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Home My WebLink About184-017 ALASKA OIL AND GAS CONSERVATION COMHISSION WALTER J, HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 August 19, 1994 Robert C. Gardner, President Fairweather E&? Services, Inc. Agent, Amerada Hess ? O Box 103296 Anchorage, AK 99510-3296 Re: Final Location Clearance, 5 Amerada Hess Wells Dear Mr. Gardner: On August 10, 1994 our inspector Jerry Herring accompanied you and others on an inspection of five Amerada Hess locations. Based on his observations, Mr. H'erring recommends Location Clearance for the five wells. Final Location Clearance is hereby approved for these Amerada Hess wells: BF-47-1 PTD 83-074 BF-57-1 PTD 84-093 'OCS-Y-181-1 PTD 84-017 OCS-Y-180-1 PTD 84-22.0 Colville 25136 #1 PTD 85-278 Chairman c: Blair Wondzell bew/llahns5w MEMORANDUI . TO: State of A, aska Alaska Oil and Gas Conservation Commission DATE: August 13, 1994 THRU: Blair Wondzell,~ P. I. Supervisor olcf FROM: Jerry Herring, ~{'[~ SUBJECT: Petroleum Inspector FILE NO: i99khjbd.doc Location Clearance Amerada Hess, Seal Island North Star Unit BF-47-1 (PTD 83-074) BF-57-1 (PTD 84-093) "" OCS-Y-180-1 (PTD 84-220) OCS-Y-'I' 81-1 (PTD 84-017) Wednesday, Au.qust 10, 1994: I traveled to Seal Island, North Star Unit, to review the condition of the (4) wells listed above. Travel was completed on an ERA Bell 412 with Robert Gardner representing Amerada Hess, operator of the North Star Unit. These wells were drilled by Shell Western. Exploration & Production. I traveled to Seal Island in June of this year tO review, the'status of the (4) wells which were not ready for abandonment at that time. Alaska Interstate Construction was mobilized and had completed all of the required island abandonment work. All of the debris, island armoring and wellhead equipment had been removed and the gravel on the island was leveled. Because this location is offshore and the island is being abandoned, the casings were cut ~nd removed 19 feet below the original mud line. No markers were installed. The gravel island is anticipated to be washed out to sea over the next few years. .... .. ... ,. .,..,. . , . ,,. ,.., .., , .... The island is in very good shape now and ready for abandonment. I recommend the location clearance for these (4) wells be approved at this time."" ". ,. Summary: I completed a location clearance inspection of the (4) Seal Island wells in the North Star Unit and recommend approval of final abandonment of these wells. Attachment: i99khjbd.xls, i99khkbd.xls, i99khlbd.xls and i99khmbd.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Surface Abandonment I Location Clearance Report ( Title 20 AAC 25, Article 2 ) Operator: Address: Amerada Hess Corp. 1201 Louisiana, Suite 700 Houston, Texas 77002.568f Surface Location: F L, F L Section ff ,T 13N ,R 13E ,MUm Well Name: PTD No.: APl No. 50- Unit or Lease Name: Field and Pool: Downhole P&A Date: Seal Island OCS. Y-18f.f 84-017 North Star Unit Inspection Date: N/A I'i'=:;?~'II:'::20 AAC2$,J2$..~.'ABAND...QNMENT. MARKE..R..'.:i ?.. .;I Approval Date: Steel Post OD: (4" min) N/A "Length (10' min.) N/A ft. Height Above Final Grade Level (4' min.) N/A ft. Top of Marker Post Closed With: N/A 0Nelded-'--,~mt., Cap), Set: N/A (On Wellhead, Csg'~' Cmt) Distance Below Final Grade Level: - '---~-~' ---'---- "--'- Side Outlets: All valves and nipples removed ? N/A All openings closed? N/A With N/A 1 Marker Plate Diameter: N/A "Thickness: N/A "Distance Below Final Grade Level: N/A ft. Marker Plate Attached To: Wellhead N/A ~utoff Csg N/A Other N/A Information Beadwelded Directly to Marker Post or Blind Marker Plate: Operator: Well Name: Surface Location: F L, Section ,T Inspection Date: PITS: Filled In: N/A Liners Removed or Buried: SURFACE CONDITION OF PAD AND / OR LOCATION · ( Note when different from file information) N/A Unit / Lease Name: N/A N/A Remarks: Seal Island is bein~l abandon~led. Casin(~ was cut and removed ~9 feet below original mud line. No marker F .. L plate was installed due to offshore location. ,F~" 8/10/94 Approval Date:' Contoured N/A Debris Removed: Yes ( Rough, Smooth, Contoured, Flat, Compacted ) Type &Quan. of Debris if any remaining on pad and I or location: None Clean: Yes TYPE AND CONDITION OF SURROUNDING AREA' Arctic Ocean (Wooded,Tundra,Grass,Brush,Dirt,GraveI,Sand) Clean: Yes Type &Quan. of Debris if any remaining on surrounding area · None TYPE AND CONDITION OF ACCESS ROAD AND SURROUNDING AREA: N/A Clean: N/A ( Dirt, Gravel, Ice, Other) Type &Quan. of Debris if any remaining on access road or surrounding area · N/A CLEANUP WORK REMAINING TO BE DONE' None RECOMMENDED FOR APPROVAL OF ABANDONMENT: Distribution: Reason: orig - Well file Yes XX No ( If "No" See Reason ) ¢ - Operator c- Database c- Inspector FI-000 (Rev. 3193) FINAL INSPECTION: Yes XX INSPECTED BY: ~ ~ 199KHMBD.XLS NO DATE: 8/10/g4 E & P SERVICES, INC. August 8, 1994 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ATT: Blair Wondzell, Senior Petroleum Engineer RE: Final Abandonment, Amerada Hess Corporation OCS Y-181, #1, Seal A-2 (Redrill)(Well formerly operated by Shell Western E&P, Inc.), Seal Island, Beaufort Sea Gentlemen: Please find attached the following documents relating to the above-referenced project: 1. Two (2) originals: AOGCC Form 10-407, Well Completion Report, , Two (2) copies: Summary of Operations for Final Abandonment (attached to Form 10-407), m Two (2) sets: Daily Field Progress Reports covering the final abandonments of all Seal Island wells. All technical data required under 20 AAC 25.070 (Records and Reports) and 20 AAC 25.071 (Geologic data and Logs) has previously been submitted by Shell Western E&P, Inc. Seal Island was severely damaged by storm waves during the fall of 1993. The damage did not put the wells in jeopardy, but another storm event of similar magnitude could have eroded the island back to the wellheads. Amerada Hess Corporation (AHC) elected to abandon the four wells on Seal Island and to then abandon the island itself, as the exploration objectives of the island have been met. R£CrclVrcD /kL)G 1 0 1994 Gas Cons. Commission Anchorage 715 L Street Anchorage, Alaska 99501 (907) 258-3446 FAX (907) 258-5557 Mr. Blair Wondzell August 8, 1994 Page two Island abandonment operations are currently underway. It is anticipated that the island will be ready for a final site clearance inspection by an AOGCC representative on or about August 11, 1994. Please contact me if you have any questions. R. C. Gardner Agent for Amerada Hess Corporation RCG/js Attachments CC: C. R. Richard, AHC John Simon, AHC Steve Schmitz, DNR RECEIVED AUG 10 1994. Alaska 0il & Gas Cons. Commission Anchorage ¢ STATE OF ALASKA (" ALASKA O~LAND GAS CONSERVATION COMlv~tSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED F'] ABANDONED [] SERVICE ~1~,,,,~(:1~ ~. Name of Opera[or ~i~ 7. Permit Number ~e=ada ~ess Co~o~a~on '~ 8~-[7 3. Addres~ ~20~ ~s~a~ S~e 700 ~~ 8. APl Number EousCoa~ ~ 77002 ~ ~ 5O- 029-2[07~ ~. Location of well at surface ~30 ~C ~'~ b~Z ~C ~'~ ~ec. ~ ~N~ ~ U~ 9. Unit or Lease Name Northstar Unit/Seal Island At Top P~oduc~.9 ~n~val 295 ft FSL~ ~30 Ft ~L~ Sec. 12~ ~3N~ ~3~ ~ 10. w~N Numb~ (~D~) OCS Y-181~ ~1~ (Seal At To~a~ Oepd~ 4.5 ft FSL~ 900 ft ~L~ ~c. 12~ T13N~ ~E~ ~ ii. Field ~nd Pool 55 ~t ~~ OCS Y-181 (Bt~) ~2. Date Spudded 33. Oa~a T.O. Reached 14. Oa~e Comp., Sump. o~ Aband. 15. Water DepHL Jf ofl~hofe J'18. No. o[ Completion= 2/~/84 5/27/84 6/30/84 39' feet MSL~ 0 ~'~.Total Depth (MO+TVO} 18.PlugBackOepth(MO+~D) ]9.0irectionalSurvey ~ 20. OepthwhereSSSVse~ 21. Thickness o[ Permafrost ~,078 ~/~,4~ ~ 187' ~ & ~ YES ~ NO ~~ (None) lee~ UO 1,700 '~2. Type Electric or Other Log~ Run ' ' DIL/~, BHCS, DIS~ ~ C~, ~ S~ N~ VSP, ~, ~ 23. CASING. L~NER AND CEmENTiNG RSCORO SETTING OaPTH ~O CASING SlZEWT. P~mFT. GRADE TOP 8OTTOM HOLESlZE CEMENTINGRECORO A~OUNTPULLED 20W~[ 166~ . Surf -- 249 ' Driven ~ive Pipe 80 13-3/8" 72~ N-80 Surf 2,650' .17-1/2" 5/?:/: SX Pe~afrost II 80 9-5/8" 53.5 ~ N-80 Sdr[ '12,288' i2-3/M' 1,450 SX G ...... 80 7" 32 · L-80 ~,997 13,072' 8-1/2" 240 SX G ~nterval, size and numbec} SIZE OEPTH SET {MO) PACKER SET None ; , No~e 2~. ' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KINDOF MATERIAL USED N/& , ,,, ,, 27. PRODUCTION TEST Date First Production Med3od of Operation (Flowing, gas lift, etc.) 9S~ 6./~/8~J 9S~ 9eta Submitted Dateo~'Tes[ Hours Tested , PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE sIZE GAS-OIL RATIO TEST PERIOD ~ .... Flow Tubing Casing Pressure CALCULATED OIL.BDL GAS.MCF WATER-BBL OIL GRAVITY-APl {corr) Press. 24-HOUR RATE ~ 28'' .... CORE DATA ' , , ~rief description of litho~ogy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Co~e 9ate ~e~[ous[7 Submitted ' ORIGINAL AUG 1 0 1994 .... kt~ Oil & ~as Cons. Commissio Form 10-407 ~lll~iu~-~tt in duplica[e Rev. 7-1.80 CONTINUED ON REVERSE SIDE 29. NAME Colev 11 le Pebble Shale Cretaceous uncon£ormi ty Kingak Sag River Shublik Sndlerochit Ivishak Echooka Lisburne 1~) (Driller' s) GEOLOGIC MARKERS MEAS. DEPTII I 'TRUE VERT. 7,76~' 9,892' 10,262' 10,6~7' 12,232' 1.2,3~8' 12,~51' 12,838' 12,92~' 12,960' 13,078' 6,903' 8,791' 9,032' 9,637' 10,700' 10,796' 10,887' ]2,210' 11,290' 11,322' DEPTH 30. FOflMATION TESTS Include interval tested, pressure data. all Ut, ids recovered and gravity, GOFt, and time of eacl~ phase. DST Data Submitted Previously 31. LIST OF ATTACHMENTS 32. I hereby cortily II,at tho foregoing is ~ and correct to the best of my knowledge ~ Agentz Amerada Signed &-jW'/' ' ~-., -~ ~//_ Title tless corporation Date Aug. 8m 199~ INSTRUCTIONS General' This form is designed for submitting a complete and correct welt completioa report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, 'air injection, salt water disposal, water supply for injectioR, observation, injection for in-situ combustion. I te['n 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If tills well is completed for separate production from more than one il~terval (multiple completion), so state in item 16, and iR item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, si]owing the data pertinent to such interval. Item 21' Indicate whether frorn ground level (GL) of' other elevation (DF, I<B, etc.). Item 23' Attached supplemental records for this well slmuld show the details of any multiple stage cement- ing and the location of the cementing tool. · ,, Item 27' Method of Operation' Flowing, Gas. Lift, Rod. P..Ump,..Hydraulic Pump, Submersible, Water In- jection, Gas InjectioR, Shut-in, O[l'mr-explai'n. Item 28: If no cores taken, indicate "none". Form 10.407 SUMMARY OF OPERATIONS Final Abandonment Well No. OCS Y-181 #1, Seal A-2 (Redrill) Seal Island, Beaufort Sea The well was temporarily abandoned in 1988 by Shell Western E&P Inc. A wellbore diagram of the Temporary Abandonment was previously submitted to the AOGCC. The work covered by this operations report consisted of severing all casing strings below the original mudline and the recovery of the wellhead and cutoff casing strings. , Barged equipment to Seal Island on Sunday, July 24, 1994. . Removed tubing bonnet and opened all annulus valves. Tested contents of well- bore and 9-5/8" x 13-3/8" annulus and determined that fluid did not contain any diesel or crude oil. Weilbore and annulus were filled with CaCI2 solution. 3. Excavated and removed well cellar. . Attempted to drift wellbore to 7.5 inches. Encountered obstruction approximately 8 ft. below top of wellhead. Cutoff wellhead below obstruction and found ice plug. Cleared ice from wellbore and drifted 9-5/8' Casing to 7.5 inches to top of top plug. . , Lowered 78 lb. charge of Composition B into wellbore. Detonated charge and severed 9-5/8", 13-3/8" and 20" casing strings simultaneously at approximately 80 ft below island surface (= 19 ft below original, mudline). Rigged up vibratory hammer on 20" conductor. Hammer jaws failed. While changing jaws, pulled shot-off 9-5/8" casing with crane. Re-rigged vibratory hammer and pulled shot-off 20" and 13-3/8" casing together. , Backfilled hole left after extraction of 20" conductor as precaution against accidents. RECEIVED AUG 1 0 1994 Alaska 0ii & Gas Cons. Commission Anchorage HOTEL --.. F.,,2 i · F, 59 '"'"':' %_. .'[UL 22 '9~ ( · :t5'20 No,010 P.04 FAIRWEATHER E&P SERVICES, INC. FIELD PROGRESS REPORT CLIENT: AMERADA HESS CORPORATION PROJECT: SEAL ISLAND WELL ABANDONMENTS REPORT NO: · JOB NO. 002-02-400 __ AFE NO. --. NORTHSTAR/SEAL ISLANDS RECLAMATION AND ABANDONMENT REPORT' PERIOD: Activity Repod: --. ---- , i ,, -- '' LI[ I [ ' .... Jl[ , .... Ill . II I . . ]11 ' · ,, Weather ~ ~ I~rs ~//~f'...__. Temp: _.¢! e~- Wind: ~/~q~ ..~t~{~.E~Visiblilly; Pressure: .~.~? ~ Precipitat{on:~Z~ Sky: d~J~t~', d~..~ .... Chill Factor: Submilled by: ~ tepreser~talive R ErE I VE D AU6 1 0 1994 Alaska Oil & Gas Cons.Commission' Anchorage dH'T" HOTEL '659-2'?52 JUL L2 94 (, 15'19 No.OlO P.02 FAIRWEATH ER E&P SERVICES, INC. REPORT NO: ~ FIELD PROGRESS REPORT DATE: JOB NO. 002-02-400 CLIENT: AME RADA HESS CORPORATI ON AFE NO. ~4~/4 ~J PROJECT; SEAL ISLAND WELL ABANDONMENTS NORTHSTAR/SEAL ISLANDS RECLAMATION AND ABANDONMENT REPORT PERIOD:..OO~/ tll'S ?'/~/.,~ ....___temp..tits ~.~//~ ..... Activity Repmt,: Precipitation'./-,/Z~.~._ Sky~j ././'~_ ~:~t~'.,~ .. Cllili Factor: _~ ~i~ ~',..~, Submitted by: ~~. Representative RECEIVED ~tlG 'JO 19,94 Alaska U~ & Gas Cons. Commission Anchorage ,BRY HOTEL 'iD:r-,S9.-.2?52 JUl_ 22'94 15'19 No.OlO P,O1 FAIRWEATHER E&P SERVICES, INC. FIELD PROGRESS REPORT REPORT NO: _ ,,.,,,~ JOB NO. 002-02~00 CLIENT: AMERADA HESS CORPORATION PROJECT: SEAL ISLAND WELL ABANDONMENTS NORTHSTAR/SEAL. ISLANDS RBCLAMATION AND ABANDONMENT REPORT PERIOD: ,,,~/ hfs _-?'/~2.~._4¢ tO~ .hfs ..... ~///~//~f~ Aotivity Report: ~~ ~~,~~~~~/z,~,.~,,~. .... . ..... ...... .. - ,, , ,, ,, .. ,,,, Woather (~ ~hrs .X_~..~"/~ · Tm'np: ~ Wind: ,~ ~/~, Visibility:_ Submitted by:. ~~ .... 0~~ ~epre~ative RECEIVED AU6 1 0 1994 Alaska Oil & Gas Cons. Cgmmission Anchorage dH¥ HU't EL I D ' b59- Z 75'z (" 3UL 2~4 ' 94 (r~ 21'10 No.OlO P.O1 FAIRWEATHER E&P SERVICES, INC. FIELD PROGRESS REPORT REPORT NO: DATE: JOB NO. 002-02.400 AFE NO. CLIENT: AMERADA HESS CORPORATION PROJECT: SEAL ISLAND WELL ABANDONMENTS NORTHSTAR/SEAL ISLANDS RECLAMATION AND ABANDONMENT REPORT PERIOD; ~/~__hrs_..~._/~ ~_~._..¢'~ ,o. Z~/~::J¢__i,~m Z/~'$/~'. _~... Weatller ~ hrs Tern p: Pressure: ~- ~,,? ? Submitted by:_ ~ _~ ~tofs Representative RECEIVED AUG 1 0 1994, ~.taska Oil & Gas Cons. Commission Anchorage dRY' HOTEL I D(.~59-2752 JUL 24 '94 (" 21:10 No.OlO P .02 FAIRWEATHER E&P SERVICES, INC, FIELD PROGRESS REPORT CLIENT: AMERADA HESS CORPORATION REPORT NO: 5" DATE: JOB NO. 002-o2-400 AFE NO. PROJECT: SEAL ISLAND WELL ABANDONMENTS NORTH,.~TAI:t/SEAL ISLANDS RECLAMATION AND ABANDONMENT .- ii .__ I ii i . I i _ i i - -- -- i i ..ii - .. iii .. i i i i -- i Weather ~ ¢,30,0 hm . Tomp: . _. ,[, Pressure:. /j//~ ._ Precipitation: --' Sky: _~ _'.