I . 4"'~ V.hell unocal king salmon circdrawing one mud pumps revl.jpg (JPEG Image, 100lx747 pixels) fiB" _..~-=~~- ~mt ~: '~?f' 1~ Ism WIIM, ,ho \ , )~KdJy, ~Bbic ~rSsn , \~ , ~~)J,äåÎmon:~~tmd~g: .4 ~~,,- ;N~'~,',~, ~C, C!n~,,:Jj 'i1~~ PropOSed :Rtgùþ lI'ûátriítlon Wlth:Flâng' øaacm: 'H' ',', ",,' ",,' -, ~s, , ' ~j~¡:: ,..;:1 r~~&øt," T~" '1' I !it» Weœ "" --..... ~ :z."~'nu. ' i- J5f12 'OIe.:cI '" l ".. ~-::nu:u'm-..~...A:\IJ..U';J.I'\'CU' AY::;:';;-~.~ ~ IfIWA,\t5'>-.-..- - - =--j ". It: lJ , ~ - F :r r.lO"ftwt: w¡" >~I ~ ~, , ~ '... 111 'III, I '"'-. I ""-... :,~; ¡. ; ,; '~ï.' ~ I:cär 'þ' "~ußIc, ~~~'~ I " ~ .... ' ~ ~'.5m,1'IIImp$ ~ , , '1",' IS02 weeD \ "'II'" ' \ , . ,," ,'" ,""~: "..»,.,'~, ,~ '-í"1Jì"~~~~"^&-"-" ." v" ,', :, 'X:~~~:_~:-""':',~";' ., " ~ "~' , 1rmudNt:er Pønip,MøitøJd IOU q.tc,v~~ 2" Ol'ml" Ii.. 2" . 51).} '11-, ~ W J"'""", Or v..-n R~ -IW 1 of 1 --4 ~' 12/16/20047:52 AM ) ) ~, L Po able E ani Id Drilling Flow Pa~ .. ~ H 2" 1502 ,', 2" 1502 Hook up to RIG GAS BUSTER ræ,lí,',:,"; i. I~: 'Ii:~ E .. ;. ~4 }; D IJ.,I A- f I "f1 riL ,t~~ ',1 ""£,è;,;' Drain w/1502 Bull plug A,B,C,D,& E. 4"SM National Ball Valves The rest of valves are 3" SM National Ball Valves 2" HP Hose w/4 1/16" 5M Flange 0; ~/H//H/////H///////U///////////////H////HJi: ~ I~'~ :..,:,',' ::<:".""". """,-..,,-,": Well Control Flow Paths , ,j" ,~ ~:' J~' : ;~t ! 1 ~¡ :I~ " ,1 ~:, ~ I . l + =: c Hyd CHOKE ;J'; ~¡( .11 If. ri' , I ,," . - '~., ~;j 1, ' : ll,,-, "ff£ . ~ ~~:;-- , -- ~:;~..~ I ~~ RE: K-1RD2 WO with HWOU Unit ) ) Subject: RE: K-IRD2 WO with HWOU Unit From: "Buster, Larry WIt <lbuster@unoeal.eom> Date: Mon, 29 Nov 2004 05:49:07 -0900 To: Thomas Maunder <tom - maunder@admin.state.ak.us>, Tim Brandenburg <brandenburgt@unoea1.eom>, Jerry Bowen <jbowen@unoea1.eom>, Larry Buster <lbuster@unoea1.com>, Evan Harness <ehamess@unoea1.com> CC: Jim Regg <jim _regg@admin.state.ak.us>, AOGCC North Slope Offiee <aogec -prudhoe - bay@admin.state.ak.us> Tom, I can speak to your question. We have met with representatives from our HWOU Contractor (CUDD) and have discussed proposed CL, KL and manifolding for the upcoming work. Keeping regulatory requirements artd past lessons learned in mind, we will have a schematic of the proposed rig-up later this week. I will forward to you ASAP. Regards, Larry Buster UNOCAL Alaska -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Saturday, November 27, 2004 1:37 PM To: Tim Brandenburg; Jerry Bowen; Larry Buster; Evan Harness Cc: Jim Regg; AOGCC North Slope Office Subject: K-1RD2 WO with HWOU Unit Tim, et al: I have received the application to pull tubing to replace the ESP on the K-1RD2. Unocal proposes to employ a hydraulic workover unit (snubbing unit) to move the tubulars. Unocal' has previously employed a HWOU on other platforms and wells in Cook Inlet including King Salmon. The application provided a "stack up" drawing, however there was no detail provided regarding the choke line, kill line or choke manifold. We would appreciate your sending this information. Please be advised, that Unocal should do everything possible to minimize the number of connections that might be proposed in either line and that "lines" assembled of chicksan are not acceptable. As the beginning of operations gets closer, please have your Drilling Supervisor(s) make contact with the Inspectors to make arrangements to inspect the equipment rig up. Please call or message with any questions. Tom Maunder, PE AOGCC 1 of 1 12/16/20047:58 AM ) ) ~lr 1fŒ (ill ~~ FRANK H. MURKOWSKI, GOVERNOR AlASKA. OIL AND GAS CONSERVATION COMMISSION 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 '..4..........Ck.,. ~ . ,~"~'~i,í-:;;J f,." 'P'i¡:,\'f.:Jj;;'!'!í;!;~¡;~'>i t Tim Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196247 Anchorage, Alaska 99519 Re: King Salmon K-12RD Sundry Number: 304-482 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superio~~ unless rehearing has been requested. r ~ 1~ / J . an Chairman DATED thisßdaY of December, 2004 Enc!. SCANNED DEC 1 4 2004 1. Type of Request: '\ STATE OF ALASKA, ALA;...Á OIL AND GAS CONSERVATION COMI\t..~ION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: Suspend U Repair well D Pull Tubing 0 _¿~A~t ~ ' '1"'11 10 >-:;::;\,J ~~ Perforate U Waiver U Other 0 Stimulate D Time Extension D Re-enter Suspended Well D replace failed ESP 5. Permit to Drill Number: Abandon U Alter casing D Change approved program D 2. Operator Name: Union Oil Company of California 3. Address: Exploratory D 78-57 D 6.API~~~ PO Box 196247, Anchorage, AK 99519 5D-133-2°'~~~11 ~ ~ ~:'BA~:~ation (ft): ~i::~~;:e :~::~mber: 4/,,¡, Oq D£C lOa V~D 8. Property Designation: 10. Field/Pools(s): ;1) 8., C. '004. Trading Bay Unit McArthur River 1 Hemlock Pool 4hCh O/JI. C~ 11. PRESENT WELL CONDITION SUMMARY ~ðge 14-'/;0 Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,775 9,867 11,641 9,754 11,429 Length Size MD TVD Burst Development Stratigraphic 0 D Service N/A Casing Structural Collapse Conductor 393' Surface 2510' Intermediate Production 10747' Liner 1278' 24" 133/8" 61 ppf 393' 2510' 393' N/A 2429' 3090 psi 8973' 6870 psi 9859' 8460 psi N/A 1540 psi 16. Verbal Approval: 95/8"47ppf 10747' 7" 38 ppf 11765' Perforation Depth TVD (ft): Tubing Size: Tubing Grade: (see attached) 4 1/2" 12.6 ppf L-80 IBTC None - ESP artificallift wI live annulus, Packers and SSSV MD (ft): No-Flow status approved 2/8/2002 FB-1 at 10,350' (see schematic) Description Summary of Proposal ~ 13. Well Class after proposed work: 0 BOP Sketch 0 Exploratory D Development 15. Well Status after proposed work: Oil 0 Gas D Plugged WAG D GINJ D WINJ 4760 psi 11390 psi Tubing MD (ft): 10,114' Perforation Depth MD (ft): (see attached) Packers and SSSV Type: N/A 12. Attachments: Wellbore Schematic 0 Service D 14. Estimated Date for Commencing Operations: Jan. 24, 2005 (approximate date) Date: D D Abandoned WDSPL D D Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Tim Brandenburg Title Drilling Manager Signature -z...:... ~ ~.ß- Phone 90:~:-~::ON USE ONLY Date Contact Larry Buster 6-Dec-04 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: :!/J~: L/f?- Plug Integrity 0 BOP Test . Mechanical Integrity Test D Location Clearance D Other: ~O()O\>CŠ\ ßC)V\<-c~~. "ßO?~~-\\.~-\-~r'Ù~.\ ~ ~ aú...'iS 'OQ(l.Xo.\\o"S \)<e c.o~~L~'ð~,^, o..u:..~~ wi 0~()c.û..~ ~~~ ~~C\jt.r- \'>~~ ~ RBDMS BFL DEC 1 4 20D4 ORIGINAL BY ORDER OF THE COMMISSION COMMISSIONER Date: s~~i~f '-- INSTRUCTIONS ON REVERSE ) ) King Salmon Platform Well K-12RD, AFE 163357 ESP Repair . UNOCAL8 OBJECTIVE: Replace the failed ESP assembly currently in Well K-12RD. PROCEDURE SUMMARY: 1. Shut off gas lift gas. Bleed down SIWHP slowly to avoid damaging ESP cable. Turn off cathodic protection system. 2. Perforate tubing above ESP. 3. Circulate oil out of annulus and load well wi 3% KCL. 4. Spot sized salt pill (if necessary) to manage losses and keep hole full while POH and while RIH wi tubing and ESP assembly. 5. Set BPV and N/D tree on Well K-12RD. N/U BOPE and CUDD HWOU. Test 13-5/8" BOPE (see attached diagram) to 25013,000 psi. 6. Verify well dead. Circ. well clean to verify no oil has entered the tubing or annulus. 7. POH wi tubing, cable & failed ESP. Visually inspect tubing & LID singles while POH. Send primary ESP equipment & unusable tubing to shore. 8. RIH wi replacement ESP assembly similar to the current failed completion (see attached diagram). 9. Install BPV. RID CUDD HWOU. N/D BOPE. N/U & test tree. 10. Install flow line and surface facilities & turn well over to Production. Turn platform cathodic protection back on. 11. Startup ESP as per separate startup procedure and confirm that ESP is functioning properly. AOGCC K-12RD ESP Workover Summary 1 of 1 December 3, 2004 U'NÖCALe 2,51 O'~ 2 3 10,350' ..1 ~ ,'. .,.",'....',."'..' ..' .----- 5 . j I. " l \\ 10,487' .. ~ 10,747' ~ = G-5 == B-1 == B-2 = B-3 == B-4 = B-5 :Josi-Set Plug @ 11,429' wI Toe @ 11 ,419' 7%~~~~~~~~~~~%~~%~'= B-6 ................. . : >~:~: ~::: ~:~: ~: ~:~:~: .................. . ./' """"""""",,- PBTD = 12,170' TD = 12,250' MAX HOLE ANGLE = 42° @ 5800' ) SIZE 13-3/8" 9-5/8" 7" Liner Tubing: 4-1/2 " ~ NO. 1. GLM #1. GLM #2. GLM #3. GLM #4. GLM #5. GLM #6. GLM #7. GLM #8. GLM #9. 2. 3. 4. 5. JEWELRY DETAIL Item 13-5/8" x 4-1/2" FMC type "TC-EH-VH" EVE bUm x IBT top Tbg Hngr wi CIW "H" BPVP & 2 Cap Tube ports. Cameo 4-1/2" SFO-2 Gaslift Mandrels. 2311' 4-1/2" SFO-2 GLM wi RA Latch 4110' 4-1/2" SFO-2 GLM wi RA Latch 5329' 4-1/2" SFO-2 GLM wi RA Latch 6137' 4-1/2" SFO-2 GLM wi RA Latch 6702' 4-1/2" SFO-2 GLM wi RA Latch 7208' 4-1/2" SFO-2 GLM wi RA Latch 7717' 4-1/2" SFO-2 GLM wi RA Latch 8231' 4-1/2" SFO-2 GLM wi RK Latch 8743' 4-1/2" SFO-2 GLM wi RK Latch 10,056' Centrilift ESP - 213 Stage GC6100 Pump, HST3 Seals, & 600 hp HMI Motor BHA. Length=99.98' Pump Intake 15' 4-1/2" tbg stub, Locator Seal Assy wi 20' of seals. Spaced out 3' above pkr Baker Model "FB-l" Penn Pkr, size 192-60 wI 1 0' WT 61.0 47 38 12.6 Depth 33.80 10,114' 10,331 ' 10,350 ) Trading Bay Unit King Salmon Well No. K-12RD Actual Completion 11/07/02 CASING AND TUBING DETAIL GRADE CONN ID K-55 12.515 N-80 & S95 BTC/LTC 8.681 P-II0 LTC 5.920 TOP 38' 38' 10,487' BTM. 2,510' 10,747' 11,765' Zone Top 10,826' 11,037' 11,070' 11,175' 11,216' 11,310' 11,372' 11,424' L-80 Spec. Cl. BTC 10,053 ' 3.958 37 ID 4.875 6.00 FISH: 1-~" Orifice Valve E/line work: Fill tagged at 11458' with 1-11/16" OR/CCL 1/15/02 Set Posi-Set plug @ 11,429'. Dump bail TOC @ 11,419' Post job production results indicates plug failed. G-5 HB-1 HB-2 HB-3 HB-4 HB-5 HB-6 HB-6 PERFORA nON DATA Btm Amount Condition 10,910' 84 Open in '95. Reperfd 1/02 11,057' 20 Open in '78. Reperfd 1/02 11,175' 105 Open in '78. Reperfd 1/02 11,200' 25 Open in '78. Reperfd 1/02 11,236' 20 Open in '78. Reperfd 1/02 11,330' 20 Open in '78. Reperfd 1/02 11,402' 30 Open in '78. Reperfd 1/02 11 444' 20 Open in '78. , Attempt isolation 1/02 C:\Documents and Settings\lbuster\Local Settings\Temporary Internet Files\OLKI97\K.12RD Actual Dwg 11-07-02.doc 11129/04 Revised: BY: JHM ) ) RIG UP ON KING SALMON PLATFORM WELL K-12 D RIH NEW ESP ~ - , '.. ~ .°0" t." API 13 518"5000 NO GASKET API 13 SIS" 5 000 BXl60 API 1] 5/8" 5 000 BXl60 ~IJS~'SOOO ~164) API 13 5/8"5000 BXl60 API 13 SfS' 5 000 BXl6Ø API 13 5/8" 5 000 BX 16& m13m"SOOO ~I~ -CIIDD- .-=--""'mo<°- 0 AI. 37.1' meter I well de(k 122.03 Ft I well deck n.86~ 340K TH / Cudd Reference ~ 59.86 Ft ., 14.33 meter I well deck 47.03 Ft I well deck .. , -- l.l,m... 13.14 meter/well deck I r 43.11 Ft / well deck 1.S1m~ .. 11.62 meter f well deck .... 38.11 FtI well deck - ~ ""'.............. JI~ 8.23 meh.'r / well dt'Ck 27.01 Ft I well d,,'k ~ \ , ... meter I well deck ~ ~ ~I' Ft I well deck '''''' fi IIWIIIIIi 4.94 meter I well deck 13.26 Ft I well deck =- ., 4.04 meter I well deck . 13.26 Ft I well deck 0,6'",- ... 3.43 meter I well deck ... 11.26 Ft/welldeck .- ., 3.43 meter I well deck , 11.26 Ft I well deck :~¡VALUE! .... ,¡1 .....1.' ...lId;"l"a. " II:" F' "'...1'(4....:1.. 1.38 m..... 2.05 meter I well deck 6.72 Ft I weO deck ~ '0"",- IS~ MIU~t""'.~"O]ÞI"j';[ - ~.. '.78 meter I well deck 2.56 Ft I well dec:k ~ '.25 meter I wf'll deck 0.82 Ft J well deck ..ZS 811.... r///////////~'/~ Tft;;}/ / //// ////~ J,""- Hl"B 13 ~8~ 5 000 B.XI64I ~1'. l~fc - 1.7S metn- I ",'eIl deck $.74 FU ",'ell det'k 1.15 81 ........ W')I/7////////1 1///////////1 Shed ('akubtioA is automatk~ just ('huge nlue ill ') King Salmon K12RD BOP Stack Test Pressure: 250/3000, psi 3 1/16"SM x 4 1/16"SM DSA A 41/16" SM Foster HCR Valve B 41/16" SM Manual gate valve C 3 1/16" SM Manual gate Kill line D 3 1/16" SM Manual gate Kill line Graylock Hub HWOU ') .. .. 55" 10.90' y A 34" y ... 27" w ..... 14" Top Deck w - .. Top of FMC Type aBS Tubing Head Adapter 12.67' - ) ) WO~L KING SALMON Platform K-12Rd slot #4-29 McArthur River Field TBU, Cook Inlet, Alaska SUR V E Y LIS TIN G by Baker Hughes INTEQ Your ref: PGMS <0-11400'> Our ref: svy5149 License: Date printed: 12-Feb-2004 Date created: 10-Aug-1993 Last revised: 29-Jul-1996 Field is centred on n60 50 4.803,w151 36 18.018 Structure is centred on n60 51 48.792,w151 36 18.403 Slot location is n60 51 56.026,w151 36 21.223 Slot Grid coordinates are N 2511809.144, E 213758.357 Slot local coordinates are 734.56 N 139.64 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ) UNOCAL KING SALMON Platform,K-12Rd McArthur River Field,TBU, Cook Inlet, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 0.00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 800.00 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1800.00 1900.00 2000.00 2100.00 2200.00 2300.00 2400.00 2500.00 2600.00 2700.00 2800.00 2900.00 3000.00 3100.00 3200.00 3300.00 3400.00 3500.00 3600.00 3700.00 3800.00 3900.00 4000.00 4100.00 4200.00 4300.00 4400.00 4500.00 4600.00 4700.00 4800.00 4900.00 6.44 7.13 8.31 9.01 10.08 11. 52 12.45 13 .61 14.97 16.19 18.33 20.87 23.17 25.64 29.87 33.11 35.39 36.12 36.38 36.01 35.77 35.75 36.32 36.74 36.70 37.33 36.89 37.32 37.49 37.63 0.00 0.12 0.18 0.65 0.78 0.00 196.52 170.22 209.72 211.40 0.95 1.58 1.62 2.91 4.60 345.00 8.43 8.80 356.95 346.03 328.91 307.61 291.98 275.49 269.70 268.63 269.96 271.76 274.24 275.61 269.41 258.35 253.15 252.33 253.54 252.95 253.07 252.67 253.72 256.16 260.85 263.89 264.45 264.93 263.61 264.25 264.89 264.57 264.68 264.74 37.38 38.45 38.43 38.54 39.01 264.50 265.56 265.57 265.49 265.18 39.31 39.29 39.10 39.54 39.82 264.99 266.27 266.41 266.14 266.04 0.00 100.00 200.00 300.00 399.99 499.98 599.96 699.92 799.84 899.62 999.16 1098.48 1197.58 1296.45 1395.07 1493.30 1591.12 1688.54 1785.45 1881.77 1977.27 2071.50 2164.21 2255.27 2343.74 2429.00 2511.66 2592.81 2673.45 2754.16 2835.19 2916.34 2997.21 3077.56 3157.72 3237.57 3317.32 3397.07 3476.51 3555.78 3635.11 3714.00 3792.32 3870.60 3948.56 4026.10 4103.49 4180.99 4258.35 4335.31 R E C TAN G U L A R COO R DIN ATE S 0.00 N 0.10 S 0.36 S 1. 00 S 2.08 S 1. 86 S 0.31 N 3.07 N 7.00 N 13.43 N 22.12 N 30.71 N 37.21 N 40.66 N 41.36 N 41. 08 N 40.83 N 41.19 N 42.50 N 44.82 N 46.02 N 42.26 N 32.96 N 20.69 N 7.06 N 8.01 S 24.45 S 41. 66 S 58.76 S 74.10 S 85.79 S 93.54 S 99.52 S 105.02 S 110.99 S 117.36 S 123.07 S 128.61 S 134.30 S 139.92 S 145.63 S 150.94 S 155.75 S 160.60 S 165.70 S 171.11 S 175.93 S 179.97 S 184.08 S 188.44 S 0.00 W 0.03 W 0.03 W 0.29 W 0.92 W 1.49 W 1. 50 W 1.09 W 1. 01 W 2.11 W 5.97 W 13.79 W 25.41 W 39.90 W 56.45 W 75.19 W 95.95 W 118.49 W 143 .13 W 169.89 W 199.49 W 232.68 W 268.96W 308.41 W 352.92 W 402.93 W 456.75 W 512.59 W 569.19 W 626.21 W 683.62 W 741.52 W 800.05 W 859.32 W 918.80 W 978.67 W 1038.73 W 1098.80 W 1159.28 W 1219.98 W 1280.59 W 1341. 81 W 1403.79 W 1465.84 W 1528.25 W 1591.17 W 1654.32 W 1717.39 W 1780.62 W 1844.32 W Dogleg Deg/100ft ) SURVEY LISTING Page 1 Your ref: PGMS <0-11400'> Last revised: 29-Jul-1996 Vert Sect 0.00 0.12 0.09 0.52 0.13 0.00 0.03 0.03 0.27 0.89 1. 59 0.80 0.04 1. 37 1. 83 1.46 1. 51 1.13 1.11 2.31 2.45 2.59 2.40 2.57 1.44 6.31 14.25 25.97 40.52 57.07 1.45 0.97 1. 23 1. 49 1. 27 75.80 96 .56 119.10 143.76 170.55 2.82 4.49 3.01 2.49 4.27 200.17 233.29 269.43 308.69 352.99 3.25 2.28 0.77 0.67 1.49 402.76 456.33 511 . 90 568.23 625.01 2.76 1. 78 0.66 0.51 0.79 682.23 740.01 798.44 857.62 917.01 0.74 0.59 0.47 0.18 0.14 976.77 1036.74 1096.72 1157.10 1217.71 0.29 1. 25 0.02 0.12 0.51 1278.23 1339.36 1401. 26 1463.22 1525.55 0.32 0.81 0.21 0.47 0.29 1588.38 1651.45 1714.45 1777.61 1841. 24 All data is in feet unless otherwise stated. Coordinates from slot #4-29 and TVD from wellhead (100.00 Ft above mean sea level). Bottom hole distance is 5706.86 on azimuth 270.87 degrees from wellhead. Vertical section is from wellhead on azimuth 270.87 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ) ) UNOCAL SURVEY LISTING Page 2 KING SALMON Platform,K-12Rd Your ref : PGMS <0-11400'> McArthur River Field,TBU, Cook Inlet, Alaska Last revised: 29-Jul-1996 Measured Inclin. Azimuth True Vert R E C TAN G U L A R Dogleg Vert Depth Degrees Degrees Depth COO R DIN ATE S Deg/100ft Sect 5000.00 40.75 267.39 4411.59 192.14 S 1908.87 W 1. 28 1905.72 5100.00 40.96 267.55 4487.23 195.02 S 1974.22 W 0.23 1971. 02 5200.00 41.46 267.84 4562.46 197.67 S 2040.05 W 0.54 2036.80 5300.00 40.93 267.92 4637.71 200.11 S 2105.87 W 0.53 2102.57 5400.00 41.09 268.47 4713.17 202.18 S 2171.45 W 0.39 2168.12 5500.00 41.87 267.73 4788.09 204.37 S 2237.65 W 0.92 2234.28 5600.00 41.82 267.97 4862.58 206.88 S 2304.32 W 0.17 2300.90 5700.00 41.19 267.44 4937.47 209.53 S 2370.53 W 0.72 2367.06 5800.00 42.61 267.41 5011 . 90 212.53 S 2437.24 W 1.42 2433.72 5900.00 40.94 266.68 5086.48 215.96 S 2503.77 W 1. 74 2500.19 6000.00 40.64 267.37 5162.19 219.35 S 2569.01 W 0.54 2565.37 6100.00 39.25 267.75 5238.85 222.08 S 2633.16 W 1.41 2629.47 6200.00 39.80 268.03 5315.99 224.43 S 2696.76 W 0.58 2693.02 6300.00 38.42 268.57 5393.58 226.30 S 2759.81 W 1.42 2756.04 6400.00 37.08 268.83 5472.64 227.69 S 2821.01 W 1. 35 2817.22 6500.00 37.05 268.72 5552.44 228.98 S 2881. 27 W 0.07 2877.45 6600.00 35.81 270.27 5632.90 229.52 S 2940.65 W 1.54 2936.81 6700.00 37.08 270.55 5713.34 229.09 S 3000.05 W 1. 28 2996.21 6800.00 38.99 270.86 5792.10 228.33 S 3061.65 W 1. 92 3057.82 6900.00 39.85 271. 68 5869.35 226.92 S 3125.14 W 1. 01 3121. 32 7000.00 39.10 272.13 5946.54 224.81 S 3188.68 W 0.80 3184.88 7100.00 38.50 272.72 6024.47 222.16 S 3251.28 W 0.70 3247.52 7200.00 38.29 273.39 6102.85 218.85 S 3313.30 W 0.47 3309.58 7300.00 37.16 274.26 6181.94 214.77 S 3374.35 W 1. 25 3370.68 7400.00 36.93 273.40 6261.76 210.75 S 3434.46 W 0.57 3430.85 7500.00 37.37 273.99 6341. 47 206.85 S 3494.72 W 0.57 3491.16 7600.00 36.80 274.73 6421. 24 202.27 S 3554.84 W 0.72 3551. 35 7700.00 36.52 275.36 6501. 46 197.02 S 3614.32 W 0.47 3610.90 7800.00 37.40 275.09 6581.37 191.55 S 3674.19 W 0.89 3670.85 7900.00 38.10 275.34 6660.43 185.98 S 3735.16 W 0.72 3731.89 8000.00 38.47 276.51 6738.93 179.58 S 3796.78 W 0.81 3793.61 8100.00 38.58 276.77 6817.16 172.38 S 3858.65 W 0.20 3855.58 8200.00 39.13 277.37 6895.04 164.66 S 3920.91 W 0.67 3917.95 8300.00 38.03 277.23 6973.21 156.73 S 3982.76 W 1.10 3979.91 8400.00 39.01 277.36 7051.45 148.83 S 4044.54 W 0.98 4041.80 8500.00 37.05 276.66 7130.21 141.30 S 4105.68 W 2.01 4103.05 8600.00 36.07 277.42 7210.53 134.00 S 4164.80 W 1. 08 4162.27 8700.00 35.46 277.02 7291. 68 126.66 S 4222.78 W 0.65 4220.36 8800.00 35.36 278.52 7373.18 118.82 S 4280.18 W 0.87 4277.88 8900.00 31.85 272.49 7456.48 113.39 S 4335.19 W 4.84 4332.96 9000.00 33.00 271. 29 7540.89 111. 63 S 4388.78 W 1. 32 4386.57 9100.00 34.13 272.23 7624.21 109.92 S 4444.04 W 1.24 4441.85 9200.00 34.61 272.31 7706.75 107.69 S 4500.45 W 0.48 4498.29 9300.00 34.95 274.27 7788.89 104.41 S 4557.39 W 1.17 4555.27 9400.00 35.52 275.15 7870.57 99.67 S 4614.89 W 0.76 4612.83 9500.00 36.09 274.58 7951.67 94.71 S 4673.18 W 0.66 4671.19 9600.00 36.75 275.61 8032.14 89.43 S 4732.31 W 0.90 4730.40 9700.00 35.80 276.51 8112.76 83.19 S 4791.15 W 1. 09 4789.32 9800.00 36.56 275.92 8193.47 76.81 S 4849.83 W 0.84 4848.10 9900.00 36.62 278.20 8273.77 69.48 S 4908.98 W 1. 36 4907.35 All data is in feet unless otherwise stated. Coordinates from slot #4-29 and TVD from wellhead (100.00 Ft above mean sea level). Bottom hole distance is 5706.86 on azimuth 270.87 degrees from wellhead. Vertical section is from wellhead on azimuth 270.87 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ , . ') ) UNOCAL SURVEY LISTING Page 3 KING SALMON Platform,K-12Rd Your ref : PGMS <0-11400'> McArthur River Field,TBU, Cook Inlet, Alaska Last revised: 29-Jul-1996 Measured Inclin. Azimuth True Vert R E C TAN G U L A R Dogleg Vert Depth Degrees Degrees Depth COO R DIN ATE S Deg/100ft Sect 10000.00 34.42 276.67 8355.16 61. 94 S 4966.58 W 2.37 4965.06 10100.00 33.59 277.24 8438.06 55.17 S 5022.09 W 0.89 5020.67 10200.00 33.40 278.80 8521. 45 47.48 S 5076.74 W 0.88 5075.42 10300.00 32.85 277.87 8605.20 39.55 S 5130.80 W 0.75 5129.60 10400.00 32.75 278.50 8689.26 31. 84 S 5184.42 W 0.36 5183.33 10500.00 31.75 279.19 8773.83 23.64 S 5237.15 W 1. 07 5236.18 10600.00 32.23 279.81 8858.64 14.89 S 5289.40 W 0.58 5288.56 10700.00 33.13 280.75 8942.81 5.25 S 5342.52 W 1. 03 5341.82 10800.00 33.22 282.59 9026.51 5.82 N 5396.10 W 1. 01 5395.57 10900.00 31.46 283.23 9111. 00 17.76 N 5448.25 W 1. 79 5447.88 11000.00 31. 70 285.85 9196.20 30.91 N 5498.93 W 1. 39 5498.76 11100.00 32.27 285.35 9281. 01 45.15 N 5549.94 W 0.63 5549.99 11200.00 32.50 284.02 9365.46 58.73 N 5601.75 W 0.75 5602.00 11300.00 32.85 284.42 9449.64 71.99 N 5654.08 W 0.41 5654.53 11400.00 32.83 287.60 9533.66 86.94 N 5706.19 W 1. 72 5706.86 All data is in feet unless otherwise stated. Coordinates from slot #4-29 and TVD from wellhead (100.00 Ft above mean sea level). Bottom hole distance is 5706.86 on azimuth 270.87 degrees from wellhead. Vertical section is from wellhead on azimuth 270.87 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL Larry Buster Drilling Engineer 907-263-7804 Direct 907-276-7600 Main May 13, 2003 AOGCC 333 West 7th Avenue Anchorage, AK 99501 Re: Updated Schematic-Trading Bay Unit, K-12RD Dear Sir of Madam: Attached is m~ updated Schematic for Well Number K-12RD, APl number 50-733- 20156-01. Please replace the Schematic previously sent with the Form 10-404 on 3/29/03 with this updated Schematic. Thank. ~! /~uster %kx, kk Drilling Engineer Attachrnent RECEIVED MAY 16 2003 ;Alaska 0il & Gas Cons, Cemmis~n Unocal Alaska / Union Oil Company of California 909 West 9th Avenue, P.O. Box i96247 Anchorage, Alaska 99519-6247 STATE OF ALASKA ALASKA ,OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: X Alter casing: Repair Well: Other: X 2. Name of Operator 6. Type of Well: 6. Datum elevation (DF or KB) UNION OIL COMPANY OF CALIFORNIA (UNOCAL) Development: X 33.8 RKB feet 3. Address Exploratory: 7.. Unit or Property name P.O. Box 19-6247 Stratigraphlc: Trading Bay Unit/ Anchorage, AK 99519-6247 Service: McArthur River Field 4. Location of well at surface 8. Well number 735' N, 140' W, SE Cr, Sec 17, T9N, R13W, SM K-12RD Ai top of productive interval ,i 9. Permit number/approval number 532' N, 392' W. SE Cr. Sec 17, T9N, R13W, SM 78-57 At effective depth 10. APl number 50-733-20156-01 At total depth 11. Field/Pool 607' N, 780' W, SE Ct, Sec 18, T9R, R13W, SM McArthur Rive, r Field/Hemlock 12. Present well condition summary Total depth: measured 11775 feet Plugs (measured) Posi set plug @ 11,425' TOC ~ 11,419' true vertical 9,867 feet ~ ., Effective depth: measured 11,641 feet Junk (measured).. 1.5" oriface valve below posi set plug true vertical 9,739 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2472' 13-3/8", 61# 1500sx 2,510 2,436 intermediate Production 10,709' 9-5/8", 47# 1000sx 10747' 8,891 Liner " 1,278 7#, 38~ ~350sx 11,765' 9,842 Perforation depth: measured Zone Top Btm Amount Condition true vertical G-5 10,826' 10,910' 84 Open in '95. Reperl"d 1/02 H B-1 11,037' 11,057' 20 Open in '78. Reperf'd 1/02 HB-2 11,070' 11,175' 105 Open in'78. Reperf'd 1/02 HB-3 11,175' 11,200' 25 Open in '78. Reperf'd 1/02 HB-4 11,216' 11,236' 20 Open in '78. Repert'd 1/02 H B-5 11,310' 11,330' 20 Open in '78. Reperf'd 1/02 H B-6 11,372' 11,402' 30 Open in '78. Reper~l,lJ~? _ __ HB-6 11,424' 11,444' 20 Open in '78. Atte~tll~,[~l~ ~ V~" L) Tubing (size, grade, and measured depth) 4-1/2", 12.6~, L-80 IBTC ~ 10,053' MAY 0 ]. 2003 Packers and SSSV (type and measured depth) 90' !ong ESP ~ 9,985', FB-1 Perm Pkr ~ 10,350' Alaska 0il & Ga_, ~nn_~' 13. Stimulation or cement squeeze summary Anchorage Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 156 290 2496 1100 250 Subsequent to operation 273 794 2677 75 75 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: C O ~,~0I Daily Report of Well Operations: X Oil: X Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: Larry Bu Title: Drilling Superlntendant Date: ~ ~,,,m ~n.,~n,~ R~v n1~1~5/88 ' ~,~, ~ ,, .~ SUBMIT Ir DUPLICA 2,510'i 10,350' 10,487' 10,747~ PBTD @ *i 2,'170' TD @ 12,250' Hole AnCe = 42 degrees @ 5800' '~hnicaJ Schematic Trading Bay Unit, K-12RD Actual EompJetion 'l 1/04/02 last ~evised 05/13/03 by Dia~}e Dunham, U~ocal Alaska Casing and Tubing Detai~ SiZE WT~ GRADE CONN iD TOP BTM. 13-3/8" 61~L ~K:~ 12.515 38' 2,510' 9-5/8" 47 iN-80 & S95 BTC/LTC 8.681 38' 10,747' 7"Liner 38 I P-110 LTC 5.92 10,487' 11,765' Tubing: 12.6 4-1/2" N-80 B~TC 3.958 35 9,985' JeweJry No. Depth JD Item 34.75' 4d/2" CIW Tub!rig hanger. 1 2,311' 3.833 GLM FSO-2 W/1-1/2" Valve #1 2 4,110' 3.833 GLM FSO-2 W/1-1/2" Valve #2 3 5,329' 3.833 GLM FSO-2 W/I-1/2" Valve #3 4 6,137' 3.833 GLM FSO-2 W/1-1/2" Valve #4 5 6,702' 3.833 GLM FSO-2 W/1-1/2" Valve #5 6 7,208'_ 3.833 GLM FSO-2 W/1-1/2" Valve #6 7 7,717' 3.833 GLM FSO-2 W/1-1/2" Valve #7 8 8,231' 3.833 GLM FSO-2 W/t-1/2" Valve #8 9 8,743' 3.833 GLM FSO-2 W/1-1/2" Valve #9 10 10,053' 3d/2" EUE 8rd Pin x 4-1/2" IBTC Box L-80 Crossover Sub 11 10,055' CentriIift ESP Pump & Motor BHA. Length=90.07' 12 10,331' 4.875 15' 4-1/2" cut tbg stub, Locator Seat Assy w/ 20' of seals Spaced out 3' above pkr 13 10,350 6 Baker Model "FB-I" Perm Pkr, size 192-60 w/10' SBE. Set on E/line. PT t/2000 ps! .... FISH: 1-%" Orifice Valve F!!! tagged at 11458' with 1-11/16" GR/CCL 1/15/02 Set Posi-Set plug @ 11,429'. Dump bail TOC @ 11,419' Post job production results indicates plug failed. Perforations Zone Top Btm Amount Condition G-5 10,826' 10,910' 84 Open in '95. Reper['d 1/02 HB-1 11,037' 11,057' 20 Open in '78. Reped'd 1/02 HB-2 11,070' 11,175' 105 Open in '78. Reperf'd 1/02 HB-3 11,175' 11,200' 25 Open in '78, Reperf'd 1/02 HB-4 11,216' 11,236' 20 Open in '78. ReperFd 1/02 HB-5 11,310' 11,330' 20 Open in'78. Reper?d 1/02 HB-6 11,372' 11,402' 30 _Open in 78. Reperf'd 1/02 HB-6 11,424' 11,444' 20 Open in '78. Attempt isolation 1/02 UNOCAL RKB to TBG Head = 33.80' Tree connection: Trading Bay Unit Well # K-12RD Actual Completion 3/04/02 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61.0 K-55 12.515 38' 2,510' 9-5/8' 47 N-80 & S95 BTC/LTC 8.681 38' 10,747' 7" Liner 38 P-110 LTC 5.920 10,487' 11,765' Tubing: 4-1/2" 12.6 N-80 BTC 3.958 35 9,985' 10,350' 10,487' 10,747' osi-SetPlug @ 11 / TOC @ 11,419' J ---- G-5 --- B-1 -- B-2 --= B-3 ---- B-4 _= B-5 B-6 PBTD = 12,170' TD = 12,250' MAX HOLE ANGLE = 42° @ 5800' K12RD Actual Dwg 03-04-02.doc NO. JEWELRY DETAIL Depth ID item 34.75 12" x 4-1/2" OCT type "UH-TC-1A" Butt Tbg Hngr !. Camco 4~U2' SFO~2 GLM #L 2284 4-1/2" SFO-2 GLM w/RA Latch GLM #2. 4085 4-1/2" SFO-2 GLM w/RA Latch GLM #3. 5320 4-1/2" SFO-2 GLM w/RA Latch GLM #4~ 6109 4-1/2" SFO-2 GLM w/RA Latch GLM #5. 6688 4-1/2" SFO-2 GLM w/RA Latch GLM #6. & 7199 4-1/2" SFO-2 GLM w/RA Latch GLM #7. 7715 4-1/2" SFO-2 GLM w/RA Latch GLM #8. 8195 4-1/2" SFO-2 GLM w/RK Latch GLM #9~ 8708 4~1/2" SFO-2 GLM w/RK Latch 2. 9984' 3.75" ProVUe 3. 9,985' Centrilift ESP Pump & Motor BHA. Length=90.07' 4. 10,331' 4.875 5. 