~/ __ Chili Fau-'tor; ,~ oF ~ii~erator'a Representative AUG 1 0 1994. klaska Oil & Gas Cons. Commissio~ Anohora¢~ FAIRWEATHER E&P SERVICES, INC, FIELD PROGRESS REPORT CLIENT: AMERADA HESS CORPORATION REPORT NO: DATE: ,~_~q. JOB NO. 002-02-400 AFE NO. PROJECT: SEAL ISLAND WELL ABANDON~IENTS NORTHSTAR/SEAL ISLANDS RECLAMATION AND ABANDONMENT Pressure: 3' O.__O. Tl _ P,'edpitalion:~ Sky: _~/'~._ ~,.;c.j~ Chill Factor: ~:~perator'$ Representative ~,klG 1 0 1994 Gas Cons. Commissiol Anchorage, . :BRY HOTEL 3UL. 26'94 (. 2f'54 lqo.015 P.01 FAIRWEATHER E&P SERVICES, INC. FIELD PROGRESS REPORT REPORT NO' DATE: JOB NO. 002-02-400 AFE NO. CLIENT: AMERADA HESS CORPORATION PROJECT: SEAL ISLAND WELL ABANDONMENTS NORTHSTAR/SEAL ISLANDS RECLAMATION AND ABANDONMENT ,/ Chill Factor: Submitted by: ~rPorato'r's Representative AUG 1 0 1994 Alaska Oil & Gas Cons. Commission, Anchora~j~ ~R'¥ HOTEL ID ' 659-'"752~ JdL -,"'-'," ' 25:52 No.O15 P.Oi FAIRWEATHER E&P SERVICES, INC. FIELD PROGRESS REPORT CLIENT: AMERADA HESS CORPORATION PROJECT: SEAL ISLAND WELL ABANDONMENTS REPORT NO: ~ DATE: ?'" ~-"7-' qq JOB NO. OO2-O2-400 NORTHSTAR/SEAL ISLANDS RECLAMATION AND ABANDONMENT Weather~g6gehrs ~..~~: Temp: ~' ~ Wil'~d: /~,c~.-~ ~ Visibility:_~"~,~ Pressure: _~,0,0 ~ Pracipilafion: '"'- Sky: ~/e~.~ Chill Factor: Z?. BRY HOTEL I1'"":'59-2752 JUL 2/'94, q'47 No.OO2. P.01 FAIRWF. ATHER E&P SERVICES, lNG. FIELD PROGRESS REPORT REPORT NO: .... _ _ ~,, u, JOB NO. 002-O2-400 CLIENT: AMERADA HESS CORPORATION PROJECT: SEAL ISLAND WELL ABANDONMENTS NORTHSTAR/SEAL ISLANDS RECLAMATION AND ABANDONMENT REPORT PERIOD: Activity Report: ~,'~. ~.~,~) ,, 0 fl ....... i .... II It Pressure: II ~ ECEIVED 1994 HOTEL iD(r~5c3-2752 JUL 29 ' 23'2! No.022 P.O1 FAIRWEATHER E&P SERVICES, INC. REPORT NO: /o FIELD PROGRESS REPORT DATE: CLIENT: AMERADA HESS CORPORATION JOB NO. 002~2-400 AFE NO. PROJECT: S-EAL ISLAND WELL ABANDONMENTS NORTHSTAR/SEAL ISLANDS RECLAMATION AND ABANDONMENT REPORT PERIOD: ~___-~/ Woather ~ Ilrs ~: Temp: __.G5 ~ ...... RECEIVE hUG 1 0 1994 & Gas Cons. Anchorage .iCH';" HUTEL iii. ' 659-2'752 ,JUL i$1'94 .... 8'09 No.O05 P.Ot FAIRWEATHER E&P SERVICES, INC. FIELD PROGRESS REPORT REPORT NO: // ,lOB NO. O02-02-4Q0 CLIENT: AMERADA HESS CORPORATION PROJECT: SEAL ISLAND WELL ABANDONMENTS NORTHSTAR/SEAL ISLAND8 RECLAMATION AND ABANDONMENT REPORT PERIOD: Pressure: ~¢~, ~:~,~ ..... Precipitatiorl: ~ Sky:.~4 ._~/.__ Chill Factor: Submitted by: "' RECEIVED AUG 1 0 1994. Ataska Oil & 6as Cons. Commi~ion June 23, 1994 Mr. David Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ATT: Blair Wondzell, Senior Petroleum Engineer RE: Final Abandonment of Wells on Seal Island, Beaufort Sea, Alaska Gentlemen: Please find enclosed three (3) originals of AOGCC Form 10-403 and supporting documentation covering the final abandonment of the following wells: ~ Shell Western E&P Inc. Shell Western E&P Inc. Shell Western E&P Inc. Shell Western E&P Inc. BF-47 No. 1 (Seal A-l) OCS Y-181 No. 1 RD (Seal A-2) BF-57 No. 1 (Seal A-3) OCS Y-180 No. 1 These wells are located on Seal Island in the Beaufort Sea. The lease upon which Seal Island is located is committed to the Northstar Unit, and Amerada Hess Corporation (AHC) is the Unit Operator. Accordingly, the final abandonment work on the above wells will be performed by AHC. A separate submittal is being made to the MMS for the OCS wells. If you have any questions concerning this work,' please contact the undersigned. We would appreciate, receiving a copy of the approved 10-403 forms in this office. The. originals .should go to AHC in Houston, as the address appears on the form. for Amerada Hess Corporation Enclosure cc: John Simon, Amerada..I Hess C0rP~ration Cliff Richard, Amerada Hess Corporation 715 L Street Anchorage, Alaska 99501 (907) 258-3446 FAX (907) 258-5557 -' STATE OF ALASKA CA OIL AND GAS CONSERVATION COMMI ' q APPLICATION FOR SUNDRY APPnOVALS SusDer~d .--- Operation shutdown ..._ Re-enter susDencle~l w~ __ Time extension ~ Variance ~ Perforate 2. Name pf Operator 5, Type of Well: Amerada Hess Corporation Oeve~ooment_ Exoloratoq/X.~ 3. Address 1201 Louisiana, Suite 700,';., $[ratigraoh,c_ Houston· 33[ 77002 ~ Se~ce__ 4. Location of ;;~l at sudace ].530 :it FSL, 642 Et..~'~[., Sec. 13., 33.3N, R]3E, ON , Al top of productive interval 295 .Et. FSL, 1130 ft. 1;'EL· Sec. 12, T3_.3N, R.].3E, ON · 6.' Datum elevation (DF or KB.~.) 55 :Et. ~ 7. Umt or Property name Northstar Unit/Seal Island 8. Well numOer (redrill) OCS Y-181, ~:1 (Seal A-2) 9. Permit number 86-17 10. APl number 50-- 029-21076 11. Field/Pool 12. Present ',vs{~ condition summary Tolal depth: measured 13,O78 feet true vertical 11,6].5, feet EI1ective depth: measured 187 lee{ true verticaJ 187 feet Casing Length Size Structural - _ Conductor 269" 20" Sudace 2650, 13-3/8,, Intermediate 12,288, 9-5/8" Produc~on - _ Uner lO75 "' 7" Pedoration depth: measured 12 · 726, -12 · 738 ~ true vertical 11·112'-11,126' Tubing (size, grade, and measured depth) None Exploratoz7 Plugs(measured) 12,738'-12,672,, Cat. Ret. @ 12,698' 12s576'-].1·890'· Cat. Ret. @ 12·380, 1,750'-1,668', 335~-187~ Junk (measured) None Cemented Measured depth True vertical depth Driven 269' 269' 5%h': SX + top job 2650' 2650' 1650 SX 12·288' 10,746' -- 260 SX 13·072' 11,617' 12,526'-12,576' 10,965'-10,987' RECEIVED JUN ?_ 4 1994 0ii & Gas Cons. Commission Packers and ~ (type and measured depth) Liner packo££ @ 11,978' ,, ~3. AP_~".,hments ' Description summan/of proposal .._. 14. Estimated date for cc~T, mencing ~peration' ' July 15· 1996 16. If proposal wa~ verbally ap~oved Name of approv~ Anch0mge De~led'oper~ona program ~ BOP sketch .._ feet 15, Status c~ wetl clasaficatJon as: Oil __ Gas __ Suspended Date approved Service ' i7. I hereby ce~ty that the foregoing is~,.,~'-~?,nd.cx:~'rect to the best oi my knowledge,' , ...... , R.C. Cardner~~~'~ / Conditions of approval: Notify Commission so representative may witnes~ .Plug integrity ._. BOP Test ._. , Location clearance MechanicaJ Integrity Test .._ Subsequent form required 1"~'- _/-/'0'7 Approved by order of the Commission _ Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY RUSSELL A, DOUGLASS Commissioner Approved Copy Returned suBMIT IN fRIpMCATE OPERATIONS PROGRAM FOR SWEPI OCS Y-0181 No. 1 RD (Seal A-2) FINAL ABANDONMENT Present Well Status: Top plugs in 9-5/8" casing and 9-5/8" X 13-3/8" annulus set and approved by AOGCC. Top plug in 9-5~8" casing is approximately 154 feet below island surface. Top of plug in 9-5/8" X 13-3/8" annulus is also approximately 154 feet below island surface. The 13-3/8" X 20" annulus is plugged at the surface with a top job at the time of primary cement job on 20" casing. The 9-5/8" casing and 9-5/8" X 13-3/8" annulus contain 10.2 ppg CaCI2 fluid. Wellhead is in place. (See attachments No. 1 and No. 2.) 1. Barge equipment to Seal Island as soon as ice conditions allow. . Grade island surface as necessary to provide firm work surface and access to and from well location. . Thaw any remaining ice in well cellar using steam. Pump out cellar using vacuum truck. . . . . Crack open valve on "C" Section of Wellhead and bleed off any accumulated pressure due to seasonal temperature changes. Repeat with valves on "A" and "B" Sections. Valves may be hard to open and require application of steam. Nipple down tubing bonnet on top of "C" Section of Wellhead, exposing access to 9-5/8" casing. NOTE: It will probably be necessary to torch bolts due to accumulated corrosion. Determine nature of fluid in 9-5~8" casing using water sensitive paste. Use lead line and verify that casing is open to top of plug at approximately 154 feet below island surface. If fluid in casing is frozen at any point, thaw with steam lance. If fluid in casing is not diesel or otherwise oil based, go to Step 6 below. If fluid in casing is diesel or oil based, displace with water and recover displaced fluid with vacuum truck. Remove one valve from "B" Section of Wellhead to improve access to 9-5/8" X 13- 3/8" casing annulus. Using water sensitive paste on the end of small flexible wire line, work into annulus and determine nature of fluid therein. If fluid in annulus is not oil or oil based, go to Step 7 below. If fluid is diesel or oil based, perforate 9- 5/8" casing at approximately 153 feet below island surface with two jet charges. Displace fluid in annulus with water dumped or pumped down 9-5/8" casing. Recover displaced fluid with vacuum truck. Rig up Halliburton Services to blow casing. Use 78 pound charge of Composition B explosive. Hold safety meeting. Lower charge down 9-5/8" casing through top of wellhead to approximately 80 feet below island surface. Clear area of non- essential personnel and equipment before arming the explosive charge. Maintain ' radio silence and follow procedures laid out by Halliburton technician. RECEIVED JUN 2 4 1994 uti & Gas Cons. Commission Anchorage . . 10. 11. 12. 13. Detonate shot and sever three (3) casing strings simultaneously. Make up crane slings to wellhead and cutoff wellhead externally, exposing 9-5/8", 13-3/8", and 20" casing stubs. Lay down wellhead. Rig up vibratory hammer on 125 ton crane. Make up hammer to 9-5/8" casing stub. Pull 9-5/8" casing and lay down. Make up vibratory hammer to 20" casing stub and attempt to pull 20" and 13-3/8" casing together. Strings are cemented together, but if cement fails, recover casing as it comes and repeat until all strings have been recovered. It may be necessary to use steam lance to thaw interface between 20" casing and frozen island core in order to pull large OD connectors on 20" drive pipe. If 20" casing is not severed and cannot be pulled after fatiguing with vibratory hammer, re-rig up Halliburton Services and re-shoot casing observing same precautions as in Step 7 above. Rig down vibratory hammer and crane. Excavate and recover cellar box. Backfill excavation as necessary to provide work surface for adjacent well abandonment. Dispose of all recovered casing and wellhead as scrap - use scraplift if available. Dispose of all recovered fluids at Pad 3. REEEiVED JUN 24 1994 Oil & Gas Cons. Commission AnchoraDe Attachment No. 1 OCS Y-0181 No. 1 RD (Seal A-2) Present Wellhead Condition (Attached to and made a part of program for final abandonment of OCS Y-0181 No. 1 RD well) Island SECTION /8' x 5,000 p~! 5/8'x 5,000 psi I I r-.--J I I . Cellar Ii II ! 20" 2 000 psi ~, ? 2,000. ,., I II II II II 2o" ~ ~# (o.a~ 2" wa[k) CON~UCTO~ , s/s", 53.5#, N-OO RECEIVE Attachment No. 2 OCS Y-0181 No. 1 RD Near Surface Casing Detail (Attached fo and made a part of program for final abandonment of OCS Y-0181 No. 1 RD well) All depths are from original KB, unless otherwise noted, TOP JOB CEMENT IN 15 3/S" x 20" ' ANNULUS TO 80' .-a ORIGINAL MUDUN '!"..i ~LOW ~SLA.D SURrAC£) ~"~IN~ ~TRINGS TO BE SEVERE~ e m 80' BELOW IS~ND SURFACE (19' BELOW ORIGINAL MUDLINE) 10.2 ppg CaCl2 (0.812" WALL) 15 5/8" 72t~, N-80 TOP PLUG IN 9 5/8' csg 187'-335' KB, TOP I$ 154 FT. BELOW ISLAND SURFACE (95' BELOW ORIGINAL MUDLINE) PLUG IN 9 5/8" x 15 ANNULUS, 187'-687' KB TOP OF PRIMARY CEMENT UNKNOWN, BUT ESTIMATED TO BE INSIDE 20" DRIVE PIPE SHOE .~ 9 s/s". 53.5/A N-SO 20" DRIVE PIPE SHOE O 249' KB (216' BELOW ISLAND SURFACE) REEEIVED JUN 2 4 199,1, AnchoraDe Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 November 7, 1988 Alaska Oil and Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: SUBJECT: SUBMISSION OF REPORT OF SUNDRY WELL OPERATIONS FOR SEAL ISLAND NOS. BF-47, BF-57, 0CS-Y-0181 & OCS-Y-0180 Enclosed, in duplicate, is the Report of Sundry Well Operations for Seal Island wells BF-47, BF-57, 0CS-Y-0181 and OCS-Y-0180. If you have any questions, please call Ms. Susan Brown-Maunder4(907) 263-9613. Very truly yours, W. F. Simpson Manager Regulatory Affairs Alaska Division WFS/SBB/ljm Enclosures: Report of Sundry Well Operations (8) RECEIVED NOV 0 ~ 198{t Alas~ 0il .& Gas Cons. Commission SBBH/aogcc. 101388 STATE OF ALASKA ALA ... OIL AND GAS CONSERVATION CO . ,SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging I'-1 Perforate [] Pull tubing [] Alter Casing [] Other IX[ 2. Name .o.f Operator She11 Western E&P Inc. 3. Address 601 West Fifth Avenue, Suite 810, Anchorage, AK 99501 4. Location of well at surface 1530' FSL, 6/+2~ FEL, Sec. 11, T13N, R13E, UN At top of productive interval At effective depth 295' FSL, 1130~ FEL,Sec. 12, T13N, R13E UN At total depth /+5' FSL, 900' FEL, Sec. 12, T13N, R13E, UN 5. Datum elevation (DF or KB) 55' above sea level Feet 6. Unit or Property name Seal Island 7. Well number 0CS-Y-0181 No. 1 & Redril] No.1 8. A~_Ps~)O6val number g. 50-- 10. Pool wi 1 dca1: 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13,078' feet Plugs (measured) feet 11,/+15' feet Junk (measured) feet Casing Length Structural 2/+9' Conductor 2650' Surface 12288' Intermediate Production 1075' Liner Size Cemented Measured depth 20"DP Dr~ve Pipe 2/+9' 13-3/8",72#,N80 5/+/+/+ sx Permafrostll 2650' 9-5/8",53.5,#N80 1/+50 sx "G" 12288' 7",32#,L80 2/+0 sx "G" Perforation depth: measured Zone I - 1272/+'-12738' true vertical Zone I - 11112'-1112/+' True Vertical depth 11997'-13072' Zone II - 12526'-12576' Zone II - 109/+5'-10987' (Previously cemented.) Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) Packers set at 11976 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 170 Sx Permafrost cement, at 15.0 ppg, down annulus followed by 10 bbl calcium chloride. Tested 1:o 1500 psi for 15 min. Tes1:ed o.ko 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 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 ~ Title Division 0petal:ions Manager Form 10-404 Rev. 12-1-85 Submit in Duplicate Unitect States Department of th( interior MINERALS MANAGEMENT SERVICE ALASKA OUTER CONTINENTAL SHELF REGION 949 E. 36TH AVENUE, ROOM 110 ANCHORAGE, AK 99508-4302 Shell Western E&PInc. Attention: W. F. simpson 601 West FifthAvenue, Suite 810 Anchorage, AK 99501 Dear Mr. simpson: Your J,zuly 26, 1988, letter to the ~'na%erals ~mg~t Sea-vice (~) and State of Alaska Division of Governmental Coordination indicated that Shell proposed to conduct island maintenance and remedial well operations at Seal Island starting in August. The. letter also requested specific waivers frc~ the State of Alaska's Tier II policy and seasonal drilling restriction. Because there will be no exploratory drilling, testing, or other downhole exploratory activities associated with the remedial well operatio~ on Federal wells, an exception was not requested, nor is one necessary for Sale BF [ease Stipulation No. 8. Shell submitted Sundry Notices to the District SuperviSOr (DS) on August 3,. 