10,350 6.00 15' 4-1/2" tbg stub, Locator Seal Assy w/20' of seals. Spaced out 3' above pkr Baker Model "FB-I" Perm Pkr, size 192-60 w/10' SBE. Set on E/line. PT t/2000 psi FISH: l-~" Orifice Valve E/line work: Fill tagged at 11458' with 1-11/16" GR/CCL 1/15/02 Set Posi-Set plug ~ 11,429'. Dump bail TOC ~ 11,419' Post job production results indicates plug failed. PERFORATION DATA Zone Top Btm Amount G-5 t0,826' 10,910' 84 HB-1 11,037' 11,057' 20 HB-2 11,070' 11,175' 105 HB-3 11,175' 11,200' 25 HB-4 11,216' 11,236' 20 HB-5 11,310' 11,330' 20 HB-6 11,372' 11,402' 30 HB-6 11,424' 11,444' 20 Condition Open in '95. Reperf'd 1/02 Open in '78. Reperf'd 1/02 Open in '78. Reperf'd 1/02 Open in '78. Reperf'd 1/02 Open in '78. Reperf'd 1/02 Open in '78. Reperf'd 1/02 Open in '78. Reperf'd 1/02 Open in '78. Attempt isolation 1/02 5/29/02 BY: SLT Operations Summary K-12RD ESP Conversion AFE # 155224 Day I (10/21/02): MI/RU HYD WO unit. PT pump and lines. Shut in/secure well. Installed BOP remote control unit in work basket. Pulled BPV and set 2-way check. Shell tested BOP stack to 5000 PSI. Checked choke lines w/choke line flanges, TIW valves and I-BOP to 250/5000 psi. Day 2 (10/22/02): Operations secured. RU WLU and grease head for running APRS tbg punch. P/U lubricator w/pump in sub. PT lubricator w/2500 psi. RIH w/tbg punch loaded over a 4' interval. Tied in and space out shots mid-joint in the first joint above the pump (9970' to 9966'). POH w/tbg punch. RD WLU. RU circ line to tree. Circulate to displace annulus. Day 3 (10/23/02): Circulate well and checked for flow. Set BPV. RD circ lines and pump. Day 4 (10/24/02): Prep for HYD WO unit. Tighten BOP bolts. RU choke and kill lines. Spot accum. Hook up accumulator, Day way ~nd 5 (10/25/02): Continue to prep HYD WO unit. PT BOP equipment. Pulled 2- chech and installed BPV. Replaced sealing element on rams. Pulled BPV installed 2-way check. Day 6 (10/26/02): Continued to prep HYD WO unit. Day 7 (10/27/02): Continued to prep HYD WO unit. RU H2S sensors and gas detector in work basket and work window. PU and set gin pole. RU lights on HYD WO unit. Ran and hooked up circulating pump. Day 8 (10/28/02): Operations secured. Checked well, equipment and prep work for killing well. Day 9 (10/29/02): HYD WO unit on downtime due to weather. Day 10 (10/30/02): RU/MI HYD WO unit. Picked up and unseated hangar. Day 11 (10/31/02): Open and secured well. POH w/4.5" tbg. Visually checked tbg string intermittently. Changed out tbg string. Cut off ESP cable splice and prepped to change out cable spool. Day 12 (11/01/02): Continued POH w/4.5" tbg. Day 13 (11/02/02): RU SLU and fished. POH w/o fish and RD SLU. Last revised 4/30/2003 (DED) Day 14 (11/03/02): RIH w/4.5" tbg to circulate. Continued fishing. RD SLU w/o fish. Day 15 (11/04/02): Serviced HYD WO unit. Day 16 (11/05/02): Ran ESP/gas lift comp w/4.5" tbg. Day 17 (11/06/02): Continued running ESP/gas life comp on new 4.5" tbg string. Jacked landing jt down to work window. Installed false rotary and manual slips and bowl. Broke out landing jts and made up tbg hangar. Installed penetrator through tbg head and land hanger. Closed annular BOP and test tbg hanger. Day 18 (11/07/02): RD BOPE. NU and test tree. Day 19 (11/08/02): RD/MO ESP. ~, Last revised 4~30/2003 (DED) [I'WCI: l%-l~I'(U HIT II~TJ . Subject: [Fwd: K-12RD Hit list] Date: Tue, 29 Oct 2002 23:14:33 -0900 From: "Jeff B. Jones" <jeffiones~admin.state.ak.us> Organization: AOGCC To: Tom Maunder <tom_maunder@adm in.state.ak.us> Hi Tom, This is the notification of repairs from the King Salmon. See you later, Jeff Subject: K.12RD Hit list Date: Tue, 29 Oct 2002 15:11:58 -0800 From: "Harness, Evan" <eharness~unocal.com> To: "'jeff_jones@admin.state.ak.us"' <jeff_jones@admin.state.ak.us> ~sual Alarms for gas detection that is tied into platform system is complete & tested as of 10:30 10-29-02 - Choke Hose Secured to Drill Deck 09:30 10-29-02 Crew training on MD - Totco is under way and ongoing - Valve handle for TIW will be on location prior to Pulling any tubing Thanks Evan K. Harness Drilling Foreman, Alaska Unocal e-mail eharness@unocal.com Office Ph. 907-263-7932 Cell Ph. 907-229-3592 1 of I 10/3o/2002 7:06 AM Unocal Alaska October 9, 2002 Mr. Tom Maunder Sir, , The attached graphs show the production history and the downhole pressure data for the King Salmon K-12 well for March & April of 2002. The pressure data is taken at the ESP intake @ 8363 ft TVD. If you need any additional information please advise. ~~Leo Phelps '~' Drilling Engineer RECEIVED OCT 0 9 2002 Oil & Gas Cons. 6ommissior, Anchorage 4000 35O0 3000 ................................. . . 2500 2OO0 1500 IOO0 5O0 20-Mar Pump Discharge Psi '. . . . . . . . .............................................. :' .................... ": ....................... :'"">'"":7'""~ .......... 7'"":'i ............. :""T":'""7'"'7'", . . · . , , . , . ~ ,' : ' . . . , ., , ., .. ,. : , . . . , ',, . ; , , 25-Mar 30-Mar 4-Apr 9-Apr 14-Apr 19-Apr 24-Apr 29-Apr 4-May Page 1 of 1 >Historical Data >Wells >Tests >Producing Wells Select Years of Select Tbg TBU K-12 ~ii Data: String: ............. Report Name Tbg String Years of Data Date Created Well Tests TBU K-12 2 10/8102 12 TBU K-12: Well TeSt Data UNOCAL,. Co°k Inlet, Alaska 10/8/02 ~l __l----_ Illl II 'i I I ! --' IIi ~ I i '~ O e ~: "~ O - Date- · Gross · Oil Oil Water Water Form Gas Lift Length Gross ~ ~ [] ~ [] [] (hrs) ~ (bpd) ~ (bopd) ~ Cut (%) (bpd) Gas Gas [] GLR ~ Tbg ~ Csg ~ Pwr Oil PwrOil Pump ~ Press ~ Press ~ Press [] Rate ~ Stroke [] Eft ~ Fluid GOR Pump Depth STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. TyPe of Request: Abandon: SusPend: Operation shutdown: Re-enter suspended well: Alter casing:' Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: X Va'ri'ance: Perforate: X Other: X 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Unocal Corporation Development: X feet 3. Address Exploratory: 7. Unit or Property name ,L P.O. Box 196247, Anchorage, Alaska 99519-6247 Stratigraphic: Trading Bay Unit/ ,L Service: McArthur River Field 4. Location of well at surface 8. Well number 735' N, 140' W, SE Cr, Sec 17, T9N, R13W, SM K12-RD At top of productive interval 9. Permit number 532' N, 392' W, SE Cr. Sec 18, T9N, R13W, SM 78-57 At effective depth 10. APl number 50- 733-20156-01 At total depth 11. Field/Pool 607' N, 780' W, SE Cr, Sec 18, T9N, R13W, SM McArthur River Field/Hemlock t2. Present well condition summary motaldepth: measured 11,775' feet Plugs(measured) ~0¢'''' ~ ~/~'~ ~' 14~/~.~' ~/'O~ ~ true vertical 9867' feet Effective depth: measured 11,641' feet Junk(measured) ! '/z ,,~'~'~e u,~.~' ~'~/ true vertical 9754' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2,472' 13-3/8", 61# 1500sx 2,510 2436 Intermediate Production 10,709' 9-5~8", 47# 1000sx 10,747' 8981 Liner 1,278' 7#,38~ 350sx 11,765 ..... ~ ".~ .... . , .~ :~ -~' - 9842 Perforation depth: measured (See attachment) ~..~:~.~ i~i--' -i: i' "~'~ true vertical (See attachment) ~ i';' ~"~ ~: Tubing (size, grade, and measured depth) 4-1/2", 12.6~, L-80 @ 9,985' Packers and SSSV (tYpe and measured depth) 90' long ESP ~ 9,985', FB-1 Perm Pkr ~ 10,350' 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: 1-Oct-02 16. If; proposal well verbally approved: Oil: X Gas: Suspended: Name of approver Date approved Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed.;~,~_ ~.., ~ Title: Drilling Manager Date: Zp .~'~.~ ns~a/ FOR COMMISSION USE ONLY · Conditio ppmval: Notify Commission so represen~tive may witness IApproval No. Plug integritY BOP Test )% Location clearanceI Mechanical IntegritY Test ' ~ubse, quent form reqj. lir~d 10- L.~[~_~ ~ OF{IO;NAL SIGNED BY Approved by order of the Commissioner Commissioner Date .. . Form 10-403 Rev 06/15/88 DUPLICATE / SUBMIT IN TRIPLICATE King K-12RD Unocal Alaska requests a sundry approval to perform workover operations on King K-12 well with the following exceptions to surface equipment requirements. 1.) To employ the use of 2" 5M Steel molded lines with 1502 weco unions ( no chicksan or swivel joint to be used ) for service as kill line and service between the HCR Valve & 2"10 M Dual manual choke manifold. 2.) To take returns to the production low pressure separator system as opposed to the use of a poor boy degasser. Unocal Alaska Business Unit King Salmon Platform Workovcr of K-12 ESP (ESP Replacement) Prepared by Leo Phelps - 7-25~02 Estimate to Replace ESP UNOCAL(S) No. Preliminary Procedure Time CUM cuM Estimate Time Time (Hours) (Hours) (Days,) 1 Activate Rig (Activation included in cost estimate) 0.0 0 0.0 2 Prepare rig for Operations (Locate Tree Cap Pulling Tool) 0.0 0 0.0 3 Take on and mix kill fluids (800 bbls of 8.8 Filtered KCL) 0.0 0 0.0 , 4 Shut-off gas lift & bleed SICP to 0 psi 5 Set tubing check valve on slickline 010 0 0.0 6 Rig up Hydr WO rig over K-12 0.0 0 0.0 7 Load tubing and annulus. Bleed off tubing & verify dead. 5.0 5 0.2 8 Install BPV 2.0 7 0.3 9 ND tree/flowline 4.0 11 0.5 10 Inspect hanger threads 1.0 12 0.5 11 NU BOPE 22.0 ' 34 1.4 12 Water to 3000 psi. 8.0 42 1.8 13 Spot LCM pill in place 3.0 45 1.9 13 Recover TWC valve & engage hanger with landing joint 2.0 47 2.0 14 RU to pull Buttress tubing. Limit pull to 80% of New rating. 2.0 49 2.0 15 cable on spool. 3.0 52 2.2 16 tubing on TOOH to prevent drips. 1.0 53 2.2 17 up. Use pipe wiper above Rotary. Determine ESP Failure 30.0 83 3.5 18 RU to Run ESP. Change out Spooler Reels 4.0 87 3.6 19 needed. MEG cable each 1000 feet going into the hole. 36.0 123 5.1 20 tubing hanger. 8.0 131 5.5 21 hanger. 5.0' 136 5.7 22 LD Landing joint & RD Tbg Tools 4.0 140 5.8 23 Install BPV 1.0 141 5.9 24 ND bell nipple 4.0 145 6.0 25 ND BOPE & RISER 20.0 165 6.9 26 NU adapter and tree. NU wing valves to tree. 10.0 175 7.3 27 Pull BPV, Install TWC & Shell test tree to 3000 psi.. 6.0 181 7.5 28 Turn well over to production 3.0 184 7.7 29 for baseline. 0.0 184 7.7 30 ' Secure and backload out all tools. 4.0 188 7.8 31 Rig Down and secure rig 14.0 202 8.4 Subtotal (Days) 8.40 Lossfl'rble Time 3.60 Total Project Days 12.00 UNOCAL ) RKB to TBG Head = 33.80' Tree connection: Trading Bay Unit Well # K-12RD Actual COmpletion 3/04/02 CASING AND TUBING DETAIL SIZE WT GRADE CONN 1D TOP BTM. 13-3/8" 9-5/8" 7" L~cr Tubing: 4-1/2" 61.0 K-55 12.515 38' 2,510' 47 N-80 & S95 BTC/LTC 8.681 38' 10,747' 38 P-110 LTC 5.920 10,487' 11,765' 12.6 N-80 BTC 3.958 35 9,985' NO. Depth ID 34.75 JEWELRY DETAIL Item 12" x 4-1/2" OCT type "UH-TC-IA" Butt Tbg Hngr ]o GLM GLM GLM GLM GLM GLM GLM GLM GLM 2. 3. Camco 4-1/2" SFO-2 Gaslifl Mandrels. #1. 2284 4-1/2' SFO-2 GLM #2. 4085 4-1/2" #3. 5320 4-1/2" #4. 6109 4-1/2" #5. 6688 4-1/2" #6. 7199 4-1/2" #7. 7715 4-1/2" #8. 8195 4-1/2" #9. 8708 9984* 3.75" 9,985' w/RA Latch SFO-2 GLM w/RA Latch SFO-2 GLM w/RA Latch SFO-2 GLM w/RA Latch SFO-2 GLM w/RA Latch SFO-2 GLM w/RA Latch SFO-2 GLM w/'RA Latch SFO-2 GLMw/RK Latch 4-1/2" SFO-2 GLM w/RK Latch Profile Nipple, Size 3.813" w/3.75" No Go ID Centriliff ESP Pump & Motor BHA. Length=90.07' 10,331' 4.875 10,350 6.00 15' 4-1/2" tbg stub, Locator Seal Assy w/20' of seals. Spaced out 3' above pkr Baker Model "FB-I" Penn Pkr, size 192-60 w/10' SBE. Set on E/line. PT t/2000 psi 10,350' 5 10,487' ~ll 10,747' FISH: 1-½" Orifice Valve ilL E/line work: Fill tagged at 11458' with 1-11/16" GR/CCL 1/15/02 Set Posi-Set plug ~ 11,429'. Dump bail TOC ~ 11,419' Post job production results indicates plug failed. --; G-5 ;--- B-1 _==- B-2 -=-- B-3 --_= B-4 -'_---- B-5 si-Set Plug @ 11,429'] -- ---- B-6 PBTD = 12,170' TD = 12,250' MAX HOLE ANGLE = 42° ~ 5800' PERFORATION DATA Zone Top Btm G-5 10,826' 10,910' HB-1 11,037' 11,057' HB-2 11,070' 11,175' HB-3 11,175' 11,200' HB-4 11,216' 11,236' HB-5 11,310' 11,330' HB-6 11,372' 11,402' HB-6 11,424' 11,444' Amount 84 Open in 20 Open in 105 Open in 25 Open in 20 Open in 20 Open in 30 Open in Open in 20 Attempt Condition '95. Reperfd 1/02 '78. Reperfd 1/02 '78. Reperfd 1102 '78. Reperfd 1/02 '78. Reperf'd 1/02 '78. Reperfd 1/02 '78. Reperf'd 1/02 '78. isolation 1/02 K12RD Actual Dwg 03-04-021 5/29/02 BY: SLT K-12rd BOP Stack Leg # 4 Afe #1555224-O-00 13 518" Hydril 5M 4.54' \ ? 3 1116"5M x 4 1116"5M DsA A 4 1/16" 5M Foster HCR Valve B 4 1/16" 5M Manual gate valve C 3 t/16" 5M Manual gate Kill line D 3 1/16" 5M Manual gate Kill line 2.56' 11.26' Top of drill deck 12.83' Hub To of FMC T, 3 Unihead C. O. Taylor, Chair D. T. Seamount, Commissioner M. L. Bill, Commissioner Fr: T.E. Maunder, PE Re: Unocal Sundry Application 302-290 K-12RD 178-057 Unocal has proposed bringing a "hydraulic workover unit" to conduct a workover on King Salmon platform. Due to the April fire, the platform rig is not capable of being used for the work. Unocal previously employed this style of equipment to perform 5 workovers in the latter part of 1997 on Baker and Anna platforms. The work was successfully accomplished. Unocal has requested two variances to the requirements at 20 AAC 25.285 for their operations. This document examines the proposed work, Unocal's variance requests and makes recommendations. Unocal has submitted a description and sketch of the proposed BOP equipment and arrangement. The BOP equipment is that normally employed on the platform. According to the Drilling Engineer, it is the same equipment that was in use when the fire occurred. The equipment was removed from the platform for examination and repair or replacement. Unocal's request has been commented on by 2 of the Inspectors. Prior to the operations, a physical inspection and test of the installed equipment will be conducted by one of the Inspectors. Unocal intends to perform I workover with the equipment. K-12RD passed a witnessed no-flow test by Lou Grimaldi in early February, 2002 and recommended that the well be approved as such. According to the file, no additional perforations have been added since then. In March 2002 the well was equipped with a submersible pump. The pump failed in early June and the well has been on gas lift since then. When the pump was installed, a downhole pressure gauge was included. This gauge provides real time pressure information from near the end of the tubing. In the supporting information for this work, Unocal has provided pressure information from the gauge and has determined that the bottom-hole pressure gradient is less than the proposed workover fluid gradient. Given that the well is a high water cut producer (water:oil ratio of about 10:1), Unocal represents that it is unlikely that the well will flow. Unocal indicates that it is likely that them is an oil column in the annulus due to downhole separation effects and they will circulate that fluid from the wellbore at the beginning of the work. With a column of the proposed workover fluid in the well, the well should be overbalanced as required by 20 AAC 25.033 (b) and not capable of flowing. As the work proceeds, Unocal must maintain the integrity of the fluid column as required by 20 AAC 25.033 (a) and (b) and in particular when tripping as required by 20 AAC 25.033 (e). Failure to maintain the integrity of the fluid column could lead to the M:\tommaunder~Well Information\By Subject\BOP-Diverter~Unocal\021007-KinghydWO.doc development of a partial oil column in the annulus that could potentially underbalance the well and allow it to flow. It should be noted that based on the provided pressure information and the TBU oil gravity (from meter proofs) if a full oil column were to be in the annulus the well could potentially flow. Unocal has requested an exception to 20 AAC 25.285 (e) (6) (use of hammer unions on choke and kill line connections) and also plans to route any oily fluid returns to the production system rather than their "poor boy" degasser. Our regulations do not specifically address the degasser, however APl RP 53 provides for the optional installation of a mud/gas separator, 20 AAC 25.285 (c) (9) and (e) (6) are very specific with regard to connections being flanged or hubbed. However, (e) (6) allows the use of hammer unions if the Commission determines that those joints do not comPromise the maintenance of well control. 25.285 (h) allows the Commission to approve a variance from the requirements if the variance provides at least an equally effective means of well control. Since the well work is unlikely to encounter flowing hydrocarbons, use of the threaded connections should not compromise maintenance of well control. The waiver request should be approved as provided by 20 AAC 25.285 (e) (6). Unocai's proposal to route oily returns to the production system should prevent the accumulation of oil on the surface of the fluid pits. Providing a connection to the production system will allow Unocal to direct any returned hydrocarbon into the system designed to handle it. There is no specific regulation to cite with regard to this request, however I believe 25.285 (h) could apply. I believe providing the connection to the production system as planned will enhance the overall ability to maintain well control. Your approval of these recommendations is requested. T. E. Maunder, PE Senior Petroleum Engineer C. O. TaYlOr .............. Chair 'D. ~-."s~am0~nt Commissioner M. L. Bill Commissioner M:\tommaunder~Weil Information\By Subject\BOP-Diverter~Unocal\021007-KinghydWO.doc RE: King Salmon K-12 BHP info Subject: RE: King Salmon K-12 BHP info Date: Wed, 9 Oct 2002 16:40:40 -0700 From: "Phelps, Leo -Alaska" <lphelps~unocal.com> To: "Phelps, Leo -Alaska" <lphelps(~unocal.com>, '"Tom_Maunder@admin.state.ak.us"' <Tom_Maunder@adm in.state.ak.us> CC: "'Phelps Leo -Alaska'" <lphelps~unocal.com>, "Nienhaus, Doug R" <nienhausd@unocal.com> Tom, Here is some information on the K-12 wells ability to flow. The well has a downhole pressure gauge at the ESP intake that reads pump intake pressure and pump discharge pressures. I am sending you a hard copy printout of this wells downhole pressure data for the months of March & April while the pump was running and the gauge was working. The data shows that the well can hold a 7.8 ppg EMW column of fluid. The data says It should not flow against a full column of water. The well is a high water cut producer but will have a column of oil in the annulus while the well is on production ( due to downhole separation effects while ruining the pump ) . The workover calls for us to displace that oil rich fluid out prior to pulling the tbg hanger and filling the well with 3% KCL water from top to bottom, if it will hold that fluid head. This data supports the well being a no flow as last tested. Here are some of the specifics on the numbers; Pump intake is at 10,015 ft. MD = 8,363 ft TVD There are 6 good shut in data points on the graph for this well. Highest seen Shut In pressure at the pump depth is - < 3400 psi 3400 psi @ 8363 ft would mean an equivalent of 7.8 psi mud weight above the pump to surface to equalize the BHP ( less than 3% Kcl water) Shallowest perf is at 9,046 ft TVD Deepest perf at 9570 ft TVD. If we take a pure water column below the pump to the top perf to calculate BHP at the perf it would work out to even less gradient needed -- 6.5 ppg EMW Based on the above data and the previous well history and passing NO FLOW test, it appears reasonable that the well should NOT flow against a standing water column to surface. I'1t send you these curves by hard copy today. Thanks Leo Phelps 350-8036 I of I 1019/2002 4:01 PM Re: [Fwd: K-12RD ESP Change out] Subject: Re: [Fwd: K-12RD ESP Change out] Date: Thu, 29 Aug 2002 20:35:41 -0800 From: Lou Grimaldi <lou_grimaldi@admin.state.ak.us> To: Tom Maunder <tom_maunder@admin.state.ak.us> I think it would be OK as long as all equipment is in good repair. I would rather see the stack and choke connected by hubbed/flanged connections, but if the well is no-flowed they should be OK. Lou Tom Maunder wrote: > Hi Guys, > Another one to consider. I have not really looked at this yet. What > are your thoughts? Does anyone remember what wells such a rig up might > have been used on? > Tom Subjech K-12RD ESP Change out Date: Thu, 29 Aug 2002 14:05:03-0700 From: "Nienhaus, Doug R" <nienhausd@unocal. com> To: "'Tom Maunder' (E-mail)" <torn_maunder~admin. state, ak. us> Tom We are going to bring up CUDD Pressure control hydraulic jack unit to pull & run ESP on K-12RD The 13 5/8" Stack will have annular + 4 1/2" pipe rams & Blind shear rams, CUDD'S equipment is 2" steel line with 1502 connections for kill line & choke line. Cudd also has 2" 1Om dual manual choke. My question is, can we reduce down to 2" & 1502 connections on the choke and kill line, for this type of work over ? Just asking ahead of time for planning purposes. We have done this before once or twice in the past & i beleive the well is a No Flow. <<King Stack K-12rd. xls> > Doug R Nienhaus Unocal Drilling Foreman Office 263-7840 Cell 223-6947 nienhausd@ unocal, corn > Name: King Stack K-12rd. xls > King Stack K-12rd. xls Type: Microsoft Excel Worksheet (application/x-msexcel) > Encoding: base64 Tom Maunder <torn_maunder@admin. state, ak. us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission Tom Maunder Sr. Petroleum Engineer <torn_maunder@admin.state. ak. us> Alaska Oil and Gas Conservation Commission 333 W. 7th Ave. Suite 100 Cellular: 907-244-1567 1 of 2 10/8/2002 12:20 PM Re: [Fwd: K-12RD ESP Change out] Subject: Re: [Fwd: K-12RD ESP Change out] Date: Fri, 30 Aug 2002 09:52:24 -0800 From: Chuck Scheve <chuck_scheve@admin.state.ak.us> Organization: State of Alaska, Dept of Admin, AOGCC To: Tom Maunder <tom_maunder@admin.state.ak.us> Hi Tom I don't remember well # but this sounds like the rig up they used on the Baker platform a couple years ago. Chuck Tom Maunder wrote: > Hi Guys, > Another one to consider. I have not really looked at this yet. What > are your thoughts? Does anyone remember what wells such a rig up might > have been used on? > Tom Subject: K-12RD ESP Change out Date: Thu, 29 Aug 2002 14:05:03-0700 From: "Nienhaus, Doug R" <nienhausd@unocal. com> To: "'Tom Maunder' (E-mail)" <torn_maunder@admin. state, ak. us> Tom We are going to bring up CUDD Pressure control hydraulic jack unit to pull & run ESP on K-12RD The 13 5/8" Stack will have annular + 4 1/2" pipe rams & Blind shear rams, CUDD'S equipment is 2" steel line with 1502 connections for kill line & choke line. Cudd also has 2" 10m dual manual choke. My question is, can we reduce down to 2" & 1502 connections on the choke and kill line, for this type of work over ? Just asking ahead of time for planning purposes. We have done this before once or twice in the past & i beleive the well is a No Flow. <<King Stack K-12rd. xls> > Doug R Nienhaus Unocal Drilling Foreman Office 263-7840 Cell 223-6947 nienha usd@ unocal, com Name: King Stack K-12rd. xls King Stack K-12rd. xls Type: Microsoft Excel Worksheet (application/x-msexcel) Encoding: base64 Tom Maunder <tom_maunder@admin. state, ak. us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission Tom Maunder Sr. Petroleum Engineer <torn_maunder~admin.state. ak. us> Alaska Oil and Gas Conservation Commission 1 of 2 10/8/2002 12:20 PM RE: K-12RD ESP Change out Subject: RE: K-12RD ESP Change out Date: Fri, 30 Aug 2002 10:51:15 -0700 From: "Nienhaus, Doug R" <nienhausd@unocal.com> To: "'Tom Maunder'" <tom_maunder@admin.state.ak.us> CC: "Phelps, Leo -Alaska" <lphelps@unocal.com>, "Hauck, Shane R" <haucks@unocal.com>, "Byrne, Don S" <byrneds@unocal.com> Tom Some of the Hydraulic work over wells were Baker 13, Anna 38, 5, 26 & 7 I have looked in the well files this AM and noticed that we did run a 3 1/8" 5M Choke Hose & A 3 1/8" 5M Choke Manifold. The kill line was 2'5M With 1502 connections. We expect to start the work over in October, currently waiting on approval from partners. ( Time frame on well 7-8 days total, we expect to pull & run pump in about 3-4 days.) Most of our well kill procedures involve taking returns to production. If CUDD'S 2" Piping & 2" 10 M Manifold can be used it would save us form having to nipple down allot of our 3 & 4" iron and hoses to make this a drilling stack, which-is not the plan. Mr Leo Phelps is the project engineer & will have more additional information about the well itself for Sundry, which as you know will help with your decision, we respectfully request the following variances be granted. 1 .) To employ the use of 2" 5M Steel molded lines with 1502 weco unions ( no chicksan or swivel joint to be used ) for service as kill line & servive between the HCR Valve & 2"10 M Dual manual choke manifold. 2.) To take returns to the production Iow pressure separator system as opposed to the use of a poor boy degasser. Thank you for the time & attention concerning this matter. Doug R Nienhaus Unocal Drilling Foreman Office 263-7840 Cell 223-6947 nienhausd@unocal.com ..... Original Message ..... From: Tom Maunder [mailto:tom maunder@admin.state.ak, us] Sent: Thursday, August 29,'2002 1:10 PM To: Nienhaus, Doug R Subject: Re: K-12RD ESP Change out Doug, Could you provide some additional information with regard to what wells such a unit was used on?? Also, what timing are you considering? Tom "Nienhaus, Doug R" wrote: > Tom > We are going to bring up CUDD Pressure control hydraulic jack unit to pull > & run ESP on K-12RD > The 13 5/8" Stack will have annular + 4 1/2" pipe rams & Blind shear rams, 1 of 2 10/8/2002 11:20 AM RE: K-12RD ESP Change out > CUDD'S equipment is 2" steel line with 1502 connections for kill line & > choke line. Cudd also has 2" 10m dual manual choke. My question is, can we > reduce down to 2" & 1502 connections on the choke and kill line, for this > type of work over ? Just asking ahead of time for planning purposes. We have > done this before once or twice in the past > & i beleive the well is a No Flow. > <<King Stack K-12rd. xls>> > > Doug R Nienhaus > Unocal Drilling Foreman > Office 263-7840 > Cell 223-6947 > nienhausd@unocal, com > Name: King Stack K-12rd. xls > King Stack K-12rd. xls Type: EXCEL File (application/msexcel) > Encoding: base64 2 of 2 10/8/2002 11:20 AM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnst ,~~ DATE' Chairman ~ September 9, 1997 THRU' FILE NO: Blair Wondzell, P. I. Supervisor FROM: Lou Grimaldi,/~/~,- SUBJECT: Petroleum Inspector AOAJIIEE.PIR Not Confidential BOP test 'HWC #123 UNOCAL Anna platform Well #A-5 Granite Point field PTD #67-014 Tuesday, September 9, 1997; I WitneSsed the initial BOP test on the Hydraulic Well Control's unit HWC #123 , owned by Hydraulic Well Control of Houma, Louisiana. They Were preparing to change tubing and cavity in UNOCAL's Granite Point, Anna well # A-5. The BOPE for this rig was for the most part, second party owned. The stack, a 5000 pound Schaffer double gate shorty and Hydril annular preventer are owned by UNOCAL. The Accumulator and Choke manifold assemblies were provided by DSR of Anchorage. The rest of the equipment was owned by Hydraulic Well Control. I found all necessary ancillary equipment including PVT, gas detection and remote choke panel to be in place and in good operating condition. The BOP test went fairly well with two failures observed. The single pipe rams had a small leak at the high test of 5000 psi, these were changed requiring a special flight from the beach for replacement elements. The IBOP also failed and the replacement that was onboard was brought up and tested "OK". There were two floor safety valves that tested good, these and the good IBOP all had the proper connections for the tubing they were preparing to pull (3 1/2 buttress). AOAJIIEE.DOC (PAGE 2 OF 2) I worked with both the Day and Night pusher's (Lenny Goin/Gene Buquet) and found them to be highly competent and a pleasure to work with. Both pushers held MMS certification for well control. The test spanned nine hours which inclt~ded approximately three hours of downtime waiting on and installing the pipe ram elements. SUMMARY: I witnessed the initial BOP test on the Hydraulic Well Control unit HWC #123. Two failures observed, parts replaced, and retested ok. Test time 6 hour's - 2 failures. Attachments: AOAJIIEE.XLS cc; Dan Williamson (UNOCAL drilling supt.) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial Workover: X Hydraulic Weft Control Rig No. 123 PTD # UNOCAL Rep.: A #5 Rig Rep.: Set @ Location: Sec. X Weekly Other 67-014 DATE: 9/9/9 7 'Rig Ph.# 776-662'6 Larry McA/lister Lenny Goin/Gene Buquet T. R. Meridian TEST DATA MISC. INSPECTIONS: Location Gen.: Fair Housekeeping: Fair (Gen) PTD On Location N/A Standing Order Posted n/a* Well-Sign P Drl. Rig N/A Hazard Sec. N/A BOP STACK: Quan. Annular Preventer 1 Pipe Rams 1 Lower Pipe Rams N/A Blind Rams Choke Ln. Valves 1 HCR Valves 1 Kill Line Valves 2 Check Valve N/A Test Press. P/F 250/2500 P 250/5,000 F 250/5,000 N/A 250/5,000 P 250/5,000 P 250/5,000 P 250/5,000 P 250/5,000 N/A FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F N/A 250/5, 000 N/A N/A 250/5, 000 N/A 2 250/5,000 P I 250/5,000 F CHOKE MANIFOLD: No. Valves 10 ~' No. Flanges Manual Chokes 1 Hydraulic Chokes I Test Pressure P/F 250/5,000 P 27 250/5,000 P Func~oned Functioned P P ACCUMULATOR SYSTEM: System pressure 3,050 I P Pressure After Closure 1,950 I P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 42 Trip Tank P ' P System Pressure Attained 2 minutes 43 Pit Level Indicators P P Blind Switch Covers: Master: P Remote: Flow Indicator P P Nitgn. Btl's: Four Bottles Meth Gas Detector P P 2150 Average Psig. H2S Gas Detector P P TEST RESULTS Number of Failures: 2 ,Test Time: 6.0 Hours. Number of valves tested 16 Repair or Replacement of Failed Equipment will be made within N/A days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No'. 276-7542 Inspector'North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: i ii i Pipe rams failed, replaced elements and retested "OK". IBOP failed, brought up spare and tested "OK" sec. sec. P No place for standing orders in basket,. Explained meaning with workover crew and Drilling foreman. Gas detectors tested after test "OK". Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c- Inspector STATE WITNESS REQ01RED? YES X NO 24 HOUR NOTICE GIVEN 'YES X' NO Waived By: Witnessed By: Louis R. Grimaidi FI-021L (Rev. 12/94) AOAJIIEE.XLS · 1~UG'-22-97 FRI O1:09 PM Fro: Dan Williamson ~. Re: Hydraulic WO Unit Well Control Piping Y ~/~.~ ~..~ ...... i ii ... iiii . i iii ii i ! iiii =ILII~II~. On August 28, 1997, Unocal Alaska will mobilize Hydraulic Well Control's hydraulic workover unit to Baker Platform to perform a pump and tubing change on Baker Well 13. Upon completion of this work the unit will be sent to Anna Platform to pedorm the same task on Anna Wells._~5, 26, and 38. These wells are all no flow wells, having no packer or safety valv6Tn them'T' Our data shows that the Anna wells are extremely subnormal pressured (1,840 psi at 8,200 ft TVD), have a high water cuts and produce very little gas. The Baker well is higher pressured but will be readily killed with filtered inlet water; it also has a high water cut and produces very little gas. The hydraulic unit will be on each well for a brief time. The wells are not considered by Unocal Alaska to be a high well control risk. We respectfully request the following variances be granted: 11 To employ the use of 2", 5M, Steel Molded Lines and Fittings with 1502 Weco Unions for service as a Kill Line and Downstream Choke Line. 2. Post-it® Fax Note 7671 ICo./Dept. IPhone # ' [Fax# To use the production Iow pressure separator system as opposed to the use of a "Poor Boy Degasser". Phone # Fax # Page 1 o~ 1 aura-22-9? FRI O1:09 PH Calculation .Recor~I~ UNOCAL jI~RE~ARED BY J CHECKED P, 03 iOATE W.O/Aj: I;. ~} - f · · FORM 1,2C.50 (REV, 2-67) PRIlfrio IN U,S,A, UNE FLANGE 2, 5M 1502 UNION TO PRODIEIlON 5M STEEL w/1502 UNION CIRCULATING PLATFORMS SYSTEM FOR HWC ANNA AND BAKER CHOKE 13 5/8; 5M UNE UNE ANNULAR AND OOUB~E ~TE~ i ;3 1/8; 5M k.qMOREO HOSE 4.', 5M ./. 2", 5M t502 UNION I(ELLY UNE F 1502 'TEJE §M LOTORC 2', 5M SI£EL w/1502 UNION FRO}4 PUI~P TO PRODUCT(ON OVERHEAD VIEW FROM WELL GAUGE VALVE Bi" AT gO DEGREES PANIC UNE 113" PRODUCt'ION SIDE VIEW 3 1/8" , 5M CHOKE MANIFOLD PLATFORMS BAKER/ANNA UNE ~. :-~BG-22-97 FRI 01:08 P~I ~--,~ ^ P, O1 IUNOCAL )I UNOCAL Alaska Drilling Department To: Mr. Jack Hartz AOGCC From: Dan Williamson Hydraulic WO Unit Well Control Piping Pages including cover sheet: 5 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: X Alter casing: Repair well: Other: X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil of California (Unocal) Development: X 100' feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Trading Bay Unit/ P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: McArthur River Field 4. Location of well at surface 8. Well number 735' N, 140' W, SE Cr, Sec 17, T9N, R13W, SM K-12RD At top of productive interval 9. Permit number/approval number 532' N, 392' W, SE Cr. Sec 18, T9N, R13W, SM 78-57 At effective depth 10. APl number 50-733-20156-01 At total depth 11. Field/Pool 607' N, 780' W, SE Cr, Sec 18, T9N, R13W, SM McArthur River Field / Hemlock 12. Present well condition summary Total depth: measured 11,775' feet Plugs (measured) true vertical 9867' feet Effective depth: measured 11,641' feet Junk (measured) true vertical 9754' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2,472' 13-3/8", 61# 1500 sx 2,510 2436 Intermediate Production 10,709' 9-5/8", 47# 1000 sx 10,747' 8981 Liner 1,278' 7", 38# 350 sx 11,765' 9842 Perforation depth: . measured (See Attachment) true vertical (See Attachment) Tubing (size, grade, and measured depth)RECEIVED 4-1/2", 12.6#, L-80 @ 9,985' Packers and SSSV (type and measured depth) 90' long ESP @ 9,985', FB-1 Perm Pkr @ 10,350',lllh ri zt2002 13. Stimulation or cement squeeze summary Naska 0il & Gas Cons. C0mm~ss~o[, Intervals treated (measured) Anchorage Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 342 BOPD 588 Mcfpd 4069 BWPD 910 psi 150 psi Subsequent to operation 550 BOPD 192 Mcfpd 6500 BWPD 80 psi 80 psi 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: X Gas: Suspended: Service: ~___.,(~) "-o~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed:~_ ,r~~'~~' Title: ~.Z/~.~ V~...~ //~/~~¢-" Date: ~'/~~..',~ ~ Form 10-404 Rev 06/1 0RI6I AL SUBMIT IN DUPLICATE ~...~' Zone G-5 HB-1 HB-2 HB-3 HB-4 HB-5 HB-6 HB-6 MD Top 10 826' 11 037' 11 070' 11,175' 11,216' 11,310' 11,372' 11,424' MD Btm 10,910' 11,057' i1,175' 11,200' 11,236' 11,330' 11,402' 11,444' TVD Top 9048 9226 9,255' 9,344' 9,378' 9,457' 9,509' 9,553' TVD Btm 9119 9243 9,344' 9,365' 9,395' 9,474' 9,535' 9,570' Amount 84 20 105 25 20 2O 30 2O Condition Open in '95. Reperf'd 1/02 Open in '78. Reperf'd 1/02 Open in '78. Reperf'd 1/02 Open in '78. Reperf'd 1/02 Open in '78. Reperf'd 1/02 Open in '78. Reperf'd 1/02 Open in '78. Reperf'd 1/02 Open in '78. Attempt isolation 1/02 King K-12RD Daily Report of Operations Febuary 26 to March 5, 2002 26-Feb-02 27-Feb-02 Skidded rig over K-12RD. RU lines. Bullhead 80 bbls of FIW down tbg. Pumped 280 bbls of 3% KCl/FIW down csg. Installed BPV. ND tree. NU BOPE. Tested same. Pumped 80 bbls of 3% KCI/FIW down tbg. Pulled 198m. Tbg hngr not free. 28-Feb-02 1-Mar-02 2-Mar-02 RU APRS. RIH w/E/line. Cut tbg @ 10,331' (15' above Iocator). POOH RD E/line. Pump 80 bbls of 3% KCI/FIW down tbg. Pulled tbg hngr to rig floor. LD same. POOH laying down tbg. Finished laying down 4-1/2" tbg. Tested blind rams. PU & RIH w/new 4-1/2" tbg. Finished RIH w/4-1/2" tbg string. POOH standing tbg in derrick. Wait-on workboat w/ ESP equip. 3-Mar-02 PU ESP BHA. RIH on 4-1/2" tbg. 4-Mar-02 Finished running ESP BHA on 4-1/2" tbg. PU/MU tbg hng. Made final splice. 5-Mar-02 RI land tbg hngr w/top of ESP @ 9985'. ND BOPE. NU Tree. Test void to 5k psi. installed wing valves. Retrieved BPV. RD mud lines. Release Rig. Trading Bay Unit Well # K-12RD Actual Completion 3/04/02 RKB toTBG Head = 33,80~ Tree connection: 2,510' 10,350' 10,487' B-1 PBTD = 12,170' TD = 12,250' MAX HOLE ANGLE = 42° @ 5800' CASING AND TUBING DETAIL SIZE ~'1' GRADE CONN [D TOP BTM. 13-3/8" 6I0 K-55 12515 38' 2,510' 9-5/8" 47 N 80 & $95 BFCklC 8681 38' [ 0,747' 7" Liner 38 P-I I0 I.TC 5920 10,48T [ 1.765' Tubing: 4-1/2" 126 N-80 BTC 3958 35 9,985' JEWEt. RY DETAIL NO. ~ I~Q [ten~ 3, 34.75 12" x 4-1/2" OCI' type '2JH-TCdA" Butt Tbg Nngr 2284 4-I/2" SFO-2 GLM w/ RA 4085 4-1/2" SFO-2 GLM w/RA Larch 6688 4-1/2" SFO-2 Gt.M w/RA Latch 7199 4-1/2" SFO-2 GLM w/RA Latch 7715 4-1/2" SFO-2 GLM w/RA Lzitcb 8708 4-[/2" SFO-2 GLM w/RK Latch 4. 10,331' 4875 15' 4-1/2" tbg stub, [,ocator Seal Assy w/20' of'seals Spaced out 3' above pkr 5. 10,350 6 00 Baker Model 'FB I" Petal Pkr, size 192-60 w/ FISH: 1-½" Orifice Valve E/line work: Fill tagged at t 1458' with bi 1/16" GR/CCL 1/15/02 Set Post-Set plug ~} 1 t,429'. Dump bait TOC ~} 11,419' Post job production results indicates phtg.f~d/ed. PERFORATION DATA Zone Top Btm Amount Condition G-5 HB-1 HB-2 HBo3 HB-4 HB-5 HB-6 HB-6 10,826' 10,910' 84 Open in '95. Reperf'd 1/02 11,037' 11,057' 20 Open in '78. Reperf'd 1/02 11,070' 11,175' 105 Open in '78, Repertd 1/02 11,175' I1,200' 25 Open in '78. Reperrd 1/02 11,216' 11,236' 20 Open in '78. ReperFd 1/02 11,310' 11,330' 20 Open in '78. Reperf'd 1/02 11,372' 11,402' 30 Open in '78. ReperCd 1/02 Open in '78. 11,424' 11,444' 20 Attempt isolation 1/02 K 12RD Actual Dwg 03-04-02 5,,'29,"02 BY: SLT .. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other~Annular Injection 2. Name of Operator 5. Type of well: 6. Datum elevation (DF~f'KB) Union Oil Company of California (UNOCAL) 'Development: X 100' KB abov~eqVlSL feet 3. Address Exploratory: 7. Unit or Property/ri'ama P. O. Box 196247 Stratigraphic: Anchorage, AK 99519-6247 Service: Trading I~y Unit 4. Location of well at surface 8. Well nu~oer 735'FSL&140' FELofSeo. 17, T9N, R,3W, SM RECEIVED King/Salmon K-12RD At top of productive interval 9. Per~it number 532' FSL & 392' FWEL of Sec 18, T9N, R13W, SM /78-57 At effective depth r' r n 1 5 ') n n t '1~. APl number rED .L LUU, ~b~,,/50. 133-20156-01 .. At t°tal6~;'P~sL & 780''' -- FEL of Sec 18, T9N, R13W, SM Alaska 0il&Gas Cons. Com~r~/11"'-'"'"'--';';~u~River/Hemlock and G zone Pool 12. Present well condition summary Am;hu~a~= Total depth: measured 11,775 feet Plugs (measuL~d)/ ' true vertical 9,867 feet Effective depth ~rueea~;~al 1;~5414 ffee: tt Junk (mea~i~ed)k_(mZe~,. )~7' N°niil~--u~ _ Casing Length Size Cem/~m[eod) M red depth True vertical depth Structural ./ _ _ . , Conductor 393' 24" /Circ to Surf _ 393' 393 Surface 2510' 13-3/8" 1~00 sx circ to surf 2510' 2429' Intermediate 10747' 9-5/8" ~ 1000 sx 10747' 8973' Production Liner 1278' ~ 7" ~ 350 sx 10487'-11765' 8755'-9859' Perforation depth: measured 10826'-10910', 1~7' 1057', 11070'-11200', 11216'-11236', 11310'-11330', 11372'-11402', 11424'-11444' true vertical 9039"95 ..t,~/62' 1~' Tubing (size, grade, and measured depth) 1'\''~/12"'k,.j/12.6~, N-80 @ 10430'. ' Packers and SSSV (type and measure~~Baker FB-1 packer @ 10,350' . . . . -'% · 13. Attachments Description summaryyoposa,: x Detailed op_eration_s pi~gram: BOP sketoh: . 14. Estimated date for commenoJng operation / 15~ well olasaifioation as: 3/1/00 ~ . , 16. If proposal well verbally approved: / Oil: X Gas: Suspendeo: / Name of approver / Date_approved_- . Se.wi.ce: 17. I hereJzy certify tha~tll~foregoing is t~ to the best of my knowledge. ~igneaa~U/VUVJd ' ' : g g .o. Conditions of approval: Notify Comn~lssion so representative may witness - Plug integrity ~/ BOP Test Location clearance Mechanical Integdyest_ Subsequent form required 10- .. Approved by order of the Commissioner Commissioner Date Form 10-403 Rev 06/15/88 nl IOI Ir, ATF SUBMIT IN TRIPLICATE Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL ) Dan Williamson Drilling Manager February 14, 2001 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Commissioner Julie Heusser Sundry Application (Form 10-403) McArthur River Field, King Salmon Platform, Well K-6RD Well K-12RD Well K-25 Well K-26RD Applications for Annulus Injection Commissioner Heusser: Enclosed are Sundry Applications (Form 10-403) for King SalmOn Well #K-6RD, K-12RD, K- 25 and K-26RD. Unocal requests permission to dispose of oil-based mud and cuttings from the upcoming drilling program at King Salmon into the 9-5/8" x 13-3/8" annulus at these four wells in addition to the annulus of K-19 which had a Sundry Application Form 10-403 submitted 12/28/00. The planned drilling program at King Salmon will be K-1 RD2, K-13RD2, K-5RD, K-20RD and potentially K-18RD. There are five proposed annuli because if one of the annuluses becomes plugged during disposal operations, the process can continue in the remaining four annuli. The attached pages to each Sundry Application provide information required under 20 AAC 25.080 regarding annulus disposal. Also included for all four applications is a summary of all the surface casing cement jobs at King Salmon and a summary of leak-off tests performed beneath the surface casing. Thero has been no prior annulus disposal at any of the wells at King Salmon platform according to ARCO and Unocal records and production personnel on the platform aro not aware of any prior annulus disposal at King Salmon. The expected start date for annulus disposal is March 1, 2001 so your timely consideration for approVal is appreciated. If there are any questions, please contact Dan Williamson at 263-7677 or Tim Billingsley at 263-7659. Dan Williamson Drilling Manager RECEIVED 1 5 001 Alaska Oil & Gas Cons. Commission Anchorage AOGCC cover letter K-25.doc DUPLICATE Tim Billingsley UNOCAL ) RKB to TBG Head = 33.80' Tree connection: 10,350' Trading Bay Unit Well # K-12RD Last Workover 11/02/78 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 24" 38' 393' 13-3/8" 61.0 K-55 12.515 38' 2,510' 9-5/8" 47 N-80 & S95 BTC/LTC 8.681 38' 10,747' 7" Liner 38 P-110 LTC 5.920 10,487' 11,765' Tubing: 4-1/2" 12.6 N-80 BTC 3.958 35 10,430' JE~rELRY DETAIL NO. Depth ID Item 34.75 1. 303' 3.813 2. Camco 4-1/2" MMG Gaslifl Mandrels. GLM 4/1. 2378 4-1/2" Camco MMG GLM #2. 4299 4-1/2" Camco MMG GLM 4/3. 5664 4-1/2" Camco MMG GLM #4. 6502 4-1/2" Camco MMG GLM 455. 6971 4-1/2" Camco MMG GLM #6. 7417 4-1/2" Camco MMG GLM g7. 7857 4-1/2" Camco MMG GLM 88. 8298 4-1/2" Camco MMG GLM 89. 8766 4-1/2" Camco MMG GLM #10. 9183 4-1/2" Camco MMG GLM 4/11. 9629 4-1/2" Camco MMG GLM #12. 10,044 4-1/2" Camco MMG GLM 4/13. 10,304 4-1/2" Camco MMG 3. 4.875 4. 10,350 6.00 5. 10,430 12" x 4-1/2" OCT type "UH-TC-1A" Butt Tbg Hngr 4-1/2" Camco TRB-6, SSSV Locater Seal Assy w/?' of seals Baker Model "FB-I" Perm Pkr, size 192-60 EOT 10,487' 5 10,747' ::::::::::::::::::::::::::::::::::::: -- G-5 -- B-1 _- B-2 -_-B-3 B-4 _- B-5 -= B-6 PBTD = 11,641' TD = 11,775' MAX HOLE ANGLE = 42° @ 5800' K12RDCurrentSch0900.doc Kinley Caliper run 4/98 indicates possible holes in tubing at 10,200' and 10,248'. (joint 327) Corrosive damage located in tubing from joint 37 through 323. (10% tubing wall loss) Slickline work" Fill tagged at 11430' with 3.8" GR 6/27/00 Zone G-5 HB-1 HB-2 HB-3 HB-4 HB-5 HB-6 PERI?ORATION DATA Top 10 826' 11 037' 11 070' 11 175' 11 216' 11 310' 11 372' 11 424' Btm 10,910' 11,057' 11,175' 11,200' 11,236' 11,330' 11,402' 11,444' Amount Condition 84 Open 20 Open 105 Open 25 Open 20 Open 20 Open 30 Open 20 Open RECEIVED FEB 1 5 2001 AlaSka Oil & Gas Cons. Commission Anchorage REVISED: 9/26/00 DRAWN BY: SLT Information Required for Annulus Disposal of Drilling Waste 20 AAC 25.O80 K-12RD RECEIVED I Annulus to be used for disposal: FIB 5 g001 K-12RD, 9-5/8" x 13-3/8" annulus, 13-3/8" shoe is at 2510' MD/2429' TVD. Alaska 0il & Gas Cons. Commission Anchorage 2 Depth to the base of freshwater aquifers and permafrost There is no permafrost at the King Salmon platform. At the 13-3/8" casing shoe depth of 2510' MD/2429' TvD for K-12RD, the formation waters exceed 6000 ppm chlorides. Also, there is a fresh water exemption for wells at the King Salmon platform. Stratiaraphic description of the interval exposed to the open annulus and other information sufficient to support a commission finding that the waste will be confined and will not come to the surface or~ except to the extent allowed under (e) I of this section~ contaminate freshwater The 13-3/8" shoe is at 2510' MD/2429' TVD in K-12RD. This corresponds to the Middle Tyonek formation. The waste is expected to be confined within this strata as this is the primary gas trap in the McArthur River Field with no evidence of surface breaching. 4 List of all publicly recorded wells within ~ mile~ and all publicly recorded water wells within one mile~ of the well that will be receivina drilling waste The attached plat shows the adjacent wells to King Salmon K-12RD. 5 Types and .maximum volume of waste to be disposed of and the estimated density of the waste slurry The waste will consist of 9.0 ppg oil base mud with small concentrations of drill cuffings mixed with high concentrations of water or ground cuttings slurrified in gelled water. Seawater will be injected ahead and behind the waste slurry injections. The average density of the waste will be appx. 8.8 ppg when the seawater dilution and the pre/post- flushes are taken into account. The estimated maximum volume from the five potential redrills to be disposed of is 8,000 bbls OBM/water and 26,000 bbls seawater. Description of any waste sou;ht to be determined as drilling waste under (h}(3) of this section: 20 AAC 25.080(h)(3) Other substances that the commission determines upon application are wastes associated with the act of drilling3 a well permitted under 20 AAC 25.005. None at this time. 7 Estimate of the maximum anticipated pressure at the outer casin; shoe durin~ disposal operations and calculations showing how this value was determined. An injectivity test was performed on the 9-5/8" x 13-3/8" annulus of K-12RD on 10/26/00 and 800 BWPD was injected at 500 psi. The maximum injection pressure while disposing of mud and cuttings down the K-12RD annulus will be 1500 psi. The proposed 1500 psi limit on injection pressure will not cause a problem with 13-3/8" casing burst or 9-5/8" casing collapse as shown in item #9. AOGCC ann disp K-12RD.doc Tim Billingsley Details that show that the shoe of the outer casing is set below the base of permafrost, if present, and any freshwater aquifer,other than freshwater excepted under (e)(1) of this section, and is adequately cemented to provide zone isolation; the information relied upon and submitted must include (A) cementing records; and (B) a cement quality log or formation inte;ritv records; The 13-3/8" shoe on K-12RD was set at 2510' MD/2429' TVD which is below any freshwater aquifer. (A) The 13-3/8" casing was cemented on 12/6/68 with 1100 sx (2288 cuff or 408 bbls) of 12.8 ppg lead cement and 400 sx (82 bbls) of 15.8 ppg tail cement. There were "approximately 150 sx cement returns" to surface. (B) No bond log was run on the 13-3/8" casing. There also was no leak off test below the 13-3/8" shoe when the well was first drilled in 1968 as K~12. In 1978, the 9-5/8" casing was cut and removed and the well was redrilled as K-12RD from an open hole kick-off plug just below the 13-3/8" shoe. There was no leak-off test performed at this time either. Details that show that the inner and outer casing strings have sufficient stren_~th in collapse and burst to withstand the anticipated pressure of disposal operations.: The 13-3/8" outer casing in K-12RD is 61#, J-55 which has a burst rating of 3090 psi for new pipe. Therefore, the anticipated maximum injection pressure of 1500 psi will not be a problem and will only be 49% of new pipe burst rating. The 9-5/8" inner casing in K-12RD was run in 1978 and is as follows: RECEIVED 47#, S'95 from surface to 1841,, collapse rating = 5080 psi 47#, L-80 from 1841' to 8568', collapse rating = 4750 psi 47#, S-95 from 8568' to 10747', collapse rating = 5080 psi 7" 38# P-110 liner top at 10487', collapse rating = 15,110 psi FEB 1 5 2001 Alaska 0il & Gas Cons. Commission Anchorage The collapse force exerted by the anticipated maximum injection pressure to 1500 psi on the 9-5/8" x 13-3/8" annulus Would be: (1500 psi + (8.8 ppg x .052 x TVD)) -1020 psi gas lift pressure K-12RD is a gas'lifted producing well with a tbg x 9-5/8" annulus pressure of 1020 psi. The worst collapse case woUld be above the top of cement at 8680' MD (as calculated in item #11 below) and at the base of the 47#, L-80 casing at 8568' MD/7175' TVD which would be: ((1500 psi + (8.8 ppgx.052x7175')) - (1020 gas lift pressure) = 3763 psi = 79% of new collapse rating of 4750 psi for 9-5/8 47#, L-80 casing 10 This collapse pressure is acceptable and there will be a requirement placed on the annulus ~iisposal crews to verily that the K-12RD inner annulus is on gas lift at 1020 pSi before any injection down the outer annulus can begin. The injectivity test in K-12RD on 10/26/00 indicated the formation 2510' MD/2429' TVD will readily take fluid at 500 psi. Therefore, the actual disposal pressure will probably be less than 1500 psi but Will not be allowed to exceed 1500 psi. The downhole pressure obtained during a formation integrity test conducted below the outer casing shoe; There was no leak-off test performed on the original K-12 well when the 12-1/4" hole was drilled on 12/5/68 below the 13-3/8" casing shoe at 2510' MD/2429' TVD. When the well was redrilled in 1978 as K-12RD, the 9-5/8" casing was cut and pulled all the way back to surface. An open hole cement plug was utilized to kick-off the redrill. On 8/19/78, the cement was drilled below the 13-3/8" shoe without a leak off test. On 10/26/00, an injectivity test with 8.5 ppg filtered inlet water was performed down the 9- 5/8" x 13-3/8" annulus of K-12RD. The test injection rate was 800 BPD at 500 psi. The 13-3/8" x 24" annulus was monitored during this test. There was no communication up to the 24" conductor set at appx 393' during the injectivity test. This test indicates the leak off test would be 12.5 ppg EMW or 0.65 frac gradient, f As per 20 AAC 25.080(e)(2), Unocal requests the AOGCC to grant an exception for the downhole disposal pressure exceeding the downhole pressure obtained during the injectivity test of 10/26/00. The proposed maximum disposal pressure of 1500 psi at the surface with 8.8 ppg disposal slurry as opposed to the 500 psi with 8.5 ppg water during the injectivity test on 10/26/00 is justified due to the good 15.8 ppg tail slurry pumped at the 13-3/8" casing shoe with cement circulated to surface, the evidence of no communication up to the 24" conductor shoe at 393' during the injectivity test, and the geological interpretation that the Middle Tyonek formation is sufficiently confined with no evidence of surface breaching in the McArthur River Field. 11 Identification of the hydrocarbon zones, if any, above the depth to which the inner casing is cemented; The 13-3/8" shoe is at 2510' MD/2429' TVD and the 9-5/8" shoe is at 10747' MD in K- 12RD. There is a 7" liner top at 10487'. There was no bond log on the 9-5/8" casing or the 7" liner in 1978. The 9-5/8" casing in K-12RD-was cemented on 10/7/78 with 1000 sx (205 bbls) of 15.8 ppg cement. The calculated top of cement was 8680' MD. This calculated TOC is based on the following: 205 bbl total cement pumped Float track = 80' x .0732 bbl/ft = 6 bbls Rathole = 10924'-10747'= 177' x .146 bbl/ft of 12-1/4" hole = 26 bbls Cement behind pipe = 205 - 6 - 26 = 173 bbls No caliper, annulus size = .0558 bbl/ft for 12-1/4" hole by 9-5/8" csg Cmt behind pipe = 173 bbls/(.0558 x 1.5 for est 50% washout) =2067' TOC= 10747'- 2067' =8680' The open annulus in K-12RD is therefore from 2510' MD/2429' TVD to 8680' MD/7266' TVD which is in the Middle Tyonek of the Northwest Feature of the McArthur River Field. This interval is Iow on structure in K-12RD and there are no hydrocarbon zones present. 12 The duration of the disposal operation, not to exceed 90 days; 13 Unocal requests permission to use K-12RD's 9-5/8" x 13-3/8" annulus for oil based mud and cuttings disposal for more than 90 days. It is anticipated that the workover/drilling program at King Salmon will be 3 workovers and up to 5 major redrills. The first drilling well will be K-1 RD and disposal from this drilling well should commence about 3/1/01 and the entire drilling program could last until December 1, 2001. Disposal operations for the drilling mud from the five drilling wells should be completed by December 31, 2001. There will be applications for annulus disposal at four other wells at King Salmon in case one or more annuli become plugged. The five wells which will be applied for annulus disposal are: K-6RD, K-12RD, K-19, K-25 and K-26RD. Whether drilling waste has previously been disposed of in the annular space of the well and, if so, a summary of the dates of the disposal operations~ the volumes of waste disposed of, and the wells where the drillin; waste was aenerated; No drilling waste has previously been disposed of in the annular space of K-12RD. There has also been no known annulus disposal at any of the other King Salmon wells. 14 The well where the drilling waste to be disposed of was or will be aenerated; 15 16 The 2001 proposed drilling program consists of K-1RD, K-13 RD, K-20RD, K-5RD and possibly K-18RD. There will also be 3 workovers at K-15RD, K-24RD and K-30. Fluids from these'three workovers will not be disposed of in the K-12RD annulus. If the operator proposes not to comply with a limitation established in (d) of this section, an explanation of why compliance would be imprudent; Compliance with section (d) limitations as outlined below will not be a problem. The commission will not authorize disposal of drilling waste (1) in a volume greater than 35,000 barrels through the annular space of a single well. (2) For a period longer'than one year throUgh the annular space of a single well (3) Into a hydrocarbon-bearing stratum; or (4) Through the annular space of a well not located on the same drill pad or platform as the drilling operation generating the drilling waste. Any additional data required by the commission to confirm containment of drillin; waste;, The attached spider plot describes K-12RD's 13-3/8" casing shoe in relation to other King Salmon wells' 13-3/8" shoes. In order to verify that the proposed annulus injection in K- 12RD does not communicate to other wellbores, Unocal proposes to monitor the following four 9-5/8" x 13-3/8" annuli: K-1RD, K-22RD, K-26RD and K-25. These four wellbores are close to K-12RD and in different directions from K-12RD thereby surrounding the proposed injection point with monitoring locations. RECEIVED FEB 1 5 200 Alaska Oil & Gas Cons. Commission Anchorage King Salmon Platform Surface Casing Cement Summary Well Surf Csg Size Shoe MD Shoe TVD Cmt Volume, sx Comments K-1 RD 13-3/8" 2384' 2147' 2608+80 Tag firm cmt at 82', pump 80 sx top job with cmt to surf K-2RD 13-3/8" 2372' 2298' 2608+450 Lost returns during primary job, pump 450 sx top job @ 350' with cmt to surf K-3RD 13-3/8" 2506' 2337' 1560 No top job required No cmt to surf on 3675 sx primary job. Top job found TOC @ 125', pump 125 sx with K-4RD 13-3/8" 2880' 2769' 3675+125 Rood cmt to surf K-5 13-3/8" 2476' 2252' 1625 Cmt returns to surf K-6RD 13-3/8" 2186' 2088' 1760 Cmt returns to surf K-7RD 13-3/8" 3618' 3039' 1600 650 sx 1st stage and 950 sx thru DV tool @ 1480' K-9 13-3/8" 2492' 2360' 1625 No top job required K-10RD 13-3/8" 4998' 3883' 2255 1300 sx 1st stage, 955 sx thru DVT @ 1511', 335 sx cmt returns to surf K-11 13-3/8" 2470' 2400' 1550 Cmt circ to surface, 500 cuff K-12RD 13-3/8" 2510' 2429' 1500 Cmt circ to surface, 150 sx. K-13RD 13-3/8" 5011' 4166' 1050+200 650 sx 1st stage, 400 sx thru DVT @ 2509', 200 sx top job @ 180' with 25 sx to surf . K-15RD 13-3/8" 2401' 2284' 1550 Cmt circ to surf, 500 cuff K-17 13-3/8" 2183' 2032' 1371 Cmt circ to surf, 350 cuff K-18 13-3/8" 2477' 2283' 1800 Cmt circ to surf, 1030 cuff K-19 13-3/8" 2591' 2302' 1750 Cmt circ to surface, 800 cuff K-20 9-5/8" 4999' 2899' 2325 1400 sx 1st stage, 925 sx thru DVT @ 1396', circ 150 sx cmt to surf on 2nd stage K-21 RD 13-3/8" 2714' 2390' 1775 Cmt circ to surface, 798 cuff K-22RD: 13-3/8" 5493' 4825' 2200+500 1500 sx 1st stage, 700 sx thru DVT @ 2881', 500 sx (905 cuff) bradenhead top job K-23 13-3/8" 5005' 3940' 2387 Cmt circ to surface K-24RD 13-3/8" 5712' 4229' 2412 Cmt circ to surface, 798 cuff K-25 13-3/8" 1997' 1997' 1260 Originally known as K-16, cmt circ to surface K-26RD 13-3/8" 2938' 2710' 2050 Cmt circ to surface, 80 bbls. K-30RD 13-3/8" 2187' 2012' 1490 Cmt circ to surface Bold indicates updated information from K-19 12/28/00 info and 1/23/01 info. Tim Billingsley KS surf csg cmt and LOTsummary.xls 1/26/01 King Salmon Platform Surface Casing Leak-off Test Summary Well Surf Csg Size Shoe MD Shoe TVD LOT, ppg Comments . K-1 RD 13-3/8" 2384' 2147' No leak-off test performed below 13-3/8" shoe, 11/2/67 K-2RD 13-3/8" 2372' 2298' , No leak-off test performed below 13-3/8" shoe, 11/10/67 K-3RD 13-3/8" 2506' 2337' No leak-off test performed below 13-3/8" shoe, 10/68 K-4R D 13-3/8" 2880' 2769' No leak-off test performed below 13-3/8"'shoe~ 1/15/68 K-5 13-3/8" 2476' 2252' No leak-off test performed below 13-3/8" shoe, 2/26/68 No leak-off test performed below 13-318" shoe, 2/26168, on original K-6 well. K-6RD had 9-5/8" cut and pulled and an open hole kick-off; LOT on 4/10/88 @ K-6RD 13-3/8" 2186' 2088' 15.0 2295' MD/2190' TVD was 15.0 pp.q EMW. K-7RD 13-3/8" 3618' 3039' No leak-off test performed below 13-3/8" shoe, 7/9/68 K-9 13-3/8" 2492' 2360' No leak-off test performed below 13-3/8" shoe, 5/28/68 K-10RD 13-3/8" 4998' 3883' No leak-off test performed below 13-3/8" shoe, 1/24/69 K-11 13-3/8" 2470' 2400' No leak-off test performed below 13-3/8" shoe, 10/3/68 No leak-off test performed below 13-318" shoe, 12/9/68, on original K-12 well. K-12RD had 9-518" cut and pulled and open hole kick-off just below 13-318' shoe K-12RD 13-3/8" 2510' 2429' but no LOT on 8119/78. K-13RD 13-3/8" 5011' 4166' .No leak-off test performed below 13-3/8" shoe, 12/6/68 K-15RD 13-3/8" 2401' 2284' No leak-off test performed below 13-3/8" shoe, 2/18/69 K-17 13-3/8" 2183' 2032' 10.6 2/5/73, pumped into formation at 150 psi with 9.2 ppg mud @ 2257' MD/2091' TVD K-18 13-3/8" 2477' 2283' 10.3 6/4/73, pumped into formation at 125 psi with 9.3 ppg mud @ 2492' MD/2295' TVD K-19 13-3/8" 2591' 2302' 11.3 3/1/74, pumped into formation at 325 psi with 8.6 ppg mud @ 2637' .MD/2336' TVD K-20 9-5/8" 4999' 2899' No leak-off test performed below 9-5/8" shoe, 7/17/69 K-21 RD 13-3/8" 2714' 2390' No leak-off test performed below 13-3/8" shoe, 5/23/75 K-22RD 13-3/8" 5493' 4825' 11.3 2/17/75, pumped into formation at 550 psi with 9.1 ppg mud @ 5560' MD/4852' TVD K-23 13-3/8" 5005' 3940' 12.5 2/9/78, pumped into formation at 625 psi with 9.5 ppg mud @ 5070' MD/4000' TVD K-24RD 13-3/8" 5712' 4229' No leak-off test performed below 13-3/8" shoe, 10/28/79 Originally known as K-16, no LOT on 3/23/69. K-25 had 9-5/8" cut and pulled and an Open hole kick-off: LOT on 6/26/85 @ 2202' K-25 13-3/8" 1997' 1997' 11.5 @ shoe MD/2202' TVD with 9.1 ppg mud pumped away @ 250 psi. 12/23193, pumped into formation @ 735 psi with 8.6 ppg mud @ 2946' MD/2716' K-26RD 13-3/8" 2938' 2710' 13.8 TVD K-3ORD 13-3/8" 2187' 2012' No leak-off test performed below 13-3/8" shoe, 1/29/70 Bold indicates updated information from K-19 12/28/00 info and 1/23101 info. RECEIVED Tim Billingsley KS surf csg cmt and LOTsummary. xlsLOTs FEB i 5 1001 Alaska 0i~ & Gas Cons. Commission Anchorage .I o 1,ooo ~ooo 3,ooo ~ I I SCALE IN FEET W. BAY I K-26 MtDLE RIVER ST. g K- 12 R D ~1 I K-10 .d,- K-10RD K-1 ...j ~ K-SRD { G-17 K-3RD , G-15 G-g9RD G-g7 30 KI K-18~ G-13 a9 G-5 ,/ A-27 KI MC K-17 lO (OH) G-25 G41-RD ~-~Zding Bay Unit Boundary ST. 1 ,x ?.? ::. ,."; ?:"':.: K-13 i K-2RD K-7~ 0 Plats~King Prop OBMud Disp 3883' --~400~ 1,000 