1988, and a subsequent letter dated August 5 for teal0orary abandonment of wells OCS-Y 0180, No. 1 and OCS-Y 0181, No. 1. We understand that Shell does not intend to cut' or remove casing at this time. The Sundry Notices will be addressed by the DS under separate letter. As reflected in Section 11 of the lease agreements for Leases OCS-Y 0180 and OCS-Y 0181 (copy enclosed), wells drilled into a Federal lease, 'whether or not drilled fr~m tb~t lease, are subject to Federal regulations and laws. Shell should be. aware that abandonment of both Federal wells must comply with 30 CFR 250.113 and be approved by the DS. Shell should continue to keep the DS informed of any additional proposed activities which, affect Federal wells on Seal Island. On August 10, 1988, Shell submitted an updated Oil-Spill-Contingency Plan (OSCP) for planned activities at Seal Island. We have noted a few minor errors in the update, that Shell should consider in additional revisions: 1.. Table 5,1(c): The criteria for written reports to ~94S should reflect 15 days after the sPillage bas stopped instead of the end of cleanup. 2. Table 3-2 (a): The telephone numbers for MMS should be (907) 261-4066 or (907) 261-4065. 3. Table 6-1(a): The on-site equipment inventory does not reflect or include response vessels which your August 10 transmittal letter states Will be located on the island. The consolidated regulations, 30 CFR 250.43(b), require annual drills for familiarization with pollution-con~rol oquipmmat and. operational procoduros. R[CEIVED 2 1588 AiaSk8 Oil & Gas Con~. Commi: AnchOrage '" ' 'i' '' '"'" ow proDaD~±ity of a large oll spill/occurring. However, as refl~"by.. · Shell's placement of response equipment on the island and the mture of .... proposed activities which will involve reenterir~ a well which has an annulus open to formation, it is kmportant .that. r~sponse personnel be familiar with the on-site response equipment. Thas can be accomplished either through documentation that personnel have received training in the on-site equipment within the last year, or by conducting a drill for familiarization with on- site response equipment. Please submit, training documentation or a notice for conducting a drill to this office 'prior to initiating proposed remedial 'well operations on either F~deral well. If you. have any questions, please contact Jeff Walker or Tcm Murrell at (907) 261-4188. Sincerely, Field Operations Enclosure cc: Lonnie Smith, ADGCC . Elizabeth Benson, DGC containing approximately These rights include: acres or hectares (hereinafter referred to as the "leased area"). 1623.10 fa) the nonexclus'ive right to conduct within the leased area geological and geophysical explorations in accordance with applicable regulations; (b) the nonexclusive right to drill water wells within the leased area, unless the water is part of geopressured-geo- thermal and associated resources, and to use the water pro- duced therefrom for operations pursuant to the Act free of cost, on the condition that the drilling is conducted in accord- ance with procedures approved by the Director of ~he United States Geological Survey or the Director's delegate (hereinafter called the '*Director"); and (c). the right to construct or erect and to maintain within the leased area artificial islands, installations, and other devices permanently or temporari!y attached to the seabed and other works and structures necessary to the full enjoy- ment of the lease, subject to compliance with applicable laws and regulations. Sec. 3. Term. This lease shall continue for an initial period of ]0 years from the Effective Date of the lease and so long thereafter as oil or gas is priced from the leased area in paying quantities, or drilling or well reworking opera- tions, as approved by the Lessor. are conducted thereon. Sec. 4. Rentals. The Lessee shall pay the Lessor, on or before the first day of each lease year which commences prior to a discovery in paying quantities of oil or gas on the leased area, a rental of per acre ( $8.00 per hectare) or fraction thereof. Sec. 5. Minimum Royalty.- The Lessee shall pay the Lessor at the expiration of each lease year which commences after a discovery, of oil and gas in paying quantities, a minimum royalty of per acre ( $8.00 per hectare) or fraction thereof or, if there is production, the difference between the actual royalty required to be paid with respect to such lease year and the prescribed minimum royalty, if the actual royalty paid is less than the minimum royalty. Sec. 6. Royalty on Production. fa), Co) The value of production for purposes of computing royalty On production from this lease shall never be less .than the fair market value of the production. The value of production shall be the estimated reasonable value of the production as-determined by the Lessor, due consideration being given to the highest price paid for a part or for a ma- jority of'production of like quality in the same field or area, to the price received by the Lessee, to posted prices, to regulated prices, and to other relevant matters. Except when the Lessor, in its discretion, determines not to consider special pricing relief from otherwise applicable Federal regulatory requirements, the value of production for the I purposes of computing royalty shall not be deemed to be less than the ~ross proceeds accruing to the Lessee from the sale thereof. In the absence of good reason to the contrary, value computed on the basis of the highest price paid or offered at the time of production in a fair and open market for the major portion of like-quality ~[~ducts produced and sold from the field or area where 'the leased area is situated, will:be considered to be a reasonable value. (c) When paid in value, royalties on production shall be due and payable monthly on the last day of the month next following the month in which the production is obtained, unless-the Lessor designates a late~ time. When paid in amount, such royalties shall be delivered at pipeline con- sections or in tanks provided by the Lessee. Such deliveries shall be made at reasonable times and h',~cz~'als and. at · .~L,r-a option, anal.: De effected either fi) on or L-nmediately adjacent to the leased area, without cost to the Lessor, or (ii) at a more convenient point closer to shore or on shore, in_ which event the Lessee shall be entitled to reimbursement for the reasonable cost of transporting the royalty substance to such delive.~i paint. The Lessee shall not be required to.--.-.l~.?...v~,de~ ~torage for royalty paid in amount in excess of tankage required when royalty is paid in value. When royalties are paid in amount, the Lessee shall not be held liable for the loss or destruction of royalty oil or other liquid products in storage'from causes over which the Lessee has no control. Sec. 7. Paymen:s. The Lessee 'shall Inake all payments to the Lessor by check, bank draft, or money order unless olher- .. -;3':;~'-;S~ .~;~..' .... :..;-e~ .... ';.-~.;'t~..>- - .... -' -:, ' ?;.:.~"~: · .?:..-.. ~~:- . ."-~ . .. . . :.. :.:i.',._/.'.!:.i.-:.-ii;it !i. : - . :. '... ?----.'. ~,!-..(~..-:.' .,.-,.:~;.: ;;::,..,, ... - . : :,"f:-'.;"" ;' ,.¢~':;-':( i~;,;$-~'".:;-'. ' '"'"'";- 011 & G3S 0'.'"'- .-.<,: :;.,..-..,, . Ancho.ra~ . ~--; .- ...-q.~.,:. ~.. .. · . ·-: -,'.~ ';,~,t,::- ;..:"'~': ~4~-~;:.",..- v .'~ -'":..~ 'zi>- - '~-~.~.~.-. :'-,. - '.' =-'-' Sec. 9. Plans. The Lessee shall conduct all operations on the leased area in accordance with approved exploration plans, and approved development and production plans as are required by regulations. The Lessee may depart from an approved plan only as provided by applicable regulations. Sec. 10. Performance. The Lessee shall comply with all regulations and orders relating to exploration, development, and production. After due notice in writing, the Lessee shall drill such wells and produce at such rates as the Lessor may require in order that the leased area or any part thereof may be properly and timely developed and produced in accordance with sound operating principles. Sec. I 1. Directional Drilling. A directional well drilled under the leased area from a surface location on nearby land not covered by this lease shall be deemed to have the same effect for all purposes of the lease as a well drilled from a surface location on the leased area. In those circumstances, drilling shall be considered to have been commenced on the leased area when drilling is commenced on the nearby land for the purpose of directionally drilling under the leased area, and production of oil or gas from the leased area through any directional well surfaced on nearby land or drilling or rework!al/ of any such directional well shall be considered production or drilling or reworking operations on the leased area for ail purposes of the lease. Nothing contained in this Section shall be construed as ~ranting to the Lessee any interest, license, easement, or other right in any nearby land. Sec. 12. Safety Requirements. The Lessee shall (a) main- tain all places of employment within the leased area in com- pliance 'with occupational safety and health standards and, in addition, free from recocnized hazards to employees of the Lessee or of any contractor or subcontractor operatin8 within the leased area; 03) maintain all operations within the leased area in com- pliance with regulations intended to protect persons, property, and the environment on the Outer Continental Shelf; and (c) allow prompt access, at the site of any operation subject to safety regulations, to any authorized Federal inspector and shall provide any documents and records which are pcrtinent to occupational or public health, safety, or ! environmental protection as may be requested. Sec. 13. Suspension and Cancellation. fa) The Lessor may suspend or cancel this lease during the initial lease term or thereafter pursuant to Section 5 of the Act and compensa- tion shall be paid when provided by the Act. (b) The Lessor may, upon recommendation of the Secre- tary of Defense, during a state of war or national emergency declared by Congress or the President of the United States, suspend operations under the lease, as provided in Section 12(c) of the Act, and just compensation shall be paid to the Lessee £or such suspension. Sec. 14. Indemnification. The Lessee shall indemnify thc Lessor £o~, and hold it harmless f:om, any claim, includina claims for loss or damaEe to property or injury to ~ons caused by or resultinE from any operaLion on the leased area conducted by or on behalf of the Lessee. However, thc Lessee shall not be held responsible ~o the Lessor under this section for any loss, dameEe, or ~jury caused by or resultin[ from: fa) neEli~ence of the Lessor other than the commission or omission of a discretionary functim~ or duty on the pa~ of a Fedcral a~ency whether or not the discretion involved is abused; or (b) the Lcssee's compliance with an order or directive of the Lessor sEa,st which an administrative appeal by the Lessee is filed before ~e cause of action for the claim Sec. 15. rOi~position of Production. fa) As provided in Sec- tion "' ~"~ ~(,~,,~-~ of the Act, the Lessor shall have the right to purchase not more than 16-2/3 percen~ by volume of the and fas produced pursuant to the lease at the regulated price, or if no re,fated price applies, at ~he fair market value at the well head pf the oil and gas saved, removed, or sold, except lhat any oil or gas obtained by the Lessor as royalty or net profit share shall be credited against the amount that may be purchased under ~is subsection. (b) As provided in Section 27(d) or the Act, the Lessee shall take any Federal oil or gas for which no acceptable bids are received, as determ~ed by :he ~ssor, and which is not ffansfe~ed to a Federal agency pursuant to Section 27(a)(3) of the Act. and ~ha~ ~y to th~ ~e~or a ~a~h amount . , August 9, 1988 Mr. L. Smith Alaska Oil and Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 SUBJECT: SUBMISSION OF APPLICATIONS FOR SUNDRY APPROVAL FOR BF-47, 0CS-Y-0181, BF-57, AND OCS-Y-0180 REFERENCE: TELEPHONE CONVERSATION ON 8/8/88, MR. L SMITH AND MS. S. B. BROWN ' This letter is to further clarify that Shell Western E & P Inc.'s intent of our Sundry Notices submitted August 3, 1988 is to suspend the Seal Island wells in a manner that will remove any potential environmental hazard due to possible future storms. We plan to leave the wells in a condition to be easily re-entered with a rig when field development commences or allow for removal of the casing and wellheads without a rig if future island storm damage warrants. Also included in this submittal are~ Applications for Sundry Approval {submitted in triplicate) fom the above-mentioned wells. These should replace those forms previously submitted. If you have any additional questions, please call me at (907) 276-2545. Very truly yours, W. F. Simpson Manager Regulatory Affairs WFS/SBB/ljm Enclosures: Notices of Sundry Approval (12) RECEIVED SBBH/aogcc. 080588 AUG ! o 19BB , ~ Armhorage ,- · APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend I~ Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator Shell Western E&P Inc. 3. Address 601 West Fifth Avenue~ Suite 810, Anchorage~ AK 99501 4. Location of well at surface At top of productive interval At effective depth 1530' FSL, 6/+2' FEL~ Sec. 11, T13N, R13E, UN 295' FSL, 1130' FEL,Sec. 12, T13N, R13E UN At total depth /+5' FSL, 900' FEL, Sec. 12, T13N, R13E, UN 5. Datum elevation (DF or KB) 55./+' KB feet 6. Unit or Property name Seal Island 7. Well number 0CS-Y-0181 No. 1 & Redrill No. 1 8. Permit number 8/+-17 9. APl number 50-- 029-2107/+ 10. Pool Wi ] dcat 11. Present well condition summary Total depth: measured true vertical Effective depth: 13078' feet Plugs (measured) 11/+15, feet measured true vertical '-' Casing Length Size Structural Conductor 2/+9' 20"DP Surface 2650' 13-3/8",72#,N80 Intermediate 12288 ' 9-5/8",53.5, #N80 Production 1075' 7",32#,L80 Liner Perforation depth: measured Zone I - 1272/+'-12738' feet Junk (measured) feet Cemented Measured depth True Vertical depth Drive Pipe 2/+9' 5/+/+/+ sx Permafrostll 2650' 1/+50 sx "G" 12288' 2/+0 sx "G" 11997'-13072' Zone II - 12526'-12576' true vertical Zone I - 11112'-1112/+' Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) 12.Attachments Description summary of proposal W~II ~IA~DAU 13. Estimated date for commencing operation August 20, 1988 (Previously cemented. ) Zone AUG 1 o 1988 Packers set. at 11976 Alaska i:lil & Gas Cons, i,0mr~smm, Detailed operations pro~ira~ ~l}c~q~l~ sketch [] 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoin~ is true and correct to the best of my knowledge Signed . ' - Title Division ODerations Mi~q~r ~ - ~/ Commission Use Only Conditions of approval Approved by Notify com .m'i'S'sion so representative may witness I Approval [] Plug' i~t~'{irity [] BOP Test [] Location clearanceI ORIGINAL SIGNED' BY LONNIE C, SMITH Form 10-403 Rev 12~-85 Approved Copy eturned Commissioner __ REVISED 8/8/88 ~ No. ~ ....~.~-.,~,/~..~ by order of the commission Date Submit in triplicate August 5, 1988 Mr. B. Wondzell Alaska Oil and Gas Conservation Commiss ion 3001 Porcupine Drive Anchorage, Alaska 99501 Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 'T:bi~ M I ' COMM I RES ENG L SR ENG I SR ENG I SR GEOL SR GEOL ENG ASST I .T._.L STA. Z..T_E_gH I STAT TECHI · -.fl 'E: Dear Mr. Wondzell: SUBJECT: SUBMISSION OF APPLICATION FOR SUNDRY APPROVAL FOR TEMPORARY ABANDONMENT OF BF-47, 0CS-Y-0181, BF-57, AND OCS-Y-0180 REFERENCE: TELEPHONE CONVERSATION ON 8/5/88, MR. B. WONDZELL AND MR. WAYNE SIMPSON This letter is to further clari~ that Shell Western E & P Inc.'s intent of our Sund~ Notices submitted August 3, 1988 is to temporarily abandon the Seal Island wells in a manner that will remove any potential environmental hazard due to possible future storms. We plan to leave the wells in a condition to be easily re-entered with a rig when field development commences or allow for removal of the casing and wellheads without a rig if future island storm damage warrants. If you have any additional questions, please call me at (907) 276-2545. Ve~ truly yours, W. F. Simpson Manager RegulatO~ Affairs WFS/ljm '' Ar]chorage SBBH/aogcc. 080588 SEAL ISLAND ABANDONMENT. This enclosure encompasses our planned operations to modify the existing Seal Island well bores to comply with the present State requirements for abandonment and plugging, except for removing the wellhead and casing to two feet below the mud line. This work is recommended in case a severe storm(s) damages the island and wellheads to the degree that a rig can not move over a well without significant complications. By approval and completion of this proposed plan we intend to have gained full compliance with all aspects of Article 2, Section 105 of the April 2, 1986 State Regulations administered by the Alaska Oil and Gas Conservation Commission. Our proposed plan effectively segregates all portions of the well bores preventing vertical movement of fluid within them. All surface abandon- ment requirements will also be met. On Seal #1, the existing temporary abandonment surface cement plug will be drilled up and a permanent abandonment cement plug set in order to comply with existing regulations. All annuli exposed to potential sources of fresh water will be plugged with sufficient cement to effectively seal the annular space. Intervals below and between all plugs are filled with fluids of a density greater than the pore pressure equivalent density for each interval. The higher mud weights used to drill intervals of the wells (which were greater than the weights of the abandonment fluids presently in the wells) were used solely for shale stability and not for well control purposes. Attached is our proposed plan to prepare each well for abandonment and plugging (in case such is required in the future as a result of a severe storm) along with a schematic of the proposed condition of each well at the conclusion of these operations. VEU8/072588 SEAL #2 (OCS-Y-0181 #1) ABANDONMENT PROGNOSIS NOTE' All depths based on 79' from KB to sea level 1) Move rig over wellbore. Check all wellhead components for trapped gas. Nipple up annular preventer. 2) Pump into 9-5/8" x 13-3/8" annulus with 10.2 ppg CaC12 water just enough to establish an injection rate. 3) Squeeze 500 lineal feet (174 sx) of permafrost cement into annulus; r ' displace with 10.2 ppg CaClo wate 17 below mud line (sufficient cement to effectively seal the annular space per 20 AAC 25.105.i.2 and cement across permafrost must have a low heat of hydration per 20 AAC 25.105.j) 4) Run 1" tubing in annulus to confirm the location and the competency of the cement plug (per 20 AAC 25.105.1). VEU8/071588 i~I::AL .-.~2 [OCS-Y-0181 · 1) '-PRESENT CONDITION 9.7ppg CaCl2 9.7ppg CaCI2 8/5/87 NOT '1'O SCALE KB=0' · - ~ TOP OF ISLAND 56' f~,-~.~ ..4 , ,,e.,.;~ SEA LEVEL at ,79 .~-~!~ TOP JOB at 80' ! MUD LINE at, 118' ...,, .;J CMT in 9-5/8 at 135' ~..~J)';.'i~ CMT in ANNULUS at ? :.-;i~!~,~20 at 249' . , ~:~i:~ CUT in 9-5/8 at 335 :~'.-~.;E. CMT mn 9-5/8 at 1648 · ;'~¥.'_'~CMT in 9-S/e' a~ 1?SO' · r_*.~'~.:~BOT of ARCTIC PAC 1979' ' ~,::.~ii_~SQZ PERF at 2200' ~e~.~ BOT of DIESEL at 2547' ~'""~"'~'"SQZ PERF at 2590' TOP CMT at 2610' 13-3/8' at 2650' CMT at 9650' CMT in 9-5/8' at 11890' 7' LINER at 11997' 9-5/8' at 12288' CMT RETAINER at 12380' PERF at 12526-12576' 9.7ppg CaCI CMT at 12672' CMT RETAINER at 12698' PERF at 12724-12738' 9.7ppg CaCl2 7' at 13072' TD at 13O78' SEAL ~¢ 2 [OCS-Y-0181 ~ 1 .'{ PROPOSED P&A STATUS 7/26/88 Nol To Scale KB=O' TOP of ISLAND 56' SEA LEVEL 79' ;MT in 20' Io 80' 10.2ppg CaCI2 9.7ppg CaCI 9.7ppg CaCl2 MUD LINE 118' CMT in 9-5/8 & 13-3/8' al 135' CMT in 20' at ? 0' at 249' , , ,,..{~MT~[~_9__-,518 lo, 335 I,.~M/ Jn ~3 3/8 ,IO 635 , CMT in 9-5/8 at 1648 CMT in 9-5/8' to 1750' ,SQZ PERF at 2200' BOT of ARCTIC PAC al 2590' SQZ PERF at 2590' TOP CMT at 2610' 13-3/8' at 2650' CMT at 9650' CMT in 9-5/8' at 11890' 7' LINER at 11997' 9-5/8' at 12288' CMT RETAINER at 12380' -- PERF at 12526-12576' 9.7ppg CaCI2 9.7ppg CaCl2 CMT at 12672' CMT RETAINER at 12698' PERF at 12724-12738' 7' at 13072' D at 13078' TELECOPY NO ~ (907) 276-7542 July 22., 1988 Mr. M. L. Woo~son Division Operations Mgr. Shell Western E & P,.Inc. 601 W. Fifth Avenue, Suite 810 Anchorage, AK 99501-225? Dear Pete~ ion'with your Hs. Susan Confirming today's telephone conversatlearn that you alreadvhave Brown, the Commission is gratified to underway plans to repair erosional damage suffered by your ~arttfictal gravel island. Further, you are giving serious consideration to sealing the'surface casing by oil string annulus of each of the three suspended wells on the island early.this fall. We sincerely .appreciate your prompt attention to these matters. Further,. we will look forward to notification as you near com- pletion of this season's island integrity maintenance work so that one of our inspectors may have the opportunity of visiting the site. dlf ~ 1. CVC. 43 cc: Jim Eason, Director Division of Oil & Gas Department of Natural Resources MEMOR, ' M ' Stat , "'of 'Alaska AL AND GAS CONSERVATION '~ ~ISSION "'... .. James E. Eason DATE: ' Director, Div.Oil & Gas . FI LE NO.: June 3, 1987 ' B,~r~A, 33 J THRU: W.W. Barnw61.1~i~: Commissioner FROM: William Van Aleff'f~ Sr Petroleum Geol6gist TELEPHONE NO.: SUBJECT: Release from Confidentiality Shell OCS-Y-181 & Shell BF-§7 No, 1 · Pursuant to your Hay 27, 1987 letter to C. 'G. Svab, copy to C. V. Chatterton, AOGCC acknowledges the following release daces for the repor.~s, and information filed under 20 AAC 258 Well Shell OCS Y-181 Shell. BF-57 _Release..DaCe May 26, 1987 June 10, 1987 2-001 A ( Rev 10-84) United States Department of the Interior MINERALS MANAGEMENT SERVICE ALASKA OUTER CONTINENTAL SHELF REGION 949 E. 36TH AVENUE, ROOM 110 ANCHORAGE, AK 995084302 J~,q 0 ~ L;'.,.:? Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Chatterton: Mr. Bill VanAllen and Commissioner Barnwell of your office recently requested written confirmation that the geological and analyzed geological data from Well No. 1, Lease OCS-Y 0181, drilled by Shell Western E&P, Inc. in the Beaufort Sea, have been released. Please be advised that the above-mentioned data were placed in our public file on May 26, 1987. Sincerely, Supervisor Field Operations August 21, 1986 Transmittal "No. 7357 Alaska Oil & Gas Conservation Commission Al'TN Mr. Bill Van Alen 3D01 Porcupine Dr. Anchorage, AK 99501-3192 R CEIVED AUG 2 5 19116 Alaska 0il & Gas Cons. Commission Anchorage Subject: SWEPI et al 0CS-Y-181 No. 1, R/D No. 1 ',Seal' Prospect Beaufort Sea Area, North Alaska · ?~" 2 BLP, I Mylar, NGT, 5" TVD (stretch correCted) "~2 BLP, 1 Mylar, NGT, 5" {stretch corrected) ~2 BL'P, I Mylar, LDT/CNL/NGT, 5" TVD {Raw Data) {stretch corrected) :~ 2 BLP, I Mylar, LDT/CNL/NGT, 5" (Raw Data) {stret*ch corrected} ~2 BLP, 1 Mylar, LDT/CNL/NGT Porosity, 5" TVD (stretch.corrected) . i'.:'..'."'~ 2 BLP, I Mylar, LDT/CNL/NGT, 5" Porosity {stretch corrected} BLP I ar, .'. './..].'i:..i...:..:.~ii?i,]i'.;~ 2 , Myl Proximity-Microlog, 5" TVD (stretch corrected) · .:~.'.~:iiiiil;i!'!~"~i~,~'2 BLP, 1 Mylar, Proximity-Microlog, 5' (stretch corrected) ' "'.".'.?.,~;.fi?~~2 BLP,- 1 Mylar, Logarithmic Dual Induction-.SFL-GR, 2" & 5" TVD {stretch corrected) "'.'"'.':::"/:C.::?~2 BLP, 1 Mylar,' Borehole Compensated Sonic, 2" & 5" {stretch corrected) ~.! ~ BLP, .1 Mylar, Logarithmic Dual Induction-SFL-GR, 2' & 5" (stretch corrected) . ' ;'!~i 'BLP I Mylar, Linear Dual Indu~tion-SFL-GR, 2' & 5' TVD (stretch corrected) ', BLP, I Mylar, Borehole Compensated Sonic, 2" & 5" TVD {stretch corrected) ~/2 BLP, 1 Mylar,'Linear Dual Induction-SFL-GR, 2" & 5" {stretch corrected) , BLP, 1 Mylar Porosity LDT/CNL/NGT, 2"'TVD {stretch corrected) ~ BLP, 1 Mylar LDT/CNL/NGT, 2" Porosity (stretch corrected} ~_ BLP, I Mylar I~GT, 2" {stretch corrected) ~.~ ~2 BLP, I Mylar, LDT/CNL/NGT {Raw Data}, 2" TVD {stretch corrected) "~2 BLP, 1 Mylar, LDT/CNL/NGT {Raw Data}, 2" {stretch corrected} "~j2 BLP, I Mylar, NGT, 2" TVD (stretch corrected) / ~mmm~ ~m NOTE:. These logs have been stretch-corrected by Schlumberger. Please replace the original uncorrected logs and mylars with these logs. RE'CEI?¥ED AUG 2 5 198 ,A,I~I(~ Oi,I & Gas Cons. Commission CRCC8623304 SWEP-293 TO: SHELL WESTERN E&P INC. PACIFIC FRONTIER DIVISION P. O. Box 527 HOUSTON, TEXAS 77001 ATTN' M. A. Balzarini 1330 Woodcreek Alaska Oil & Gas Conservation Commission ATTN Mr. Bill Van Alen 3001 Porcupine Dr. Anchorage, AK 99501-3192 We transmit by U.S. Mail QUANT ITY DESCRIPTION OF ITEN I Stretch-Corrected TVD LIS Tape with Verification Listing DTNA Date 8/21/86 Transmittal No. PD- 7357 Subject: SWEPI et al OCS-Y-181 No. 1 "Seal" Prospect Beaufort Sea Area North Alaska the fol 1 owi ng: REG. NO, DISPOSITION See attached page Sender' s ~ gnature PLEASE SIGN AND RETURN COPY OF THIS MEMORANDUM Above items received, except as noted: Date CRCC861602 WHITE (ORIGINAL) YELLOW (1st COPY) PINK (2nd COPY) -ADDRESSEE (RETAIN) -ADDRESSEE (SIGN AND RETURN TO SENDER) -SENDER's "'HOLD" FILE August 21, 1986 Transmittal No. 7357 Alaska Oil & Gas Conservation Commission ATTN Mr. Bill Van Alen 3001 Porcupine Dr. Anchorage, AK 99501-3192 Subject: SWEPI et al 0CS-Y-181 No. 1, R/D No. 1 "Seal" Prospect Beaufort Sea Area, North Alaska "~2 BLP, 1 Mylar, NGT, 5" TVD (stretch corrected) ~"2 BLP, 1 Mylar, ~NGT, '5" (stretch corrected) ~'~2 BLP, I Mylar, LDT/CNL/NGT, 5" TVD (Raw Data) (stretch corrected) '"~2 BLP, 1 Mylar, LDT/CNL/NGT, 5" (Raw Data) (stretch corrected) '"~2 BLP, I Mylar, LDT/CNL/NGT Porosity, 5" TVD (stretch corrected) '~u2 BLP, 1 Mylar, LDT/CNL/NGT, 5" porosity (stretch corrected) '"~2 BLP, 1 Mylar, Proximity-Microlog, 5" TVD (stretch corrected) '"~2 BLP, I Mylar, Proximity-Microlog, 5" (stretch corrected) "-~2 BLP, I Mylar, Logarithmic Dual Induction-SFL-GR, 2" & 5" TVD (stretch corrected) I-~2 BLP, I Mylar, B:or,ehole Compensated Sonic, 2" & 5" (stretch corrected) ~'~2 BLP, I Mylar, Logarithmic Dual Induction-SFL-GR, 2" & 5" (stretch corrected) "~2 BLP, I .Mylar, Linear Dual Indu~tion-SFL-GR, 2" & 5" TVD (stretch corrected) '"~2 BLP, I Mylar,. ,Borehole Compensated Sonic, 2" & 5" TVD (stretch corrected) -"~2 BLP, I Mylar, Linear Dual Induction-SFL-GR, 2" & 5" (stretch corrected) '"~2 BLP, I Mylar, Porosity LDT/CNL/NGT, 2" TVD (stretch corrected) ~"J2 BLP, I Mylar, LDT/CNL/NGT,' 2" Porosity (stretch corrected) '"-~2 BLP, I Mylar, NGT, 2" (stretch corrected) '"~2 BLP, I Mylar, LDT/.CNL/NGT (Raw Data), 2" TVD (stretch corrected) '"-2 BLP, 1 Mylar, LDT/CNL/NGT (Raw Data), 2" (stretch corrected) ~-~2 BLP, 1 Mylar, NGT., 2" TVD (stretch corrected) NOTE: These logs have been stretch-corrected by Schlumberger. Please replace the original uncorrected logs and mylars with these logs. Aiasl~a Oil & Gas Cons. Anchorage CRCC8623304 July 30, 1986 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ATTN' Commissioner C. V. Chatterton Shell Western E&P Inc. .,. '~'~'~,:~:,~,~ 601 West Fifth Avenue * Suite 810 1'CO~''~ '~' Anchorage, Alaska 99501 ~ ................ i '!.':,?:~ ~¥.-.: .,,..- ~ ,.c... ~:~ ,.9. '"--.;7. L { ' l--' '.--"..-:~..:-'"' ::'.. ~' t F i'!('.": :':::::',"- T I / IFil,E: Director Department of Natural Resources Division of Oil and Gas Pouch 7-034 Anchorage, Alaska 99510 SUBJECT: PARTIAL RELEASE OF CONFIDENTIAL DATA ON FEDERAL WELL 0CS-Y-0181 No. 1 Gentlemen: Reference is made to recent discussions with the Department of Natural Re- sources and the Alaska Oil and Gas Conservation Commission concerning the release of proprietary data from the subject well which was drilled from State land but bottomed under Federal land. It is our understanding that the State will release only that portion of the well data that pertains to the State Lease (ADL-312799) and will not release that portion of the well data pertaining to the Federal Lease (0CS-Y-0181). Our records indicate the State portion of the well data to be released would terminate at 7370' measured depth, or at 6600' TVD. We would be willing to assist or provide' information to AOGCC regarding the delineation between the State and Federal well information. For any information or questions you may have, please contact the undersigned at 263-9626 in Anchorage. We thank you for your cooperation in this matter. Very uly you s, D~. W. Loh~' Land Representative RECEIVED DWL/bc cc: Commissioner Wunnicke Department of Natural Resources, Juneau JUL o Alaska Oil & Gas Cons. Commission Anchorage Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 November 11, 1985 State of Alaska Alaska Oil & Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 Commission Gentlemen- SUBJECT: PRODUCTION TEST REPORT FOR OCS Y-181 #1 In your letter of August 5, 1985, you requested the Production Test Report for the OCS Y-181 #1 well. The desired information is included in the Well Completion Report, which is enclosed. If further reports or information is required, contact Susan Brown at Very truly yours, _~~"~-~ ,~ ~ ~9~ ~r:D. L. Yesland Sr. Staff Environmental Alaska Division Engineer SBB/kka Enclosure Anchora[t~ SBBC/aogcc. lc Shell Western E&P inc. A Sub$i(liery of Shell Otl Complny 200 N. Dairy Ashford P.O. Box 527 Houston. TX 77079 August 2, !984 Alaska Oil & Gas Conservation 'Commission ATTN C. V. Chatterton 3001 Porcupine Anchorage, AK 99501 Gent l emen: Enclosed for your information is the Well Completion Report on Form 10-407 for Shell Western E&P Inc.'s well 0CS-Y-181 No. 1 on Seal Island. A separate form is attached for the two production tests. Also enclosed is a complete Well History Summary Report. Please treat these reports as confidential material. If you have any questions, please contact me in Houston, telephone (713) 870-4445. Yours very truly, R. G. Hollis Manager Production Administration Pacific Frontier Division RGH'jc Enclosures bc' M. L. Woodson RECEIVED Nov 2 ~ 1985 Alaska 0il & Gas Cons. Commission Anchorage RGH52151 .,:. .~' STATE OF ALASKA (,. ALA:,.