2,000 l SCALE IN FEET 2284'(K-15RD) (K-iV) 3,000 M-30 K-6 K- 2 February 20, 2002 TONY KNOWLES, 'GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 UNOCAL Field Superintendents 260 Cavair Street Kenai, Alaska 99611 RE: No-Flow Verification TBU Well K-1 RD2 PTD 201-009~_, TBU Well K-12~" Gentlemen: On February 8 - 9, 2002 AOGCC Petroleum Inspector Lou Grimaldi witnessed "no-flow" tests on Wells K-1 RD2 and K-12 at UNOCAL's King Salmon Platform, Trading Bay Unit, McArthur River Field. Mr. Grimaldi arrived on King Salmon Platform and proceeded to observe the wells. Over the course of the nearly 3 hour witnessed periods, the test performance of TBU wells TBU Well K-1RD2 (201-009) and K-12 (178-057) demonstrated that the wells are incapable of unassisted flow of hydrocarbons to the surface. Therefore, these wells need not be equipped with a commission approved fail-safe automatic surface-controlled subsurface safety valve ("SSSV") system. However, these wells must be equipped with fail-safe automatic surface safety valve ("SSV") systems capable of Preventing uncontrolled flow and maintained in proper working condition. If for any reason any of the wells become capable of unassisted flow of hydrocarbons, the SSSV must be returned to service. A copy of this letter should be maintained in the respective well files on board King Salmon. Thomas E. Maunder,~E~' Sr. Petroleum Engineer TEM/jjc Dan Williamson Drilling Manager t' : Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL 08/01/01 RECEIVED AUG 0 1' 2001 Alaska 0il & Gas Cons. Commission Anchorage Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Commissioner Julie Heusser Proposed Drilling Waste from Monopod Platform to King Salmon Platform Approved and Proposed Annulus Disposal Wells Well K-6RD (Ap.proved) ~Weli~K~12RD ~ Well K-19 (Approved) Well K-25 Well K-26RD Commissioner Heusser: Unocal requests permission from the AOGCC to disPose of drilling waste from proposed drilling on the Monopod platform in the above annuli on the King Salmon platform. Sundry Applications (Form 10-403) for King Salmon Well's #K-6RD, K-12RD, K-19, K-25 and K-26RD have been submitted to you.' Two wells, K-6RD and K-19, were aPproved and the remaining three have been on hold pending whether more than two annuli will be required to dispose of all of the drilling waste. The two approved annuli, K-6RD and K-19, have been used as annulus disposal wells for drilling waste generated by drilling on the King Salmon platform at K-1RD, K-13RD2, K-18RD and will be used for the upcoming K-24RD. After K- 24RD is completed, no more drilling will be done on the'King Salmon platform and the crews will move to Monopod to drill one to two wells as follow-up wells to the highly successful K- 13RD2 (8000 BOPD). There will also be one or more workOvers on Monopod while the rig is active but workover waste will not be transported to King Salmon for annulus disposal. It is unknown at this time how many annuli will be needed at the King Salmon to handle all of the waste from the Monopod without exCeeding the 35,000 bbl limit on any one annulus. Therefore, Unocal requests a waiver from the AOGCC for all 5 of the above King Salmon annuli as described in 20 AAC 25.080(d) (4) "Unless the operator demonstrates that compliance with a limitation established in 1-4 of this subsection is imprudent, the commission will not authorize disposal of drilling waste: ... (4) through annular space of a Well not located on the same drill pad or platform as the drilling operation generating the drilling waste." Unocal believes it is more prudent to utilize existing equipment on the King Salmon platform to dispose of drilling waste from the Monopod platform than to haul and store waste at other locations. The grind and inject unit and disposal annuli on the King Salmon platform have AOGCC letter Monopod Waste to King. doc Tim Billingsley proven to be an efficient, safe and environmentally attractive means of disposing of oil based mud cuttings. Unfortunately, there is not as much room on the Monopod platform as the King Salmon platform and the grind and inject unit can not be moved to the Monopod. There will be one to two wells drilled with oil based mud on the Monopod platform and the ultimate disposal of the cuttings are in question. The cuttings could be hauled to Bruce platform and ultimately injected into a disposal well there. However, this would be a longer process due to lack of equipment currently on Bruce, summer-only operating situation currently at Bruce and lower throughput capacity at Bruce that would limit injection and necessitate long.term storage of cuttings in drums. · The big advantage of the King Salmon grind and inject unit is that it can process cuttings as soon as theY are generated. Cuttings could be hauled from Monopod in 25-bbl rental totes. The rental totes could be quickly dumped into the 300 bbl receiving tank of the grind and inject unit and return to Monopod for more cuttings. This would be much better than hauling and storing the cuttings as would be the case on the Bruce platform or other disposal options. The Monopod-King Salmon relationship has many characteristics that are beneficial regarding this disposal proposal. The Monopod platform is only one platform to the north of the King Salmon. The proposed wells on the Monopod will be drilling to the south and will be targeting the same Northern.Nose geologic feature that K-13RD2 is currently completed in. The Monopod and King Salmon Platform have the same ownership, Unocal and Forest Oil. Therefore, it would be environmentally and economically more prudent to transport oil based mud cuttings from the Monopod platform, to the King Salmon platform where annulus disposal will be quick and storage problems will be minimal. Please respond with your decision regarding this request for waiver of 20 AAC 25.080(d)(4) in a timely manner. If the waiver is not granted, there will be significant planning required to provide a viable alternative to the cuttings disposal problem. The proposed drilling on the Monopod platform should commence in October 2001. If there are any questions, please contact Dan Williamson at 263-7677 or Tim Billingsley at 263-7659. Dan Williamson v ~ ,, ~, Drilling Manager Dan Williamson Drilling Manager Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL 08/01/01 RECEIVED AUG 0 1' 2:001 Alaska Oil & Gas Cons. CommJssi0fl Anchorage Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Commissioner Julie Heusser Proposed Drilling Waste from Monopod Platform to King Salmon Platform Approved and Proposed Annulus Disposal Wells Well K-6RD (Approved) Well K-12RD Well K-19 (Approved) Well K-25 Well K-26RD Commissioner Heusser: Unocal requests permission from the 'AOGCC to dispose of drilling waste from proposed drilling on the MonopOd platform in the above annuli on the King Salmon platform. Sundry Applications (Form 10-403) for King Salmon Well's #K-6RD, K-12RD, K-19, K-25 and K-26RD have been submitted to you. Two wells, K-6RD and K-19, were approved and the remaining three have been on hold pending whether more than two annuli will be required to dispose of all of the drilling waste. The two approved annuli, K-6RD and K-19, have been used as annulus disposal wells for drilling waste generated by drilling on the King Salmon platform at K-1 RD, K-13RD2, K-18RD and will be used .for the upcoming K-24RD. After K- 24RD is completed, no more drilling will be done on the King Salmon platform and the crews will move to Monopod to drill one to two wells as follow-up wells to the highly successful K- 13RD2 (8000 BOPD). There will also be one or more workovers on Monopod while the rig is active but workover waste will not be transported to King Salmon for annulus disposal. It is unknown at this time how many annuli will be needed at the King Salmon to handle all of the waste from the Monopod without exceeding the 35,000 bbl limit on any one annulus. Therefore, Unocal requests a waiver from the AOGCC for all 5 of the above King Salmon annuli as described in 20 AAC 25.080(d) (4) "Unless the operator demonstrates that compliance with a limitation established in 1-4 of this subsection is imprudent, the commission will not authorize disposal of drilling waste: ... (4) through annular space of a well not located on the same drill pad or platform as the drilling operation generating the drilling waste." Unocal believes it is more prudent to utilize existing equipment on the King Salmon platform to dispose of drilling waste from the Monopod platform than to haul and store waste at other locations. The grind and inject unit and disposal annuli on the King Salmon platform have AOGCC letter Monopod Waste to King. doc Tim Billingsley proven to be an efficient, safe and environmentally attractive means of disposing of oil based mud cuttings: Unfortunately, there is not as much room on the Monopod platform as the King Salmon platform and the grind and inject unit can not be moved to the Monopod. There will be one to two wells drilled with oil based mud on the Monopod platform and the ultimate disposal of the cuttings are in question. The cuttings could be hauled to Bruce platform and ultimately injected into a disposal well there. However, this would be a longer process due to lack of equipment currently on Bruce, summer-only operating situation currently at Bruce and lower throughput capacity at Bruce that would limit injection and necessitate long term storage of cuttings in drums. The big advantage of the King Salmon grind and inject unit is that it can process cuttings as soon as they are generated. Cuttings could be hauled from Monopod in 25-bbl rental totes. The rental totes could be quickly dumped into the 300 bbl receiving tank of the grind and inject unit and return to Monopod for more cuttings. This would be much better than hauling and storing the cuttings as would be the case on the Bruce platform or other disposal options. The MonOpOd-King Salmon relationship has many characteristics that are beneficial regarding this disposal proposal. The Monopod platform is only one platform to the north of the King Salmon. The proposed wells on the Monopod will be drilling to the south and will be targeting the same Northern Nose geologic feature that K-13RD2 is currently completed in. The Monopod and King Salmon Platform have the same ownership, Unocal and Forest Oil. Therefore, it would be environmentally and economically more prudent to transport oil based mud cuttings from the Monopod platform to the King Salmon platform where annulus disposal will be quick and storage problems will be minimal. Please respond with your decision regarding this request for waiver of 20 AAC 25.080(d)(4) in a timely manner. If the waiver is not granted, there will be significant planning required to provide a viable alternative to the cuttings disposal problem. The proposed drilling on the Monopod platform should commence in October 2001. If there are any questions, please contact Dan Williamson at 263-7677 or Tim Billingsley at 263-7659. Dan Williamson Drilling Manager Unocal Corporation Oil & Gas Operations 909 West 9th Avenue, P.L~. dox 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL ) October 19, 1995 Alaska Mr. Russ Douglas, Commissioner Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501-3192 Dear Mr. Douglas: Re: King Salmon Platform Well K-12RD APl Number 50-733-20074-01 On April 25, 1995 the following intervals were perforated in Well K-12RD: BENCH TOP (MD) BOTTOM (MD) FEET G5 10,826 10,910 84 TOTAL 84 Attachment Very truly yours, Candace Williams OCT 2 5 ~995 0il & Gas Cons. Commission Anchorage · , - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM,.;:SSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown__ .--- Stimulate__ m Plugging ,-. Pull tubin~l After casin~l Repair well X Perforate X Pull tubing 6. Datum elevation (DF or KB) 100' KB above MSL 7. Unit or Property name Trading Bay Unit 8. Well number--~/~'- 5'~7 K-12RD Plugs (measured) 2. Name of Operator 5. Type of Well: Development UNION OIL COMPANY OF CALIFORNIA (UNOCAL) Exploratory 3. Address Stmtigraphic P.O. BOX 196247 ANCHORAGE~ AK 99519 - 6247 Service 4. Location of well at surface Leg 4, Cond. 29, King Salmon Platform 735' FSL & 140' FEL, Sec. 17, T9N, R13W, SM At top of productive interval 474' FSL 221' FEL, Sec. 18, T9N, R13W, SM © L At effective depth [~ ~" i /~i 521' FSL, 469' FEL, Soc. la, T9N, R13W, SM I~ ~ ~ i~! /~t At total depth 534' FSL~ 554' FEL~ Sec. 18, T9N~ R13W~ SM 12. Present well condition summary Total depth: measured . 11,641 feet true vertical 9,762 feet 9. Permit number 7-176 10. APl number 50-733-20074-01 11. Field/Pool McArthur River/Hemlock feet Effective depth: measured 11,517 feet Junk (measured) true vertical 9657 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2,510' 13-3/8" 2,510' Intermediate Production 10,747' 9-5/8" 10,747' 9,003' Liner 1,278 7" 11,765' Perforation depth: measured See Attached !13. true vertical Tubing (size, grade, and measured depth). 4-1/2", 11.6#, N-80 BTC ~ 10,430' MD Packers and SSSV (type and measured depth) Camco TRB-6 ~ 303' MD~ Baker Model FB-1 Packer ~ 10~350' MD Stimulation or cement squeeze summary Intervals treated (measured) OCT 2 5 ~995 ~as~a u~ & Gau Gu.~. Gummi~iu Anchorage 14. Treatment description including volumes used and final pressure Representative Daily Average Production or InJection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Data Tubing Pressure Prior to well operation 3128/95 215 90 2,647 1110 100 ._Subsequent to operation 4/28/95 269 60 3,099 1140 190 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run , Daily Report of Well Operations Oil X Gas Suspended Service 17. I hereby certify that the for{~j~i] i~~ ~.~_~ ... e best of my knowledge. Signed G. Russell Schmidt ~~/~.~,wwcx/- Title Drilling Manager Date F°rm 10-404 Rev 06/15/88 ! .... SUBMIT IN DUPLICATE Sheet3 ATTACHMENT #1 TBU WELL K-12RD PERFORATION INTERVALS I New Perforations: Bench G-5 10,826'- 10,910' MD 9,061'- 9,133' TVD Bench 3 11,175' - 11,200' MD 9,367' - 9,388' TVD Bench 5 11,310' - 11,330' MD 9,481' - 9,498' TVD Re-Perforations: Bench I 11,037' - 11,057' MD 9,249' - 9,266' TVD Bench 2 11,070' - 11,175' MD 9,277' - 9,367' TVD OCT 5 19 5 ~tt & Gas Cons. ,, ~chorag.e Page 2 Unocal North Amed ~ Oil & Gas Division Unoc-~l C~rcor~tton P.O. Box 190247 Ancnoraa_ e. Alaska '3_9519-024.7 Teiepnone [90~ 276-7600 13 OCAL Alasxa Region April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, kK 99504 Attn: Ms. Elaine Johnson Dear Ms. Johnson: I have attached surface survey locations of the "Legs" and conductors for the four platforms in tke Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. Yours very truly, G Shl~ Regional Dri ling Manager GSB/lew KING SALMON PLATFORM FROM SE CORNER SEC. 17, TgN, R13W CONDUCTOR LEG ~l' "Y" COOR. "X" COOR. WELL #' FNL 2,511,762 213,819 K-21 & RD 688 2,511,761 213,815 K-30 687 2,511,76q 213,811 K-18 690 2,511,768 213,810 K-17 694 2,511,772 213,812 K-23 (23-19) 698 2,511,773 213,817 K-19 699 2,511,770 213,821 K-22 & RD 696 2,511,766 213,822 K-20 692 LEG #2' 2,511,690 213,768 , l0 ll 12 13 14 15 16 _~G #3' 17 18 19 20 21 22 23 24 Leg #4' 25 26 27 28 29 30 31 32 2,511,686 213,772 K-15 & RD 611. 2,511,684 213,768 K-9 610 2,511,687 213,763 K-4 & RD 613 2,511,691 21 3,762 K-11 617 2,511,695 213,765 K-13 & RD 621 2,511,696 213,769 K-2 & RD ' 622 2,511,694 213,776 K-7 & RD 619 2,511,689 21 3,774 K-5 615 2,511,723 2,511,721 2,511,724 2,511,728 2,511,732 2.,511.,733 2,511,731 2,511,726 2,511,799 2,511,798 2,511,801 2,511,805 2,511,809 2,511,810 2,511,807 2,511,803 213,712 213,708 ~213,703 213,702 213,705 213,709 213,713 213,714 213,760 213,756 213,752 213,751 213,753 213,758 213,762 213,763 K-8 K-1 & RD K-10 &'RD K-16 K~..12 & .~RD K-6 & 24 K-3 & RD 725 724 727 731 735 736 729 FWL 74 78 82 83 81 76 72 71 121 126 130 131 128 124 120 ll9 133 135 141 142 140 135 130 "~ ..... ~ ..... ~ * ALA~f"'% OIL AND GAS CONSERVATION COMMIS'. ~ .-.. REPORT: OF SUNDRY WELL OPEN TIdlIN w. ' oc Woo 1. Operations pedormed: Operation~down ~ Stimulat~ ~ Plugging ~ Pedo'rate ~ Pull tubing __ Nter casing __ Rear ~11 __ Pull tu~ng __ ~her __ 2. Name of Operator ' 5. Ty~ of Well: 6. Datum elevation (DF or KB) UNOCAL (ARCO Alaska Inc. is sub-operafor De~lopment~ 100~ KB feet Ex,oratory __ " 3. Address Stratigra~ic __ 7. Unit or Prope~y name P. O. Box 190247 Anchorage, AK99519 Service__ Trading Bay Unit 4. Location of well at surface 735' FSL, 140' FEL, Sec. At top of productive interval 474' FSL, 221' FEL, Sec. At effective depth 521' FSL, 489' FEL, Sec. At total depth 534' FSL, 554' FEL, Sec. 17, T9N, R13W, SM 18, T9N, R13W, SM 18, T9N, R13W, SM 18, T9N, R13W, SM 8. Wellnumber K-12RD 9. Permitnumber/approvalnumber 9-173 10. APInumber 50-- 773-20156-01 11. Field/Pool Hemlock 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11,641 feet Plugs(measured) 11,464' 9,762 ~et 11,464 feet Junk(measured) 11,464' 9,612 feet Casing Surface Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 2,510' 13-3/8" -- 2,510' 2,438' 10,747' 9-5/8" -- 10,747' 9,003' 1,278' 7" -- 11,765' 9,867' measured 11,037-11,057'; 11,175-11,200'; 11,310-11,330'; 11,424-11,444'; 11,070-11,175'; 11,216-11,236'; 11,372-11,402'. truevertic~ 9,151-9,168'; 9,266-9,288'; 9,384-9,401'; 9,478-9,494'; 9,176-9,266'; 9,302-9,318'; 9,431-9,456'. Tubing (size, grade, and measured depth) 4-1/2", 12.6~, N-80 BTC ~ 10,430' MD. B P, ackers and SSS,V,Qv~e arid measured clept, b)~ aKer mooewrm'-'~ KKr. g ~U,~2U MD. Camco TRB-6 ~ 303' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED OCT 1 91989 Naska 0il & Gas Cons. C0m~lssl0~l ' ~ ~chora~e ' 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operation (2/10/89) 518 736 Tubing Pressure ... 2210 1200 psi 350 psi Subsequent to operation (3/10/89) 584 585 3065 , , , 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 1180 psi 16. Status of well classification as: Oil X Gas Suspended 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. ! Signed/~ .~,_¢-~, ~-~ (~ 'title Envi ornmental Enqi neer Form 10-404~ev06/15/88 Roy D. Roberts 0 Service 300 psi Datel 0/16/89 SUBMIT IN DUPLICATE WELL TBU K-12RD RE-PERFORATION REPORT OF WELL OPERATION Procedure: 1. Obtained a representative 12 hour well test prior to perforating. 2. Conducted a safety meeting. 3. Rig-up E-line unit. 4. Re-perforated the following intervals under draw-down conditions: Run No. Bench Interval (MD-CBL) Interval _(MD-DII.) Length 1 6 11424-11444' 11424-11444' 20' 2 6 11382-11402' 11382-11402' 20' 3 6 11372-11382' 11372-11382' 10' 4 4 11216-11236' 11216-11236' 20' SPF NOTE: Lubricator was pressure tested to 2500 psig prior well operation. 5. Rig-down E-line unit and lubricator. 6. Returned well to production and obtained a stabilized 12 hour well test. MEMORAN DU:M· State of Alaska ALAS~ OIL A/~D GAS CO~SERVATION COMMISSION TO: Lonnle C. Smit DATE: April 12 1989 Commissioner / v ' roLE NO: D. BDF. 044 TELEPHONE NO: THRU: }-{ichael T. Minder 4~~.. Sr. Petrole~ Engineer SU BJ ECT: No Flow Test Arco-King Salmon Pltf Well K- 12 Mc Arthur Rv Oil Pools FROM: Petroleum Inspector Friday, March 24, 19~9, I traveled this date to Nikiski heliport for a'~-fligh~ tOe'ArC0 S King Salmon Platform to witness the no flow test on well K-12. At 8:25 am, as I was about to board the helicopter, I received a phone call from Jess Renfro, Production Supervisor, in forming me that the well was producing fluid and there was no need for me to come to the platform. Jess said, a gas lift line valve was leaking and would have to be repaired before the could be performed again. I departed the heliport and returned to the AOGCC Office in Anchorage. 02-001A (Rev. 8~85) STATE .OF ALASKA ~ AL/-,~KA OIL AND GAS CONSERVATION COMMI~..~ON APPLICATION FOR' SUNDRY APPROVALS 1.'Type of Request: Abandon __ Alter casing __ Change approved program __ 2. Name of Operator I UNOCAL (ARCO Alaska Inc. is sub-operatorl ) 3. Address P. O. Box 100360 Anchorage, AK 99510 I I 4. Location of well at surface 735' FSL, 140' FEL, Seco At top of productive interval 474' FSL, 221' FEL, Sec. At effective de pth 521' FSL, 489' FEL, Sec. At total depth 534' FSL, 554' FEL, Sec. Pull tubing __ Suspend- Operation shutdown __ Re-enter suspended well __ Repair well -- Plugging --- Time extension __ .~timulate __ Variance __ Perforate ~ Other 5. Type of Well: Development _~X Exploratory ~ Stratigraphic ~ Service __ 6. Datum elevation (DF or KB) 100' KB above fvlSL 7. Unit or Property name Trading Bay Unit 8. Well number K- 12RD 9. Permit number 7-176 10. APl number 50-- 773-20156-01 11. Field/Pool Hemlock 17, T9N, R13W, SM 18, T9N, R13W, SM 18, T9N, R13W, SM 18, R9N, T13W, SM feet 12. Present well condition summary Total depth: measured true vertical 11,641 feet Plugs (measured) 9,762 feet Effective depth: measured true vertical 11,464 feet Junk(measured) 9,612 feet Casing Length Size Surface 2,510' 13-3/8" Prod uction 1 O, 747 ' 9- 5 ! 8" Liner 1,278 ' 7" Cede ~ Measured depth True vertical depth 2,438' 9,003' 9,867' Re-perf°rati°n~easured Bench 4: 11,216-11,236'; Bench 6: 11,372-11,402'; Bench 6: 11,424-11,444'. trueve~ical Bench 4: 9,402-9,418'~ Bench 6: 9,534-9,558'; Bench 6: 9,578- 9,594'. ~bing(size, g~de. and measureddepth) 4-1/2", 11.6#, N-80 BTC @ 10,430' ~D. PackersandSSS~(ty..p^e~Dd.rg.eas~edde~ . Camco TRB-6 u ~u~' Nu, uaKer model FB-1Pkr @ 10,350' MD. 13. Attachments Description summary of proposal ~ Detailed operations program ~ BOP sketch X,_ 14. Estimated date for commencing operation ! 15. Status of well classification as: February 21, 1989 16. If proposal was verbally approved I Oil ._.X Gas __ Suspended .__ I Name of approver ~:i. ke ~-i~der 2/27/8~ateapproved~ Service.. 17. I hereby certify that the foregoing i.,s trUe and correct to the best of my knowledge: " Si-ned ~~ ~'~~ Tiff- ' ' · ,.r U Rofff/fY. Roberts ~ Environmental~Enginee~ Date 3/1/89 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test __ Location clearance __ Mechanical Integrity Test ~ Subsequent form required 10-., .... ovea CoPY 0R,GINAL SIGNED BY Approved by order of the Commissioner LONNIE C. SMITH --- Commissioner I Approval No. ~' ..... / V ~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE WELL TBU K-12RD RE-PERFORATION PROCEDURE KS 4 Objective: Increase well productivity. The tool string will consist of perforating guns, CCL and adequate weight bars. Current Stares: K-12RD is producing approximately 2500 BFPD at an 82% water cut. Procedure: 1. Obtain a representative 12 hour well test prior to perforating. 2. Conduct a safety meeting. 3. Rig-up E-line unit. 4. Re-perforate the following intervals under draw-down conditions: Run No. Bench Interval (MD-CBL) Interval (MD-DIL) Length SPF 1 6 11424-11444' 11424-11444' 20' 6 2 6 11382-11402' 11382-11402' 20' 6 3 6 11372-11382' 11372-11382' 1 O' 6 4 4 11216-11236' 11216-11236' 20' 6 NOTE: Lubricator will be pressure tested to 2500 psig prior well operation. 5. Rig-down E-line unit and lubricator. 6. Return well to production and obtain a stabilized 12 hour well test. RECEi¥_ED ;'~laska.0ll & Gas Cons. Commission ,~,~,..~. ~0h0rage~ E-Line BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension l_ Manual Rams Swab Valve Double Master Valves Wellhead DML 7/22/88 STATE OF ALASKA /--, AL/' A OIL AND GAS CONSERVATION CC' .ISSION REPORT OF SUNDRY WELL OPERATIONS Feet 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing Alter Casing [] Other [] March 29, 1987 2. Name of Operator 5. Datum elevation(DF or KB) UNOCAL (ARCO Alaska, Inc. is sub-operator) 100' KB above MSL 3. Address 6. Unit or Property name P.O. Box 190247, Anchorage, AK 99519. Trading Bay Unit 4. Location of well at surface Leg 4, Cond. 29 King Salmon Platform 735' FSL, 140' FEL, Sec. 17-9N-13W-SM At top of productive interval 474' FSL, 221' FEL, Sec. 18-9N-13W-SM At effective depth 521' FSL, 489' FEL, Sec. 18-9N-13W-SM At total depth 534' PSL, 554' PEL, Sec. 18-9N-13W-SM 11. Present well condition summary 7. Well number K-12RD 8. Approval number 7-176 9. APl number 50-- 773-20156-00 10. Pool Hemlock RECEIVED Total depth: measured 11641' feet Plugs (measured) true vertical 9762' feet Effective depth: measured 11517 ' feet true vertical feet 9657' Casing Length Size Structural Conductor Surface Intermediate Production Liner Perforation depth: 2510' 13-3/8" 1074'7' 9-5/8" 1278' 7" New Perforations: Bench 3 Bench 5 Re~er~orations: Bench 1 Bench 2 ~bing(size, grade and measured depth) 4½" 11.6# N-80 BTC @ 10430' MD JUL 3 0 1987 Junk (measured) Nast~ 0It & Gas Oe~. Ceaaalssi0. kn~omge Cemented Measured depth True Vertical depth 11175-11200'~ 11310-11330'MD 11037-11057'MD 11070-11175'MD 2510' 2438' 10747' 9003' 11765' 9867' 9367-9388' TVD 9481-9498' TVD 9249-9266' TVD 9277-9367' TVD Note: Lubricator was pressure tested to 2500 psig prior to well operations. Packers and SSSV (type and measured depth) Camco TRB-6 ~ 303' MD, Baker Model FB-1 Packer @ 103,50' MD 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 497 156 1763 1320 769 245 3755 1320 290 230 14. AttaChments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,~ ,~. ,~~' Form 10-404 R~v. 12-1-85 Roy D. Roberts Title EnviroDJQent al Engineer - Date-7/28/8% Submit in Duplicate STATE Of ALASKA ALAS. . OIL AND GAS CONSERVATION COM, .,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon .~ Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing ~ Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order r-q Perforate ~ Other [] 2. Name of Operator 5. Datum elevation (DF or KB) UNOCAL (ARCO Alaska, Inc. is sub-operator) 100' KB above MSL feet 3. Address 6. Unit or Property name P.O. Box 190247, Anchorage, AK 99519 Trading Bay Unit 4. Location of well at surface Leg 4, Cond. 29 King Salmon Platform 735' FSL, 140' FEL, Sec. 17-gN-13W-SM At top of productive interval 474' FSL, 221' FEL, Sec. 18-gN-13W-SM 7. Well number K-12RD 8. Permit number 9. APl number 50--733-201 56-00 10. Pool At effective depth 521' FSL, 489' FEL, Sec. 18-gN-13W-SM At total depth 534' FSI_: 11. Present well condition summary Total depth: measured 11641 ' true vertical 9762' Effective depth: measured 11 51 7 ' true vertical 9657' Casing Length Size Structural Conductor Surface Intermediate Production Liner 2510' 13-3/8" 10747' 9-5/8" 1278' 7" feet Plugs (measured) feet feet feet Junk (measured) Cemented Measured depth True Vertical depth 2510' 2438' 10747' 9003' 11765 9867' Perforation depth:New perforations. Bench3 Bench 5 Re-Perforations' Bench 1 Bench 2 Ill75-11200' MD 11310-11330' MD 11037-11057' MD 11070-11175' MD 9367-9388' TVD 9481-9498' TVD 9249-9266' TVD 9277-9367' TVD Tubing (size, grade and measured depth) Note: -Lubricator will be pressure tested to 4½", ll.6#, N-80 BTC @ 10430' MD 2500 psig prior to well operations. Packers and SSSV (type and measured depth) Camco TRB-6 @ 303' MD, Baker Model FB-1 Packer @ 10350' MD 12.Attachments Description. summary of proposal [] Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation March 20~ 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing .~oy D, Roberts. Signed /f-~'%¢¢-, ~ ,~~~'((; Conditions of approval is true and correct to the best of my knowledge Title ~~/~r~¢~ Commission Use Only Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Form 10-403 Rev 12:1-85 IApproval No. ~o.~ C ~1~,: ..... ~; - ~ "~'; :;': ~7;--~ommissioner the commission Date Submit in triplicate Unocal Oil & Gas Division_.~. Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-,,,.-~7 Telephone (907) 276-7600 UNOCAL Environmental Group Alaska District May 6, 1986 Mr. C.V. Chatterton AK. Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: SUNDRY NOTICES & RERORTS ON WELLS K-8RD & K-12RD~ KING SALMON RLATFORM Attached for your files are two copies each of. the subsequent report of perforation for K-BRD and K-12RD, King Salmon Rlatform. Very truly yours, · o~ D. Roberts Environmental Engineer cwl 00280 cc' Trading Bay Unit Participants' RECEIVED MAY- 8 1986 Alaska 0il & Gas Cons. Commission ~cPorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL COMPLETED WELL OTHER [] 2. Name of Operator UNOCAL* 3. Address P. O. Box 6247 AnChorage, AK 99502 4. Location of Well King Salmon Platform; Cook Inlet Surface: 735'N-140'W from SE corner sec. R13W, SM 17, :_ 5, Elevation in feet (indicate KB, DF, etc.) ; KB 100 12. 