*.:~ "~L AND GAS CONSERVATION . v"./IISSION WELL COMPLE' OR RECOMPLETIO . EPORT AND LOG 1. Status of Well Classification of Service Well OIL f-I GAS r"] SUSPENDED [] ABANDONED [] SERVICE [] 2. Neme of Operator 3. Address 4. Location of well at surface. At Top Producing Inter~al At Total Depth 5. Elevation in feet (indicate KB, DF, etc.) 12. Date Spudded 17. Total Depth (MD+TVD) 6. Lease Designation and Serial No. 13. Date T.D. Reached 18. Plug Back Depth (MD+TVm 22. Type Electric or Other Logs Run 7. Permit Number 8. APl Number 50- 9. Unit or Lease Name 0C5 Y-181 10. Well Number No. ! & Redr'Jll Nh. 1 1 1. Field and Pool 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions I feet MSL 19. Directional Survey I 20. Depth where SSSV set I 21. Thick,els of Permafrost YES I--I NO .I-I I feet MDI '. 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 24. Per~orations open to Production (MD+TVD of Top and Bottom and interval, size and number) Zone ! I 12526'-12576'~D . 10945'-10987'TVD 4 Holes per foot, ½", 200 Holes 25. TUBING RECORD , DEPTH SET (MD) PACKER SET '(MD) SIZE 12480' 11976' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production 6/22/84 Date of Test 6/22/84 Hours Tested 53 Flow Tubing Casing Pressure Pr,ss. 1257 2000 28. Method of Operation (Flowing, gas lift, etc.) Flowing TESTPERIOD I~ I 4378 9240 62 I 2"' I 2110 CALCULATED ' I OIL-BBL GAS-MCF WATER-BBL lOlL GRAVITY-APl {corr) 24-HOUR RATE I~I 4903 12800 28.1 I 39.5 CORE DATA Brief description of ,ithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chil~ ~[~ L ~ t ~? g A~aska Oil & Gas Cons. ,. J., ~.. Form 10-407 Submit in dul~lics;e Rev. 7-1-80 CONTINUED ON REVERSE SIDE ALA$1(A OIL ,4ND ~AS ~ONSEIIYATION.~Of4HISSION Bill Sheffield, Governor 3001 PORCUPINE DRIVE ANCHORAGE.ALASKA 995014-3102 TEL E PHONE (907) 279,- 1433 .,C, G. Permit NO. ~-/~ We wish to bring to your attention that the Co~ission has no~ yet received the following required items on ~he subject well which our records indicated was completed ~-,~-~ Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled.well. Please submit the above missing material. erely. )/~ Chairman lc:C.024 RECEIVED Nov 2 9 t985 Alaska Oil & Gas Cons. Commission Anchorag3 AL&SIM OIL Bill Sheffield, Governor 3001 PORCUPINE DRIVE ANCHORA~GE.ALASKA 99501.l-3192 TELEPHONE (907) 279,- 1433 ~A~.: /~-// ~ / ~o, .. Ch EL L ~~S ~E g N EX~ ZNC, We w~sh to brfng to your attention that the Com~s~on ha~ no~-' yet received the fol[ow~ng required ~tems on the ~ubjeee well which our reeord~ ~ndteated was eomploted ~-~-~ T~.~T ~#oi-~ Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates, that this material shall be filed within 30 days after completion of a drilled.well. Please submit the above missing material. Chairman lc:C.024 NM: DO Unlted States Department of tl e xnterior MINERALS MANAGEMENT SERVICE ALASKA OCS REGION Mailing Address: P.O. Box 101159 Anchorage, AK 99510 ~reh 7, 1985 2 ENG 4 ENG __ ~ ' I~GEOL ........ ~ CONR~R: Shell Western E&P Inc. Attn: G. J. Anderson 601W. 6th Ave., Ste. 810 Anchorage, AK 99501 Gentlemen: The two directional Federal Wells, OCS-Y 0181, Well No. 1, and OCS-Y 0180, Well No. 1, located on Seal Island in the Beaufort Sea, Sale BF Area have a "State" surface location and a "Federal" bottom hole location. The MMS had initially assigned these wells the following API Nos. 55-201-00005, and 55-201-00006 respectively, based on the bottom hole location. This was an exception to the API Bulletin D12A recommendation. The State of Alaska Oil and Gas Conservation Commission has issued the following API Nos. to the same wells 50-029-21074, and 50-029-21236, respectively, based on the surface location. The MMS will conform to API Bulletin D12A and use the State of Alaska API Well Numbering System for Federal wells that have a surface location on State lands. We request that you change your records to reflect the correct designated API Nos.: o OCS-Y 0181, Well No. 1, API No. 50-029-21074 o OCS-Y 0180, Well No. 1, API No. 50-029-21236 RECEIVED If you have any questions, please call us at 261-4066. Sincerely, Brian F. Schoof Supervisor, District Office Field Operations '~aska 0il & ~:,~xs t;Or]s. [;ummissioN Anchora~a cc:w Commissioner, State of Alaska, 0il & Gas Conservation Commission, Anchorage, AK Mr. Budd Burnett, Petroleum Information, Anchorage Office March 5, 1985 Ms. Susan Brown Shell Western E&P Inc. 601W.'Fifth Avenue, Suite 810 Anchorage, Alaska Re: OCS ¥-181 #1 Dear Ms. Brown: Confirming our telephone conversation of March 5, the API number for the subject well was erroneously .assigned and is therefore cancelled. The API number assigned to this well is: 50-029-21074. Sincerely~ John A. Levorsen, Senior Petroleum GeOlogist lc:B.JAL.3 SWEP-293 .., SHELL WESTERN'E&P INC. PACIFIC FRONTIER DIVISION P, O. Box 527 HOUSTON, TEXAS 77001 TO: Alaska Oil & Gas Conservation Commission ATTN Mr. Bill Van Alen 3001 Porcupine Dr. Anchorage, AK 99501-3192 DTNA Date 12/5/84 Transmittal No. PD- 5967 Subject: OCS-Y-181 #I OCS-Y-IS1 #1 (R/D #1) QUANT I TY 1 We transmit by U.S. Mail the following: DESCR I PTI ON OF ITEM REG. NO. Verification Listing for Merged Composite Tape of 0CS-Y-181 #1 DISPOSITION I Verification Listing for Merged Composite Tape of OCS-Y-181 #1 (-R/D #1) '~ender' s S~~ur~ ' PLEASE SIGN AND RETURN COPY OF THIS MEMORANDUM Above items received,.e~cept as noted: ~~ " ~ ~ E ' Date .~JGS'n:& Oii& aas Cons. C0mmi~E (ORIGINAL) Anchorage YELEOW (1st COPY) PINK (2nd COPY) -ADDRESSEE (RETAIN) -ADDRESSEE (SIGN AND RETURN TO SENDER) -SENDER's "HOLD" FILE TO: ~1~293 SHELL WESTERN'E&P INC, PACIFIC FRONTIER DIVISION P, O. Box 527 HOUSTONs TEXAS 77001 Alaska Oil & gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501-3192 ATTN C. V. Chatterton ,., DTNA Date 10/2g/84 Transmittal No. PD- 5869 Subject: 0CS-Y-181 t/1 OCS-Y-181 //1 (R/D //1) We transmit by QUANT I TY 1 U. S. Mail the fo(lowing: DESCRIPTION OF ITEM REG. NO. DISPOSITION Merged Composite Tape of 0CS-Y-181 //1 Merged Composite Tape o)'0CS-Y-181 //1 (R/D//1) /./ ~EASE SIGN AND RETURN COPY OF THIS HENORANDUM Above items recetveds except as noted: Date ',CE E ' - .WH.I TE (ORIGINAL) Al.~im,... Oil & Ga;h Con;. uomml~Lq~ow (lst coPY) anc..orage PINI(" (2nd COPY) -ADDRESSEE (RETAIN) -ADDRESSEE (SIGN AND RETURN TO SENDER) · -SENDER's "HOLD" FILE .~WEiP-293 TO: QUANTITY DTNA SHELL WESTERN E&P INC. PACIFIC FRONTIER DIVISION P. O. Box 527 HOUSTON, TEXAS 77001 Alaska Oil &6as Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501-3192 ATTN C. V. Chatterton Date 10/29/84 Transmittal No. PD- Subject: 0CS-Y-181 #1 0CS-Y-181 #1 (R/D #1) 5869 We transmit by U. S. Mail the following: I ~ DESCR I PTI ON OF ITEM REG'. NO. Merged Composite Tape of OCS-Y-181 #1 DISPOSITION Merged Composite Tape of OCS-Y-181 #1 (R/D #1) ~ L=~EASE SIGN AND RETURN COPY OF THIS MEMORANDUM Above items received, except as noted: - WHITE (ORIGINAL). Alumna 04! & Gas Cons. Anchorage (1 st COPY) PINK' (2nd COPY) -ADDRESSEE (RETAIN) -ADDRESSEE (SIGN AND RETURN TO SENDER) -SENDER's "HOLD" FILE October 11, 1984 Shell Western E&P Inc. A Subsidiary of Shell Oil Company 200 N. Dairy Ashford P.O. Box 527 Houston, TX 77079 U. S. Department of the Interior Minerals Management Service ATTN Mr. Brian Schoof Supervisor District Oil and Gas Office Offshore Field Operations 411 West Fourth Street, Suite 2A Anchorage, AK 99501 Alaska Oil and Gas Conversation Commission ATTN Mr. Harold Hedlund 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen' Enclosed for your information are duplicate copies of the Well Completion or Recompletion Report and Log form with revised well pro.ducing interval and total de_~p_~h_.]ocatioD~, for Shell~rn E&P 'Inc.'s Seal Island Well OCS~Y-181 "~1 ..... ~-6]' 1'. A surveyor's plat of these locations is also enclosed. RGH' jc Yours very truly, R. G. Hollis Production Administration Manager Pacific Frontier Division Enclosures RGH52851 RECEIVED OCT e e ~,laska Oil & Gas Cons. Commission Anchorage U.T.M 'Zone 6 Y = '7~821~454.027 ~ X = 456~896.075 CONDUCTOR ,,~ Il ~3. U.T.M. Zone 6 Y= 7,820,948.950 X: 438,365.385 ..... ..TOP OF PRODUCIN~ FORMATION AS BLT. LOC'N. C-ONDUCTOR OCS'Y't'8~ AT II,liP- FT. T.V.D. Y= 6~ 0;2,9~ 885,4 5 X= 664~723.07 L.A'T; .: 70~'29' 16.444" LONG.= i056'EE.t..i 6 'F.S~L. S. ~2.~ "r. 13 N.,R.~3 E.,U. M.,.AK, BASED ON GYRO iNFORMATION PROVIDED BY SHELL OIL CO. ON 9'1~'84. i HEREBY' CERTIFY THAT I AM PROPERLY' REGISTERED AND LICENSED TO F'RACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THiS PLAI' REPRESENTS AN AS-BUiLT SURVEY MADE BY ME, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT, AS OF: 9- ~[?.-84 OES. O. B. CH~. d.B. ................... c,,n, LL ~.!o~ N o. ' C 0 M PA N Y iIt.~,IilI~ iim~lmrl~m ..... . ,,~.', ,,.'t¢..,,~ ,,'.~.. -,."~..~ ';,' .. ' ' ' ~ ( a, '~.' ~, .,,,:~ ,,A~' ...'" ~'.',%., '. , ' a:;' C")~' ,"' '~;~ '"?,. "'"'"~;' ?' ' '...' ...... ~,~".,.,.' ..,' '"...'"'..,,;, .... '",'; ....... :~' .. T M. p~, ,'". ,c'.~n: ~,','~ .~,. ~ .,', ~ '". '"~t '. · ' ~.., ~ ",' .,'..,. '.'.,'.~ ',, . ........ ,,, COORDN. ;;,~. ~ ..... ,~ ...... ~.,,~..,.,~ ...... , .... · .,~":~:, .....:... .... R E C ElY E D ""~' , ~ ,',~ [. ,, ,,., . s ~ ~~', ,,~'~{~['~ ~ .... ~ ..t.,,, ~.~ .. .,. ,,. .... ~ .,... .,., ,. ..~.... ~ . :. ..... OCT 2 2,' .... ,.,' .~.~ ~ ~ ,- ,. ~' v~ ~,' ...... . ,~ : .~ .... ~ , ,~' ... .... . Alaska O' ~ · · '~2~ ~.,.:~%.~x...2~:2.~.:?::,; .... II & ~aS ~0~8. ~Offiffi18810 ..... Anchorage SHELL. OIL, SEAL PRODUCING AS BUILT AT I1,112' ISLAND FACtLI'TY s,~.~.~. I FORMATION LOCATION OF 'F. V.D. t FORM ! 0.432 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE WELL RECORD APl NUMBER i~ · . .... " ' DATEOF RECORD CARD CONFID OPERATOR FIELD AND POOL CODE NAME CODE ~lr - NAME ' "'," :",'""' " '"' "'"":'~'~"~:";~':":~""';"::'~' '" ,:"',',i',,':'i",'," :":,'", i,,",,, '",,,,,i i · ...' ~.' ,:i',.', ':"""." .... · ' '' ' ' · "'~"i'. ....... ':" -'2 ...::~..'~:,~'~;'.!':':~'~,~f.,~.::'..:" .:,' '".'~'~,' · , ~ 21 ' ...::., ',. , . .. '.. CARD PERMIT NO. PERMIT ISSUED RQMTS ON:OFF M O Y SAMP MUD SURV OTHER SHORE UNIT NO. LEASE NUMBER WELL NAME AND NUMBER ' .... .... ':' :':-" ', 22 , , SURFACE OCATION - CARD INITIAL WELL LAT LONg SURFACE LOCATION BOTTOM HOLE LOCATION CLASS STATUS DEG MIN SEC DIG MIN SEC FEET DIR FEET DIR SEC T R M FEET DIR FEET DIR SEC J R M · ' . .... -, - ...?' , : :: i~ .!~ :- .. 23 CARD FINAL WELL DATE SPUDDED DATECOMP. ETC ADDITIONAL FLD & POOL FOR MULT. COMP. GEOLOGICAL AREA CI ASS STATUS M D Y M D I Z:r...i? !~ ' ." '~ CODE ~i~!~ =...:.:...i~ !i.~ii: M E il ~~i=!i. '": -~.: '""':::"'"?:'~'~" .... '" ' .... ' .... i~ '?-i :i i!...~i~.;i...; .i'.~: .... ~:'....- ...... . .. _ :'. ........ .. .~!.-::'- ':. . · ' ', , .', " d ,~ ~: . ... CARD 'CURRENT WELL STATUS DATE DEPTHS FOOTAGE -DRILLED ELEVATIONS CLASS STATUS M D Y . MD TYD YR FEET YR FEET YR FEET CODE FEET CODE FEET " ..... ~' ' "' ':' ........ :'?~-' "" '-~' ~- 4:: :~-:-?.~-i.?:-_-~. ',.~..: .- . · .'..)~'. . . ..:... . . .'::.. .. .. . ,, . ,, ,. 2§ [CARD SAMPLE SAMPLES INTERVAL CORE SET NO FROM TO CHINS TYPES OF LOGS AVAILABLE . ' . ' : iL~'i.~ " -. : :.-~'-.-. " :' '--'-- i:~:'f:.- .- :'..-.~': " i~ ~! i:-.'~i 'i i:.':i. ~.i~'.~ '~."- ' ' :.':.-......i::' ?..':: ' '~ '- . -:' .',' -. .... :: : - '",--~i'--;';:- ' '"' ' -' 'i:' ~; ":" ' L' ' · ... 26 ~hell ocs ¥-olgl ...... 1530 J_ TI. 31t] If, 6,3 ~5 ¥"~g3 ' E · . 1.~30 . , · ,. ALA~IM OIL AII~ ~A~ ~OII~EIIYATI#II , ~,OHNI~IOII Bill Sheffield, Governor 3001 PORCUPINE DRIVE ANCHORAGE.ALASKA 99501'1'3~ 92 TELEPHONE (907) 279.-1433 A ~ ~ , ' E, G. //~ II/ ~ RE: Well 0~~/ ' ~o,. ~~./~ r/3~ ~/,~ ~. ~. We w~h to bring to your attont~on that the Com~s~on ha~ no~'' yee received the followfng required ~t~m~ on whfch our record~ ~nd~cated w~ completed Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled.well. Please submit the above missing material. Chairman .- lc:C.024 August 13, 1984 Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 Shell Western E&P Inc. Seal Island OCS-Y-O181 fl RD ~.~ Alaska Oil and Gas Conservation Commission 3001 Porcupine Anchorage, Alaska 99501 Attention: Mike Minder . , Gentlemen: Delivered to you by personal courier the following: 6 boxes of core samples 1) 10396-10504 2) 12301-12430 3) 12431-12560 4) 12561-12678 5) .12679-12802 6) 12803-12872 Please sign the enclosed duplicate' of this letter as receipt of the above. Enclosure , , Date' Very truly yours, D, D. Caddy , Exploration Operations RECEIVED AUG 1 Alaska 0i! & Gas Cons. Commission Anchorage 7/27/84 OCS-Y- 181 No. 1, Redrill No. 1 Transmittal #5674 to Alaska Oil & Gas Commission LOG 2" Linear & Log DIL/SFL (TVD) 2" & 5" BHC Sonic 2" BHC Sonic (TVD) 2" LDT/CNL/NGT 2" LDT/CNL/NGT (TVD) PML 2" & 5" Density-GR (PGT-K) Raw Data GCT-Run 1 Cyberdip GR/CCL 2" NGT RFT RFT Quicklook GCT -Run 2 5" NGT 5" LDT/CNL/NGT Raw Data 2" LDT/CNL/NGT Raw Data NGT TVD) CET 2" & 5" DIL/SFL/GR (Linear) 2" & 5" DIL/SFL/GR (Log) Cyberlook SHDT , CNL/GR (~N) CNL/GR (NRAT) LDT/CNL/NGT CET Run 1 LDT/CNT/NGT (TVD) 2" & 5" Density -GR Porosities I sepia and 2 diazo each of the above. Alaska Oil & Gas Corls. Commission Anchorage Shell Western E&P Inc. A Subsidiary of Shell Oil Company 200 N. Dairy Ashford P.O. Box 527 Houston, TX 77079 August 2, 1984 Alaska Oil & Gas Conservation Commission ATTN C. V. Chatterton 3001 Porcupine Anchorage, AK 99501 Gentlemen' Enclosed for your information is the Well Completion Report on Form 10-407 for Shell Western E&P Inc.'s well 0CS-Y-181 No. I on Seal Island. A separate form is attached for the two production tests. A1 so enclosed is a complete Well Hi story Summary Report. Please treat these reports as confidential material. If you have any questions, please contact me in Houston, telephone (713) 870-4445. Yours very truly, ~;nGa~eHr°~lrlo~ucti on Administration Pacific Frontier Division RGH: j c Enclosures RECEIVED AUG 0 6 ~ Alaska 0il & Gas Cons. Commission Anchorage RGH52152 · WELL COMPLETION OR RECOMPLETION' REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number 3. Address 8. APl Number 50- 4. Location of well at surface 9. Unit or Lease Name OCS Y-181 At Top Producing Interval 10. Well Number No. I ~, ~cJv-~' [( ,~ / ~ At Total Depth 11. Field and Pool "" 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 12. Date Spudded 13' Date T'D' Reached 14'DateC°mp"Susp'°rAband' 115' Water Depth' if offshore 116'No'°fCompleti°nSfeetMSL 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost YES [] NO [] feet MD 22. Type Electric or Other Logs Run 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 1 24. Perforations open tO Production (MD+TVD of ToP and B'~ttom and 25. TUBING RECORD '. interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Zone II 3½" 12480' 11976' 12526'-12576'MD 10945' - 10987 'TVDi 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 4 Holes per foot,' ½", 200 Holes DEPTH INTERVAL (MD) AMOUNT& KINDOF MATERIAL USED ,. 27. PRODUCTION TEST , Date First Production Method of Operation (Flowing, gas lift, etc.) '. 6/22/84 Flowing Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAs-OIL RATIO 6/22/84 53 TESTPER~OD m~ 4378 9240 62 2"I 2110 ' Flow Tubing Casing Pressure CAL'CUL'ATED.~ OIL,BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (c~rr) Press. 1257 2000 ' 24-HOUR RAT.E m?', 4903 1'2800 28.1 39.5 28. CORE DATA' Brief description of lithology, POrosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ., £C£1V£D o 6 Form 10-407 Submit in.duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered ,md gray it¥, GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed_~./~~-~. _ . ,~_z~r-~ Title Div . Prod. Adm. Mgr~ate 7/30/84 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced showing'the data pertinent to such interval. ' Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 :j " Class,iic,J;,on o! Service 1. S:atus of Well OIL ~( GAS '.~. SUSPENDED ~-} ABANDONED [] SERVICE [] "~N~me of Operator 7. Pe;mi! Number JShell Western E&P, [nc. 84-17 8. APl Num i Aodress 6_0.1 W_e_.s.t 5th St., #810, Anchorage, AK 99501 50- 5.5_20!'.-00005._ Iz~i' ~'ocation of well at surface 9. Unit or Lease Lame 1530 FSL, 642 FEL, Sec. 11, T13N, R13E UM OCS Y-181 At Top P~oducing Interval " 10. Well Number 295' FSL, 1130'FEL, Sec. 12, T13N, R13E UN No. l~'~A~<l'.~.y'''''' _ At Total Depth 1 1. Field and Pool 45' FS_L. 90Q]__F__E£, Sec, 12, T13N, R13E UM, nan - 5. Elevation ir~ feet (indicate K~, DF, etc.') I 6. Lease Designat'o d Serial No. Wi 1 dcat 55.4' KB (Cor~e_cted__bY_ surve~v_)] ...... OCS Y-181 (BHL) , 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 2/4/84 5/27/84 6/30/84 39' feet MSL I 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey., 20. Depth where SSSV set I 21. Thickness of Permafrost 13078MD/11415TVD .135'., . ' '. ,:YES[~( N~'I-] _ feetMDI 1700i 22..,'[xpe Electric or Other Logs Run SFL,BHCS, DISFL, LDT, CNL, GR~ SHDT~ NGT~ VSP~ CET, GCT, RFT .... - ...... CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 20" DP 0 249' 20." Drive Pipe -0- 13 3/8" 72# N-80 0 2650' 17¥ 5444 sx Permafrost I'I -0- 9 5/8" 53.5# N-80 0 12288' 12 3/4 1450 sx ,,G,, _0_ 7" 32# L-80 11997' 13072' 8½" 240 sx "G" -0- , 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3½" 12678 11976 Zone I 12724'-12738' MD 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 11112' -111~24'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4 Holes per foot, ½" Holes, 56 Holes 27, PRODUCTION TEST Date First Production Method of Operation {Flowing, gas lift, etc.) 6/12/84 Flowing Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 6/12/84 25 TESTPERIODI~ 339.9 .358 166 20/64I 1053 Flow Tubing Casing Pressure CALCULATED OILoBBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press.303 150024-HOUR RATE m~320 344 160 40.2 28. CORE DATA · Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core .chips. Conglomerate & SandstoneRECEIVED AUG 0 6 19ll ..... Alaska 0il & Gas Cons. Commission Anch0ra.~e 29. GEOLOGIC MAR K~I-~ NAME Colville Pebble Shale Putriver/Kupara Kingak Sag River Shublik Sadlerochit Ivishak Echooka; Lisburne MEAS. DEPTH '/,764 9,982 10,262 10,647 12,232 12,348 ...... 12,451 12,833 12,924 12,960 TRUE VERT. DEPTH 6,903 8,791 9,032 9,367 10,700 10,796 10,887 11,210 11,290 11,322 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered Jnd gravity, GOR, and time of each phase. Production tested as shown on previous page. 31. LIST OF ATTACHMENTS _W...e. 1Z..._._H.~ s.t..0, r..y..,_..P.r_0.d u c_t..i.0 n T.est,_5e.QI_Q~CC· 32 ...... '.;'. I hereby certify that the foregoing is true and correct to the best of my knowledge '" '"';*' ~ '""? ¢~'-/' .-/~ ..... ............" ' ................... i .......... INSTRUCTIONS General' This form is designed for submitting a complete and correct, well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well'is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional, interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whettmr fronl ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attach~:.'d sut)pl~l~'~enl:al records for this well should show the details of any multiple stage cernent- in!:t and tl~e location of the cen~entir')g tool. Itun~ 27' Method of Operation' Flowir~g, Gas Lif't, Rod Pump, Hydraulic Pump, Submersible, Water In- jcctio~'l, Gas Injcct:,'.~n, Stout.in, Ott~er-explain. SEAL -~2 (OCS-Y-0181 PRESENT STATUS 10/12/88 Not To Scale 10.213139 CaCI2 9.713pg CaCl2 KB=O' 'V~ TOP of ISLAND 33' ~ SEA LEVEL,55' MT in 20' to 80 ...... MUD LINE 94' CMT in 9-5/8 & 13-3/8' al 187' CMT in 20' al ? ~...~ .3~ :.:::~...~.~.~ ~-20' at 249' ....~MT_in_9_-.5/8' lo 335' ~ ~J~ ,n 13.3/8 .to687' , 1~,5,.~ CMT in 9-5/8 at 1648 ~! CMT in 9-5/8' to 1750' ~,'~SQZ PERF at 2200' ~'.~:~ BOT of ARCTIC PAC at 2590' SQZ PERF at 2590' ~,~TOP CMT at 2610' . 13-3/8' at 2650' CMT at 9650' CMT in 9-5/8' at 11890' 7' LINER at 11997' 9-5/8' at 12288' 9.7ppg CaCI2 CMT RETAINER at 12380' ~ PERF at 12526-12576' 9.7ppg CaCl2 CMT at 12672' CMT RETAINER at 12698' PERF at 12724-12738' 7' at 13072' D at 13078' SUMMARY OF OPERATIONS OCS-Y 0181 Seal #2 1) 2) 3) Squeeze 9-5/8" x 13-3/8" annulus with 170 sx (500 lineal feet) of Cold Set II cement (15.0 ppg, 0.961 cf/sk) followed by 10 bbls of 10.2 ppg CaC12 water. Ran 8-3/8" drift inside 9-5/8" casing to 24' below mud line. Pressure tested cement job to 2000 psi. This was witnessed by Randy Howell of Minerals Management Service. Tested good. 4) Test squeeze between 9-5/8" x 13-3/8" annulus to 1500 psi for 15 mins. VEU8/101388 )/' -l ~f Colville I~ebble Shale Cretaceous Unconformity Kingak Sag River Shublik Sadlerochit Ivishak Echooka L-isburne TD (Driller's) PRIVATE A~D CO;:FIDENTAL SWEPI 'E:F"-AL OCS2Y- 18-1--~EDRILL BEAUFORT SEA AREA NORTH ALASKA MD 7,764' 9,892' 10,262' 10,647' 12,232' 12,348' 12,451' 12,833' · 12,924' 12,960' 13,078' TVD 6,903 8,791 9,032 9,367 10,700 10,796 10,887 11,210 11,290 11,322 11,415 Core # 1 Core # 2 Core # 3 Core # 4 Core # 5 Core # 6 Core # 7 Core # 8 Core # g Core # 10 Core # 11 Core # 12 Core # 13 Core # 14 Core # 15 · Core Depths 12,301-12,361' 12,361-12,421' 12,421-12,424' 12,424-12,466' 12,466-12,513' 12,513-12,534' 12,534-12,549' 12,549-12,598' 12,598-12,627' 12,627-12,634' 12,634-12,654' 7" Cut 60, Rec. 58' 7" Cut 60' Rec. 59' Cut'3.' Rec. 3" Cut 42' Rec. 40' 10" Cut 47' Rec. 42' 6" Cut 21' Rec. 11" Cut 15' Rec. 14' Cut 49' Rec. 48' Cut 29' Rec. 27' 10" Cut 7' Rec. 7' CUt 20' 7" Rec. '20' 10". 12,654' 7"-12,711' Cut 56' 6" Rec. 48' 6" 12,711-12,760' Cut 4g' Rec. 48' 12,760-12,812' Cut 52' Rec. 43' 12,812-12,872' Cut 60' Rec. 60' Final 7/30/84 *This hole was lost and plugged back to 2600' and redrilled from 2600' to 13078'; thereby creating two sets of geologic markers. OCS Y-181 SUMMARY 2/ 4/84 - Spudded. 20" drive pipe @ 249'. Drilled 17 1/2" hole from 250' to 980'. 2/ 5/84 - 2/ 6/84 Drilled to 2650'. Cite & condltloned hole & mud to run 13 3/8" casing. Rigged up to run casing. Ran 13 3/8", 72#, N-80 BTC casing to 2650', Stab- in float collar at 2610'. Ran stab-in tool on DP and elrculated in casing, then stabbed in and circu- lated through float. 2/ 7/84 - Mixed and pumped 2900 sx Permafrost II (520 BBLS). Slurry wt 14.9 PPG. Stab-in came unlatched or leak- ed during job allowing cement to fill 13 3/8" casing. Circulated cement out of casing. Cleaned out cement. Ran temperature survey. Tested casing to 1800 psi. WOC. 2/ 8/84 - 2/ 9/84 Ram CBL. Drilled out float collar and shoe. Pres- sured casing to 2000 psi (1.2 psl/ft). Ran CBL from 2650'. Ran spear and freepoint tool and worked cas- ing to 400,000#. Freepoint 1200'. Perforated 2590- 2592'(8 holes). Holes would not breakdown. Perfo- ' rated 2198-2200'(8 holes). Established circulation from holes at 2590' to holes at 2200'. Established circulation from 2200' to surface. Set cmt retainer at 2550. 2/10/84 Pumped 5 BBLS water ahead. Mixed and pumped 500 sx (81BBLS) Permafros.t II cmt, followed by 2 BBLS water displaced with 37 BBL mud. Slurry wt 14.9 PPG. CIP WOC. Tagged cmt at 1901'. Cleaned out to 2220'. Circ at 2230'. POOH. 2/11/84 - 2/12/84 Circ 'to surface thru perf$ @ 2200'. Pumped 1900 sx Perma- frost II to surface. Nippled up 13-5/8". Iested to 1500psi. / Pumped 144 sx P~rmafrost II through 1-1/4" tbg ~ 80', be- tween 13-3/8" & 20" csg. 2/13/84 Tested BOP to 5000 psi, hydrill to 2500 psi, choke manifold to 5000 psi and kelly with all valves. RIH and drilled out retainer at 2148-51'. Cleaned out cmt to 2226'. 2/14/84 Drilled to 2665'. Ran leak off test. Drilled to 2685'. Ran survey. Drilled to 2800'. Ran gyro sur- vey. 2/15/84 - 2/16/84 Dyna'Drilled and surveyed from 2800-3527'. Drilled to 4363'. 2/17/84 - 1/18/84 Drilled to 5855'. Pipe parted. Recovered fish @ 1302'. Cleaned out from 4110- 4225'. 2/19/84 - 2/20/84 Contfnued washing and reaming to 4443'. Drilled and surveyed to 7268'. 2/21/84 - 2/22/84 Tested BOP. Changed to KCL-Shell Polymer mud system. Drilled and surveyed to 8500'. 2/23/84 - 2/24/84 Drilled and surveyed to 9318'. 2/25/84 - 2/26/84 Drz,led and surveyed to 9942'. Was~.J through bridge @ 970~'. Washed to bottom. Held H2S drill. 2/27/84 Drilled to 10245'. ~epaired mud line, gate valve & mud pump line. 2/28/84 - 2/29/84 Drilled to 10399'. Tested BOP, annular preventer to 2500 psi and all else to 5000 psi. Washed and reamed 10210- 10250'. 3/ 1/84 - Drilled to 10411'. Cut Core #1, 10396-10411. Recovered 14'. 3/ 2/84 - 3/ 3/84 Drilled to 10508'. Cut Core i2, 10411-10468'. Recovered 57'. Cut Core ~3, 10468-10508'. Recovered 40'. 3/ 4/84 - 3/ 9/84 Drilled and surveyed to 11545'. BOP and Manlfold equipment tested okay. Reamed & washed. 3/10/84 - 3/11/84 Drilled to 11596'. Increased mud wt. to 10.8+. 3/12/84 Increased mud wt. to 11.0 PPG. Had H2S drill for all personnel on island. 3/13/84 - 3/16/84 Drilled to 12062'. Tested BOP. 3/17/84 - 3/18/84 Drilled and surveyed to 12345. Washed 115' to bottom. No fi11. 3/19/84. Drilled to 12467'. Held H2S drill. 3/20/84 - 3/21/84 Logged/Gaamaray 12123-12225'. DP parted. Top of fish @ 7025'. Recovered fish· 'Tested BOP and manifold. 3/22/84 Drilled to 12477'. 3/23/84 -,~.3/24/84 Drilled to'12498'. RIH DLT/HSFL/CAL/SP/GR. Could not get BELOW 8050' REHOYED CALIPER AND STAND OFFS. RAN TO 11785', · ,. TOOL ~A'i['ED RAN BBC'.TO 10956' · 3/25/84 - 3/26/84 Ran DLL/GR to 9069'. Tool'.~"[bck. Fished. Ran H2S drill with all personnel on island. 3/27/8~ - 3/31/84 Tested BOPE to 5000 PSI. Continued fishing. Top 12485'. 4/ 1/84 - 4/ 2/84 ~op of fish @ 12482'r Continued fishing. 4/ 3/84 - 4/ 4/84 RIB'open end drill pipe to 12480. Mixed and pumped 600 sx class G cat with 1~ CFR 2, .3~ Halad 9, 3~ KCL followed by 2 BBL's water, displaced with 209 BBL's aud. Slurry.wt. 16-16.2 PPG. Tested BOP's. RIH. Tagged plug,~'1222.2'. Drilled to 1'2224'. 4/ 5/84 - 4/ 7/84 RIH with Dyna drill. Stuck pipe while seating steering topi. Free @ 3481'. Reran Dia-Log found pipe free ~ @ 4562'. Bac~'ed off @ 4502'. .l 4/ 8/84 - 4/10/84 Washed over and recovered drill pipe to 5443.'. 4/11/84 Ran Dia-Log Csg Callper Survey. Tested BOP. All ok. Per,o- rated DP 10518-10510'. Rigged up Bowco and equalized'1000 cu. ft. Class G cat with 1~ CFR-2 and .SZ Hal,d-9 thru perfs '~ "' , 10510-~0518'~ Backed off safety joint @ 5431~.. 12/84 - ,iii""'{';~i~-~. "~potted 885 sx class G 16.0 PPG cat plug. POOH to 2000'. Circ. hole clean. RIH to 2093'. Top of cmt @ 2152'. Drilled soft cmt to 2600'. WOC. Pressure tested csg to 1800 psi with 9.4 PPG mud. ~-~ - 4/13/84 Clean out cmt 2600-2663'. WOC Circ@ 2663~i~' ..... ~C-"'Clean out .cmt to 2725'~. Circ. RIB with~ Drilled to 3015'. ~__ 4/14/84 - 4/15/84 ~"Drilled to 4921'. Ran wirellne survey. " 4/16/84 Drilled t'o 6054', building angle slowly to 5700'. Held H25 4/17/~.._.~_~[!~/84 ..Dr~.~..~ed and surveyed to 7535'. ........ ~/~284 - 4'~'~i/8q ........ ~rilled to 8033'. Set packer @ 184'. ~ippled do~n BOP stack, weld on new 13 3/8 csg head. Tested to 1500 psi. BOP tested o1:. Lost packer and 5 stds HWDP 60' from surface, RIH with overshot. 4/22/84 Iop of fish @ 7565'. Recovered fish. Drilled to 8131'. 4/23/84 - 4/30/84 Drilled and surveyed to 11117'· 5/ 1/84 - 5/ 4/84 Ws~..d mhd reamed 70' to bottom. D._~led and surveyed to 11832'. 5/ 5/84 - 5/ 7/84 BOP 'tested okay. Circ for samples. Drilled and surveyed to 12288'. Held H2S drill with all personnel on island. 5/ 8/84 - 5/ 9/84 Circ. for samples. R,_an 9 5/8 csg (201 its. 53.5# N-80, 100 its. 53.5# L-80. Shoe @ i2~88'. Float--~6-fiar @ 12199. Pumped 1450 sx Class G cmt with-l% CFR 2, .3% Halad 9, 3% KCL. Slurry wt. 15..8 PPG. Displaced with 862 BBLS water. Bumped plug. No returns over entire job. Filled annulus with 6 BBLS water. WOC. 5/10/84 Nippled down BOP. Installed 9 5/8 csg slips with 450,000~ hanging weight. Cut off csg. Installed 13 5/8 5M x 11 10M csg spool. Tested seal to 3000 psi. Nippled up BOP. Rigged up and ran CET log. Tool failed. Reran. Logged 11930'-9650'. Mixed mud. prehydrate gel in 800 BBLS water. 5/11/84 Ran Gyro 11935' to surface. Ran Dis-Log csg caliper 11775 to surface Tested BOP and Manifold. 5/12/84 Tagged cmt @ 12194'. Displaced water with mud. Drilled float collar and cmt to 12217'. Tested csg to 2500 psi. Drilled cmt, csg shoe @ 12288'. Ran leak-off test eq. mud wt. 14.1 PPG. Began coring. 5/13/84 - 5/16/84 Cored from 12300-12361'. Recovered 61'. Cored from 12361-12421'. Recovered 60'. Cored from 12421-12424'. Recovered 3'. Cored from 12424-12446'. Cored from 12446-12466. Recovered 20'. Cored from 12466-12513. Recovered 42.5'. Cored from 12513- 12534'. BBL jammed. Recovered 11' 9". 5/17/84 - 5/18/84 Cored from 12534-12549."' Recovered 14' 4". Cored from 12564= 12598'. Recovered 48'..~. Ran wire line survey. 5/19/84 - 5/21/84 Cored from 12598-12627'. Recovered"28'. Cored from 12627-12634'. Recovered 7'. Cored 12634-12654'. Recovered 20'. H2S drill. 5/22-/84 - 5/23/84 Cored 12654-12711'. Recovered 49'. Washed and reamed 12708-12711'. 5/24/84 - 5/25/84 Cored 12711-12760'. Recovered 48'. Cored 12760-12812'. Jammed. POOH. Recovered 48'10". Cored 12812-12872'. · 5/26/84 - 5/27/84 Drilled to 13078'. Ran Dis-Log Casing Caliper 11485' to surface. 5/28/84 Ran DIL/SFL/BHC 13058-12268'. Ran LDT/CNL/NGT 13061-8254'. Ran 'SHDT- c~-~"~"t Om 'at' '""~3056,. 5/29/84 Reran LDT/CNL/NGT. Held H2S drill. Checked camp fire alarm. 5/30/84 - 5/31/84 Ran velocity survey, density log and RFT. Tool stuck at 12713'.~ Waited on fishing tool. 6/ 1/84 Recovered fish. 6/ 2/84 - 6/ 3/84 Reduced mud wt to 9.8 PPG. Ran 25 its. 7", 32~, L-80, 8RD, csg as follows: guide shoe, 1 jt 7", float collar, 1 jt 7", landing collar, 23 jt~. 7", Baker PBR, tie back receptable, liner hanger. Dressed liner hanger. Liner stopped at 8067'. Laid down liner. BOPE equipment tested ok. 6/ 4/84 RIH with 8 3/8" washover shoe to 13078'. Circ bottoms up. Short trip to 12288'. Hit something 18' off bottom. Rotated thru. Circ. bottoms up. Bottom clean. 