7. Permit No. 8. APl Number 50- 733-20156-00 9. Unit or Lease Name Tradinq Bay Unit 10, Well Number T9N, K-12RD 11. Field and Pool Hemlock Pool j6. Lease Designation and Serial No. McArthur River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [~ Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [~ Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following Hemlock interval was perforated in March, 1986: Bench 4 11216-11236 DIL ~ The following Hemlock interval was reperforated in March, 1986: Bench 6 11372-11444 DIL * ARCO Alaska, Inc. is sub-operator of the King Salmon Platform. RECEIVED MAY- 8 986 MAY 6 1986 Naska 011 & 8a~ ~on~, C,0mml~ Ak Environmental Group 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space belo~; C~mg~sion use~y Date 5/7/86 Conditions of Approval, if any: I~u nrrl~r nf STATE Of ALASKA ALASK ~')ILAND GAS CONSERVATION ¢~'MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2, Name of Operator UNION OIL COMPANY OF cALIFORNIA 3. Address PO BOX 6247, Anchorage, Alaska 99502 4, Location of Well '735' N and 140' W of SE corner sec.17, T9N, R13W, 5M King Salmon PlatfOrm, Cook Inlet 5. Elevation in feet (indicate KB, DF, etc.) KB 100ft 6. Lease Designation and Serial No. I7. Permit No. 8. APl Number 50- 133-20156-01 9. Unit or Lease Name. TRADING BAY UN IT iKiO' ~e~,-~umber - 12RD I11. Field and Pool McArthur River Field Hemlock Pool 12. Check ApprOpriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~] Altering Casing [] Stimulate [] Abandon [] .Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple, completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for. Abandonment see 20 AAC 25.105-170). The following Hemlock intervals were per'fora~ed- On July 5 1984: Bench 2 11075-11155 ft. CBL Bench 6 11372-11400 ft. 'CBL 11426-11442 ft. CBL Note: CBL reference is 10/24/78 * ARCO Alaska, Inc. is sub-operator ~rtify that the%er~g Signe itle Th ommission use RECEIVED AUG .Z 1984 Alaska Oil & Gas Cons. Commission Anchorage is true and correct to the best of my knowledge. DIST. DRLG SUPER. ions of APproval, if any: Approved by. ' By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ~.~ STATE OF ALASKA ALASKA ¢ .iAND GAS CONSERVATION CO"~'~ISSION SUNDRY NOTICES AND.REPORTS ON WELLS . , OTHER 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator Union Oil Company of C.alifornia 3. Address P-_ O- Box 6247, Annhorage: AK 99502 4. Location of Well 7. Permit No. 735 ft. N and."~40:ft. W of SE Corner Sec. 17,. T9N, Ri3 W, 5Mi · 5. Elevation in feet (indicate KB, DF, etc.) _K.B. ]00 ft. 12. 8. APl Number 5o- 133-201 56-01 9. Unit or Lease Name · ADL ] 8777 10. Well Number K-1 2RD 11. Field and Pool McArthur River Field I 6. Lease Designation and Serial No. Heml cc k Pool CheCk Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO:. SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~] Alter Casing [] Perforations [] Altering Casing [] ' Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of startin'g any proposed work, for Abandonment see 20 AAC 25.105-170). ., We propose to perforate the' following Hemlock intervals' Bench 2 11,075 - 11,155 ft. DIL Bench 6 11,372 - 11,400 ft. DIL 11,426 - 11,442 ft. DIL RECEIVED SUbsequent Work *ARCO Alaska, Inc. is suboperator. I . ]14.1 her~y Ce/~ify that the,t,m]egcjj~is true and correct to the best of my knowledge. S~gned e ~Dist. Drlg. Superintendent I ~'~onditions of APproval, if any: JUN ! 3 :[984 Alaska 0il & Gas Cons. Commission Anchorage Date,, 6/12/84 Approved bY Approved Returne~d By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate October 12, 198~' Union Oil Com~&ny of California P. O. Box 6247 Anchorage, Alaska 99502 Re. ~O Flow Test on K-i2, ~ing Salmon PlaUform C~ntle~en I We have reveiwed the test data from the no flow test on Tradin~ Bay Unit Well ~-12 which was w~see~ by Petroleum Inspector, Bobb}. Foster. ~ell K-12 has demonstrated by test that it is not capable of unass&ste~ flow and therefore, removal of the subsurface safety valve from this well is approved. $incer el y, LC S/J~T ~ lc ~ ~03 ~ M MEMORANDUM State of Alaska ALA$~KA OIL A~D GAS CONSERVATION COMb~ISSIO~ C. ~.~~erton/) DA/E: September 13, 1983 /~ FILE NO: 108B~F Thru= ~n~e C. S~th FROM: Commissioner ~ Bobby Fost~'f%' Petrole~ Inspector TELEPHONE NO: SU BJ ECT: : Witness No Flow Test on ARCO's ~-12,~D King Salmon Platform. ~mnda¥, ~ept~r 12'_..!983: I traveled this date to ARCO's King S:al~'-p-ia~0~ and witnessed the no flow test on well K-12. As the attached charts show the gas lift gas was turned off at am, Monday. The well, which was lined up to the test separator, produced one bbl. of oil. At 2~15 am the 55 psi of pressure was bled off of the separator through a 5/8" lane. When I arrived at the p lat fo rm , ?i ~nt to the separator and checked the fluid level and pressure which was 0 psig. I also checked the well by closing the wing valve and opening a %" valve on the swab cap. There was a small blow, approximately 3-5 psi coming from the wel 1. I spoke with Don Gann, platform supervisor and he informed me the water cut on this well w~s 77%. I recommend to the Commission that this well be accepted as unable' to flow without assistance. Atta~ment 02-00IA(Rev. 10/79) :~A TURDA y 9 12 , CHART NO. IART PUT' ON ;AN L-IO-S II 'Ir.lZ) O~LM SINGER AMERICAN METER DIVISION MEMORANDUM State of Alaska Edgar W. Sipple, Jr.. ~trole~ Inspector FROM: SU BJ ECT: Witness a No-flow on K-12, ARCO's King Salmon Platform, TBU Cook Inlet. Sa~t~Urday, Aug~.t 13, 1983: I left ~nChorage via South Central ~-~'~ ~nd"~rri%ed th~':kena'i~at 7:45 AM. I rented an Avis car and drove to the NikiSki Heli~rt where I ~arded a helicopter to ARCO's King Salon Platfo~ to witness a no-flow. The no-fl~w on K-12 c~nc~ on Thursday at 12~'00 PM until Friday, 12: O 0 PM. As the attached chart indicates, there wa s no flow of fluid from K-12 for a ~riod of 24 hours. I recommend to the Co~mission to not approve a no-flow status on K-12. The test separator was vented to the flare line with 60 lbs of back PSI on the test se~rator, ~ing held by a motorized valve going to the flare line. The AO~C office will have to witness another no-flow on K-12 with no ~I on test se~rator. Don Gann said it will be a week 'or longer before ~ can witness a no-flow on K-12. In summary, I wi~essed a no-flow on ARCO's K-12, King Sal~n platform, TBU, Cook Inlet. Attachments CAN CHART NO. L-10 ~TON m i v ,v)e,v-/ r' TAKEN OFF M _ ~-~3-A3 _.M LOC^TION ~'-/Z REMARKS ~ ,,'g'~'O/~ ,, ,,,7-~ ~, ~'-~ (~ SINGER AMERICAN METER DIVISION ? / F~R! REV. 1-10,73 Subml t "1 ntentions" in Triplicate ~--~ & "Subsequent Reports" tn Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to d rill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) APl NUMERICAL CODE 50-133-20156-01 6. LEASE DESIGNATION AND SERIAL NO. .~ ADL 18777 ' 1. OIL ~ GAS r"'] 7. IF INDIAN, ALLOTTEE OR TRIBE NAME /~fyj WELLI~--J WELL L--J OTHER NAME OF OPERATOR Union Oil Co. of Califo'rnia* 3. ADDRESS OF OPERATOR 909 W. Ninth Ave', Anchorage, AK 99502- 8. UNIT, FARM OR LEASE NAME Trading Bay Unit WELL NO. K-12Rd (44-18) 4. LOCATION OF WELL At su dace 735' N & 140' Sec 17, T9N, W of 'SE Corner Ri3W, SM FIELD AND POOL, OR WILDCAT McArthur River - Hemlock 11. SEC., T., R. M., {BOTTOM HOLE OBJECTIVE.) SEC 18, T9N, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) W.B. I ~0 ' ahnv~. MT,T.W Check Appropriate Box To Indicate Nature of Notice, Re .12. PERMIT NO. ~ort, or Other Data NOTICE OF INTENTION TO= TEST WATER SHUT-OFF ~] PULL OR ALTER CASING F RACT U R E T R EAT ~ M U LTI PLE COM PEET E SHOOT OR AClDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Reper...f Existinq Intervals SUBSEQUENT REPORT OF: WATER SHUT-OFF' ~ REPAi RING WELL FRACTURE TREATMENT . ALTERING CASING ! SHOOT lNG O R AC I D I ZING A~AN DONM ENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report ar~! Log form.) 15. DESCRIBE PROPOSED OR COMPLETED' OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. -We propose to reperforate the following intervals: -- 11037'11054 DIL 11072-11175 DIL *ARCO Oil and Gas Company, Suboperator 16. I hereby .~is true and correct SIGNED~'? ' ' ' , TITLE --u ~..gA~L District Engineer DATE 9/16/80 (This space for State office u~) . / COM ~ APPROVED BY TITLE CONDITIONS OF AP~OVAL, IF AN0: BY ORDER OF T[IE C0rAU~SSI0N Instructions On Reverse Side Document Transmit~:l Union Oil Company of Ca' nia union DATE SUBMITTED ~ACcOUNTING MONTH Dec; 13, 1978 TO ~ROM ' H. W. Kugler R.' C. Warthen AlT AT An,chorage, AK Anchorage, AK TELEPHONE NO, TRANSMITTING THE FOLLOWING: , TBU K-12 RD., ~ur River F. ~eld ,., ] Se.l-_ Sepias 1 Radius of Curvature Please a..cknowled~e receipt signing and returning copy Date: , Received: .... ..... , . i i i i I i i i i FORM I~2M02 (REV. 11-72) PRINTED IN U.S.A. - : -. 'SUBMIT IN D'~PL~;CATE* STATE OF ALASKA (see other . : st ructions on OIL AND GAS CONSERVATION COMMITTEE r.vers, side, 50-133-20156-C i [_ I I WELL fOMPLETION OR REfOMPLETION REPORT AND LOG* ~.~.~X~o~ ~L 18777 WELL ~ELL b. TYPE OF COMPLE~OH: ' : WeLL OVia E~ nne~ n~SVR. ~ other' R~ ~ I Union 0il ~ay ~. W~L ~O. 909 West 9~ Av~ue, P.O ~x 6247, ~chorage, ~aska 99501 ~0. r~~r~.o~ 4. nocar,OS or WrLL (Report location clearly and tn accordance w~th any state requirements)* " -' ~~~ ~ve] At ~.~ace735.N & 140'~ SE Cr~ Sec 17~ TgN~ ~3~ ~ At top prod. interval reported below · 532'N & 392'~ SE ~,'Sec 18, TgN~ ~ SM Sec At total dep~ 12. P~IT ~O. · 607'N & 780'~ of SE ~, Sec 18, TgN, ~3~, ~ 78-57 13. DATE SPUDDED 14. DATE'T.D. RF-,A,C~ [15. I),~T~ C(>IVIP 8/14/78 10/28/78 1/2 8 100' RKB ' I{OWII~.A_~Y* ROTARY TOOLS CABLE TOOLS 11,775 MD 9867 TVD [1i641 MD 9754 TVD [Single All None ~.. PRODUCINa IN~VAL(S). or ~s COM~ST~O~--~O~. BOSOM. ~XUE (~n AWO rrm. [~. w~s DmECnO~ 11,031' ~ -- 9237' ~ ~ch ~1 H~k ~ SURVE~DE '11,175' ~ -- 9359' ~ ~ch ~3 H~~k ~ Yes 24. TYPE ELECTRIC AND OTHER LOGS RUN DIL/SP, BHC/Sonic./~GR, FDC/CNL/GR, CBL CASING RECORD (ReDort all strings set in well) CA, SING SIZE WEIGH~, LB/FT. DEPTH SET (1VID) I{OLI~ SIZE .9-5/8" CEIf.L~, N'TING RECORD ! A. NIOUNT PULLED 26. LINER I~ECO~D SIZE ~ TOP (MD) BOTTOM (MD) SACI~S CEMEi~T* 7" 10,487' 11,765' I 350 9.8. PERFORATIONS OPFL~ TO ~L ,i~ ~ L~ Pg '~,~ 11,037 '-054 ' 4 sPF 11,072 '-175 ' 4 SPF ~. r~bb~3~8~~ DATE FIRST PRODUCTION J- ~ODUCTION METHOD (Flowh~g, gas li~L pump.s--size and tyDe Gas lift 27. TUBING REOOI%D S~R~ (MD) SIZE [ DEPTH SET (MD) I PACKER SET (MD) , , ~ 4-1/2" 10. 430 ' 1 0. 350 ' I ,i _ 2.9. ACID, St!CT, F/'~A.~'-I'URE, CF_~VlE:NT SQUEEZE, ETC. DIilPTI-I INTI~RVAL (MD) I A1ViOUNT A_ND KIND O,F M~T~ER/AL USI~D I WELL STATUS (Producing or shut-in). DAT~ OF T~ST, II-ICI/RS TF_~TI!iD. '[CHO-'~IE SIZE [PROD'N FOR O~BBL. G~CF. WA~B~. ] GAS-O~ ~O ! ' I ' /~ST PZOD I 11/2/78 ! 12 i I ~ ] 1531 I 178.5 I ~ ,116.6 -- FLOW, ~BING' ~S~G P~S~ [CAL~~ -OI~BBL. GA~. WA~B~. [ OIL GRAV~Y-~ (C~.) 1 ' · " >. 3062 I 357 I 0 31. DISPOSITION Or Ga8 (8old,.~used for fuel, vented, etc.) ' 9T WITNESSED BY 32. LIST OF ATTACHMENTS Drill~n~ History & Gyro Survev 33. I hereb~ ~rt~ that, t~~_ and attached in-formation is complete and correct as determined from all:available records , SIGN~/~'/, './(, ~~_~_.~TITLE Di at. Dr'illinq Su,,. ~i~, · I ~ *(See Instructions and Spaces lor Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end~ log on all types of lan:Js and leases in Alaska. Item: i6: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- mentsgiven in ether spaces on this form and in any attachmer~ts. Items 20, an~l 22:: If this well is completed for separ~tc, production from more th~n one interval zone (multiple completion), so state in item 20, ~nd in item 22 show the p~cducing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (pa0e) on this form, adequately identified, for each additional interval to be seperately produce.J, show- ing the acklitional data pertinent to such interval. It*m26: "Sacks Cemer~t": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to .be separately produced. (See instruction for items 20 and 22 above). · ...... '34. SUMMA, I~Y Oii' I~O~MATION TE~'I'S IN(JLUI~IN(; INTERVkL TES'I~Elr). I~I:{F--.SSUIRE'DAT~ A~ RF--,COV'ERIF_~' OF OI[.,i GAS.- ' ~ ' ~s. ~Ot.Oo~c r~,,.'R~C~=tS . WATER AND MUD , i ~ - , 1.- -~ NAM~ ........... . -.. , "~ i' ' -.¢., ...... ..--.~.~...~..,,.~.~. '.. ............ ~. .... ¥' ' -~'." '~'n'*~"l .... r"-"'T"''~ ''~ r~--'r--~'rr -.'-r'~---r .... , ..... .- ~lfk ~j~{~.E DATA. A'r~i'A(';i{ :fi{tf~ ~r'ii4~-a{'~tvf:tl~]~Yt~q~ .~}{*. 'blTiio~¥. i~O'}tU~iYV, 'i~R.~.~'.,~.PTiJ,fR~cN~ ~{ ,1 ...... .... ..... . . : , . . .. . ' :_ ., .;... .1 K-12 RD (44-18) Drilling History Skidded rig over K-12, killed well with 8.8 ppg brine, NU and test BOPE.' CirCUlate well and pUlled packer loose. POH and laid down 4-1/2" completion assembly. Made round trip w/bit and scraper. Ran Gyro survey to 10,681'. RIH and set retainer @10,560'. Tested lines and squeezed perf's below retainer w/260 sx cmt. PU and left 40 sx cmt on top of retainer. PU 5 stands and reversed out. POH. PU 9-5/8" spear, pulled spacer spool. Ran BY/CCL. Set retainer @ 2680'. Ran 9-5/8" cutter on DP and cut casing @ 2586'. circulate 9-5/8" csg & POH. Changed to 9-5/8" rams. Pulled and laid down 9-5/8" csg from 2586'. RIH w/2-3/8" tubing tail on DP to 2674'. Circulate bottoms up and pum~ 350 sx cmt w/10% sand. Reversed out @2210' .' CIP @3:27 AM 8/18/78. RIH w/12-1/4" bit and dressed off hard cmt to 2518'. Directionally drilled 12-1/4" hole to 9465'. Tripped for bit. R~3m~d through bridge @6425'. Lost 1500 psi pump pressure. POOH. R~aming. Left fish in hole. Top of fish @9336'. -~ .... PU fishing tools, engage & POOH w/fish. Drill to 1~0~, 924_'. POOH & stuck pipe in keyseat. Circ & work pipe. Freed pipe & POOH. Test BOPE, Kelly valves & choke manifold - OK. RIH w/reaming assy. Reamed. DP backed off @1363'.' Tagged TOF @8978'. Circ, POOH, & pulled tight w/bit. Reama~ up & twisted off, RIH & tagged fish #2 @7519'. RIH with 17-1/2" hole opener & opened hole to 3510'. POOH & PU fishing tools. Tagged but could not get over .fish. RIH, dressed off & engaged fish. POOH & rec 1450' of fish leaving 12-1/4" bit & stabilizer in hole. Reran fish assy & rec same. RIH w/OS #3. TOF @9064'. Engaged fish & POOH. Rec 37 jts. DP. RIH reamed tight spots to top of fish @10',220'. Ran various sized grabbles, engaged fish, would pull off when stroking w/jars. Ran mechanical cutter, cut heavy wt DP @10,224 '. POH w/4 ' of fish. Ran free point and found stuck point @ 10,670.' Fired shot @ 10,560', no back off. Ran overshot and jarring assy and caught fish @10,224'. Ran and fired stringshot @10,558'. POH rec'd 10 jts HWDP, leaving top of fish @10,554'. RIH, screwed into TOF and established circ through and around remaining fish. Spotted black magic around fish, jarred on fish moving black magic once per· hr. Jarred 50' up the hole and pulled free. Rec'd all the fish except 8-1/2" x 1.42' long bull plug. Made three attempts to recover remaining fish.~ Lost 10-3/4" x 3' long rotary shoe in the hole. Total fish left 4-1/2'. Ran bit to top of fish @ 10,918', conditioned hole to run csg. Ran 268 jts 9-5/8" 47# S-95 and N-80 csg and set @ 10,747'. Cemented w/1000 sx class "G" cmt w/0.75% D-31L, 0.3# D-19, & 0.1% D-6L. CIP @ 2100 hrs 10/7/78. Installed 9-5/8" wellhead pack-off & tested to 3000 psi. OK. Tested BOP's and ran 8-1/2" drilling assy & drld out cmt & float equipment & -1- cleaned out to top of fish @ 10,918'. POH. Mixed 185 sx class "G" cmt & spotted plug from 10,918' to 10,700'. RIH and tagged top of cmt @10,630', drld reed to hard cmt from 10,630' - 10,727'. Directionally drilled sidetrack hole to 10,875'. Tripped for stiff BHA, stuck pipe @ 10,864'. Spotted black magic pill and worked pipe. Ran free point & backed off & 10,700'. PU fishing jars and engaged fish, pulled fish looSe and circ black magic out from csg shoe, POH. Directionally drilled 8-1/2" hole to 11,775'. Ran DIL/SP, BHC/Sonic/GR and FDC/CNL/GR- caliper logs. Ran 7" 38# P-110 LT&C liner and set @11,765' at top @10,487'. Cemented w/350 sx low water loss cmt. B~ plug. CIP @6:10 AM 10/22/78. RIH w/bit and 9-5/8" csg scraper, drld out to top of liner, last 30' hard cmt. Tested 9-5/8" csg w/3000 psi. RIH w/5-3/4" bit and 7" scraper, cleaned out to liner to 11,641'. Tested liner to 3000 psi. RIH w/DST tools, set packer @10,445' w/1600 vertical ft water cushion. Good WSO test on liner lap. Ran CBL & Gyro survey. Changed over to 8.8 ppg brine. Bond log indicated less than acceptable bond in critical areas. RIH & perf'd 11,365'-367' w/2 SPF, set rtnr @11,335'. Squeezed 82 sx cmt below rtnr leaving approximately 3 sx on top of rtnr. Reversed out. RIH & perf'd 11,210'- 212' w/2 SPF, set rtnr @ 11,180'. Squeezed 54 sx cmt below rtnr. R~versed out. RIH & perf'd 11,028 '-030' w/2 SPF, set rtnr @10,994 '. Attempted to squeeze perf's w/6200 psi w/no break down. Repeated w/same results. Ran 5-7/8" bit, drld cmt and rtnrs and cleaned out to 11,641'. Tested liner to 3000 psi. Spotted Dril-S pill in liner and ran CBL. Ran junker pusher & gauge ring to top of liner @10,487'. Set Baker FB-1 9-5/8" pkr @10,350'. RU and ran 4-1/2" completion assy. Tested tubing w/3000 psi. OK. NU and test tree. RIH and perf'd 4 SPF 11 037'-054' 11,072'-175'. Released rig @ 1200 hrs 11/2/78. Well on gas lift. -2- / / / Eastman/ A PET~O/_A/VE COMPANY REPORT of SU~-SURF,4CE D~t~EC T~OA~ A SURVEY ATLANTIC RICHFIELD COMPANY K-12-RD WELL NAME KING SALMON PLATFORM LOCATION JOB NUMBER TYPE OF SURVEY A1078 G0041 GYROSCOPIC (Radius of Curva%ure) DATE 10-23-78 SURVEY BY _Jeremy Beattie OFFICE Alaska ...... {;O~PLET iON- REP(:)'RT ................................ NOV" 17, !:)78 ~.A..T L A. 1 ~.~..C- R-~.CH F..I.6 L.D,-,~OM. PAN,Y .......... F.,. I NG -SA L~ON-P LA.T. ......... T BU,.- K 1 ~RD _.GYROSCOPIC $UR.VEY .............. DBCLiNATiON ..... 2~ ._RADIUS OF CUR.VATURE METHOD OF COS~PUTATiONS .... K~ EL. EV 100. FT. ..................................................................... RECORD 0¢ .... ~UR.V, EY ................................. ALL_.CALCU. LAT.~.ONS PERFORMED. BY ~. B._M.-.E~ECTRON~ .... COMPUTER . ....... TRUE DOG ..¢T.H ANGLE., .DEP.TH .... SEA D~R~C D~STANC~ ....... ANGLO .......... L.-DBG/.~OOF% ............................ D. M .................................... DEG. D ...... H ......... $ .............. 1.0.0 ....... O 0 ..... 100,0.0 ....... :..._.; .... 0~00 Si7,00W ._ 21.8.,56,.,.N ................. 14~6.~....:.W ................ 1,19,46 N ..... 7.:_.....2 .... 2&~...W_ ...... -.~.0,.00.0 ......... 300 ........... 1 15 ............... 299.99 ........ ~...199,99 S17.00~ 117...5& .....N .......... 1z,,.95 ....~ ............. 118,4& .... N .7 .... 15 ..... 1.5.-W, .......... ~-..2.50 .............. ~0.0 .......... 1...0 ..... 3.99.97 ............. ..,..2.99.,97 .832,00W _. i,I= .......... 600-:. :...20 ...................... 599.9.0 .............. ~,99,90 N z,.OOE 1.1..8,_.7..6.._N ........................ 18..i&_._.W ................ 120.15 N .... 8 .... ~l_..50.-...W ........................ ............ 700 ........... 1..4.5 ............ 699,8~ .......... 599,8!+ N 3.:~OE .........122,Q~ .... N ................. 17.98 ........ W ................... 123.35 .N ..8 22.._3.~_..W .................. .... 800.,,~.2.&5 399,'/6_ ....... 699,7.6 .N 5 00~ ..........12..5..,,_95._N ....... 1.Z,..6.9__W .............. i.2.7_.,1.8 .... N .......... 2.9__&.9._.W .... ~,.,000 .......... 900 ........... 4,_..30' ................ ' 8 9 9,26 ~ ........79 9, 56 ...... N 0 · 00 W ..... i 3 2., 2 5~_..N. ......... 17,91 ....... W ................... i 33, ~ 6._ N. ~_..~ Z ..... 5. i_...W ............... i..,.752 .... !.00.0 ......... :6 0 ...... 9.9~9,..1.~ ........... 8.99,1.4 N35.00W ........... 140,6..6._..N ............ _.~,1..~I ...... W 142.27 .... N ....8 ...... 36 ...... 5,5.._._W ............... 1-52.7 ............................... ...... 1.,8.00,,_.lA.....4_ 5 ............. 1785 ,.gF~ 1.685.,95. N8.7,.OOW ............. I. ~" ~. ( ~ 2.,;,,0. %..23 ........ 0.,..:_~2.1.6A,,,9.8:........ ~ 06.A,.,.9 ............ S.,7. 3,..,. 0 OW ........... _Lz+3,.,..QO.~,.N;. ....2.,81_...?..~+--'~--~ ...... 3.!..5.,,.,9~ 5..~_63',~¢ ..... 5..._,ZI_...W ....... . .2...0.9.1 -- ARC. O-...K i2RD ............ . ........ GYi';(OSCOPIC SURVEY ........................................... NOV.-17',--1'978 ................................................. RECORD OF SURVEY ...................... '" NH ~',I '-CT;'~,O~x~]:C CO; ~P~JTER ....... ALL....CALCULAT~.ONo PERFO ED BY [ [~ ELf:. :,4 ............................. T R u r:: ,_ .......................... D 0 G.-L,-E.G __N, EAS, .D~FT .VERTICAL._ ,SUP.; DRIFT .............. TOTAL COORDINATES ......... C L.O...S_.U R E 5 ................. 5EV.ERLTY ............. SECTION .... D EP..TH ANGLE ..DEmTH SEA DIREC ....... [~ [ STANCE ...... ANGLE ........ D. EG/~..OOFT _DJ$TANC ..................... D ....... M ........................................... DEG, D ....... M ....... 5 __¢'"~00 .... 32. 45 .... ?z~29,63 ..... 2329,63 585,00W.. .iOZ+.18 F,: 41,5,3,+ w .. ~+.29,.].8..N....25 5'/ .. z,_.W ............... ~.8~5 ............. .,.00 .... 3,5.. 0 ...... 2.5 ~, 2,,.65 ........... 2~1.2,55 ,'"488,.00W ............. 102,72. N ........~.'"2, ...02.. ',',,' ............. ".,,,83,0.3 ..... N._?? z+3 .... 20_..W ......'.5, ,.2..2 0 ................ ........ 2700..35 .... ~5 .......... 2,Sg4.Z9 .......... 249z,,.,19 NSg,OOW .........10.4,24 t',,: ..")"'4:,~o90 ~¢ ....... ....... 5~0,05 ...... N_._'/8..52~l.~.....W .................. 0,82~. ..................... 528,5,4 ....... 2800..35.&5 ........... 26'"/4,83 .... 2.5."~4,[.",3 NS?,OOW .........~05,30 hl .588,99 W ......... 598_~0 ....N._?g..~.z+5 ..... 8 W .............. ]..,2.30 .........587.'7~. ........ 3.00(.) .... :35 ......... 0..:~-2.8.$5,-/-~.7 .......... 2..7.~5~7 N.88,00W' ..... i1~ 09 N 70'/',86_W 7.~ ........... 3100 .... 35 ........ 0..,.,,.;2_9i6~38 ........ 281..6~38 ,586~00W _ ~-Z:3~O? ;~l .765.60,..W ................ '7'/'!~.9.0...N_81 .... 35 ....... 3~_...W ................. :'~..526 ................ 76.5.23 ' ~ 9 ~ ~ ~ ........ 82~.~.7.5 ...... W.~ ....... 83.i,,,7.2..-N.~.82 ........ ~.4..-.~.,2-J,'~ .................... 1,. 128 ......................... 823 ..... 3200 ....... 3 ....... 30 ....2.9 .... 7.....:~ ~ ......... 2.8 9,.7.,..=,3 .... &8.3, O0W ............ ~07,4'Z. F! . *,..~ ................ 9.~.~,7.9 Ft ...... 8~ ..... 1.8 ....... 5.1..W. ................. 0.5.8.8 ................... 9~9,98 - ,.... ~ ~ ....... 100.,~ · 60._N_ 8~..._~..9._.~6..,.W ...................... 0 ~.2~0 ............... 998,68 -.-3500 ...... ~ ...... 15..;.._32~0~.~,?...,..:~_~.1.~0~.37 ........ $S&,OOW ............. 87.,'~$ N ............... 999 ~' ......... 3500 .37 .0.: .....3.3.2.0,.62 ....... 3.2,~0,52 584,00~ ..... 81,30 N 1059,10...k' .......... 1052,22 ...... N....85....36 Z 7 W 0'750 .................. ........ 3,'Z00 .... 35....45 ........... 3.40.0_,51 ............ ~00.,61 58a,00~,~ .... 75,02...N 1.118 ,:~ ¢~ ............... 11.21 29 ...... N......85 9 48..W ........... 0.250 ......................... 111.7,83 ...... 3.8.00 .... 37 ............ 0 ........... .~.~8.0~,51 .......... 3..=.80,.5~ 583 0ow F,[i~2,~..N .... ZZ?.8,40 ..... W ...... ~280,38_.N_.85..,.~ ......... 9 ..... W 0,.~.~O ........... 3900. ~ 0 ....... ...356.0.~47. ........ ...3460,~7 58~00W ..... 6~,42..N ..... ~238,20 .... W ...... ,..~Z~9.,..72 .... N.._¢,Y 9 ~6...W ........ 0.~602 ........................ ....... ~+ 5.00 ...... 39 0 ....... ~..03 .~ ~.~ 0 ......... : ~ 9 .~.~ ~ ~ 0~ 8 :~ · 0.0 W ........ Z 3 · 9 ?. N .... ~ 802 · ~ ~ ._ .~ ............ 2.50.2 ~ 83 ...... N .... 89... 30 ._ ~_. ~' .......... L.,,,.O, ~,?-.~O ...................... 2 ~ 0 ~ · ~_7.0.0 ..... B.9 ........ 0 ........ ~..1.,9. 0.,,.3.,~ .... ~ 0,9D..*,31 ....... S 82., 00 ~ ....................... i, [55 ....... ~ ..... 1..,~ ~ 7.,~.8 ..... w 1.Y..Z,.7...2,.E_5_.8.9__56 ....... 12L_.W_ .....0.,,.4.&8 1.-72 ? ........... 48.0.0 .... 39 30_:.~_~2~7,74...._L4t67,'~ 58~5,00~ .... ~..12 S i790 Ol W iVg0,O&_,S ....... 89.,&O .... 33...:.W ............... 0.~.543 ................... 1790,01 ....... ~900 3..9 30 .... ~3z~z~.9~ .......... ~2~z~.91 S83,00~ ..... 1V.~87...5 .......... ~85.3,15 ...... W ............. 1853.~2.3 ..... 5_,89 ..... 25 ...... 50.._.W .................. .0.,O. 00 .................. ~ ' , ...... 5200..,..~.~ ......... 0 .......... ~573 ~.5.9 .............. ~z~7~...5~ ..... 5~5..00W.... ................. 3.~ 03.,.: 5 ............. 2,.0~5,.35.-W ........... 20~6.~6.9 ..... 5-.88-, 5.7 ....... ~.~.....~ .................... 0.50.0 .................... 20~6 . ....... .... ARCO-K' i2. RD ............................................ GYROSCOPIC SURVEY ........................................................................................... NOV'-17,~-1978 ............................. RECORD OF SURVEY ............................... ALL.._CALCULATIONS PERFORMED ~.Y. I..[5 M ELgCTRON~C .... COMPU.T.ER .... L ............................ T R U E ' .............................. DOG -- b.E ...... DEP. iH ANGLE ..........DEPTH ..... &EA DIREC DISTANCE ................... ANG~g ................. DEGIiO OF.T- ....... DISTANt .................... D ........ H D E G. D ....... M ........ O0 ..... ......... 5.500 ......... 5.900 ~0 ........ 30 ......... 5099,58 ~999, .... 6..i00..~39 ..... 1.5_~525.1,79 ......... 5151, ..... 6200 .... 39.:..30 .... 5.329.10 ..... 5229,10 ......... 6300 .38 ......... 0 ........ 5~07,08 5307,08 ~.6~00....38 .... 0.,_54.85,88 ....... 5385,f~8 : ......... 6500 .....36....4.5 ........ 5.565.35_ 5465,Bfl ...... 6600 .35..30 ............ 56~6,12_.55~6,~2 ...... 6800 38..30.]:_5806.,.61. 5706,6i ...... 6900 .... 39.30 ...... :,5~8~,.33 575z~33 ........~,Z00..38 0 6118.83 ....... 6018.~3 ---./.3,0.0 ..... 37 ........ O ...... 6!9.8..,..16,~..:~.8098.~6 .... 3400 .... 37 0 _.._7.60.~.~.37 ...... 0 ....... 6&.36.,..96 ..... 6..336,g5 .......... 7.7.00 ..... 36~...~5 ...... 6.5i6e9.5..~:,..6~i6.95 93 $84.00W .......... O0 585' OOW 55,32. gO 582,00W ........... 62.82 79. SS~..OOW .......... 70.90 5~ ........ S82.,00W ................. 78,.99 58 S83,.00W 87.6~ 33 $81..0.0W ....... 96.70 79 ........ S85.00W .............. $83.00W 111.18 S .2i77,01--W ............ 2.!71,56-$--.88.---~2 3~-.--W ................ 0-,-65.6 ............2t77,~B $ ....22 ~,3.i .... W ............ 2.2~.3.,00-...-$--88 .... 35--1.1--~ ..... --0,656 22~2,81 S 2308,i4.--..W ....... 2309.00 &..---88-26 ..... 2-.~.-W .............. t~-6~-5 ................... 230~.72 S_. 2373,90 ..... W .... 23..7~,96.....5..-88 .... 17-2.1..~W .............. 1.,319 ............ 237&,57 S ..... Z505,.36 ..... W ................ 2506,89_..$ .... 8.7 _59 ~g--W .............. 2,.8.00 ................ 2506o~1 S ...... 2570.,.00.._~ ............ 25~71~82~5_.8.7 .... 5~.._&2_~ ....... 0.,9.96 ................. Z570,95 S ......... 2633...9.5._W ........ 26.36.02 S.....8.7__43--g.6--W~,..,~2 263~ S ....2697,0~_W ............ 269~,B3 S 87 ..... 38 .... 21 .... W ..................... 0-..$.4..~ ............ 2698 · 9,9 SSA,OOW .i18',27 S 27.59,22.~.....W ............ 2761.76 S 87 .... 32......~.3._.W ............... 1..5A7 .................. 2760.4.2 583 ~ O. OW ................. 125,2z~.. S ............ 2820.,Bg_.w, ....... 2.8.23 ,i 7 ....5......87 ........ 2.7__26_W .............. 0-616 ................ 2621 · 66 584,00~ ....... 132,11 .b 2680,70._'....~: ............... 2883,73 S 87 2.2 ..... 26......W ................... L,.300 ................. 2882,05 $85.00W,. ..........1,'37,76.5 2939.38 ....... W .......... 29z+2,61 5..87 ..... 18 ..... 59__W ......................... 1.,2.95 ................... 29z,,,0.79 $ 85.00W.. ............... 1 z~2 . 87 . ,S ........ Z9.9.7...76.~ ..... 30.01.17 ..... 5.,...67 ........ 1.6--l.6_.W ...... 0..33.0 2999.23 S87.00W.........: I~7,,,10 S 3058.3~_.W ................ 30~i..85_5 87 .... 1/+_.A. 6.....W ............... 2, B80 ................... 3059.82 586 · 0 OW .............. 150. ,:') z~ ..5 ..... 3121,1 Z:LW ....... 3 i 24.. 7.7 $ 87 .... 1.3 .... 52-.,W.-_' ........ L. 019 .................. 3122 · 67 . , 587~00W ........... 15.14..81 S ......... 318.~-2.8:....W% ...... 18.8,04...:.5_.87 ..... 12..-59--W-: 0..,638 ........ 3185,87 0 S 88 · 0 ~. W ............... 15 ..7 · 52 .S ... 32 ~ 6, ~ ILW._: ............. 32.50,29... ,5 .... 87, :,..... 1.3 ...... 1,.9.,,,,..W ................ 1 ~ 0.59 ................... 324. 8 · 08 S88 · OOW ............... ~59,67 S ~..3308.., O0.]W ............ 331 i, 8.5... 5... 87 .......... i&.]:L.I:~.W..- ............ 0~0.0.0.: ................ 3309 · 63 S 89,00 W:--,.__i. 6 i., ,,::, 6 ~ ........... 3.368..-.85 ....~ ........3.7..2...,,..7. L-S.-.. 8-7--.15 _33.._.W ...... t.-..0..6 ~ ........... .3370 · 5 C S8:'-,). 00~',..':. ....... :t,.52,, 3 i 5 ....... 3&'..29,.OZ._....J,'L_ ............ 343.;::'.. 85 ..... S......83_.:.13.,_...:23_..W. ............. 0,,0.00 3z,,,,30.68 588 ,,. 00 W ............ 16 6., 02 ....S ........... 3..5. ~ O, ...... 7.~..W ....... 3 ~ ,.2 ~ ......... S_8~Z_ 1.9 ....... 21_W__ O...7.,.50 ...... 355.2. · 0 $8 8 · OOW ............... 16 8 ,~ 12 S ....... 3610.,3.&._._W .......... 36, 1/-+, 2, 5 ...... S. 8_7 .... 20 ............ 1._W ............... 0 ,_ZSO .............36~2,, .0~ _ 3' ~ ~' " .._3.670 ,_3.1 ...... W ........... 3.67&,25 .... S ..8.7...]20._~.1_..W ......... O..ZSO ..................... 36.72 ............ ..7...80.0 ....... 3,~ ....... 0 ............ 6596.·95...:..:._6~96~,95 $88,0~w ............. 