6/ 5/84 RIH with 7" liner. Same configuration as earlier. Tagged bottom at 13078'. Cmtd liner with 240 sx class "G" with 1% CFR-2, .3% Halad 9 and .1% HR-5. Mixed @ 15.8 to 16.0 PPG. Bumped plug 10 BBL early with 3000 psi. Bled back 2 1/2. BBL. Shut well in for 12 hfs with 200 psi. 6/ 6/84 - 6/10/84 WOC while holding 200 psi. RIH to top of liner with 8 1/2" bit and scraper. Tested liner lap @ 3000 psi for !5 min. OkaM. Set packer @ 11836', draw down test liner lap 30 min ok. Tagged top of cmt @ 12820'. Drilled firm cmt to 12975'. DP parted. Recovered fish. %ested csg to 3000 psi for 30 min. DisplAced mud with sea water. Pumped excess mud down 9 5/8 x 13 5/8 annulus. Max psi 575 lbs. 6/11/84 - 6/13/84 Displaced sea water with CaC1. Ran cmt evaluation & gyro 1 . Kan Gamma'Ray. Tested 3 1/2{'~ ....... 9 5/8 ~--,~'us,, to 3000 ¢ psi. Dropped bar. Began testing well. ~/j4/84 - 6/15/84 Kan ?roduction tests. 6/!6/84 - SI for build up. 6/17/84 - 6/18Z84 Ran production tests. Prepared to kill well. 6/19/84 Pumped 160 BBLS 9.8 PPG CaC12 water down tbg 50 BBLS outside perfs at 2800 psi max. Installed BPV. Nippled down tree. N£ppled up BOP. Tested BOP hydrll to 3000 and top rams to 7500 psi. O.K. Pulled tbg out of PBR @ 11975'. 6/20/84 Pulled PB¥ reverse c~rc tbg well dead. Pulled tbg. Tested lower pipe ram, csg rams & choke manifold. Ran CNL/CCL/GR across zone. Ran Howco 7" 32~ cmt retainer and set @ 12698'. 6/21/84 Break down formation with ~300 psi @ 1 CFM & 1BBL @ 4300 psi. Pumped 10 BBL$ water ahead. Mixed and pumped 30 ax. class "G" cmt with 1% CFR 2, .3% Halad 9, .1% HR-5 followed by 5 BBL water displaced with 67 BBL CaC12 fluid. Closed tool w~th 5 BBL water outside. Squeezed 3 BBL cmt below retainer locked up with 4500 psi. CIP @ 1500 hrs. Slurry wt 15.9 to 16.0 PPG. Dropped 3 BBL cmt on top of retainer. POOH. RIH with bit. Tagged cmt @ 12672'. 6/22/84 - 6/23/84 Tested tbg & pbr to 2500 psi. Ran GR/CCL. Tested tree to 10000 psi. Tested production llne to 5000. 6/24/84 - 6/25/84 SI @ surface. Ran 3ohnston DPTT. Flowed well (Pumped 300 BBLS 150 deg. water down 9 5/8" x 13 3/8" annulus). Pumped 150 BBLS hot oil __~ 120 deg. down annulus 9 5/8"x 13 3/8". SI well on bottom w/Otis. Pumping prod fluid down 9 5/8 x 13 3/8 annulus. 6/26/84 - 6/27/84 Nippled up and tested BOP. Kllled well. Laid down tbg and jewelry. 6/28/84 - 6/29/84 Set 7" 32~ cmt retainer @ 12380'. Circ& added Nalco 3900 lnhlbitor .0004% by volume. Mixed & pumped 125 sx class "G" cmt wlth 3% CFR-2, .3% Halad 9, .1% HR-5 followed by 12 BBL water. Displaced 25 BBL water outside. Squeezed 5 BBL water & 3 BBL cmt below retainer. Dropped 22 BBL cmt on top of retaine.~. Est. top of cmt @ 11890'. · ..C.~ ........ S.lu~...~t ......... 1.5...8 to. 15.9 PPG...! RIH to 1750' O/E to lay "' plug 75 sx permafrost. WOC. 6/30/84 Cmt firm @ 1648'. Held 10000~, witnessed by MMS Representative. Pumped 75 sx Permafrost II cmt, wt 15 PPG. Circ. hole clean. Dumped 15 sx CaC12. Installed tbg hanger. Removed test equipment. ND and removed BOP equipment. Installed top flange and valve on well. Released rig. · · W-E:E:K'-'ENDING " ' · AREA OR FII:'LD " co.~ ~.o~,.10'lll. .o,_!o%P, _ "CORE RECORD . co~,^.~ 5WEPI . _ ~ ..... =~ =~~,,--.-~.~o-~-.- .._...~. _--.-__- ~_-. , ~ ..... . . ,, , ·., , , ! . , , ~ ~ · __ T,....~.~,,.,,~'-,-: . , ~ RE:CO I I H D ICA, T IOl'ql':- OiSJ:llV[O I - ~.. NO. FROM TO FORMATIONAI~, STRUCTURAL. AND PROI]AOL. E PRODUCTIVITY DEGCRIPTION OF COg; I%'MOOl. DsP , ..~O_IL-- GA.~ ! CORC OR DITCH J ~ . ~"~;.oo~: c.~,,~ on ~,,,%~ ;%,, o.,~.~. ~.~,,~ ~. ~",~, ..,, ~~~~=~.~ =~,~,~.~ ,,~;'~, ,,~;,. ~ &~; o, ,,,,~.~ ~;"';~o ,,,., ;,~;~, 3 ,-~,~, .,--'7,~ ,%;;,c-i,,,c~%, ,,, .;;.%'T'¢,,,, ,'='~%T,';o~ NO, 4.0 8/ '.SN?CD iN U.S A. W.K'~'I{, CNDING : coa~ FROM: I_0'1!1 , CORE,G EXAIvlINED DY. ~.S. '1 R ECOV- ER~-D I .o .... /..-...~ CORE RECORD FOItMATIOH&I~, GTRUCTURAL, AND PROI~ADL. E PRODUCTIVITY OEBGRIPTIOH OF CORE · _ it ,'.~'..~. CORC INDICATIOHS GQRG orl DITCH o;I . PD 4.0 ~( '~IINTCO IN U.S &. wr' F..I( r'NDING .co.~- ..o. 10.~.11, TO · SHELL 0LL.. ;OMPANY CORE RECORD · AR~A OR FI~-LD_ , , ' - ' ' ..... ' '1-'~ .... F SVMDO~ OIS?~CO I 01~- GAS : / / I GOng on DITCH , .......... 4. --~ · ,. '· ·. . · 'SHELL 0,.._. )OMPANY CORE rEcOrD · AREA OR FIELD "::" CORe INI~ICATIOI'I5 OIL-- (;AS CORr. Orl DITCH I . ;Y#DOL$: C.CLAY 011 ,~llki. r. ,~IJ~.C 0.1·;), ~i-CLAY OR SH, AL~: WITll SkllO STKJUc5 (s~L.o s.~s%j. 2,-EL.AY OR SiiAL£ AND SA#D ISA#O s$-so%i. 3-$&IiD With SIIALI:STIII:AKS tS&ND lO.log. GO. S.S&ND NO. PD 4.8 8J-... ,11N1[0 IN U.$ A. '- COR£ FROM_ 1O411 ,TO It~lt:,8 _. SiIELL OIL--...,OMPANY CORE RECORD FROM RECOV. FORMATION&L, STRUCTURAL. AND PROBABI. Ir PRODUCTIVITy DEmCRIPTION OF CORI~ AREA OR FIELD__ ~k ~,,...2 cOM,AaV .S..!,Old~l .... CORE INDICATIONS OII.-- GAS CORC 011 DITCH ;YNDOLS: C-CLAY Off GIIALE jsxlJc O. te~i. I-CLAY OR SHALE WITII SAND. ST-flEAKS (SANO i. ll~l. J-CL&Y OR SIIAL[ &ND SkllO IllHo ll.lO~). 3-SAflD WITH SIIAL[STII~AKS IIgNO iD.tO,Gl. S.SAflD tgO-IO0~l. NO. 7_- / PD 4,B 8,(% .~IH?£0 IH U.& A. .. w,:'- ,:'- ~: co.E r.o~ 10411 .-To · FROM RECOV- · . SH£LL OIL" .~OMPANY CORE RECORD FORMATIOHA, L, STRUCTURAL, AND PROBABL,E PRODUCTIVITY OEGGRIPTION OF CORE co,~,.^.Y <~l~l~PI . .. LEASE ANO WELL NO. ~[ [--lel--I IN~ICA~ION~ OIL-- GAS CORE OR DITCH · ~ 7' "~.""f f~'~' ;' '~3 ~y~~b~ d.~ o. _ ~ rat . NOT~ GHOW FgUIO CONTENT A~ IN $1t£LL OIL COMPANY CO RE RE:CO RD o,y;,o I '""'~""~":; I OIL.- GAG i iI ,,.. , % ..... i;~ AREA oR FIELD~ . ENDING-- ~.o._ !o~!1 .... ~o !0~6 . CORE .RECORD co~,...~_ SNEPI pD ,&.Il CORE, 5 EXAMINED DY_. ..'- , .... ....=.=.:.-... .-.....:. -- . : ...... ' .... "~"'-"'---"-~-~-" ~ '"='="- --'~"'~- '-~-- ~ -"~'~ "'~-'="'"'~ .... c. r..) R ~. / J I1'I I) ICA710115 FROM TO R£COV-ERED FORMATION&,[, STRUCTURAl- AND PROD&DL, E PRODUCTIVITY DI[I~GRIPTION OF CORE S~'MI~OL OBit;rD OIL-GA5 _ _ .-,~'.'.'.'.'.'.'~,..'~..-w'=.."~ ~ '."-'~ -'"~- -~"" · .... a,{- _,c(~,,~-, ;...&o,d'2- k=. odor' " I WCC. K I=N DING__ COn~ '"nO~_ IO411 NO. F N 0,"4 TO Z I1ECOV- 1 Fit ~.' I.) I , ,.'ro~ 1046~ Si.Ii:LL 0.11. COMPANY CORE RECORD FONMATIONAL. o STRUCTURAL. AND PRoDAnLE PRODUCTIVITY DESCRIPTION OF CORE cou~,^Nv_ .SI,'OE~I ......... LEAflE A"O WELL NO._(~-"~-._3-IE~I-f CO;1 t: I~t DICATIOtI~" OIL-- GA~ COnC OR DITCH NO. · $It£L!. O... iOMPANY "CORE rEcorD FROb{ · R ECOV- ;'RED FORMATIONAL, STRUCTURAl,. AND PRODADLE PRODUCTIVITY OI;6GRIPTION OF CORi: · AREA OR FIELD COMPANY - - L~A~,~ ^.D WEL,..o,C'Y'-~ >" /~/.~,/_ CORE INDICATIONS OIL-- OAS CORr. on DITCH /CA// /4 · o/'L- SYMDOLS: C.CLAY Off 5IIALE jSAJtC O.t%). 1.CLAY OR SHALE VllTfl SANe GTflCARS (SANe S.ZJ~;I, Z-CL~Y Off SIIALC AND SAHD (SA~O Il-SO%l, 3-SAlig)YlTl( SIIALCSTIIEAXS ifAaO 80.J0%). S.SAND leO.lOOk;i, PO 4.0 ~.' .l~lhl'CO IN U.S A. ., ~,VEE~ I:NDING CORE FROM, · SHELL O~ ....;OMPANY CO RI~- R~OOR~ AREA orr FIELD__ . R ECOV- FORMATIONA~. STRUCTURA~ AND PROBAD~ pRODUCTIVITY DEBCRIPTION OF CORK COMPANY , , L.'^.-'.~ ^.o WELL .o.C~--B ~ I ~t ~'1_. i · , °!~-G~ . CORC OR DITCH SYJ4i)OL$: C.CLAY 0/~ ~IIAL£ jS,,L' o.s%). 1.CLAY Off SHALl t;IITII $A#O ST~I:AI~S (SA#O S.IS%I. Z-CL./J/ Oa SIIAL£ Alii)SAND (SJffO l~,-tO%Jo 3-$&aD.~YI11~ SIIAL[:STIII:AKS tS/,~O lO.lO%l. S.~kNI) (IG.IOG~I. NOTE~ GHOW FLtJ~D CONTrNT Air. IK ~TAND&ItG ~.EGCNO, · po ,I.o ~ ,~.o ,~ u., ,~. $1tEL~ C)'~- WEEK ~NDING , .. co,~ ~,o~. ,o .... CORE RECORD ~ L./ : ~ 4~ ~/~ ~" '~ ' /' t~/~ : ~/: , ~/2'~ 146 ~/:'~,~ , .. ., . ' , ..."'-i / -_',¢ ~.-~.~ ~..1/~ /9~..] . .- . '" ' ' ~ h 7~l: ~ yz¢'Z.~ 6~t7 ....... ' > t ~t-.'~ '~" :":'>:"-L: ~ ,7 "~'""' ' ' ...... . .'. .,,-, {..d :.. ~- ~' ~ ?~t~ ~t~ ~.'.', ,"", .-' ' ' · x-/.- /,--"-'~. ''''~ '" '~ !-/d, ~'__..~_ ..,(_ . -. . . . . , -. SYMDOL$: (;.CLAY 0/~ CORI~ INDICATIONS OIL,-- GAS CORC orl I)iTCH o.s%J. I.CLAY OR SHALl: V/Jill SAIIO STII[AI~S (SA#O S.IS%). 2.-CL.AY 011 SIIALr. Alii] SAIIO 4,,0 , SI{ELL 0.. ..,ONtPANY WEE~< ENDING _ . "' CORE FROM : TO__ co. Es CORE RECORD · AREA on FIELD: --- COMPANY- _f~.~ Y . IL~( ~[( ,, "O FROM 'ro R£C~V. FORM&TIONAL.', STRUCTURAl. AND PROBADt., P~ODUCTIVITy OE:,CRIPTION OF · . . :. /¢." . ~._~, .. ~ .. ~:' ~; Z' o~ .I · . . o7 ~ ~ lr~ . · · . . 41HT£O IN U.S A. WEEK ENDING, CORE ~ROM I0't~ CORES EXAMINED 'SllELL " CORE RECORD RECOV- NO. FROM ERED FORM&TIONAL., STRUCTURAl. AND PROBABLE PRODUCTIVITy DEBGRIPTION OF CORE ^,^ o. ,,-o_ ../~K k..: .? co..^.Y: LEASE ANO WELL NO. ~ V-181-'I CORE ' INDICATIONS OIL-- GAS CORC O!! DITCH 0;I · NO. · . ., ENDING FROM RECOV. · ...~ - ..-',. $1t£LL CORE RECORD · . o FORMATION&L, 6TRUCTURAL. AND PROOADL. E PRODUCTIVITY DEBGRIPTION OF CORE · COMPANY' %WEP! ............. . LE:A~E: AND'WELL. NO.(~C-'S V-ltgl,.-:l . CORI; IHDICA'I'IOH,~ CORC Orl DITCH --. WEEK ENDING: /~---~, ,-- .'. [ SII£LL OIL ...OMPANY CORE ~'.OM 10~1~ CORES EXAMINED BY-~ I TO ~ R ECOV- KO. FROM EflED CORE RECORD FORM&TIONAI... GTRUCTUFIAL. AND PROrlAB/1~' PRODUCTIVITy OrBCRIPTION OF COR~ COMPANY $1~F-- PI LEASE AND WELL NO. OCS ~/-~1- J . /o~¢2. s-/oi77, s ~ F- U ~ . s~ , CORi~ IN DICAI'ION5 OIL-- CORE OR DITCH =. NO, .! - . %Vr'EK ENDING core ~Ro~ )04~'~' CORES EXAMINED BY. 'to M. $. M~I SitELL OIl~- ~JMPANY CORE RECORD FROM RECO~- FORMATIONAL. STRUCTURAl. AND PROBABLE PRODUCTIVITY DEBCRIPTION OF CORE COMPANY <o~[P~ t.~^sr. ^.o w,,-LL NO. ~ ~--I~ ¢ ~ ...... COR~ INDICATIOH5 OIL-- GAG CORC OFt DITCH /,,soo -/os,~ ~-~, s~- sa, ~, ,rf~-,,:/, $/..¢;,~' 2~ flOTE; OHOW FLUID CQNTCNT A6 IH 8TANOABQ LEGCNO. ; ~/~iNTCC) IN U.S A. PD 4.8 St WEEK ENDING co.,.' ~.oM. Ioqt:O .... To IO~ ~ '3 ! , 72- 73 '75 7t3' · 'SHELL 0":~ "...!OMPANY core RECORD FORMATIONAL., STRUCTURAl. AND PRO°ADt-I~ PRODUCTIVITY DKSCRIPTION OF CORE to99o I~. 2O 36> . · .. 2. O SYKDOL$: C.CLAY OA ,~IIAL£ j|Aii~ O.|l~|. 1.CLAY OR SISAL[ WITII SAi~D STI~£AILS (SAao S.~S~& ~.-CL.AY OR $11AL[ AItD SAHD (SA#O lI.f,O%J. 3.$AIID WITH SIIALr STIII:A)~S tS&HI/ IO.to~.~l. S.$&ND (lO.lO0~l. NOTE: RDIDW FLUID C:DNTCHT AS IN ~TAHDARO [.IGi:HD, Kmd I~1 '- z o '" Kmd tit _ I"~EPTH riO00 lO0 lO I.O 0.1 2S .20 15 I0 S 0 SI'IONS F 6I~T CLAY STRUC.I TVP£ .... COHHENTS /o41o ........ ! _ -' .¢.,,.~ .....~i' ~_~.;~¢~ ~ i r,, ,. . . .......... ~i~ . ~ _ ~ r_~.?~:--..~l . ,~= I ~'~"~ ''~ i ' "' - . .. ~,~a{ " ~ j ~, - ......, '~ . '~' ?"'-.% ~ . i '-~',_ _~ ,~ .I. .,~,_ -~.: ~ I ' " ~ ';.. .... -' ~ -~ i ..'.- .. ~[ -,..,- '- '~'~ · I , : . :..." "- /¢~s .... ~i( I I~ ,',: - ~ .. .~,~ .... . _. ._~. _ . 1o~o~':::- ~ - 'I [' .... ' '."- .. ~,~ -~ ~'. . , -. i · I~ ~ - ~¢ . :...._ .... .. - .. ~ .... ~ ~:~ -,',' °l hi Kind 0 ~ ~P DEPTH IOq~,$ Kind 0 :000 100 I0 1.0 O.I 25 20 15 I0 S IO~l-lO JF.I.L N/II'IE . S~ll Ocs.. y- 161 * '1 Ak COMMENTs Z ~=~ ! Kind 0 NO. PD 4.D ~ RINTI~O IN U.$ &. ; ~VEEI~ 'ENDING CORE i=ROM-!~'I I~ CORES EXAMINED SNELL G. ;OMPANY . CORE RECORD STRUCTURAl. AND PRQI]ADLE PRODUCTIVITY DEGGRIPTION OF ¢ORF. · COMPANY L~:^~,. ^.. INDICATIONG OIL-- Co/Ir Grt DITGH 0;I . '2- . 'IIIkTCO IN U.$ &. PD 4.G 8i W .r'EK r'NDING co.c F.o~. 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SIIELL OIL'-.OMPAN¥ CORE RECORD R ECOV- FROM ER;O FORMATIOH&L, STRUCTURAL AND PRORAnLE PRODUCTIVITy DEBCRIPTION OF CORE co..^.Y LEASE AND WELL NO. ~::)~"~,~- iq~'' I~_l- I ..... COR~ OIL-- CORI: 011 DITCH Z- COrE RECORD FORMATIONAI-, STRUCTURAL AND PROBABLE pRODUCTIVITY OIrEGRIPTION OF CC)lIE SYi4DOLS: C.CLAY Oii 5il&Lr IIAPC o.l*'~). I.CLAY On SHAL~ WITII IAHO STIli:AKS llANO I-II~l, 2-CL&¥ Oil SIIALII: HO'r~'l III, lOW FLUID CoNTeNT Al IH OTANDAIIO LKgi:llO. ,0 ,., ~.~o ,,,~,. m ,.,,. $1t£LL OIL COMPANY AREA on FIELD_ . co.~ ~o~~ .~o]O4~ CORE RECORD co~,.~,~_ S~gP~ ..... ~.~ .,,0 w,:~ .o. ~.~.l~l~_.f. ....... ...... CORE5 EXAMINED DY- z.. ~':~'"" ccmc OIL-- ~ .............. ~-.. .. ........ ~ ............... s.'~0 ,.,o.,t, ,~ u., ~. SIt£LL OIL COMPANY V,' r [::1~ r'NDIN~_ ' cor~- ~.o._ !o'111 . .To_L0-~--------- COR-E: .RECORD CORE. 5 EXAMINED DY- .'-.- . _ : ..... -:~ --~-'' "~'--' ., - · .~ ~-=r~u.~ RECOV- FORHATIONAL. 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R PAGE 4 DAT~ OF SURVE¥~ lO JUNE 1984 55.40 SHEI,L ~EST~RN E&P iNC. 0C$-¥-181 ~1 (SEAL ISLAND A2 SIDe, TRACK) SEAL EXPLORATION AR~A NORT~ SI...OP~, AbASKA KEf. bY BUSHING ELEVATION: ENGINEER& UNKNOWN INI'ERPOLATED VALUE6 b'O~ {;.VEN 100 F~iET OF M~AS[{RED DEPTH TRUE SUB-SE:A COORSE ~EASURED VERTICAL YE~TICAb DEVIATION AZIMUTH DEPT~ DEPT~ DEPTH DEG ~IN DEG NIN 12000 O0 1000~.89 10450.49 34 23 12100100 10588,84 10533.44 33 37 12200' O0 10072,~b 10617,00 32 46 12300 O0 10756,29 10700,89 33 43 12400:00 10839,~0 10784.00 33 37 {Z500.O0 109~-2.96 ]0807.50 33 2 12600.00 I1000.93 10951,53 32 $3 i2'm00.00 11091,37 11035.97 32 14 t[zOO'~ O0 11170,19 11120,79 31 3.3 1 .O :00 11261.90 11206,56 30 19 VERTICAL DOGbEG RECTANGULAR COORDINATES HURIZ, ~ECTZON SEV~RITY NO~TH/SOUTH EAST/WEST DIST. FEET DEG/IO0 FEET FEET FEET S 48 26 E -1237,28 $ 45 51 E '.1275.17 S 43 09 E -1313,96 S 4~ 11E -1353 54 S 42 52 E -1394:10 S 42 40 E -1434.35 S 41 42 E -1474,54 S 41 1 E '1514,83 S 40 23 E '1555.03 8 4U 13 E '1594.15 1,20 1,34 1,08 1.99 1,25 1.01 1.47 0.69 0,09 0.00 0.00 13000 O0 11348.37 11292,97 30 11 !3078~00 11415,79 S 40 0 E -1632,68 D~PARXURE AZIHU~H DEG MIN 1237,28 S 4593,05 E 4756,78 S 74 55 E 1275,17 S 4634,08 E 4806.3] S 74 36 E 1~13~96 S 4072 84 E 4854 07 S 74 17 E 1353,54 S 4710135 E 4900 97 S 73 58 ~ 1394,%0 S 4748.37 E 4948 80 S 73 38 ~ 1434,35 S 4785.78 E 4996 10 S 73 18 ~ lq74,54 S 4822,29 E 5042 ~9 S 72 59 t 1514,8~ S 4857,B1E 5088. J3 $ 72 40 ~ 1055,03 S 4892,07 E 513~,27 ~ 72 21E 1594,15 $ 4925°45 E 5177,01 $,72 j g 1.632.68 S 4957.81 ~ 5219.72 S 71 46 E lU62,72 S 4983,03 E 5253,11 S 71 32 ~' COi~PUTATiON DA'~'E; 6 6EP'rr~Mc~ER PAGE 5 SHEbb '~L'$T~RN g&P I~C, DATf~ OF SUR~EY~ 10 dUNE 1984 UCS-Y-I~I ~1 (SEAL I~bAND ~2 8i[~.~ACK) KEbhY BUSHING EbEVA~'IUN= 5b,40 FT SEAL EXPbORATION AREA NORTH SbOPE, AbA~KA ENGINE[,~R: UNKNOWN INI'ERPOLAT~D VA~UE6 ~'OR ~V~N 1000 FE~T DF ~A~UR~D D~P'I' TRUE SUB-$~A COURSE MEASURED YERTICAh VERTICAb DEVIATION AZIMUTh DEPTH DEPTH OEPTH OEG ~IN DEG 0.00 0 O0 -55,40 0 1000,00 999~87 944.47 0 14 2000 00 1999,~5 19q4,45 0 3000~00 2997,77 2942,37 lO 49 4000,00 39]~,41 38~1,01 29 1t 5000,00 4786,58 4731,18 34 12 6000,00 558b,D1 553~,21 40 29 · O0 7084,1b 7028,75 39 43 .0 O0 7938,30 7882,90 28 34 { 0000,00 8807 23 875.1,83 32 19 1 , O0 10505 1~00~,00 11348 1~07 ,00 11415 N O 0 E N 56 2 E :5 ..]8 15 K N 85 ] E N 8U 20 E S 80 34 E S 7O 18 E $ 74 45 E '240.30 $ 72 20 E '417,62 2; 74 30 E -562,14 V~RYlCAL I)UGhEG' RECTANGUDAR COURDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/~OUTH EAST/WEST D~ST. AZIMUTH FEET D~G/IO0 FEET FEET FEET DEG 0,00 0,00 0,00 N 0,00 E O,O0 N 0 0 E 10,93 0,81 10,93 N 1,27 E I~.00 N 6 ~7 E 11,65 0,~6 11 65 N 1,94 E 1~81 N 9 ~6 E 17.61 3.83 17':ul N 31.27 E 35.89 85,94 3,61 85194 N 35~i'28 E ~69,41 N 76 32 E 133,45 0,58 13~ 46 N 87 ~8 E 888,76 N 81 '23,3b 0,53 23 35 S 1456,15 E ~456,33 M 89 4 E 0.69 240 30 $ 208B'41 £ 2102,19 S 1,37 417 b2 $ 2720,05 E 2751,92 0,85 562,14 $ 3216"79 E 3265,54 S 80 '5 E. 1,83 713.95 S 3086 b7 E 3755,..17 1,4" 916.3" S 4145:45 E 4245,53 1,20 1237,28 $ 4593,05 £'475~,78 ~.74 55 E 0,00 1632,~ $ 4957,81E 5219,72 .,. - ..... /' ~ ...... ' .. . ... .. . . .'. . . .... '' '.' ' ' .'. .' . ' i.. ..~ '... ".'. '.' '.' '~.? '.."". · · · . ,i '. ...... ..'