17J~21 o .... -7.9.00 ..... 38 ......... 0 ........ 6,.~.7.6. · 2.8 ......... 6 p..Z 6 '. 28 ......... S 88.0 OW ........... 1.12 *.33..,~ o ..... 3...7..3,1... 15 ..... W ....... 3-!3~.,12.-.-S.-..8..7~21 .... lg-W. L ~0, O0 ...........3.7~32. ....... 800'0 .... 38 ...... 0 ............ 675.:;:, ,~ 08 ......... ~655.08 Ng0,,00W ...... .: ....... 17.3~i...S .........37.92...70_.W ............ 3Y,96.66...,.S...87 ........ 22...55__~._ ....... 1.231 ......... ..... 8.1 O' 0 ..... 38 ..... 1 ~ ............ 68.3 .... · .7.5 ............ 67.33 ,,,75 N 90.00 W ............ 173 ,,,..z+ 1 .... 5 ........ 3 854 ,, ~ ~ _ W,.L ....... 3858.3 ~..5 . @ .7,.,. 25 .... 2, 6,:LW ......... .O., 2.5.0. ................... 3..856.. .... 82D0~.39..... 1.5 ......69.11.JL~....,~....6Sll, 7./,+ ........... 1":4B.9. ,~0.0 W ....... ....-.112..,..86...,:..S.~.,.39i .7..,0.3_,..'¢,L~.__..39 ZO..~ ~--S,- 8. :7....._.2.. 8,_2,2--W--'~._1~ 03..'1 ................. : -.:~:- .:_ GYRO$COPlC SURVEY .......................................................................... NOV -t7', ..... t'978 B300 38 .... 45 .... 6989,45 ...... 6889,a5 --( 00 .....38 .... 15 ....... ~7057..,.7! ....... 6967,71 ........ aS00 37 ....... 15 ........... 7.146,78 .......... 70~6,78 ........ 8600 .... 36..30 ............. ~226,T7 ........ 7126,.77 ~8700._35 ....... 0 ...... 7307,93 ....... ....... SS00 35..15 ..... 7389,72 .......7.289,.72 ......... 8900 ..3~ 0.L.:~7~7.2,50 ....7372~50 .... 9.0.00 ...... 32....~.5 ....... ~5.5.6,~8 ....~.45.&..~.~8 ...... 9100..33 0 ..... L76~0,~7 ........... ............ 9200 34 30 ...... ___.93.00_.34 30 ......... 7806,.0.2 ........ ..... 9400 35. 0 ........ 7888,19 ........7788.,19 .... 9500 35 ~5 _7969,73 ..... 7.869,73 ..... 9.6Q0.:~.36 ........ 0 ...... 8050..,.~6 ........ 7950,..~6 ....... 9.700_3& O. 81.31,66 ......... 803.1~86. . . 0.0. ~5 0 ..... 8375,38 ....... ~O0..3z~ .i5 ~57,67 ......... 8357~67 i.02..00 ....... ~.. i5 ............ 85~0,aI ......... ...... 10300.33 0 .... 8.62~.56 ........ ..... !0~00 33 0 .8.70~a3 ..... g60a,~3 _1..050~O .... 3.2 .......... 0 ...... 8792,t7 .......... ...... i010.0..L:32:.t5 ......... 89&2,..:2 ......... _/vi, EAS. DR][F.T.~_VE:RTIC:AL ....... SUB.. DRXF7 _.TOTAL COORDINATSS ....... C.L...O S .U_R 5 5 ......... 55VERLTY ..... SECTION .~ DER TH.., ANG.L5 .......... D~t?TH .................. 5~.A DIREC DISTANCE ........... ANGL5 .............. DEG/iOOF. I~._ DXSTANC .................. D_ ..... M ........................................................................... DEG, D .... M___~ N89.00W ...17i.75....$ .......... 3979~95 .... W ......... 39~3.,65 .S. 87 31...~3.-...W ................ 0-500 ............ 3981.6~ N B 9 · 0 OW ...... !70 · ~3._..5 ..... 4.0~2... ~ 9 .... W ............ 4045.79 .... 5 ..... 87 ...... 3~-.55-W ...... 0-5 O0 ................. 89.00W 170,68_5 ........ ~103,4i_.W ....... ~10~,96_.5 8.7 .... 37 ........ 5..._.W ................... 1,2~0 ............. ~105,12 [~9,COW i70,6~ .... S ..... ~163,~i ...... w ...... ~166,91 .S.87 .... 39 ......... 8__W ................... 1.~031 ................ ~165,i~ ~ 9,00W ............. L70,68 ....... S ...... 4 221.~. 83 ...... ~ ........ ~..~25., ~.8 .... 5_.8 7 .... ~ ~ . _..5_W ............. 1 ,.6 B8 .......... 89.00W 1.70.58 .... S.,: ........ .4335~,~6 W 4338.82..S 87 ..... 44..,43..,..,.W ............ 2,.32.7 ................. ~B37.-16 87, O0 W .............. 1.72,5.7.~_--.43.8.9.,..70_..W ............ 43.93 · .i 0 S...~ 87_~..~ 55-W ...... 0...,53d ~ -..--~ 39.1 · ~ 2 585 OOW 175,8.9....S ..........~ ~43.,88...W ~7,36 S...87._4~ ......... O....W ................. 0,3.88 ..................... 586 · O Ow ........... 183,71 5 ...... ~.55..~ ...... 81 ..... W .......... ~5 59 · 51 ...... S ...... 8.7_~1 .... 26.._W._: ....... 0.,0..00 ....... 4.557. .%88,00W 166,70..__..S .......... ~.&l.2.J/2.. W ......... ~616,50 $ 87_~0 ...... 5.5._.W ............... 0,8.26 .................... 588,OOW .18 $,72 ..S ........... ~57.0~58 .W .... ~57~,39 S. 87.....'.~ i. :.10...... W .................. 0,750_ ................. 4672,~7 .NSB,OOW 189,.7&.,~..._: ...... 4846..,.70 .....W .......... ~850.42 5..,.1.87.,,,~.5.:...2.~_..W .................... I.,.1..7~6.....: E 9 NBg,0OW .186~21~-..S..: ......... 50t9,53 W ...... 502B,08.S .... 8.7 52 ...... 3~.W .................... 0,-7_50 ........................ 88.0ow ........i~4~,.7,5..~ ...... 5,Q7.5,,'i6 ...... W ............. 50.78.52 ..... 5--8,7 ....... 54_5.4_W ...... 1.,.0.~4 ........50.75.97 87,00W ..i. 82,37.......S ......... 5129,.7.6 .... W ........ 51.33.,00 .... S~._B7 57 ...... 49. W .............. 0.,388 .................... 5131,54 ~6,00W _179,05....~.:5 .......... :5.i8~,.12 W_ 5187.,.21_.S.~......88 .... I 18 .... W. ............... 0.,-5.~5 ....................... 5i85,~ ~7.00W ..... 175, ~.,.L.~ ........ 5,2,37....7,.5 ...... ~ .......... :.~:~0.6,9 ...... S ..... 88 ............ z~ ...... ~,0_...W~----.i.,,,0,,39 .................. 5239.~ 86,00W 1.72,55--S ........ 5290.,27 ....W. ~;';; 3 ~ ................. ~..9 .,0B .... o ..... 8.8 ..... 7 ..... 5.~__..W ............... 0,520 ............... 5291,92 3 .... i. IID.0 ....... 1...... 3Q .... ,9302..,.9.6 .......... .9.20 2.., 96.: .......... ~7.9., 0.0W. ....... L....1.3..6. ~ ~I~..~ .... 5..55.0..,.1.5_~( .............. 5.5.5 2..,.4.3__&_8..8 ...... 3..5 ...... Z.9._W, O..,.1~0 ........................... ARCO GYROSCOP:i,C SURVEY ................................................ NOV' 17~' 1978 ....................................... R~CORD OF SURVEY ........................ ALL.CAbCUL. AT],Oi'~ F-'ERFOi~,~i'~D [3Y I I5 ,~ EI.,ECT.RON~.C,..COi~PUTEP, .............................................. ZR LI ~, -.-:v, EAS. DR~:FT ..V[RT. ICAL, .............. SUP, ...... DEP,TH,ANGLE ......... DEPTH ............... SEA .................................................................................................................................................. DOG--bEG D~R~C D~$TANCE .......... ANGLE ............ D~G~.OOF.~ ........ D~TANCI _Z"n03.~32.. 0.. 9,388,00 ......... 9288,00 .... N81,00,W .......... Z2?,,33.S .. 5602,~?..W ............ 5&O~,-01 ...... $ ..... 88 41 ~5~--~ ............... O.--TD~ ................... D603o67 ~9.~.00 ....... 2 .......... 0 ........ g~..~2.,..80 ..... L.9372,80 ..... N.7..9,0.OW ........... i18,13 .S 5(~5~.,75 ..... W ........ 56.55-,99-.-~-.88--.~8 ..... 1i .... W ....... 1~,.06.0 .................. 5655,75 -.I.I~00 3.2. 0 .... 9557,81 ........ 9A57,~i--N. 79,00W.-.~O8,02 S- 5706,.~7....-~-..4-.: ....... 5707,79.S....88.5~ 56-W ..................... O,.O.O-O ..... 5707,6~ -:1.1.500 ...... 32 15 ......... 96~2~30 .... 9542,30 ...... N78,00W .... 9_7,~.g ~S ...... 5758,.~8 ....W ............. 5759.,70 ..... $.-.89 .- 1---50..-W .................. 0,-379 ...... 5759,62. ._i&6~.0_32 .....1.5 ....... 9~2.6,.8...7~_,962..6,.8~ .......... N.79,.00~ .............. 86,78.....S ......... 5..8.1..Z,~.i.~--W~-...55.l.l,.Sg.-S-89 ......... 8 .... 39-~ ........0.,-..53~ ............ 58~t,79 ~I~638 .....32..15 ............ 9_.7.59,.0.1 ..... :.~9659,01 .....N~9,00W ......... 82,91...S .....58.B1,0.? ..... W- ....... 5.831,66....S .... 89-i.1 ........ ~--W .............. 0,0.00 .................. 5831,6~ .... B.O.Z. TOH....,,.HOLE~~,.C LO.EUR, E ......... ~903., 2 FEET ~AT -~.ARQO. K, 12RD'- ............................. GYF,,;O$COPl~ Su;:~VEY ............................ NOV .17~ .... t978 ' .................. IN.Tg?<P. CLAZ[~D .-.TRLJ~-..VF~RTiGAL ~PTHS~..COORD~NAT~._-.AND-C~OS~RES~FOR..GIVEN.D~PT.H5 .... CODE ........................... ~4EA.SUF(ED ....... VERTICAL ...... TOTAL... COORDINAT.E5 ................... C L-O...5 .... U R E 'AMF .... N ,,~ ....... DEPTH. DEPTH --DISTANCE ANGLE .......................... SEA D ...... H .................................. 11.0~I ....................... 92~b,02 . 1~2,8.9 S . 55i5,~5 W 5517~30 ...... S .... 88...30_ 57._W ...... 9_1~b,~0.2 .................. ............................................. 1..i.066 ........................... 92,7.3,95 ................... 1~9.,_7_~ .... ~ . ~55.33,33 ',~ ............... 5535.,~0 ..... & .... 88 ..... 33,....,1.1._W .............................. 11174. _ 9365,93 129.,55 S 5586,99 %~' 5590,50 ...... & B8 40...19.. W 926.5,93 ............. ................................ 112%0 ................. 9396,4~ ....... 126,~9 5. 5607.,80 ~,~ ........ 5~09.~23 ....... S .... 88_42 .... ........................... 1.%306 ............................... 94,.~7,89 ........... 11.7..,.52 ..... S _..5657,87_t'g .................. 56.59,0.9 ......... S._.88 .... 48 ....... ............................ ~13.62 ........... 9525,~8 ..... 1.i~,86 ~ 5667,0.0. t~J .............. 5688,1.0 .........$. 80 52..23 .... ............................. 1147~ ................ 9619.~.5 .. I00.38_S 5744,79 W ............ 5..7..45,6,7._._~,$ 88~ 59 .... 56 .... W ._T.D ................................. 1,ZfZ.7~5 .................... 98..7. z~,87 .............68,96.5 . . . 5902,83_..W ................... 5903,2b ......... S ..... 89 ..... i9.. 5 ..................................................................................................................................... - . . D, .D,~P-,, H.-AND..-,OTHER DATA ........................................................ T?.UE . NEASURED DEP.T.H ........................... D£RTH SEA 200 .......................... 200, 100 3.0.0 .................................... 300, ........2.00 z+00 ......................... z~00, .,300 500 ........................... 5.00, .. z, 00 ..................... 'tOO ............. 700, 800 .............................800, ...... 700 90.9 .................................... 900., ........... 800 Z001 ......................... ;I. 000, ..... 900 102 ................................... 1100, .......1000 ~,YRO$COP[C SURVEY ............................................................................... NOV"i'7', .... ],978 FOR EVERY..:.EVEN. :1,0.0 .... F, EF~,T..-.OF....,.,.SUB-.,SEA .... DEPTH, I',~D-'T VD ........ VER.T [ CAL DIFFERENCE ..... CORRECTION ....... TOTAU ......... COORDINATE~ 0 ............ 0 .......... 118.56 N .......... 0 ........................ 0 .......... i~5~7B. N ............... 25.77 0 .......... 0 ....... Z i5.~ 8 i---N .................. 0 ..........................0 ............... Z22.0B N ........... 17~96 .... 0 ........................ 0 ..................... 1.2~ ~ 95..N ...................... 17 ........ 0 .................................. 0 .......................................... LB 2 ~ 2.5-N ................ 0 ........................ 0 ....................................... 140.~ 7B N ............ 21.~6 .... 20.2 .................. 1" z. 00., ................... I100 ................... 2 ................................................... l .................................. 1..54,,81._. i30~ ........................ 1300. ........ 1200 3 ............. J, .................................................. 157,33 lZ~0.5 ........................... 1400, 1300 250'L.~ ........................ i500, ............ 2z.~00 ~ 5 1700 .1.~ _ 52 ~9~8 ..................................... ~900, .. 1~'~''~,.~,, .......................... 2023, ......................... 20.0.0, i900 2.3 .... ............. 223,~ ............................... 22.00, .... 2!00 _ __~8 ................... ....... :. .................. 2350 ................................. 23.00, ........ 2200 .............. 49 ..... .................... 2 z~ 65 .............................. 2 z+.0.0 ~ .............. ;'!300 ...................... 6/+ .................................................... i 5 .... ................................. 2707 ............................ 26.00, 2500 ..... ....t0'7, .......................... 2")56 ................................ :.Z. 8.0.0., ............... 2.700 .... ~.56 ..................25 .................... ~0~0 .... : ................................ 2.900.~ ................ 2.800 .... 180 ................ ~,. .................................................... 1 i~.~ 77.....N._.: ............... 75~. 72 ..... .............. 3203 ....................... 3.000., ............. 29..00 ........... 2.0 B ............................................. 2..3.___ 1.0.,7., 26....N~_-.8.26 ,..~.8_2~ ................................. 3326 .................................. 3. ~ 00_ ,: ............. 3000 ............ 22 ~: 2 ...... . ............ 3..5.7 ~ ....................................... 33:.OO..L: .......... .32,0.0 .............. 27.~ ...... ..' ': ........................ ~ 8,2,~ ......................................... 35.00-~ ............. ~ ~ 00 ............. ~ 2 ~ :.Z.~.::.~::3. .. · --ARCO. K-12RO ...................... GYRO$COP~,C SUR,VEY .......................................................... NOV- ,V, EASURgD. DEP,.ZH,_.AND_D.THER DATA.. FOR gVERY ..... EVEN ................................................ T. RUE MEASURED .............. VERT[CAL SLJE~ ~,ID-TVD ... VERT.iCAL ................... DEPTH ............................ DEPTH Gt~A D[FFERENCg_.. CORRE~_I.ON ........... T.QZAL ....... C.OOR.D..[NATg$ : ............................. ~0'76 ............................... 3.700- 3&O0 376 2~ ........................ ~B ~ 57_..N .......... 13~,.6 2..__W ...... ,9~ .... N ...... 14.2 .,AS_W ........... :...~ 20 2 3.80,0.. ............. 3700 ......~ 01 ................................................. 2,5 ...................................... 3 7 : 0 ............................ 4328 ........................... 3900., 3a00 /~2~ 27 ............................ 2'7,2S N .......1 ~96,6 9_.._W .................... 4455 ............................ 4000, ...... 3~00 /~55 ...... 27 .................................. 17,al .N .......... 157~..76 ..... W ......... 45aa ............................. 4100, .......... 4000 ......484 ........................... 2,9. ..................................................... 7,5~...N ............ 1655.~3_,W ........................... 4712 ........................... ~200., .......... al00 512 ...... 28 .......................................................... 2,90 .5 ...... ........................... 48~2 ................ ~300, ........ 4200 542 :.30 13,..36.5 ..... ~8i6~4.0._W 4.9,Z2 ..... ~ ...................... 4400,, ............... ~300 ........ 571 ............................................ 2.9__ 23 ,.17 ....5 ........ ............................... 5103 .......................... . .......... ~ 5..0.O, ............... a400 _[~02 ............. 3L .................................................. 3.1,50_.5 ~ 983., 1.6_W ......................... 5235 .......................... 4600,'.:....: ..... ~500 635 33 39,03 5 ..... 2069,.22 ....... W .................... 536,7 ............................. ~700,,_,. ............ 4G00 . [,67 ....................................... 32 .................................................. z+G~ 8~._& ............... .......................... 5500' 48..00, .............. 4700 70o 33 .............................................. 55,32 ..& ............... S 30,41 ..... ,563~ ................................ :~900, .... : ....... 4800 734 3~. .................. 55.82 .............. 23 ............................ 5.?57 ....................................... 5000.~ ................ 4900 766 ....................................... 3a ..................................................... 76 ._04._,..5 .............. Z~,11...93 ....... w ........................ 590~ ................................... 5100, ............ 5000 BO0 .... 34 .................. : ........................... 57.62 .S .................. 2505,3.6...W .............................. o.~2 .................................... ;.2.00 ................ 5i00 832 ...... ~.2 99, 3 $ ........... Z590,6.5 ...... W ........................ 5.~ G 2 ........................................ ~ 3 O0 ~ ................. 5200 ......862 .................................................... 30 .......................................... iQ8,. ~ 0... S ........ Z6,13 r 5 Z9_ ............................................... 1 i 7.69...._.S .............. 27_p. 3...10 .............................. 529~ ...................................... ~00.~,..: .......... 300 891 ~ , .... W ........................... 641 [~ ....................... 5500.~ ......... :..5~00 ...., 9 ~8 2.7. .................................................... ~26,56,._.S ............... 283~.. 29 ..... .................... 65.4,3 ...................................... ~.6.00.~ ................. ~500 - 'c ' o 6. .............. 6666 ........................ 570.0., ............ 5600 9G6 ......... 23 ........................................ ~1 ~ 12.,..~ ............ 297,"L, .8,0. ,....W 6~:2 0 ................................... 5900,,, ..... ~,,:,..5 800 .1 L) 20,.~ ............................ 2.9 .............................. ~5 !, 8 i_...,.&_~.3&33.80_W ......................... - ....... 7t.7G ....................... 6~00.~.,..:. ..... 6000 [076 ............... 2,7 ............................................. ~59~t~ ...... ~ .............. 329~-2.~_.W 730 2 ...................................... 5. 2.0,,O.L~ .:,,6 i 00 .... I ! 0 ~:~ ................................................. 26 ............................................ ! 51.,. 2,8-~.S ...... 33./0.-0 n .... ........................................ ?427 ........................... 630.0~ ........ '_6200 i[2'7 .......................... 25 ................................................ ~62~6~...,.S ............. 3~5e31.. ,~.: ......................................... o ,.U..U,.~ .................... 6300 1153 26 ....................................................... i 6. ,.03....& ................ 3.521,9.8 ._W .......................... 767 9 ................................. 6 ~.0,0.~ ............ ,~ 6400 .......... 1 i 79 -.2.6: ! 67.,.,,6,1,~. ~ ........... _3,,5_9~7., 6,7 ..... W .................................. 2.930 .............................. 67.0.0-~..,.~..,,,_:.6600 ........ 1.2 -, C' .............................................. 2.7 ........................................................ 1.72.~..8,,8--S ................ 3.749..6-1 ....... .:~ ..... 507, 7_~ .......... .... : 68 O0, ........ 6700 ...:..,.1,257 ....................................................... 21 .............. 173 ,..41__.5 ...... 3.823..... 8~5 .... W ................................. ~1~,5 ........... ................... -. .......... ~00~.~:~-: ....... 6SO0 ........ 128.~ .: ................2.7 ...................................................... I.-~3.02.....,.S .............. ........................... 83. i .?~ ........................................... 700..0,.~ .......... 690 0 .13.13 2 9 .......... : i~ i... 62..,_.S ......... 3988 ~ 08 ..... W ...... ARCO K 12RD ...................... --~,~EA.,SURED-..,DEP-TH.-AND~-,,O,THgR DATA FOR ........................... RUF. . gEASURED ......... V'F,R T [ CAL GYROSCOPIC SURVEY ........... NOV 17, 1978 ' EVER. Y....,..E.V.EN. iOO.-.FEE.T...OF-~,~UE~-.$EA .... DEP.TH, r~, D,-T VD ...... VERT_.] CAL DEPTh ........................ DEPTH SEA D[FFEF~ENCE ........ CORRE.CT.[.ON ........ TOT. AL ..... COORDINATES ................................................................ ~567 ................ 720.0, 7100 1367 ................. 26 .. 170.91~.5 ..... 8690 ............................. 7300, ..........7200 .... 1390 ............................. 23 ........................................ 170,59-...$ .......... @812 -- 7AO0, ..... 7300 ..1~2 22 ~?~,57--~.~ ............. ~286,27 8933 ......... 7500. .... 7400 ..IA33 ........ 2. i 171.09,-.S ............... ~353.28 ..... 9052 .............................. 760.0. ........... 7500 .... 145.1 ........................................ 18 ................................... i7~.13~..S ............ 4417,.72..-.W 9~?Z ... 7?00, _ .7600 1~?Z .................. gO ........... ~78,6£.....$ .......... ............................. 92~3 7800. ........ 7?00 1493 ................ 22 ......... ~83.~2 S 94!~ .............................. 7900, ................ 7800 ......... i. 51z~ ................................ 21 ................................... 1...8~6,.9~8~-5 ....... .............................. ~537.: .... ~000. ..........2900 1537 ....................... 23 ............................ 1.89...~0-S .............. 4592,21 966~ ......... SlO0. ....... 8000 1561 ................. 24 ................................. 1.90,~8.....S_.. .......... 9.78~ ................................ 8200, ........... B.iO0 ........... i.5~.~ .................................... 23. ........................................ 1,9.Q.,.03.~.~ ........... ~837.3.0 .... 9908 8300, 8.200 1608 ........... Zz, .................................... 188,.13..S ~0030 ....... 5400. ..... 8.300 1630 22 ................................... 186,90~..S !.0151 ........................................ ~500, ............ 8~0.0 ....... 1551 .............................. Z! ............................... 1.8.5,58_~5 ............. 5048.,.15_.W. 10271 ................ 8600, 8500 ..... 1571 20 18~.,1.7.5 ..... 5113.80 !0390 ............ ,¢?00~ .8600 ~690 ~9 .................................... 17.9,~2 5.. ~178,5~ ..... !05.08 .................................... a~O0, ...... 87.00 ....... 17Ci8 ..................... LB ........................................... ~.15,5.6__..2 ........... 106.26 ............................... 8900. ......... 8800. i.72G._. 18 ....................................................... 1.71.5~ $ lC).TZ~.....: .............................. 9000. 8900 ...... 17 15 ........................................ 16.5.31.5 ...... 10862 ............................. 9.1.00~ ,..9000 .......... 17. e.~ ..... 18 ..................................... i5.6.65.....5 ............ 1098.0 ................................ 92,00., ........... 9.!00 .... ~780 ......... 18 147~1£ S llO9&.,.,~: ....... :. .................. 9300.~: .......... 9200 ...... 1.~96 ...... 1~ ~36.86...5 .... .................. 1,1214 ~. .... ~..: ....... 9400., ....... 9300.:. 181a ................................... :.18 ....................................... i..~6.1,5..5 ........... 5&,09,.,.89 11332 .............................. 9500. ...... :..9400 .... 1B32 . . lB ll~.90.S ..... 567.1.~0 l~aSO 9600_, ..... :.~.9500 ~.~$50 1~ i02,8 ...o ................ i.i~,P.~ ,, .~ ....................... ...... (~00.,. .............. 9600 ........... 1.868 ........................................... t..8 ............ 90,0...9.~....S ..... ............................. 11686 ........................................ 980..0, .......... 9700 ...... t.8~6 ........................... 18 ........................................ 78,02..~$ ..... .... ARCO ~..,12RD ................................ GYROSCOPIC SURVEY ................................................................................................. NOV [7~ .... [978 ......... ..... N, TERPOLAT.ED,.._VALUE. 5 .... FOR_ EVbN iO00.FEET... OF. MIEASURED DEPTH. ................... MEASURED ..................... VER_T.ICAL .... ' SUB ' DER.T.H .............................. DEP_'[H ..............,SEA TOTAL .... COOR D..i NATE,5 ......................................................... · ........................... lO00 .......................... g.99. .......................... 2000 .... : .... i977, 1877, ......................... 3000. ............................... Z8.3.5.,, ............. 27.35 4000 ....................... 36.39_, _ 3539 ~2~ ................................ 6 C O0 .............................. ................... 7000 .................... 8000 ..... 140.6G..N ............ 21,31 .....W 157.30 N ....... 212,76 W ................... i14., 09 _. N .......... _7.O7,85_!/,/ 5~, 59 _N ............ i298,..5:L ....W ..... 25,!3 S ............. .96 ,.70 S .......... 257.0,.00 W 173,41 .S ............... 3792,70 ..... W .................... g 0 00 ...................................... .75~5,6,. .......... L7~56 ~ .......................172,57 ...................... iuO00 .......................... 8315, ........., 8275. ........ 18.7,20..:~ ............... 4.962,81 ..... W ................................ 11000 ........... 92. t.-7., ........ : 9117, . ................. · . .-. ........................................... - ........ : ............. ATLANTIC .,mCHFIELD COMPANY ................... ; -. ' ........ _.~_.-;.~::.'.?-i_:'_'i~..ii~..i.:-~i' -SCALE--!1" = IOO0' ' ............... ....... - 400 ......... -'_ ....................................... ;- ............... - .................................. ~ ..... ; ............... RADIUS OF CURVATURE ............. ........... t600 ....... : .............. '~ ........ : ...... ~ ' ~ _~ ........ : ....... : ..... ~--~.-:~--~-~.~-~'-~- ....... 7-: ...... 7--~ ' ~ .....~ ....... ~__: ........... ..~ ..... ~-~ ..........?:'--~ ~-~-'T":r'' - ......... . .... .. ~ .... . .... ......... -- ......................... -- -- ' -- --"000 X":: ........... :~":'~ ~ :~-: ............... : ....... /ALL-DEPTHS SHOWN'"'] ..... ~ ....... -:-- .... 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RADIUS OF CURVATURE ~ L. .... . O ............. - ............................... - ....... ~ - ... Eastman / , Whipstock A PETROLAN£ COMP~ REPORT of SURVEY ATLANTIC RICHFIELD COMPANY K-12-RD WELL NAME KING SALMON PLA.TFO~I LOCATION JOB NUMBER A1078 G0041 TYPE OF SURVEY GYROSCOPIC (Average Tangential) DATE 10-23-78 SURVEY BY Jeremy Beat%ie OFFICE Alaska -CO~4PLETiON--REPORT ..................................................... NOV .... ],7,'-1'978 ........................... DECL I NAT. I ON - 2~---DEGREES---EA~T ..G.YROSCOP ~ C ~..,URL -.Y _,.TANGE,NT[AL.AV. ERAGE ANGLE METHOD OF COMP. UTAT[ON KB-...ELEV .... ~00 .F.T. .................................. RECOR~-.OF--~URV.g Y ....................................... ALL .... CALCULAT.[ONS.-PERFORMgD-.--BY ..... ~ .... B-MEL. EC.TRON[C--COMPUTER ..A ,GL~ ......... D.E P...T H ............ SEA .............. DI REC.. DI ST.ANCE ..........ANGLE ............... Dg.G.t-], 00F-T .............. DISTANt[ D .... Pi ........................................... DEG, D ...... M---~ ............. 0 ........... 0 .... 0 ................ 0, O0 ...... -I00, O0 ..... $1.7.,.OOW ......11..8,_55_N .......... 1_.4,.64._..V~ ................ .. 19.,46._N ......... ~7 ........ 2 ..... 2.1--W .... 0,0.00 ......................... i`3,25 lO0 0 0 ................ !0.0., O0 ..... 0,00 $~7.,00W ............ i.!.8,55......N .......... 14,.6 ~..._.W ............... :L :L 9.,.~.6__N ....... 7 ....... 2 .... Zi_W ......... Q,.O00 ............................... 113,25 ...... ,. -, ....... ,,,., ~,-, . · .... . .... ~00 -0 ...... O 2U~, O0 .......!00,00 $1.7.,..OOW .:Li.8_,.5.5 ...... Fl ............ 1.4.,~64_.W. 0 ............... i.1_7.., 51. Fl .W ............. i., 2.~ 0 .................... 1`3, .58 ............. :300 ......... 1 ..... i> ........... 299,99 _. 19.~,99 ....... 51.7,0 W ia,95 ....... W ............. 11~3,46 .... N ........ 7 ....... i5 ..... 1.5_ aO0 ........ 1.. 0 ........ ~99,97 299~97 .S32,O. OW ............. 11..5,'/3...N ............. 15,77 W ___p. O0 ...... .~ 0 ...... ~9 9. ~ ..... w ................. 20., 2,.5 ..... N ............. 8 .... 52 ~+3.... W 17 60.0 ...... 2. 0.. 5°9,~0 499,o0 N a,OOE ............. 11.8,8! ..N ................. t8,56. ...........700 1 45. 699.85 599.f~5 N 3.00g ............ 122,08 ..N ................ 18,36_W .................... 1215.45 ...... N .8 .... 3,3 ..... 1_ _.W ............. 0..252 ............................. 16.9,3 900 ......... 4.30 ..... 899.,~''''':'.~, ........... "/'99,.57 N ............... 9,OOW !~2,31 N.. ..... ......... i8,30.W ............ i..:.'3B.,,5.7 ..... N ........ 7 ........ ,~2 .... ,3_ W ........... 1_,,9~9 ............................... t6.76 i000 ....... 6 ...... 0 999,15 ........899,15 N35,00W ............ 140,80. N .......... t21,7~_:_W ................... 1.42,.~+.7_._N ........ 8 ..... Z+6 .... ~2_W ........2,..72/5 ............................ 20,09 ...... . ' 4 ' 2-8~,00 "'00 7 0~'09'8 ,'5 1 9 9a.., 5.1 ....... N 55.,_O.OV,I .... i.~_$., SO_.S_ 2.9...,_ ?. ...... W ........ !_.4_00._1~0 .... 0 _i_3_9.5.,..i.3..__i29-.5-'-1,3 ..... $ 8. 8.,.0..0.:~.~___1.~.~7.,-52._N 7.2_,_8A__W .......... L7.3..,,.55-N-2.~--49---3.-W ............... £.. 651. ---71., 0 C ........ 1500 1i 0 1493,45. ~,393,46 $87,00W 156,,73 .N 9.1,0~ .... W ..... 181.,.,2..5_~__~.0 ......... 9 ....... 15_.W .......1.,.0..15 ..................... 89,21 ...... 1_8.O.0 ...... i4...75 ........ %.7.8_5.,:,9.8 ......... !685,_98 ........ N87,.00~ .......... 156, ii N ......... 15.7_.,.4.2._.~ ............ 22i.,.70 .... N__~5 ..... 14 ...... 17__W .......%.,.8.1 ................... 155.5~ 1900 15 15 188.2.~..3.~ .......... %.782,~ ..... NS.7,0OW ......... 157,51 ...... N ............. 184.,.10_..W ......... 2~.2,.29__N.._..~9_.27-.. 3.._W .......... 1...,.500 ...................... 182,21 ~_0.0..0__1 L_~.5 ......1.9 ................................. .. , ~' ~ ' 3 1 72, ~ 1 577,00W 152,89 N 246,19 ~ ..... ZS_9..,..8..l__N.__-5-8---9--2-9~W- _ .~_ .6.. _ .O 2 0 2072, : 9 .................................... _ .,_~.g~.p.,_.z 3 ...... o ........... 2...t.0..5....~..,0.~ ...... Z_0.~.5..-.o: ........ _s73,.0.0.w. ......... .i¢_3.,,..Z.0,.._~ ...... _Z._~.Z_,_~_~_~_~._I~.,..~-~--.-6.3.----~ .....~3_.W ......... z _ · R£CORD OF SURVEY ....................................................................... ............................... ALL. CA'L.-c-ULATIoN~ PERFORMF:D DY [ B ,v.. ELECTRONIC ..CO._NiP T:,R · rxu · ................. ]_~(E'/~(.5-;-..]D'~I-'F.']T.-_]~]'~'RT]i'cA'L]]]]-_-_]]]]sUB ...... DRIFT TOTAL COORDINATE'5 C L 0 $__U._R _E. S ................. SEVERI.T_Y ..... SECTION .... ~.RS..T H _ANGLE. ......... DEPT. H ........... SEA DiREC DISTANCE ...................... ANGLE ............. DEG/1. O.O-ET ....... DISTANt [3. ...... i., ...................................................... L)C.~, ............................... - .......................................................................... -"~'~00 .... 26 .... .1..5 ....... 22.5.5,93 ....... 21.55,93 S?O,OOW ...... 129,93. N 32].,89 .W ... 3.4'Z,lZ+...N.....68 ........ 0 .... ~+O_...W ..................... 3,/+81 ............. 320,35 ]]].~ ' ~ ....... ' ................ 3 B 3.. B 2._N ...72_3 6__Z,'.6--W ......... :~ ,.62.3 ................... .0..0_Z9._/,5 .... 23.~4,..23 ........... 2L 4,.23 ,572,00W .......... il.4.~69 ...:'~ 366,2!3 W ...... 2.500 ..... 32.....z+5 ......... 2.429,72 ....... 2329.,72 ... ,585,00w ___104,35_.N 417,12...W .........429,.9.? .... N._?5 ..... 5.7 .... 15.--.W ............ 7,3.65 ..... z+15,87 ___2600 ..... 35 ...... 0 ..... 2512,.74 .......... 2412,..74 ...... INSB,OOW .......... 102o89 N ..... 472,83. W ....... 483,90 .....N.....77 .... 43 ...... 23_...W.: .... 4,501 .......... /+7].,60 _ _2.7.O.O_3.5_4.5___2.5. g.z+.,28 ...... Z/+..94,~8 .......... N89~OO.W ........1.0..4.~ 1 N ............. 530,7i__W ........... 5.40,88~_N._...7.8 ....... 52_.12--W - 0..4~9_z+.? ............... __2.8.00 .... 36_...45 ........ 26.7z~.~93 ...... 257z+.,93 N87.,OOW .............106,47 N ....... 589,80 W ........ :~99,Sz+__N....79_..~+6 .... i_._W ......... 1,549 ....... 588,52 ........ ~..00 ....... .~6_~.:~ ...... 2755 05 ...... 2655,05 N85,00W .......... II0..,6~ N ,49.. W ............ 658,85 ...... N....aO_i9 .... 5.5_...~ .......... 1,197 ................. 6~8 ....... 3100 ...... ~6 .... 0 .......... 2916~z~7 28t6.,z~.7 ....~86~00W ........... 113~2~ N _.. 767,~6 W.._ 77~..76 N ....... 81 ..... 36 .... Z2...W ........... ~.~28 ...................... 768.08 .......... 3200 ..... 35 .... ¢¢0 ...,..~997,63 2897.~6~.. ....SS~,OOW i07.6~ ....N .._8"~5,61'~ .... W 812~60-..N_.SZ .....~4 .... 18._.~.~ ............ 'i.~SZ~ ................. ~ ~ .. it' , __ ............... ~ 3 O0 .... 3_6 ....... ( ..... ~.07.B · 7.8 Z'" or8 ,.~'" _583 uOW ............. i00.52 N ............ U83 ~60 ..... W. 88.9 ~3.0 ..... N._..83._.30....3..5_..~ ....... 0..,.5.0.0 ............. 882,:37 ....... 3~.00_35. 0 ....... 3159.59 ..... 3059,69 584,OOW 93,86 N 942,00 W 9~+6,67 ..... N...84 18 33....W ................ 0,588 ..................... 9~0.8~ 3500 ..... 3.6 .... i5 ~2Z~0,46.. 31z~0,..46.. $84,00V~ 87 ~20,?I .............. ~.0 ..f. 1 ~..OOW ..................... 81 __.~..6.00 ...... 3~ ....... 0 ......... 3: .' .'. ~ ~" . ......... 8 ..... 17..0.0_.36...45 ..... 3400,71 ...... 3300,71 SB4,0OW _ 75 ....... 380.0 ..... 37 ....... 0 .... 3~*80,70.._3380,.70 S83,00W 68,~+0 N 1179,g6 W... 1181.25 N...86..~+0 083..OD~ ........ ~+~?i.N. 1299,'-3.1..'~ ...... 13.00.,52 ..... N_87 3~'~ 18'__..W ............ 0,.96fi ........................... 1298.6z O0 .... 37 45 ........ 3640~0~ .... 35z+0,.04 c r~V 3~0.0 ..... 37 ...... ~5 .......... 3719,10 3619,~0 .... S82,00W .... ~6,72.N 1360.,07 .W ..... 1.360,87 .... .... ~.20,.~ ..... 37 ...... 0 ...... 3798 · 5~3 369~ ~ ~ ............... ~.2.~.~.~,~ ................. 38 ..... 8 f'~ ........ 1/~ 18 ..... W ........... i.~.2.~,.70_.N-~,..~8 .......... ~00 ....... 38 .... i~ ....... 3956~S7 ~8~6.57 $83~00W ................ 21~7~ ~ .i~1,67 W .......... I~1~3 .... ~..8.9. il .... 30..,~ ............... 0-666 ....... i~1..3~ .... ~.~00 .... 59~ ....... 0 ............ ~0.3.z~,~.7~ ......... 39~/~.70 ............ ~8.3..C ~/ .................. I~ 1~,..~{ i6.~3 ~63 ..... W ........... 1,6.03.~.6 ~._N...89 ................. z~~' c, 5.. ~012.,.5~ 583~00W... 6~z~9 N i '~' 4600 38. ~5. .......,~.~2, .................... - .................. ....... ~0.0 39 .... 0 .......... ~.190~.40 ......... ~090~.0 _ 58Z,00~ ...................... ~69 6... ~728,1~...~ ................. 1 Z8~5 .... 5 .... 89 56 ....37..~ .................. 0,6.76 ................. 1728,0[ ................... ~ ~ ~ ~ ~ ~ 7° ~ .. ~ 0,000 ...... ~.900 ..... ~: .... 30 ............ l+~,~,~,_O( ...... ~2~b ~OOW i7~70 6 . 18~0.I W. ............... 185~.~.1.0 ...... 50.00._~.0 ...... 1 b ........ ~.~ 11 ~_7 ~ .......... ~ 3 ~ 1,7 ~ ~.. ~ 8 ~.0.0~.,.. .......... 2 ~ ~.9.6 .... 6 ........... 1917.~.71 ...... ~.: ............. 1917..,. 88 .... _.f~.~_.i_O..O_.. ~ Q ..30. ...... ~.~.9~.1_,.. 9~__A 3..9.1 .~. 9. 3._.: ...... S..8.~ ~..Q.O~ ................... 3... l~,...l_7._..S .... 1.9..82.,.ig..._~___ig.B..=~,-~A--S ..... 89 ............. 5 ............................................................... RECORD OF. &URVEY ALL. ..... CAL.C.ULAIiONS PJ:"RFORMED..BY. I ..................................... TRUE ' DOG-b. EG _MEAS .... DRIFT_.VERTICAL ................ SUB DRIFT TOTAL..COORD[NATE$ ..................... G L- 0 S ~U. R E S .................. 5EVEF~I.-T-Y ............... 5EGTION _D E .P_TH....ANG LE ............ D EP_T H .................. 5EA. D I R~:C ....................................................................... D [SiANCE ........ ANGLE .......... DEG/-~O OF-T ................. Dt 5TAN( _~ _0.0__4,!.'_0___4 6/+.9. ,~_16--_/+, 5 ,.4.9, , 16 ...... $85 ...... 5500 ..... ___5.6.00_.~.2.--_0__A.815 ,.0..0 .... k17.5.00 ........ 5.82 ...... 5100._.4,1 ~.9..0.0 ..... ..... 60.00_41 ....0 ....... 5.17.5,/+4 ........ 50.7.5.. 44 581, .......... 6100 .... 39 .... 15 ...... 52.51,90...._ 5151.-90 585. . _520..0 ...... 3.9 ....... 30 .... 5.~.2~.9..20 .... 5229,20 ...... 583, ...... 6300 .... ...... 540.0 3 6600 ~3 ~0 55~5,2~ ~6.2~ 585, ~6 %0.0 ....... 38 ..... 3.0 ....... 5.806.,,,.7 ~_,.:..57Q 8.,.7.3 ....... S 87 . ~ O0 ~9 30 5884.z~5 ,~784.45 586. . ~ 0 .. ................. 42 ,,:~ .~, ...... ~ ....... 2112., ~ 8_W ..... 2,1.LB · O.l-.S- a · OOW .............. 4.$, 87....5 ......... 217.7,88 ....W. ........... 2.17~.,4B._.5 · 0 OW .......... $2 ,b 5_5_~..Z3.09_, .02_W U2.3.0.9 ..8..~__5_. · 0 OW ................. 7 0 ,.73 ..... $ ........ 2B..7.4..,.Yg_.w_ ........ 23.7.5,8 OOW .................... 8.7 .... 4.5 ...... 5._.~05J.2.~ ..... ~_ ...:..O...L...TE_.S._ OOW 104.,B9..5 ....... 2_634...86 ....... W ...... : ..... 2636.93 S...ST_ 43 .... 5Z__W..; .......... 3.,1~1..5 ........ i ...... 2635.9C OOW . i.18 ~ ..............2_/60..I.~._._W .............. 2752',~T S OOW ........ l~ ~ ~ ' ~ ...... 9 ~ ...... $ ...... 2.8.8,1..~ 62.,~ ..... 2 ~ 84 · 6 OOW .... 13 7.60._S_...g9~0.. 3.1 .... N ............ 29.~3.5.3 .. $ 87 ..i9 ....... 13_.W .............. 1,..~.82 2.9~1,..7] OOW __ 142,71 ..... 5,__:Z~..9.S....6~.._..W .............. 3002,08. 0 0 W ................. 14 6 ,.9.4_5 .... _3.,~159...2.~_A~_.. _30..b 2...7 0 OW ...... 15 o · 78....._5 .......... 3.122.,..06_W ............. ~ 1.25..70 OOw .._ . ~ 5 ~. 6~ ..... 5 ...... 3..!.8.~,2. i_3~, ......... 3t 8 8 ~ 9~_5 7100 :~8 0 6040,!5 5940,1~ SS~.OOW 157.36 S 3247,40'~ 32.51,21 S 87 13 B2 .W ..... 1,_k7.,8 __--3249,0~ 7200 B8 0 6118,95 5018,95 $88.00W ....... 1.59,.51 ..... 5 ........... 3.B08..~,?.3 ..... ~ ....... ~312,77 .....S..87 14 ....... 2~_...W ............. O.QO..O ....................... 3B10,5' 7400 37 0 5278,15 ~i78,15 $89,00W ]62,t5 S 7500 37 45 6357.61 6257,~t S88.00~..~ 163,7~ $ 3490.64 W 3~94,48 $ 87 18 51 W 0.965 ..................... 3.492,3' 7600 37 0 6437.08 6337.08 588.00W 165.86 S 3551.30 W 3555.i8 S 87 19 33 W 0,750 3553,0( " ! , - . .......... ~ ...... .79 oo ...... 3 8_._0 ......... 6 5 7..5,.~ ~ .......... S.5.7 s ,.4~ ......... s.s.8 · o ow ............. L ? z, ~ 7.. -8000 38 0. 675,~3~2~.__ 6655.2i Ngo.oow i73,25': ...... ~: ........ 7~,_9~7.3.6~ ................ ~79~,60: .............................. S ~Z__2~__~~~~' ..._.' . ._ ' ..... _ ........ 379~.~.,~'. ' , . : , :,.; ,::' < . . . ,, ,: , ' ~ : ' <,. :,,,,: ;~,., , · RECORD OF SURVEY .................................... A~'~ ........ CAUCULATIONS ~'EXFO~.~,V~L)_S¥ ..... ~_ S.....tq_~:..~.C. TBO~.~C .... ~O~.?.U.!.~_~ -J '-'~ ....... ~'"; ................ ]~'~"l .... A~ .......S~B ............ DRIFT TOTAL COORDINATES C L 0 $._U_R E $ ~$EVERI.IT_ ............. SECTION .'~EAS. D~,FT VE' C ............. ' .... ' . ~[_~.E9._~..~_. ANG_L_E ........... 9..E.PYH ................... SEA ..... D [REC D.I.S_rA.NC E ......... ANGLE DE G / ~ O_0.E! ............ D.[ STANC[ .0 ............ r 6989,5~ 6889,58 f489,00W ....... 8300 3~ ~ ........ . 25 $ .... 3855,~8 .....W ........... 3859..27._ $.. 87 . 25.-..-3J'Z--.W ............ 0.,25D .............. 3857.1~ 7'0. $ ......... 39i.7.,.97__W ....... 3921..,..7~ 5....8.7..,28._3.~_~-_ _l-,-LSO 3919.72 60.. 5 .... 398..,8_9 ...... W ......... 3984,5.9_ S 87_31 .... 53._W ...... 0,.5,00 .................... 3982 62 ......... R400 .... 38 .... 1.5 ..... ~'.0o7 84 6~6'1,8z+._ N89,00W i_70,~2 S 4043,.i3 W ~.046,7.:~ S..87 ~5 ......... 5._W ....._0..5.00 ....................... _8. 5.,0.0__3.7 ..... 15 ...... 7..I_~ 6, .9 i_..._70_~.6_, 91 ........... 5.89 · 0.0 W ......... 170, ~ Z ....... S... ...... ~. i.0.~.,.,...3,.6.,_...~.~. I..0.7_, 90 .... S_ 87 ..... 37_13_W ........ L,3 8.1 ..... ~ 10 a,, 07 __8600__..36 ....... 30 ......... 7226,90 .......... 7126,90. N89,OOW ......... 170.52 o ........ ~.16~..,3_6.._.W ........... 16.7,85_5_.87 39..18 ...... W ......... 1..._~Z5 ................ ~166,07 ......... 870.0..:.~.5 0 ...... 7308,06 .......7208,06 589,00W ....... i.70.52 ~ ........... 222,7.9 ...... '~,_,~226.23 ..5..87_ ~I .... 1..5.._.~ ......... i...9.01 ............... 422~.~9 __SB.OD ...... ~ .......... 15 .... ?..:58.9.,.B.5 ...... ~2.89..,.85.: ......... N 89,00 ~V ............. Z ? O, ~ 2 ...... 5 ...... ~.ZBO_,.32_W ..... ~28 S ,72 .... 5 ..... 87 .... ~..3 .... _1.__~ .... k.~7_~.~8_2 02 ~..8...9.0..0 ...... B~ .... 0 ............ T z,.72,63..... 737. 2, 6 ~ ..... 58.9 ~ 00 W .............. ~ ? 0,5 2. ,5 ........ ~ 336 ,.~ 2...._W ....... ~ 3 $ 9 · 7 8 $. 8 7 _ ~ &.... 53_..W .............. Z, 5..1~ ................. ~ 3 38 · 12 ..... 900.0..32 ....... ~5 ...... 7556.52 .......7456,~2 ..... 587,00W _.. iTZ,Z~l..5. ........ .4390,6~..W, .... ~3.94.,06 $ 87 .... 45 ..... i.4__W ............... l..1.,1.~ ............. 4392.39 ~.9, I.0,0_~.3 ...... 0___76 ~ O., 60 ....... 7540 ,.6. 0 ....... 586,00 w ............. 175, 3,5 .......4.~ ,.B 5 W .......... .~.~.48,3 ~ .. 5 8,7~..4,~ __9_,W ........... 0... ~9 8 .......... ~.% ~ 5 · 50 .~-9.~-0-0- 3_Z+ 30 ....... 7.723...,5 ~ ................ 76R3~75~ .. 586,o0W ...... 179. ~O.....S ......... 4500,27 ..W ..... ........... ~503,B6 5.87 .... ~2 5.~.._N .......... 1,.500 .............. .... 9.3.00 ..... Z~_..,~O ........ 7.806,16 ........ 7706,16. 585, c 0,86 8~ ....... 9600!..B6 ..... 0 ...... 8050~,_89 ......... 795.0..,89 $89,00W ....... 190,09..~$ .... Z+.730~..l~._._W ........ 473:5,95. S 87 41:.5.5._W ................. 0.63.7 ................... 4.7~2.03 5 ........ 0 ...... 813.1..,80 ........... 8.0,.S..i..,.80..~-.NgO.OOW ........ i90,50._8.__~2.88~,...91_~ .... z+79Z,.'lO.-5 ....... 87.......,.~.3.~.~..~_2N__ 0,.588 ........ :~.0. ..... 36.. 0 ....... 8212.70 .......8i12,70. ..... N88,00W .........18r~,,..5~._.,S ..... ........ ~847,68_.W ...... _485t,39_5 87 ......... ~5._.L.3.7,W, _~1.,.175 .................... 48~9.57 .... 05 ................. ~906,09 W ~909,69 5_87 ..~8 ........ 1.7__W .............. _0,_7.69_.-- ............ ~907.95 ..... ~.0,0.:._.3~ ...... ~0 .......... 8293,86.. 81..9..3,86. Nsg,oow 188, "$ ..................... - r~ x- ~,~ "NSg,O0W' LS?,O~ S ~,,19' ~_4967.,.32_..5._.8.(/ .... 50_3.~_..~ ..... 0,5.00 ............. ~ $ 6,05....~ .......... 5020.,. 6 0 ....... ~ .............. ~02"" 4,05" ...... 5_..8..~ 52 ...... B.9....W .................. OJZ 5.0 ... 10200 $~ 15 ......... 85z~Oe96 8~0,96'. ..... N8B~OOW 18~,59 c 5076,1~ W ........ 5079,50 .... 5....8.7 ...... 55 ........ 2.,.....~ ................... 1..,.l~...,L ............ 5077,95 __~_C.3.QO__ ~.~__9 .... $.fi,.Z~,.,.,.ZO ...... 8.524 ,..70 ..... N.8.7,0 0 w .............. ~..8 2.~ 21 ..... ,5.~.!~.O.,._Z~,-~ ........ 5.~ 3.3..,..~,1._..S_.8 7.5.7_57_W_~o.,.fiO ~_..-- ...... 513 2 10400 3~' 0 8708,57 8608~57 NS~,OOW 17.8,.89 ...... S ........... 5!.85:,1.0 .... ~ ....... 51~8.,~8.....~..88 ....... ~ ..... 2.6._..W ............... 0,5~5 ....................... ~6,8~ ~05 0.0 .... s ~ ........ 0:...._s_7.~.2.,..9! ..... :_.~ $ 9,.,2.,...9'~',.'"/-~ s 7,0 ow ']"] ~7 ~, ~ ~ .... s,_,:5.z.s s...,.7,s ..... w_ ..... 52 ~.~, ~ 7 ...... s... s s ........ ~_..~ s_,w ............... ~ ,.,.1~ ~ ................... 52 ~ 0 ~_0~.00.._..~1 ..... 3..0 ...... 8.8.?_7.,.,S_4 _ 83:/ff_,9.~ ...... N 8.6.., O.O.W ............ L 2,3 9 .... S.,~_~.l.,.2.5__W_ ~_2..9~_., 06 _~ ..... 8.8 ...... 8 ..... i_..W. --0_,.1.26 ...... 5292. _._I0!00 32...~ 5 ........... 8 952,...86,:,...8.862.,,.86 ...... NB.4,0 OW ............... ~ 57,.79 ...... 5 ............ ~ ~_~B..,.86:....~ .... 5..3~.6..,.~.9 ...... S...~ 88..._.~ 2 ........... 5__~. ..... 1.,295 ................ z o ~ o o ....... ~. ~_.. ~ o..~., ~ o..~..Z.~ ~..Z..~_: s.9 ~.~. ,. ~. 2 ..... :... N 8 ~, o o ~ .......... ~ 6 ~, ~ ? .... s ...... 5 ~ g. 7. o. ~ .... ~ ....... 5 ~. 9. ~.,.~.. ~ .... s_.8 s ..... ~._? ....... ~ s.._. ~....: ...... ~_. z o o ...................... ALL. CALCULATIONS ..................................... ._T_R.U.F_, ............................. _P;EA$. DRIFT__.V_..EP, TiCAL ............ SUB._ . DRIFT ............ TOTAL COORDiNATE. S ............. C L O...S--U-R E. .$ .............. ~EVER-ITY- .................. $£C~TiON __D.ER_~tH.. ANGLE ............ DE P.T H .............. ,SEA D I REC ................... D I STANC,£ ............ AN.Gl. E ........... DEG/;[OOF:T- ............... D I.&TANCE D ....... ................................................... ........ ii212.l.L.i'i ..... 22_2 .................................................................. ~O0 3~.. 0 ...... 9211,52 ...... 9~%7,52 Ngl,OOW ........... i~5,32 S ...... 5500,65 W ..........5502..,57_.-S-.88--29 .... ~.~ ..... W ..... 0.,5~0 .................... ~501,98 11200 ....32 .... 0 ........ 938.B.,i.4 ............ 9.2,,88114 NSI,OOW ............ 127,17 S .. 5603,55 W ....... 550.5,0.1 ..... 5--88 .... 41-.59:-W ....' ...... %.,.1..6~ ................. 560~,67 _.1 ~ 3,00 .... 3 .......... Q..~_9472.95 ... .........................................................11400 ~2 0 9557,75 5 642,.~4 ........ 95~2,44 .................... _11500 .... 32 .... % ......... g ..... N.78,00W ................... 97,25 S ........ 57.5.9.,88 ..... W ........ 5_760_,.70_.5.._.~9 ........ 1 .... 57......W ........... 0,5.88 5760,62 ._.1%60.0 ..... 32...15 .... ?t, 7,Ol .9627,0! N79,OOW .......... 86,52 .S ......5812,17 W ........ 58.i2,~8.1 ..... $ .... 89 ....... 8 .... 4.6..W ......... 0.,534o ................ 5812,7~ ' ' W __1..i.6_2.~3 ...... 3 2__i.5.--9.75~¢., 1 .............. 5 9659 11_71_5 32 ..... i.5. ......... 9.8!5..,.0.2_..: 91!5,.02 ..... N7.9.., O0.W ...................... 6B, 80. S .....5..90.3.,.8.~_W ............... 5.90..4~,2~.....S ..... 89 .... 19.....56._W_ ...... Q,..O.QO .................... 590~, 2~ , . .................. P ' ' E I~iTER.O.L..AZ.gD i.g_Li'~ ...... VERTICAL DgPTH$~...COORD~NATES AND CLOSU.R.E$....FOR_G~IVEN_.DgP.T.H$ '_-.-_CODE .................... ~.~As.u.r~l~.~ ................ _VER T i CAL.. ........................ T'O]'~A'~-._'.._~..iC'oC;"tRD-[-XA.T£S.. C _i..._O__..$_..U....R E .................................. SUB 11066 927~,0z,,, 139~,37 g 553&_,3_7.__.W ........... ~55_36~.i.3 .... S ...... 88 3_3._26___W .....9.1.7.4..,.0./+ ..................... iI17~ 9366,03 129,55 S 5590,09.....W ............ 5..5.9!,.59 ...... S .... 88 .... 4.0 .20_.W .... _9.26.6.,03 .......................... ~1362.. ............... ~52~,5~ i.1!,..~.0. $ ~6.88~00 W ................. ~.6..8 .... ,.1.0 .......... ~ ..... 88 .... ~2 ...... 29 ..... W ...... 94.~..~,.5~ 1..1.4~7..B ......9.6 i 9 .,.p.B .................. 10 . ,.1.2.._~ ....... 5 ~ 4_5_,..~ i_W .....5..?.4.6_~. 6 ~ ..... S_ 89 ....0 ........ 6_.W .9 ~-~.9., .................................... 1..1.%~.D ......................... 9_8 7 p = ,0 ~ ....................... ~8.,.80. ~ .......... 590~.~_8~_W .............. D_~..0..~. ,.. 2.4 .... $ ..... 89 19 ...... ~..~_._.W ........ 9._?...7.~.~..02 -M. EASUR~D DEPTH-AND-OTHER--.-DATA FOR EVERY- EVEN- lOG FF-.ET-OF-'-SUB'-$E:A ..... Dk2~TH, .............................................. TRUE ~Ml E A S i,,.J ~ '[,".~ D ................... VF_.i(T. I CAL ,SUB .... ~, D-.T V D .................. D, E R.T.H ....................... D EP_T H ......... ,S EA._D[ EF.. EP, EN C.E ................ C O R.R E. r2_T_/;..O l~ ....... -T-OT- A L, ..... COOR D .I,N A.T g,$ 20 0 2..00,o ..... 10.0.., .0 ................................ 0 .1,4, 8 ,.5.f,--N 1.z+. .......................... 30.0 ................................... 30.0, .............. 200, ................... 0 .................................. 0 ................................... ].--],7.5 1--. N ................ 1. z,. 95 .... .............................. ~00 .................... ~,00, ......... 300,, .............. 0 ........................... 0 ..................................... :1 ].5,.73 N ..................... 15.77 ...... 500 .5.00.., ........ ~.O0. .................... 0 ........ 0 -- 1-15,...8.2,--N ...... i.7 .,95-.W .................................... 600 ................................. 500, .......... 50.0. .................. 0 .......................................... 0 ........................................ L18...SZ_N .................... ............... 700 .............................. 'tOO., .......... 600_~ ................ 0 ................................ 0 ........................................... 1.2.2..,.08 ,.. N ................. ...... 800 ............................. 800.. ........... 700. .................... 0 ......................................... 0 12.6.,,.01_N ............. ........................... 900 ........................ 9.00.~ ........... 800_. ............ 0 ............................. 0 .......................................... i.32..35 ...N ................ 18.32 100i ............................. I0.00, .......... ._..900. ............ 1 ......................................... 1 .......................................... .1..~.O...B?.N ................. 21,80--W ............ i 102 ....................... i 100.~'__~ 1..00.0., ............... 2 .................................. 1 .-l-Z+.8, ..8.9.-..N ............. 2.9.-.-92,--N 1202 .......................... 1200, ......... 1100, .................... 2 ........................... 0L ............................ 15z+, 9.8 N ..................... 130Z+ 13.00, ....... 1200., ..... ~ 2 ~ r..~. 52....~< ......................... 57,3 5__W _1.."+O...5 ....... 1400., ........ i. 30.0 ..................... ~ .................................... & ................~..5..,7..,,,z~ 8._.N ....... .................. N ..... 92. ........................... 1609 ............................. t 60.0., ......... ~L 500 ~, ............... 9 ................................ 2 ............................................ 1.55 ,.83... N ............ i 13,3.~+ :...:.7 ~ .~ .......................... !7.0.0._~_. ...... ~ .,8.00., ...................... 1 ~ ................................................... 2 ....................1 .... 5 5.,.' 37_ N ........ 1.36 ,, ................................. 15~5 .................................. 1800.,.:_1700o ............~5 ............... :~ ....................................................... 156,31 N ............... 16 i,.,30_...W ............................. 19is ............................... 1900, ........... 1800. ........... 18 .............. ' .............. 3 ...................... f ............... i.57,5i R ............ 189 ~ 5..0_.1_W 2 C)23 ........................ 200. 0_, ......... 1.9.00 · .................. 23 ................................................... 5_ ................ LS. 6.,, .Lk3_ N .................. 2.2 2130 2!00,, ~..000. ~.. 7 150,OO..N ........... 257 ,.Q0 2. 350 2300, 2. 200, 50 1.2 _i2.2., 3.5._N ......... 3~+.4..,_0..E_.~ 2~,65 2500 ~400 85 20 ............................................... i ....... 10~.Ii N .......... 46.~.,2.8 ....... 2. 707 ........................... 26.0.0., ~.,~ 2,.~O 0., ............ ! 0 7 ............................................ 22._, ._1.0.~.,..5.5....~ ........... ...................... 283 ~ ........................................ 2..700., ........... 2600, ............. ~ 5 ~ ........................................... 2_~ ............................... ~.07,77_ N ................. 608 30~ 0 2_9..0.0?___280.0., ............ 1.B.0 .2 ~ 1 i 3.,75_N ........... 2 5. ................................. 332.5 .......................................... 3...1.00..,, ........... 3000. 226 2~ .................................................... 98.7,.7,.... N ..................... 898....91 3450 3200, 3100, ' 25 o 2 ~ ......... ~9., .7~._~ ....... _.9..7.:... ............................ '~ 5 ? ~ ....................................... 3.S 0~.., ......... ~ 2oo, ............... 2 7 ~ ..................................... Z_~_ ..... 8_~..t.o_7_~..~_!0~,.~..,._~J. ~ 6 9? .......................... ~.~_o.o_~ .... 3.3. o o, ........ z 9.~. ............................................. 2..5 ....................................... 7.5.,.2...5......~ .......... ~.1.~?,. LZ 3950 3600~ 3500, 350 Z6 58.18 N 1268.98 .... N.EASuRE~ ~ .. ¢ . ~ ... ........ ,30EPTR'"'AND"'O'~HER ..... DATA' F'OR"EVERY EVENi'._iOO".-_F'EE-Tii'iOF~.,atJB_._,S.,.A .D~PTH, TRUE .................. MEA~UR'ED .............. VERTICAL -'SUB' "~D-T VD .......... V E~,T"[ CAL 432.8 .......................... 39,00. _..~800. 428 ................. ~.~_5..6 ................. ~0.0.0_. ........ 39 C~0. ......... ~ 56 ........................... 2_8 __~7 · 5 a ...N ........... ~.57.6.~1~ ~.. ,/ ..... ........................... 48z~Z +:00, .4200. 5a2 ............................... ................... ~03 ............................. ~O0~ ~00. &05 ............. aZ .................................................. ~.~. ~ ....... 1~8~ ~97,_ W ............................... : . ...................... . ~.~.~ ...... ~. 60 0.~ ......... ~ ~ 00 ~ .......... G ~ ,~ 53~7 ~700, ~600. 66~ .................. 3~ .................................................... ~6.8~ $ ........2156 .5.1._.~ ............................................................. 5533 ......... -- ..... Ag.O 0., ...... ~.8_0.0., ............ 733 ............................... 33. _6~.. 3.,5._.8 ........ 2.33..0 ,_9..~ ............ ........................... ~76? ..................................... 50.00, ........... ~.900~ ........ ?6? ...................................... 5900 ........................ 5100, ........ 5000. ..b.0.3.2 ....... ;2.,0.0 ..... ;.t00 .......... 832 61&2 .......................... 530.0., ......... 5200. ...... 802 629i ...................................... 5~0.0, ........... 5300.. .6~18 5500, 5400, ........ ~8. 65~] 5600,, ...... 5500. 5666 ................................ 5700, ...... :5600. 956 ......................... 23 ........................................ :1.40.99 $ ...... 2979..._.04 ...... W 6792 . ~ _ ~ ...... 5,.800., ...... 57.00, ..... 992 2_6,_. I~6., 58'....S ........... ~0.5_4.,.,.,.~.~ ..... W. ' ....... ................... ......................................... s 7049 ............................. 6000, ......... 5900. 10~9 ..................... 29 ................................................ 155.97 S 3215 ,.~_9 7.~.76 ....... &100, ~000, ~076 ................................ 2.2 ~8 9 ..... S .............. ......................... 7302 .................................. 6200~ .......... 6.~00 ~ 1io2 2.6 ............................................ ~61~15 S 3 ~ 7~.,O._7_ W ....................... 7z~27.~ ...................... G~00, ......... 6200. ~127 ................ 25 ....................................................... 162~59 S .. 75., ~ ~ ....................... 6.4 00.~ ........... 6300 · ....~ 153 ................ .......... _.__ ........ 2.6 ..... , ...... ~.6~., 8.7....3 ............. ~ ~ ~ Z~_~..9_~ 7679 ..................................... 65.0.0 ~ ............ 6~00, 1179 .................................... 26 .............................................................. ~87.51 S ...... 3598.4.7 ' 7 ~,30~ ................................. ~6 00.~ ....... 65.00~ ..... 120z, ................................... 2.5 ............ L ......................................... Z70.~ 5 ..........36.7~ 7 g ~ 0 ............................ 6700.., ........... 6600 ~ .......... 12 ~ 0 ....................................... 26: ..................................... 1.72,50 ....S ........ 37.50 8057 6800, 6700,.. 1257 27 ................................................. i 73.25...... & 3828,.79 · ~ ~ ~ ~ ................................ ?.0,0.,0,~_..6900. ........ ~.~ ~ ~ 28 ,17 ~ ~ ~ 6, ~ ........ ~ ~ ~.~. ;./.EASURED-.DgP.TH.,..ANS--Q;'rHigR DATA FOR EVERY-EVEN-.-~.00 ...... FEE.T.--OF-.-$UB~-.-.$F2A-DEPTH, ................................................... TR U E ;~u~u. ................. V. gRT~ CAL c. UF~ ~,~D-TVD. VER..T.~ CAL , 856.6 7_Z0_O.---7..1-00...--1.35.6--~ .................2 5 ,L~.0.. 5 ~ ~ I 869.0 ....................... 7.3.00, ....... 7200. ........ 13~0 ...................... 24 .......................................... I-~0.52-.5 ......... ~216,98 ............. 8.933_ ~?. 500.. .... 7400.. ...... 14. 33 .......................... Z1 1.7.1-...1.~..-~ ......... ~ 35 .......................... 905 2 ............................ 7600 · ........ 7500, ......... ~452 ........................................... ~ g .......................... L~.~...1.g.-.S ........... 4418 ..................... 9171 ........................... 7_7.00, ....... 7600 · ...... 1.~71 19 ........................................... ~ 7.8,.~ 9...- 5 ......... ~484 · ~-4.-W ~ 2.93 ....... _7..8.0,0.., ......... 7.7.00 · .... 1 a9 3 ............................ 22 1.83-,.25--5 ........... ~ 552. _9.z~.l ~ ........................ .79.0 0, ........ 78.00, ......... 15lz~ 2i ............................. i..86_, 82 5 ....... ~62.1,98 95 3't_ ......................... 80_00, ......... 7_9.00, ........ 1537 ................................. 23 .............................. 1. 8.9...,.1.3.._ 5 ........... 4693 ........ 9.5.6.~ .......... 8 L.0.0... ......... 80.00~, ~.55 ~ ................ 2..A ............. .............. L.9..0..._A. O_..5 ..... ~.7.65 ......................... 990.8::_8..3_0.0_, ......... 8200, .......... 160 ~ ...................................... 2 z,. ~..8.~_,..9 7 ..... S ............ 4910.,..~.3 .00.3,0._ ~ ....... 8A.0,.0..,~..8300., ..... i 630 ............................... Z2 . t..8..~ ,..ZS._$ ........ LO151 .................................... 8.5.00., .......... S.~O0,_~ ..... 1651 .............................. ~1 ........................................ 1_8.5,..3~ ..... 5 .......... I062~6 ................ 8900, ...8800,. 1726 ............................................ i8. ..~..~.1..,.20__~ ............ 1..0.7..~_~ ......... 9.0.0~0 ,___890.0. .....1.7/~./+ ................................... i_5 .......................... L6.~.,..9.2__5 ...... 5.36 10R62 9100, 9000, 1762 ............. i.8 ...................... 156. 0 S ............. 5~29,.56__W 1..I.0.9.~._L .............. 9.3.0.0., ...... _9_2_0:0., .... i79,6 ........................... 1_.7 1.12 i.z+ ............................... 9 ~ 00.. ......... 9300 · ....... 1814 ............................................. 1..8 ._ .... I..2~5_,.~.8,9_ S ........... 561.0 TRUE DEPTH DEPTH SEA TOTAL COORDINATES ..... 3000 2835, .................. 400.~ ..................... 3.6_4.0_, ......... ~.5 ~+0 · ............................ 54 · ? i ._ N ......... 1299.,~ 3~__W .......................... .7000 ................................... ~6:, .......... ~86:, .......... :~,6~ ............... S 3:.8~.,2.:~ .... W ......................... ' .... ...... 7~: ~ .......................~ ~0 000_ .................................. ~.~_~. ~ ............. ........................... ~:000 ................ , ..... .9.2.$.7, .............. 9.:.~7, ............... ~.45.,.:Z .... S ........... _5.~_0.0.,.~' ATLANTIC- RICHFIELD' COMPANY SCALE--.~" = I000' F~- ...... . ............. · ................... : ..... ' ~ ~ TVD~.. _ 9875 ._: ................ ~--'; ........................... .............. ATLANTIC . .,HFIELD COMPANY .................. SCALE I"= IOO0' .......... : ................. ................................ .TANGENTIAL AVERAGE ANGLE - 800 .......................... ; ............ , ........................ GYROSCOPIC SURVEY. .................. ...........~6°l ................... . -~ ............................... ?: .................... ~ .............~ .......... : .... ~ ........ fl-7 ........ ~ .............................. .................... 2000- 2801:) .......................... } ............... 3600 .... - ............................................................... 40~ ALL-DEPTHS SHOWN ........ 4800 ' -~ ............. ........................... : ...... 5200 ~ 5600 ........................ : - ....................................... ~ -~ .......... ~ 6400 ..................... ~ .......... - .... '~ ............... ~ .............. : ........... ~ ............ :-':-7 ....... ....................................... : ...................................... .................... : ....... -? .............: ......... : .... ~ ........... : ............. 7 ....... ..... 7-- ............... ~, .................. : ............................. -T::~:: Y.':. '-:.':_ _~"'. -' :',':' :.: :~-L: ~ :'-..: .... :' ::7 '- :-:_...:.:{: ': :--7:- astman Whipstock A PETROLANE COMPANY REPORT of SUB-SURFACE ATLANTIC RICHFIELD COMPANY K-12-RD WELL NAME __ K~,M,ON P'_.-i LOCATI ON JOB NUMBER A]078 G0041 TYPE OF SURVEY GYROSCOPIC .(Tangentia 1) SURVEY BY Jeremy Beattie OFFICE Alaska DATE 10-23-78 .... ~Y. RO.SCOP..lC .S.U~.~.EY DECL.I.NAT I ON...2-~ . DE. GRE.ES.. EAST ~~GENT I.AL... ~E.~HOD___OF. ~ CO~PUTAT ION KB....ELE-~ I.O.0- . ..... ..... A~. CALCULAT.I. .No PERFOR~.ED BY I B_. M__ELECTRO.NI.C COMPUTER ........... T~ DOG LEG ................ ._~.~H.. A.NG.L.E DE_PT.H ........SEA D I REC DI STANCE ANGLE DE.G/10OFT _ . DiS~AN~ ...................................... D .... M DEG, :. D M S ........ ....... ~:0_O ........ _6_ ~..~ ................ B.~_~..,..S.9_ 7~,.~:9 .... N..g,0_0W ....... l~..~_~.8...g ............ 1.7..,..7~_..~ ......... ~..~7.,5~ N 7 ~ ~ 1..,9~9 16,.20. ....... I;~.O~0.._._;~6.......~_~ ........ 1~.~..:~.2.~ .......... ~_78.0.~..2.~ .... N.8.7..~.~O~ ........ I_~..7:~.~0._...~ _~.~.~.,.~.~....~ ..... 252,20 .N 5.1 . RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B ~ EL.ECTRONIC COMPUTER ................. TRUE ...... NEAS, DRIFT VERTICAL .... DEPTH .ANGLE DEPTH ......... D M SUB DR I FT SEA DIREC DEG, TOTAL. COORDINATES _[ 3..00..26 ..... 1.5 22..50,§9 21.50,59 S70,OOW 121,39 N 341.,19 W ,..~DO ~9.~5 2.3~.7,~I 2237~41 S72,00W . 106~0.6 ~N~ 388.~8. W 2600_35 0 2.503,.43 2403.43 N.SB,OOW 103,35 N ................ 2800.36 ..AS .... 2 66 ~ :,..71. 256~,71 N87,00~ ...107~.~0. N ............. 29.00. }6 ~5 27.~,8~ 26~.~.,8~ N85,00~ 112,?1 N 3QQ0.....3.6 .... 0 ~ 2.825.m74 2725,7~ N88,0QW .1.1~,.76 .~ 617,7.6 W 67?,,36. W 79~,74 W 852 ,,38 W CLOSURES D1STANCE ANGLE D M S 362,1.4 N 70 24 49 W 402,,60 N 7~ 4~ ~0 W ~53,73 N 77 5 35 W ~I0,17 N 78 18 ~ w 56~,69 N 79 .Z~ 20 W 627,0~ N 80 7 ~1 ~ 686,68 N 80 ~3 7 W 7~5,00 N 81 8 17 W 802,~I N 82 ~ 20 W 858,65 N 83 ~ l~ w 9'15,8i N 83 57 21 W 973-37 N 8~ ~0 ~0 W .......... 36Qfl..31 0 ..3.~10,3.6 3210,36 58.~.,.00.~ 77,Bi N 1087.,8~ .~ 1O~O.,61 N 85 5~ 30 W ........ 31'Q0__36._._~5~ 3~9.0.~.~9.. 3.2~0.,~9. SS~,.OOW 71.,5~ N.. 11~7,3~.W 11~9,57 N 86 25 51 W ......... ~.8_O:O..3_7 .... O 3~7.0.,3.5 3370.,35 5.83.,00W 6~,..22. N 12.07,07.W 1208,78 N 86 57 15 W 87.~9 ......... '.-~.1.0.0r-..37. A5 3.?08-'35 .....3608'35 $8;2..'OOW ...~.1..'95 N 1388'32--~ 138.8'95 N..88 16 8 W : .............. ,~3_0_Q...._3.8 ..O 3.86~,Q2 ......3.767~.D2 5.8.2..~00~ 2.5-'QD N 15Q8,.88_~ ISQg,Q9 N 89 3 I W ............ AAO.Q38 15 39~.5~55. 38.~5,5'5 S83,00W 17,~6 .N 1570~33 W [570~2 N 89 21 ~6 W ............. A~QO....39. ..... 0 ~.0.~.,.2:~ ..... ~92...3..,..27 ~83.,.O0.~. 9,.79~ N ..... 1.63.2..,7.9 W ....... 16.3.2.,82 N 89 39 22 W ........... ~_0.0.~8 45 ~1Q1..~.2~. .... 4001,25 $83~00W 2. e.!6 N 1.69~,.~2 W 1.6~4,92 N 89 55 36 W ...... :..._~.!O0._.~.~ 0 .~178.,9~. 4078~.97 E62..,0.ON 6,59.5 1757,.2~ W i757,2.5 ~ 89 47 6 W .......... ~.9.~0.. 3~....~0 ........ .~.~.3..~..29. 42.33~_29. $8.3.~.0.OW. 2.2,O9.S 1.88.3.,..5~ W 18.83,63 $ 89 19 40 W ........ ~.~:~...Q9 fi. 9...3Q...~.~.8.5.~..~66 ....... ~385~_66 ~85,~:Q~ 2.012,75 5 89 i 3 W DOG LEG SEVERITY DEG/iOOFT SECTION DISTANCE 3,623 7,365 4,501 0,947 1 · 5.49 1,197 1,93.1 3.,.526 1,823 0,500 0 · ~ 88 0,2.50 O~750 0 · 250 0,650 339.. 7.4 387 ~...]~1 498,35 556,?5. 6 ? 6, 73~-., :72. 851., ~9DR,_53 968 1086..,85 .11~6,.A3 12.0.~ · O, 9.65 -? .... 1.3.27. _0,612 ~ 13.87,73 0.750 ...... 1,,.OOO .iSg 8_,.~_8 O, 666 15.Tg,.O2 0 ,, 750 0 · 2:50 16.94_,_ 77 O, 8 06 ..... 1820,,,~1. 0,,0'00 .... 1.883 ,.63 0,,987 .. 19.A7,9,6 0,69~ ..... 2012 ,, 7:2~ ......... RECORD OF 5UR. VEY ALL CALCULATIONS. PERFORt,~ED BY I B M ELECTRONIC CONPUTER ............................ TRUE D,RIF.T VERTICAL SUB DRIFT TOTAL COORDINATES C L 0 $ U R E S .ANGLE DEPTH SE.A D I REC D I $,TA.NC[ ANGLE D H DEG. D M .4.0.22 S 2077.81.~ 207.8.20 $ 88 53 27 W ½5,.,9A..S 2,1A3,,17,.,~ 21A3-66.S 88 ,~6 18. W 5.~0.0..~.1. 0 .... A~l.2,,.O] ...... ~12,07 .$8~,O.OW .. B2.,80._._S .22.08,~2 W 220.9,05 $ 88 37 49 W DOG,EE~G SEVERZTY DEG/[OOFT 0.500 3 ;5... W 1.182 ......... 3.1.5-3.08. 30 ~ 0.9.65 3_5_20..6.3.. ..31 W .... 0.25_0 ................. 3].00..7]. ........ · , ~,. ~ .... ~,,__ AL.t. CALCULATIONS PERFORMED BY I g.H EL£CT. RONIC COHPUIE.R __~!EAS..DR.ZFT VERTZCAL SUB DRIFT .TOTAL.cOORDINATES C L O S U R E S DEPTH ANGLE DEPTH SEA DIREC DI STANCE ANGLE ......... O M .. DEG, D M .i'.r: {OP O-'O0.w w s ....... :..~ZQO.~9 15 69.0Q~.2.1 .... 6~O0.,,.Z~ N89,00 1.7_2...,7 5. .. ~ 3~7,.2.8 W. 395.1,0~ S 87 29 ~8 ............. 8300..~B ~5 6978,19 687B,.~9 N89,00~ ~7~.~66 S ~009,87 ~ ~0~.,5~ S 87 ~2 55 ............. B:~g.~ ....... ~_8..15 7.056,.7~ 6956_.7.~' N89...OOW .17.0~_58 .S ~_071_.77 W ~07~,~ S B7 36 ........... 8600. ~..6 3_0 ..... 7.21_6.,_71 7116.~.71 N89,00~ 170.~.60 S 4.191,76 W. ~195,23 $ 87 ~0 ........ 81Q0._3.~ ........ 0 ..... 72_~.8_,.63 7.198...6~ $8.9,00W 171,60..S ~24.9.,..~ ...... W 4252.57 5 87 41 14 ........... 8900.3.~. .... 0 ..... 1~.6~ ,16 ...... 736~, 16 ..... $89.,0.Q~ ........... 1.7Z...9~....~ ......... ~61~.27 ~ ~36~ .6.~ S 87 ~ 50 - .92.QQ__.3_~_....39 ......... ~!1.~,..5~ .......... 7_61~.,.5.~ &~6 · O'.O~ ........... 18_2.:~1.2 .S ........ ~..52.~..,.I~...~. ...... ~..~9..79 ~ 87 ~ 1 ~ ........ 9600 3.6 ...... O. B.O.~D,.9~ 79.~.0,9.~ .SBg~.OOW t.91~1~..~ ..... ~75.7,I1 w ~.760,95 $ B7 ~.I 56 _:.__~gOO...35..~_0 ....... 82~.~..~.~ ........... B.~B..~...~,..l~ ....... ~iB9 · QOW .....~88 ~OB_..,~ ...... ~.9~2..,~0 ...w ~9.~.6.,28 $ 87 ~8 5 ........... lQ600 ~1..3~ ........ 8,.~'7.~.,15 .......... R77Q,.15 N86.~.OQ~. .......... 17.1.~11......S ...... 531~.,.8~.......~ 5317.,63 ~ 88 9 2 ..... !09.00..3! .30.. 9~.2~..~..~..~ .... ~0~4,~.~. ~.81,O:OW ~88 ~ 5 72_~76 W 5..~.7.~8.! S 88:25 52 ...... ,~ ............... - ........ ........ .... .... . .~. ..... , . .,. . ......... ...... ........ DOG LEG- SEVERITY DEG/[OOFT 0,25Q 1.180 0,500 &~.II.ON. DISTANCE 3~8 5,7_9. ~011._60. 1 * 1 .~:~. 5102.-92. O: ,, 60.1 515:7.27. 0.,5'45 .SZll_., 5 5. 1 ..I.~.~ _5.264 ,~.3. 0-726 . 5-R1,6~51 1~295 ....... 53.69'51 1,10.0 . 5~.22.,. ~.~ ,. RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY ! B M ELECTRONIC COMPU.TER ........... TRUE ...... HEA$,. DRIFT VERTICAL SUB DR IFT _.DEPTH ANGLE DEPTH SEA DIREC _.. D H DEG,. t~ 300 .31 0 9210,g4.. 911,0,04, -,,:~.,,.1QO,. 3I,,30 929:5,3 1 .9195 ~,31 NTg,OOW -- 11..2.00.. 32. 0 938:0.1.1 9280.11 NSI.OOW ......... 11300. 32, 0 g46~..92 9.3&Z~.92 N79.,OOW- ..... 115,00 ...3~. 15 ~6~, 2.g 953~,29 N?8,00W .... 11600 .32 15 ..... 9718,.87 .... BGJ,BJ. 87 NTg, OOW TOTAL COORDINATES 1Z~-57 $ ~627.2& 113,.~5 $ 56 79 · 27. 103..,3~ $,, 5731,29. CLOSURES DISTANCE ANGLE D .M S 5576,4.8 & 88 38 ~2 W 5628,61 S 88 44 ~1 W 5680,41 ,$ 88 51 19 ~ 92,.2,5 82,07., 5 5835,87 78,,20 $ ....... BQ~T..Q~...HQLE..C.LO,SUR~ 5927,88 FEET AT .$ 8~ 22. ~.~ .................... , ...: ................... .... . ... ..... ..,...., . ........ : .......... DOG t..EG 5EVER l TY SEC T tON DEG/ZOOF'T DISTANCE 0.- 5 O0 5.52~-4.. 9-1 1, t 5-2 - 1 · 165 5628,32 1,060 5.68.0 -21- {3,0QO 0 ,. 5.8:8 5-784., 1 0,5 34 583-.6.. ~3.- O: ,0 O0 0 · 000 5-927,88 ................ INTERPOLAT.ED....T~UE VERT[..CAL DEPTHS, COOl, DJ.NATES AND CLOSURE.5. FOR GIVEN DEPTH,~ ...... Tf~UE . ...... ~QDE ... VER. TICA[ TOTA.~ C.O~RDINATE.$ C C 0 S U R E SUB ...... ...... SAM..E .... D.[PTH_ DE_PTH D..ISTAN~E. ANGLE 5.~A D M 5 .................................................. ~3.[ ........................... ~.~3.&.,~. [.3~B,..7.3.. S ..... 55.3.~5~....~ ........... 65~[~.26 .... S.. 88 33 $.5. ~ 9.~.3.6,~.7 11.066 9.2.66,32 135_,2~_ S. 55.5.7,..~8 W. ~5..[9.,I. 2 S 8_8 36 .21 ~ 9166,32 .... ........................ 1117~ .... 93.58_,06 125,.~2.._ 5_ ..~6..1..3.,.~..~ 5615,06 5. a8 ~3 1. W 9258,0.6 ............ _~ 11362 ................... .~.5.17..~0 ...... 1..0.7,..Z8...6 ....... 5..71.1_~._5_3____~ 57 I2.,.~ 3 5 88 55. Z9 .W ~.~ 17,.~0 ..... ~ [.1.~..7~. .......~.6..lo[.~.~6 9.~.~_.2.~.. 5. .57~6~..~.~0.....~ ....... 57.~.0.~18 $ 89. 3 .15. W 9.~1.1.~6 ............................. 1.1.6~.1 .... 97.5~.,5a ..77_~87..6 58.57,.~.5..W .5857.~86 5 89. 1.~ 17 W 965.3.,..5.~ ............. ....... !.D_ ............................... 1..I.7~.5 9866,.8.7 6~.25 $ 5_927,.5~ ~ ~9.2.7,8.8 5 89 22 ~4 W 976:6,8.7 ....................... ......... ................................................................................................... . · _ ........ F~EASURED DED-TH AND.OTHER DATA -FOR--EVE.RY..EVEN-tOO FEET-OF SUB SEA DEPTH, MEASURED V.ER.T.ICAL SUB HD-TVD ................. DEPTH DE.PTH SEA, DIFFERENCE 3 O0 · O ~.O.O, 0 500., 0 600- O 9.g 1 9 1203 ...... 1200 . V.ERT I.CAL CQRREC ,T ION .T OT.AL COQRD I NATES 0 0 0 0 0 1 0 1 1].6.47 1.17,32 123.8.6. 128.65 136,~ 1~2,02 156.,65 157,12 1:5.0.8. ........................ I500,. ........ 14D.O, .......8 .....................2 .................. 155..46 1.610 16.0.0, l~.0O, I0. 2 _15~,45 111~ ..................... I.? OD, I:6.DO · .I3 ~ 15~. ,9 8. 18...16. .............. 1.8.0Q., I.?.00,.~ 16 ....................3 .......................... 1.~21 .......... X~.Q:Q., ......... I8.90, 21 5 22.~.6 22.00~. ..... 2100, 44 1:0 129,93 17 102,55 2.5.8.,6 ............................ 2.~QO..~. ......... 2.~ D0, 9:6 .... 2.2 .... 1.03. ,. 26 15-27 15.20. 1.7. IA 34.05 ~$,.70 6~.7~ 101,08 12},~2 1~6.80 23 .............. 10~97 N ..... .2.~ IQ9~.79 N ...... 2~ Ili,O.ON 23 ........ 9~, 0~7 ~ 2.87 . 25. 78,63 N 1080eO6.W 312 2,5 7.0,6.8 N 1154,~5 W ~3 . .... 2.6 ........ 5~.,23 N !305,18 w 368,04 W ~9~e~.9 ~ 5.69~.5.0. W 6~4,01W 717,41W 78~,93 W 933,15 w ........ N._E..ASU.~ED_DEP. TH AND OTHER DA. TA FOR EVE. Y .EV:.N 100 .FEET OF :SUB SEA DEPTH. TRUE VERTICAL SUB ~D-TVD. DEPTH .SEA DIFFERE,~C£ ~.08.9 3?00, 3600, 389 4.2!.5 3800. 3700, 415 ............. 4.342. . 3900, 3800, 4100. 4000, . 498 4200,. 41.00, 527 .4300, 4200, 557 44 O0, 4 ~ O0, 587 ~5.00, 4400, 619 4?0:0, 4600. 684 4800 ,, 4 ~.OO., 717 5?85 ............................ 591 ? 517.7. 655.5 5.100., 5000 , 81 ? 52.00.,.~ 5 lO0.,. 8~.8 5300. 5:~DQ.~ 5t00, 905 560Q, .... 5 5.QO., 955 5700,... 5600, 979 ..5.8..~t ........ 5.700., ..... 10D:6 VERT I. CAL . CORRECTION TOTAL COORDINATES 2.6 ,42.85 N 1.381,91 26 3_2.29 N 1457.02 27 21,84 N 1534,68 28 12.09 N 1614,09 28 2,28 N 169~,91 29 8,70 S i77~,44 3.Q 1~,75. 30 27.99 S 32 3~.59 $ 2024.87 32 ~3,17 .S 211.1,47 .3~ 60,08 .~ 2284,88 3~ 8.2,6t $ 2.461,65 .3.2.. 9~,67 $ Z~?.iS 31 .1.04,87 12~,28 .2B 158., 2~ .S 3253,09 25 16..~,39 ..... 2.6 .......... 16~_,.8.2 25 169,43 $ 3633~82 25 ....... i 7'2,07.. $ .......... 6935 ........... 59110;, ..... 580;:0, .......... 1035 .......... 2 ........... 70.63 ............... 6:0.00., ........ 5900, ........................ 71.90 6 iOO.., 6000., 1090 ....................... 7315 ....... 62_0G.J ..... 6. l..0:O ·1115 ............................ ?i~.l .......... 6tDO, 6200., 1..1~ 1 ................... ;~071 .680.0~ .....6.700~ .i27.i ..................... ~.20'0 6900 ~. ...... 68.0.~ · 13.00 29. ............... 8454._ 7.100.~. ......... 7.0:00., ...... 13_.~ .17gj75 $ 171.,~15 $ 3787,55 3866,07 39~7,i1 4027,05 DEPTH AND OTHER .DA_IA FOR EVERY ~VEN 100. -F.EEI .OF $U0 SEA DE.PTHm TRUE MEASURED .... VERTICAL SUB MD· -T DV . VERTI_¢AL DEPTH' Dc TH SEA DIFFERENCE . ORRE~.TION TOTAL ¢OORDINATE$ .................... 8702 7300, 7200, .1~+02 23 ............. 882.3 7 ~.OO. 73 O0.. I ~.23 2 ..... 8g~.3 7 500., 7~_00..... 1 ~.~.3 20 ....................... 906.2 7.600+. 7500, 1.~62 ._~' _ ...... 8X82 7700 · 76_OD., 1.~ 82 .........................~ ~.~O~ 780.0, 7700., 1506 22 .................. 9626 79 OO..~ 7800..~ 1526 .................. 95~9 8.0~0.+.~ 790.0.. 15~.9 .................................... 9...9.1._.9. .......... 8.~.Q..~ 8.~..0'0, 16).9 ...... ?,,2. 170,81 S 417g.,$9 1.71,58 S 4250,08 170,81 S 4319,61 17.Z..75 S . ~3.8~.29 17.6,72, $ 4~8 ,.81 181,..~3 S ~.51.6. i 5 1.8.6., X 5 S 458~,76 188,6.1 S 465.5.X5 190,62 .S ~727 .B.8 1...6:61 2..0 1681 .,~.O 1_71.~ %8 ....... ! 7.8.8 17 TED .V...~_LU_[5._.F.QR__._g.V_..E.~.. 1OO. Q FE'ET.._QF..ME.A,SURED DEP..TH- .............. .................... ME A~_u._B E~ ............. V.E.R~.T.!, C.~L SuB ................ DEPTH .DEPTH SEA TOTAL .....CO0 R.P [.N AT.E._S_ ..... .................................. 1..0.0_00_ .............. 8~_,6..6.., ..... 8266 .............................. 1 l. O0.O ...... ~.21.0 · ....9110 HORIZONTAL_ VIEW ATLANTIC RICHFIELD COMPANY GYROSCOPIC SURVEY ...... ~ - ..................................... .............................. i"--%..,]"...L] ........ iL,iii ..... ],~./_; ...... ] .... VERT ICA>"',SECTION_]~] ................. ATLANTIC ,CHFIELD COMPANY SCALE i"= IOOO' - ........ ' .... TANGENTIAL ...... 8o0 ........................... ;. ......... ~ ................. ~ ................ -. ~ GYROSCOPIC SURVEY~ _ 3200 .................... ': ...................... r .................. : .................... ~ ........................... ............................ ~ :~ ~ ALL DEPTHS SHOWN ....... -~ ~' ]'~];-'-~'~'"'"~' -']"~'-~--~][L~ '-"''~ ARE' TVD .... ; ........ . 1 ............. - ................. ~ .........................s ...................................................................................................... ~ ................................... ' ....................... T~D= ..................................... ~ .............. : .............. ~ .........- ................ ~ ..... ........ ~ ....... - ..................... ~. ........... ~ ................ . .................. l~tm No, P--.4 1t,~/. ~- I-?0 STATE 0l':' ALASKA OIL AND OAS CONSERVATION COMMITTEE SgBMIT IN DUPLICA~ MONTHLY REPORT OF DRILLING AND WOR'KOVER OPERATIONS WKLL WILL NAME OF OP~?,ATOR Union Oil .Com. pany of California 909 West 9th. Avenue, Anchora.qe~ Alaska 99501 4. LOCATION O1~ W Surface: 735'N & 140'W from SE Cr Sec 17, TBN, R13W, SM ~-A~I NUMEmCAL CODE ' 50-133-20156-01 LEASE DESIGI~tATION AND S~I~L' NO. ADL 18777 .. I~ J~DIA~. A~'~ TEE OE 8. L~.'IT FAR~ OR LEASE NA~.~.E .... Tr~dina Bay Unit ~ WELL N'C~ K-12 RD (44-18) 10 F~ ~D P~L, OH WIlDCaT " , .... ,, McArthur River Fie]-d:~'":~"~ ~-~-~v~ ' ~. -. Sec 19, TgN-R13N, S~ 12. PERiVlIT NO 78-57 13. REPORT TOTAL DI~TH AT END OF MONTH, CHA~qGES IN HOLE SIZE, CASING AND C~([EN~'I~/NG JOBS INCLUDING DEPTH SET AN~ VOLUMES USED. PERFOHATIONS, TESTS AND HESULTS FISHING JO]~ JL~'~K IN HOI.~ AND SIDE-Tt~CKED HOLE A.N'D ANY OTHER SIGNIFICANT CI4_.A~G~ IN HOLE CONDITIONS POOH to chng bit. RIH broke circulation @ 5000'. Washed 90' to bottom w/8' fill. Drilled 12-1/4" hole to 8485' POOH. Test BOPE. Chng rubbers in pipe rams. Drilled to 9465'. Test ~OPE. RIH. Ream through bridge @ 6425' lost 1500 psi pump pressure. POOH. Reaming. Left fish in hole. Top of fish @ 9336'. PU fishing tools, engage & POOH w/fish. Drill to 10,924'. POOH & stuck pipe in keyseat. Circ & work pipe. Freed pipe & POOH. Test BOPE, Kelly valves, & choke manifold - OK. RIH w/reaming assy. Reamed. DP backed off @ 1363' Tagged TOF @ 8978' Circ, POOH, & pulled tight w/ bit. Reamed up & ~wisted off RIH & tJgged fish #2 @ 7519'. RIH with 17-1/2" hole opener & opened hole to 3510'. POOH & PU fishing tools. Tagged but could not get over fish. RIH, dressed off & engaged fish. POOH & rec 1450' of fish leaving 12-1/4" bit & stabilizer in hole. Reran fish assy & rec same. RIH w/OS #3. TOF @ 9064' Engaged fish & POOH. Rec 37 jts. DP RIH reamed tight spots to top of ~ish @ 10,220'. Continued fishing as of 9/30/78. , s~=~l/~ ~_~ ~. ~_//----//~_.._-. :~ DIST. DRILLING. SUPT.__ ~. 10/20/78 ~OTE --Report on this form ts required for .~ colendor ~nfh~ regardless of the atofus of operotiofl$, and must ~ flied lp duplicofe wit/) the oil and gQS ~onservation commiflee by the 15~ of the su~din~ ~n~. ~le~ otherwis~ directed. ~m ~:-~,~ STATE O, ALASKA S~SMrr 11¢ DUPLICAT~I ~. B- 1-70 OIL AND GAS cONSERVATION CO~I~EE · 50-1 33-~01 56-01 , , ~ , , ,. ,, ,, L .... L~SE DES~'G~A~ON MONTHLY REPORT OF DRILLING ~N~ WORKOV~ O~ATiO~ ~DL 18777 ~_ OIL ~ GA" ~ 0TH'. 8. ~IT F~ O~ LEASE Un,on 0~1 Company of California T~ad~n9 Bay 909 Nest 9th Avenue, Anghorggg, Alaska 99501 K-12RD (44-18) Surface' 735'N'& ]40'N f~om SE c~ Sec 17, T9N-R]3~, SM ~cA~thu~, ~ve~ o~ , FILE': --~ Sec 19, TgN-R13H, SH ................... 78-57 13. REPORT TOTAL DEPTH AT END OF MONTH, CHAI~GF_,S IN HOLE SIZE, CASING AND CL-MENTING JOBS INCLUDING DEPTH SET AND VOLUM~ USED, PERFOP~TIONS, TESTS ANT) RESULTS FISHING JOBS JI~K IN HOLE AND SIDE-TP,.ACKED HOLE A34D A/~Y OTHER SIGNIFICANT CHANGES IN HOLI~ CONDITIONS Report of Operations for the Month of August 1978' Skidded rig over K-12, killed well with 8.8 ppg brine, NU and test BOPE. Circulate well and pulled packer loose. POH and laid down 4-1/2" completion assembly. Made round trip w/bit and scraper. Ran .Gyro survey to 10,681'. RIH and set retainer @ 10,560'. Tested lines and squeezed perf's beloW retainer w/260 sx cmt. PU and left 40 sx cmt on top of retainer. PU 5 stands and reversed out. POH. PU 9-5/8" spear, pulled spacer spool. Ran GR/CCL. Set retainer @ 2680'. Ran 9-5/8" cutter on DP and cut casing @ 2586'. Circulate 9-5/8" csg & POH. Changed to 9-5/8" rams. Pulled and laid down 9-5/8" csg from 2586'. RIH w/2-3/8" tubing tail on DP to 2674'. Circulate bottoms up and pumped 350 sx cmt w/lO% sand~ Reversed Out @ 2210'. CIP @ 3'27 AM 8/1.8/78. RIH w/12-1/4" bit and dressed off hard cmt to 2518'. Directionally drilling 12-1/2" hole @ 7783' on 8/31/78. RECEIVED hereby certify that the tor~'~otng is true and correct - ' s,~'""'~.....,.~.__~'~___~~.,,,-,~ ,'n'n.m DIST. DRill ]'N~ -qllPT.._ D,~ : cl/1R/?,R ~ '~ - ' N I ~ I II I Il I __1_,~!1 ii ' ' ~TE~R~port on this form is required}or each calendar month% regardless of the status of operotlens, and must be tiled 'in duplicate with th · oil and gas conservation committee bythe 15th of the succeeding month, unles~ otherwise directed. Form 10-403 Submit "1 ntentions" in Triplicate REV. 1-10-73 ~ & "Subsequent RepOrts" in Duplicate STATE Or ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) ]' oil i~1 GAS [--] WELLIAI WELL OTHER 2. NAME OF OPERATOR Union 0il Company of Cali£ornia 3. ADDRESS OF OPERATOR - 909 W. 9th Avenue, Anchorage, ,Alaska 99501 4. LOCATION OF WELL At surface 735' N & 140' W, SE Ct, Sec 17 T9N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 100' I~B 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. K-12 (44-18) /~ ~p~ 10. FIELD AND POOL, OR WILDCAT McArthur River- Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 19, T9N, S.M. 12. PERMIT NO. 14. Check Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ F RACTU R E TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTI PLE COMPLETE ABANDON* CHANGE PLANS }orr, or Other Data SUBSEQUENT REPORT OF.' WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING, CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE; Report results of multiple completion on Well Completion or Recompletion Report and Log form,) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and 9ive pertinent dates, including estimated date of starting any proposed work. We propose to plug and abandon the present well-bore as fol.lows: . Procedure: ~. Move rig over Leg #4, Conductor #29 and rig up. 2. Kill well and NU BOPE.. 3. POOH w/completion assy. ' 4. Plug and abandon Old Hemlock producing zone by setting ' and squeeze cementing perforations from 10625' to 11110' 5. Cut and pul~ 9-5/8" casing @ 2600'.- 6. Lay kick-off plug. We propose to re-drill this well as per our prior Permit Application (a copy of which is attached). *~ Atlantic Richfield Company is Sub-operator. 16. I hereDgrtify that the fore, l~ing is true and correct ,.,,,Jl,o,L.o,,,c.u., _v __ Dist. Drl§. Supt. DATE, 7/13/78 Petroleum Engineer See InstrUctions On Reverse Side DATE 7/13/78 Approved Copy ' Return. ed .- 7/13/78 P. o. B~ 6247 'D~0~msnt of ~ ~ R.T.~ T. B. Unit K-Im~ 2- JUly 13, 1978 In the .e~a~t of s~ ~r ab~w&~s~N: please gi~ this office ~ ~ so ~ ~ may ~ a wi~ present. Imi~mtmmt of Fish axl ~, ~abitat ~ w/o eccl. ~pextmeet ~ ~ (ka~=~mtic~ w/o encl. July 11, 1978 · ADMIN I S T RAT I VE AP'P ROYAL NO. 80.24 Applicaticn of Unic~ Oil Ommpany of California, Trading Bay Unit operator, to drill and produoe the ~ad ,inq ,BaY~Unit..K~12~lRlkv~ll as part of the pressure maintenance project approved by Conservation Order No. 80. Mr. Wayne Bodg~ Unim Oil ~y. of Californi Box 6247 Anct~Drage, Alaska 99502 On July 10, 1978 the referenced application was received which stated that the proposed well %~uld provide a crestal final withdrawal point whirl% will result in additional Hemlock. recovery. The Oil and Gas Conservation Omnmittee hereby authorizes the drilling and ccmpleticm of the referenced well purer to Rule 5 of Cons~ticm Order No. 80. Yours very truly, ./'..× ...:' / . .~ .~/~' ~5. "' ~-- ~--.' ~a~ Oil ~ ~s ~~~~ ~t~ Robert T. Anderson District Land Manager /~,,, Union Oil and Gas D)~,on: Western Region - Union Oil Company of California P:O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 J._....I..__.C' ! Telex: 90-25188 [ .... ILl · ~u.l¥ ~, ~978 l' ' , State of ~aaska I Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Mr. Hoyle Hamilton TRADING BAY UNIT State of Alaska McArthur River Field Application to Complete Trading Bay Unit, K-12 RD (44-18) Gentlemen: Union Oil Company of California, as operator of the Trading Bay Unit, hereby requests approval to complete and produce the subject well to be completed in the Hemlock formation at a crestal final withdrawal point, pursuant to Rule 5 of Conservation Order No. 80. The subject well will be drilled from the King Salmon Platform by Atlantic Richfield Company, suboperator, as indicated on the attached plat. RECEIVED r~ K-22 T 3 ~0,904 K-22 K-18 2: 30 TO K-! -5 'rD II ,381 TOll T D ,o~ ~[.) I O,l ('~,; TRADING BAY UNIT - ~ ' ~i,420 .'x" K-12 (44-18) ~ (Attachment) Permit to Redrill Well K-12 (44-18) Present Status The K-12 well was originally drilled to 11,240' MD (9935' T~D) with 9-5/8" casing cemented @ 11,192' bP and is plugged back to 11,150' MD. The well has single 4-1/2" tubing string with the packer set @ 10,614'. Proposed Program Retrieve existing completion. Set a cement retainer @ + 10,600' MD squeeze cement through perforations from 10,685' to 11,110' with 200 sx "G" leaving 50' of cement on top of retainer. Cut and pull existing 9-5/8" casing @ ~ 2550' MD. Lay 400' of cement kick off plug and directionally drill 12-1/4" hole to TD @ + 11,800'. Run logs and gyroscopic survey, then complete the well as a producer~ RJ~V. I - I--7! SUBMIT IN TRIPt .1~ (Other Instructions on reverse side) STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMI¥ TO 'DRILL OR DEEPEN . lA. TIPB OF WORK REDRILL~] DEEPEN b, TYPEOr W~LL OIL [~ O&8 ~-----] 81NGLB J~] MI'I-TIPI.I; r-] WELL WELL OTHIJli ZONI; , · , ZON g . 2. NAME OF OPE:R~TOR Union Oil_ Comuanv_of California 3. 'ADDRES~ C~ OPFA~kTOR 909~We._st_Ninth_.Av~n.ue, A~_.chor.aRe, AK 99501 4. LOCATION OF WF-J.J. ^~surface 735' N & 140' W fr SE Cr. Sec 17, T9N. R13W. SM At proposed prod. zone 325' N & 600' W fr SE Ct. Sec 18. T93, R13W SM 13. DISTANCE IN MILF~ ANI~ DII~-~TION FI~OM NEAREST TOWN OR POgT OFFIC~;'' ' ~"' Apprgximate!Y 24 miles 1~. BONg INFO~ATION: ~v~Statewide s~t~.a/o~o. Federal Insurance Co. #8011-34-40 15. DISTANCE FROM PROPOSED' 116. NO. OF LOCATIO~ TO NEAREST PROPERTY OR LEASE LINE. ~. 325 ~ 1902 (Al~o to nearest drig. unit, i~ any) 18. DISTANCE FROM PROPOSED LOCAT'~O1W* TO NEAR~SI' WELL DRILLING. COMPLETED. OR APPLIED FOR. FT. 1.500,,' ,fr, om K-18 _ 21. ELEVATIONS (Show whether DF. RT. CR, etc.) RKB 100' MSL JI9.~ROPOS~DD~TH 11,800' }D 9,670' TVD ~' Exis. tin~. CASI~rG AND CEMF2~T~NG PROGRAM API No. 50-133-20156-01 · ADL 18777 IN-DIAN. AJ.~O~;rmm OR T~J~ NA/W~ 8. UNIT FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. ~ '- ~ K-12RD (44-18) ,0. mELD AND POOL. O~ WILDCAT McArthur River - Hemlock 11. SEC.. T.. R.. M., ~BOTTOM HOLE OBJECTIVE) Sec 19, .T9N, R13W, SM amo,,~t $100,000.00 n.' ~0.'AcB~ 'iSS'ONED TO THiS WELL 160 '20. ROTARY OR CABLE TOOLS Rotary =.APPROX. DATE WORK WILLSTART° July 15, 1978 SIZ~OP'Of~' i~IZE"OFCASlNG' W~IGHTP~RFOOT ~_GRAIM~, , , quantity of cement _.18" [13-3/8'' ..... 6i~' J-55 2510' 1500 sx 12-1/47 9-5/8" ..... ~7# . P&N '.".'1.1t92' 'i0'00 sx '" _ ~ropo,~sd I , , 12-1/4", 9-5/8" ''~ ........ ~.~ .' S'95--". 11800' " i000's~ ........ · ........ - · ,, : - . ....... , r . BOPE: 3000 psi double gate shaffer & GK Hydril (See attachment for present status and proposed program) R £C g / W E D ,JUL - 7 1978 DMsion of Oil and (:las Cons.~rva'don *Atlantic Richfield Company is Sub-operator Anchorage IN ABOV~ SI~AC~: D~S~RIB~ ~O~ ~R~: If ~I l$ to dee~n give ~ on p~zen~ p~u~ive zo~ ~5 p~ r~w prffdu~ve zone. J~o~; is ~ drH~ or ~n d~io~l~y, give ~en~ ~' om zdbsu~a~ ~t~ ~d ~ea~d and -yeS,cai dept. Give bio. ut 6~e~e~r - s~~-~~Q~P~~/ n~ ,Ju~y 5, 1978 . R~h~,g ~'~~'.~ . t~~ / ...... ~ . m D~st. Land ~gr. _ (T~is space fo; S~;o~,~c~'~ ' - ......... ~O~I=0NS OF ~';~V~. I~ A~: ' ' ISAMPLF-.S AND CORE CHIPS R~I/I.R,]I:O MUD [] YF.S ~i NO j ~ DIRECTIONAL SURVEY RE~t~ {~ YF~S ~ NO ~F NO A.P.I. ~CAL CODI~ 50-133-20156-01 78-57 P~Rh4T~ NO_ ~/~,,/~ . , .~__.~~ .. ._ ..._. A.PI~VAL DA'r~ API:~OV~D Bsz-- ~~- , _ T~. ~ai~ ~' ' ~ *~ I.~o., ~ R,,,~ ~d, July 13, 1978 July 13, 1978 Union Oil and Gas Divan' Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 Telex: 90-25188 union Robert T. Anderson District Land Manager .July 5, 1978 Mr. O. K. Gilbreth Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99503 TRADING BAY UNIT State of Alaska Permit to Drill Trading Bay Unit State K-12 Rd. (44-18) Dear Mr. Gilbreth: Enclosed for your approval are three (3) copies of Permit to Drill Trading Bay Unit State K-12 Rd. Also enclosed is Check No. 154327 in the amount of $100.00 to cover filing fees. sk Enclosures Very truly yours, CHECK LIST FOR ~ ?~I,l, PERMITS Yes No Remarks L. Is the pez~d.t fee attached ..................... ~. Is well to be located in a defined pool .............. 3. Is a regJ.~.~tered survey plat attached ................ ~. Is well ~cabed proper distance fr~m property line ......... ~ 5. Is well k~cated proper distance from,_ other wells .......... 6. Is sufficient undedicated acreage available in this pool ...... ?. Is well to be deviated ....................... ~ s operator the onlv affec%ed party ..... - ........... 9. Can permit be approved before ten-day wait ....... . ...... 0. Does operator have'a bond in force ' /~ 1. Is a conservation order needed ................... /~ 2. Is administrative approval needed ................. · ~. .. I rem Approve Date -(1) Fee ~..~ ~ , [2) Loc. (3) Admin. ~~ 3. Is Conductor strinq provided ' · ......... '" .... " ~!l- ~-~-~-~--' .4. Is enough cement used to circulhte on conductor and surface .... ~ '~ ,5. Will cement tie in surface and intermediate or production strings 'ill cement coVer all known productive horizons .. ........ ... ~ .7. Will surface casing protect, fresh water zones ........... ~L .8. Will all casing give adequa.be safety in collapse, tension & burst .9. Does BOPE have sufficient pressure rating - Test to ~oaO . psig . ~. !0. Has DMEM approved Plan of Operation ................ Revised 4/14/78