.".' 7' :":.'"'"'"."<'3' :.' <.: .. ' ...',.' '. ,".. '". ",'~.::":'.'."':..<. '~:' ..~':':..::: '..', :'.]'/..".'::',~: ??.'/:,.?,.':.:7.'J::"~,~?..',,'~:'./:~,::?~>J:~ C )MPUTArION DATE: PAGE DAT~ OF SURYEY'- 10 dUNE 1954 0CS-¥-181 {;1 (SEAL I~LAr~]D A2 $,r)ETKACK) SEAL EXPLORATION AREA NO[{T~ SLOPE, AhASKA K~bL¥ BDSHIIVG ELEVATION: f~NGINEER: UNKNOWN INYE/{POLATEI) VALUE6 FOR EVEN 100 FEB:I' L~F SUB-S~A DEPTH TRUE SOB-$M~ COURSE MEA8URED YEHTICAL VERTICA~ DEVIATION AZIM'UTH DEPTH DEPTH DEPTH OEG t~Ii~ OEG ~IIN VERI'ICAL DOGLEG HECTANGULA~ COORDINATES MU~IZ, SECTION S£VERIT¥ NC)RTH/SOU?H EAST/WEST D~$T. FEET DEG/IO0 FEET FEET FEET 0.00 0.00 -55 ¢0 0 0 N 0 0 E 0.00 0,00 O.O0 N 0.00 55.41 55.40 0~00 0 17 N 45 4~ E -0.25 ~.0) 0 25 $ 0.~4 I55 42 155.40 100,00 1 4~ N 12 30 W ~ 62 1,24 , ,62 N 0,21 255~48 255.40 200,00 1 41 N 7i 43 E 5.04 1.71 ~55,52 ~55,40 300.00 1 7 N 12 15 E 7,2~ 0 28 7,28 N 0.47 455,53 455,40 400.00 0 40 N 2J 25 E 8.$4 0:40 8,84 N 0,00 555.53 555 40 500,00 0 33 N ~ 46 E 9 85 0'%2 9,85 N 0,4~ 6~5,54 655:40 600.00 0 22 N 28 28 E 10:31 3.60 10.31N 0,84 ~.54 755,40 700.00 0 17 N 67 49 E 10.56 0,18 ~0,56 N 1,02 .53 855.40 800,00 0 12 N 66 13 E lO.B3 0,26 10,83 N 1,07 DEPARTURE AZINI,ITH DEG NXN 8, 00 N 0 O E ,42 S 53 52 E. 1,64 N 7 27 W 5,10 N 8 27 W 7 29 N ) 39 W 8 84 N 0 0 W 955.53 955,,~0 900,00' .0 12 $ 10 23 E 10.97 1.37 I0.97 iV 1,12 E 11.,03 N 5 48 g 1055.54 105~,40 IOO0.OO 0 14 S 49 33 W 11~02 1.17 11,02 N' 1.17 E Il.OB N 6 '2 ~ . 1155.54 1155,40 1_10.0,00 0 1'4 .... 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COMPiJ'I.'ATI'ON bAI'E: 6 SEPTEM~E~ PAGE 7 SHELb ~ESTERN E&P INC. 0C~-¥-181 #1 (dEAL I6[,A~U A2 oI"'OET~AuK" ) SEA[, EXPLORATION AREA NO,Tn 6LOPE, AbASKA DATE OF $bRYEY: 10 dUNE 1984 KELLY BDSHING EbEV'ATION: UNKNOWN iNi'EP, POI,ATED VAI.,UE~3 FO.I EVE~I 100 FEEi' OF SUB-Sr/A DEPTH TRUE S3B-$EA ~EASUhED ~ERTICAL VERTXCA~ DEVIATION AZIMUTH D~PTH DEPT~ I)E~TH 4021.84 3955.40 3900.00 2958 4139.35 4055,40 qO00.O0 3235 4257,82 4155.40 4~00.0~ 32 9 4375,92 4255.40 ~200,O0 32 0 449377 4355,40 4300.00 31%2 4611:06 4455,40 4400100 3123 4726,80 4555,40 4500.00 2926 4'42.7~ 4655.40 4600.00 3~ 52 425~d3,31 4755,~0 ~700,00 34 2 .35 4~55,40 4800.00 3434 55,40 FI VERTICAL DOGbEG RECTANGULAR COORDINATES HURIZ, DEPARTURE ~ECTION SEVERITY ~ORTH/$OUTH EAST/WEST D~ST. AZIMU~M FEET D£G/1OO FEET FEEI FEET DEG ~N ~i 80 11 E 87.76 $.79 N 80 1 E 98.36 0.26 N 7924 E 109.82 0,73 N 7927 E 121.32 0,38 N 7938 E 132.67 0,89 N 7958 E 143.64 1.75 ~! 8935 E 149.80 $ 8335 E 145.9~ S 8U 45 E ' 136 ~9 0,77 $ 7952 .E 125:47 98.36 N 430,68 E 441,77 N77 8 E 109,82 N 493,i6 E 505.24 h 77 20 E 121,32 N 554.92 E 568.03 N 7740 E 132,67 N 616,23 E 530,35 N 7750 E 143.04 N 576.56 E ~91064 N 78 0 ~. 149;80 N 734,41E 749.53 N 7828 E 145.9! N 79284 E 806.15 N 7934 E 136,89 N ~57:79 E 868,65 N 8055 E 125.4'1N 925'02 E 933,49 N 8216 E 5205.54 4955.40 i900.00 35 37 $ 77 54 E 111.90 1,44 111,90 N 993.91 .E 1000 5329,03 5055,40 5000~00 3559 8 7650 E 95.92 0,86 '95~92 N I054,59 E 1068 5452,83 5155,40 51.00,00'. 36.18 $ .75 2.4 E 78L48 1,13 78;48 N 1135,42 E 1138 5577,4~ 525~,40 5200.00 3059 $ 7335 E 58,64 1.36 58,6~ N 1207,13 E 1208 5702.55 '53'55;40' 53.00;00 ' 3'7 ..... 6..'.$'72 2.3. 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COMPOTATi{');~ OA~'E: 6 ~EPT~:MbMR DAT~ OF 8~R~EY~ 10 OUNE KEbnY BbSHING ELEVATION: 55,40 F~ ~NGINEER: UNKNOWN I(~TE~POLATED VAbOES FOR EV~', ,~N 100 FCEi OF SUB-SEA TROE $1JB-$~A COO~E ~EASUREo VERTICAL VERTICAL DEVIATION AZIMUTd 9019.4~ 7955,40 't900,00 28 24 9132.93 8055.40 8000,00 28 5 9245.9"/ 815~,40 8100,00 27 20 9358.99 8255.~0 ~200.00 28 17 9472.69 R355,40 ~300,00 28 9587.51 8455.40 8400.00 29 56 9703.42 855b.40 8500,00 30 43 9820.34 8655,~0 8600.00 31 48 99~8.49 8755,40 8700,00 32 26 10056,63 8855,40 ~800.00 31 7 10172.83 8955,40 8go0,o0 30 17 29 50 V~RIICAb DUG~E~ RECTANGOGAR COOROINAYE8 ttORIZ. DEPARTURE FEET DEG/IO0 FEET S 74 ~4 E -504.61 S 73 53 E -5'19.15 S 73 36 E -593,80 S 7~ 29 E -608.72 S 72 41 E '624,4b $ 71 50 E '6~1.55 S 71 3 E '650.18 S 70 5 E '6~0.29 S 69 12 E '702,12 $ 68 53 E '724.53 S 6~ 6. E -746,73 S 67 10 E~768,95 790.98 0,79 0,%! 0,24 O,b4 1,37 0.85 0,83 1.38 0,85 2,67 . ~5 $ 32'/7,]5 E 3328,~3 S 79 58 ~ 593.80 S 3328.00 E 3380.56 ~ 79 53 E 608.72 $ 3378.49 E 3632.89 ~ 79 47 E 624,45 $ 3430,26 E 3486,b4 ~ 79 40 E b~1,55 $ 3484.02 E 3542.60 $ 79 33 060.18 S 3539,58 £ 3600,62 ~ 79 2~ ~ 680,29 S 359b 73 E 3660,50 S 79 17 [ 1.30 '146. 10288 36 9055.,t0 9000,00 0,86 768 10403'41 9155,40 9100.00 2.9 23. S 67. 15 E 1.07 790 1 ~ 14 ' 1~ 18' 9255.4o 9200,00 29 21. S 66 43 E -812,81 0~30 3'2~99 9'355~.40... 93.0.0.0.0.. 29 3'5' ". '$ 66 9. E -835,44 '0,68 835 .10748 1.0863~7. 945.~,~.0. 94.00.0..0..29 58 . .S'.65. 24 E .-858~'80 0.79. 858 ' I '.955.5,40'. 9.5..O0:~.O.O'.]'.3.'O.:...29,..':S.'6.3..&2.':E -'8'83:'~7':2 . 1.'.'8.1' 883 0 9655.40 960.0.00 31 8 'S 61 42 E -911~56 0~5.8 911 1.10.9'7,109'80'~0.. 9755..',':.'~.0 .97.~..:~:;.~...:....~:..3i...2..~..........:.~.:.59..:..:..4.E..:~:...-.9:~..~.56 2:~.,50. ..'.9,41 .1121.4,71 .98.55,40.. 980.0,00 3i 3'6 ' '$ 57 8 E ~9'1~,04 1,9.3 . 97.4. 73 $ 3769,38 E. '3842,63 $ '78 47 E 95 $ 3822,80 E 3899,37 $ 78 37 E 98 $ 3875.23 E 3955,13 §.78 27 81 $ 3927,06 g 4010,3~ o 78 18 E 44 S 397.8.,82.E '40'65.,5B ,9 78 8 g 80 .$ 4.030,99. g .412.1..,46 ~ 77 58. E 72 ..S' 4083.4'4;.'£' ..'41:'7'I',.9.9. 7.7 4.7 .E 56 S.4136,52..E .4235.,77 ! I 34 ~. 5.6. '.~.. ",4i'89'33..~' '.E" 4.2'9'3:i8'3' ' .... 77 ' 19 04 $ 4241,34. E.435;I,,.75 : ...' ' ' ..... .:.... ...... ::...:,...: ....... .......................... 77 3 E. 11332,80 9.9_5,[} :171.451:;'9.5 i 00155 69.4,'.;'"4. 5 .'..i':0.2 ..!1816,65 1035~ '.'"'i.".'1" 9..3' 8'.~,: 7.':~ '.'.' t~,0:4:"5 $ ..12059.8 i. 1o55~ 'gt:.'2'1:.:'7: 9' ,.:7'0. ' .1.2298,93 "~'2.~4' I:'9" ~.'..1' 9.. '; :'.'~5 ..... .:'t 0'.~.5.~;:.99:L~.::."4'i~:~6 ;.:7'2 ...... '~.43~0:.',: ' ' .';.' .'" .~, .1.4 .. 1084,91 S 4.401. 5 £ 4533 .29.............I.,...i~..~....489 ,E' ':8':1". ~ '"':'.i:.1"2'6:',5"8."'.'~;".:'4457:', i""::~';E~'.':'4;59;~ 7.7 . ...b9 . 1169~8~ $ 45!'2...9.6..E. 4.662 .1..0 $. 75 28.E ~"3':4"..'.(.': "';"1':2%~..~;:6"0',"":$:.,::.'~'45,6'.6~':~, ~:.:92' ~'(.E:::'.'.'4~72:5 .:67. :.'"S' .I::5.':'.. 6 '" .g .45 125~,82 S 4618,0~ E .4786 76... ~.. 74.44 g- ,~8.:3.':.':"' '. "<':':1..3'.0:6:':,;'.'.0:8'"'::..:~?"j' ~6~6'5:: ~t~;: .'::..':..!B:/J.',:~'.8{~ :"5'67: .:'.S:. ':"~/~":'?.': 2,1"' [ 09 1353,10 S 4'/09 95 E..490~ 46 . ~ .7. 58 E ,:.~'.~ 0 :"'? :.... ~".'~:r.~0.'.i.~?.8:'8;.::~:.~..:::4~7557 :~ ~.?~.g+. 49:5'? ":9 ~.";.:.' "S. :':.7~' ...'3 ~ .....~ 1.2.6.57,48 1105b,40 IlOUO~O0 32 2,3 8 41 5 E -'1497 "7 ......... ' .............. . .,,..,'.'.... ..... .': ....... ",.': ..... .' '."....'SO'."?t'.,,.L!',:9:'..": '..&.'..:.~.'~..:.1I...,{~ "~ '"7' 5":' ' :" : .5:~.. ~,..?..~:.:.....;:...,...:, ........ : ~, .. ... ~..~ .. ... ..., .,.,~ .,..,... ,.. ..., .. ...,: .... ...: ....... ... :. ............ . ..... . ....... ... 2 ........ 1~.~4.. 1497.~ ~ ~ 484~,~1 $ 5069~.03 ~ 7~ 48 ~ :.' '2': ."~,., '.,~...5.9: il :l:'..'a,'.'40'.. l~'l:.t:'O:O~i~,Q.O'. ...... ~"3':l::~'~:;3'~"~.'.:"'":'..~:~.~'~10 '""30"~':'~". ~'~:1"5"45".":~'~2 ..... '" ::~ ..... "1~''':'''' 6 ........ ' ..... ' : ......... ~ ' ':' "' ':'"'"" '" " ..... "' ' ':"' ""'~' '''~ "' ' ~' ..... ' ...."" 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SHf~Lb WESTERN E&P iNC, 0C$-~(-181 {1 (SEAL ]6LAN~ A2 SiO[~TkACK) SEAL KXPLORA'i'ION AREA IN'.fERP[]I~AT~D VALe.iH:6 FOR CHOS£N H~.JR1ZONS ~ARKER :~EASUR ~'-D DEPTH T~/D BELOW K~ FROM i~07~.00 11415.79 i1360,39 TOTAL OEPTH ~DRIbL~R~ PAGE 9 DATE OF SURVEY~ 10 JUNE 1984 K~Lb¥ BUSHING ELEYA'£ION: 55,40 UNKNOWN SURFACE LOCATLON ORIGIN:SEC 11. TWP 13N RGE RECTANGULAR COORDINATES NURTH/$OUTH ~AST/WEST 1662,72 S 4983,0~ E COIwiPUTATIO;~ PATE: TOT/% ~ MEASORED DgPTH TVD BELOw KB f'RO~ KD DEPTH (D~ILbkR) 13078,00 11415.79 PAGE )A?m UF $ORYE~ 10 JUNE 1984 K£bb¥ BOSHING EhEVATION; 55,40 }"X ~NG,ENEER; UNKNOWN SUR~'ACE bUCATION A~' DRIG]N:6EC 11 T~P I~N RGE RECTANGUlAR'COORDINATES NORTH/SUU~H EAMT/W~ST 1662,72 ~ 49~3,03 ~ ' Suggested form to be inserted inl.each "Active" well folder to for timely compliance with our regulations, · 0~erator~" $~e~ 1 Name and Number -- Reports and Materials to be received by: Required Date Received Remarks · , .. , . Ccmpletion Report Yes h~ ~..'~'".', ~.,?'/ /~,'l-~,~ -- ~ /',,~ ~,; '. ... - . I '~:: ..... , _-_ , ~ --- :~.,..,,; , ....... .,,. ",. Core Chips -' , Core Description .... " ..... · ..... '~' 7 ..... ...:, .4 ' "~'t~ :"5, ~, o ' .... . .. · ,., "~ / . Inclination Survey Directional Survey ~ .,~.,,, ,' ,~ ,,'.,, _/,.. ~ - I ~ .. ,,,,.,, __~..,, .. , ~,f'~ ~, ! ....... ._~ ...D"rill Stern Test Reports /~.~,\',~?.~ ........ ~ .... _ __ . ~s- - - ~ ~,- -" -v ~ '---' Logs Run. Yes .., ...... .v..,.~--~----- i~e_. .,'~"' -" ,- -- . · ',,_ ,, ... .,'/ " ' 1~ ~"' '" m~t~zed Data ' ' "'"' ' I~ \ I/ ~'-" ' "-- SWEP-293 TO: ALASKA OIL & GAS COMMISSION ATTN MR. BILL VAN ALLEN 3001 PORCUPINE DR. ANCHORAGE, AK 99501 SHELL WESTERN'E&P INC. PACIFIC FRONTIER DIVISION P. O. Box 527 HOUSTON, TEXAS 77001 DTNA Date 7/27/84 Transmittal No. PD- 5674 Subject: SWEPI ET AL 0CS-Y-181 #1, RD "SEAL" PROSPECT BEAUFORT SEA AREA NORTH ALASKA i.. QUANTITY We transmit by U. S. Mail DESCR I PT I ON OF ITEM See attached 1 ist, the following: REG. NO. DISPOSITION Sender' PLEASE SIGN AND RETURN COPY OF THIS MEMORANDUM Above items received, except as noted: , I F AUG 0 71984 Date .Alaska Oil & Gas Cons. Commission Anchorage WHITE (ORIGINAL) YELLOW (1st COPY) PINK (2nd COPY) -ADDRESSEE (RETAIN) -ADDRESSEE (SIGN AND RETURN TO SENDER) -SENDER's "HOLD" FILE SW£p-293 'i ~= DTNA TO: ALASKA OIL AND GAS COMMISSION 3001 PORCUPINE DR. ANCHORAGE, AK 99501 SHELL WESTERN'E&P INC. PACIFIC FRONTIER DIVISION P. O. Box 527 HOUSTON, TEXAS 77001 Date 7/26/84 Transmittal No. PD- 5666 Subject: SWEPI ET AL 0CS-Y-181 #1 "SEAL" PROSPECT BEAUFORT SEA AREA NORTH ALASKA "- We transmit by QUANT I TY I Diazo, 1 Sepia U. S. Mail DESCR I PT I ON OF ITEM '5" Dual, Laterolog/MSFL/GR the fol 1 owl nil: REG. NO. DISPOSITION II II II II '11 II II II O' 5" BHC Sonic/GR/SP 2" Dual Laterolog/GR " " " " 2" Linear Dual Laterolog/GR II II II ' II v/"2" BHC Sonic/GR/SP II II II II ~//2'l TVD Dual. Laterol°g/GR II II II II ,.,-'2" TVD Linear Dual. Laterolog/GR II II II II '/' 2" TVD BHC Sonic/GR/SP ' /-.~"'"'"Mudlog (Composite) Sepia, Mudlog (Composite) Diazo PLEASE SIGN AND RETURN COPY OF THIS MEMORANDUM Above items received, except as noted: Date · ¥.,:~s~a Oil & Gas Cons. Commission Anchorage WHITE (ORIGINAL) YELLOW (lst COPY) PINK (2nd COPY) -ADDRESSEE (RETAIN) -ADDRESSEE (SIGN AND RETURN TO SENDER) -SENDER's "HOLD" FILE Shell Western E&P Inc. A Subsidiary of Shell Oil Company 200 N. Dairy Ashford P.O. Box 527 Houston, TX 77079 July 10, 1984 Alaska Oil & Gas Conservation Commission ATTN Mr. C. V. Chatterton 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen. Attached are duplicate co. pies of the June, 1984 Monthly Report of Drilling and Workover Operations for SWEPI's Seal Island Well No. OCS Y-181. Yours very truly, R. G. Hollis Division Production Administration Manager Pacific Frontier Division RGH' ff Attachment July 12, 1984 Shell Western E&P Inc. A Subsidiary of Shell Oil Company 200 N. Dairy Ashford P.O. Box 527 Houston, TX 77079 Alaska Oil & Gas Conservation ATTN Mr. Harold Hedlund 3001 Porcupine Drive Anchorage, AK 99501 Commi ss i on Gen tl emen: Enclosed for your Subsequent Report Well No. 1. information are duplicate copies of the Sundry Notice for the temporary abandonment of Seal Island 0CS-Y-181 Yours very truly, R. G. Hollis Manager Production Administration RGH: 1 b Enclosure RGH51943 .t ., STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL COMPLETED WELL [] OTHER [] 2. Name of Operator Shell We.~tern E&P: Tnc. 3. Address 601 We_~t .:;th St:: #RI O~ Anchora_ge~ A.K 4. Location of Well 7. Permit No. 84-17 99501 8. APl Number 50- 55-201-00005 9. Unit or Lease Name ocs Y-181 1530' FSL, 642' 'FEL, Sec. 11, T13N, R13E, UM lO. WellNumber No. 1 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. WTLDCAT 513' KB I 13£~ Y-1R1 (RFII) 12. Check Appropriate Box-r-o-Indic~e-N~t-u~e-of Notice, Report, or Oth'er Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] [] (Note: Report multiple completions on Form '10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). See Attached. Temporary Abandonment. J U L 1 6 1 184 Alaska 0il & Gas Cons, Commission Anchora(j~ 14. I hereby certify that~the foregoing is true and correct to the best of my knowledge. Signed '~X~~ Title Div. Prod. Adm. Mgr. The space below for Commission use .., Dot%. 7/10/84 Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" i n Duplicate . STATE OF ALASKA ~, };:, ALASKA (" .,_ AND GAS CONSERVATION C~~''.MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATION 2. Name of operator 7. Permit No. Shell Western E&P, Inc. 3. Address 601 West 5th St., #810, Anchorage, AK 99501 4. Location of Well at surface 1530' FSL, 642' FEL, Sec. 11, T13N, R13E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 50' KB n£.~ Y-1R1 (DEL) 84-17 8. APl Number 50- 55-201-00005 9. Unit or Lease Name OCS Y-181 10. Well No. No. 1 11. Field and Pool WILDCAT For the Month of June ,19 ~4 [12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded 2/4/84 Depth 6/30/84 - 13072' Footage Drilled - 0 Recovered RFT logging 1~ool 6/1/84, DP parted' 12975', recovered. 13. Casing or liner run and quantities of cement, results of pressure tests 7" liner 11997-13072' with 240 sx class. "G" cmt.with 1% CFR-2, .3% Halad 9 and .1% HR-5, tested liner to 3000 psi. 14. Coring resume and brief description 15. Logs run and depth where run .CET/GR 1'1870-12965; Gyro 'TD-surface; GR/CCL 12394-12636; CNL/CCL/GR 12200-12940; GR/CCL 11950-12440. ~16. DST data, perforating data, shows of H2S, miscellaneous data Perforated 12724-12738 and 12526-12576. 17. I hereby certify that the yregoing is ,. S IG N E D~~--~_J~/ u~-~- true and correct to the best of my knowledge. TITLE Div. Prod. Adm. Mgr. FCFIVE.D ... JUL ! 61984' Alaska 0il & Gas CoDs. Commis:~ion Anchorage DATE 7/10/84 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate With the Alas"~'a '. Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit irt duplicate ' Rev. 7-1 OCS ¥-181 6/20/84 Ran Howco 7", 325 cmt retainer and set @ 12698'. 6/21/84 Break down formation with 3300 psi @ 1 CFM & 1BBL @ 4300 psi. Pumped 10 BBLS water ahead. Mixed and pumped 30 sx. class "G" cmt with 1~ CFR 2, .3~ Halad 9, .1~ HR-5 followed by 5 BBL water displaced with 67 BBL CaC12 fluid. Closed tool with 5 BBL water outside. Squeezed 3 BBL cmt below retainer locked up with 4500 psi. CIP @ 1500 hrs. Slurry wt 15.9 to 16.0 PPG. Dropped 3 BBL cmt on top of retainer. POOH. RIB with bit. Tagged cmt @ 12672'. 6/22/84 - 6/23/84 Tested tbg & pbr to 2500 psi. Ran GR/CCL. Tested tree to 10000 psi. Tested production line to 5000. 6/24/84 - 6/25/84 SI @ surface. Ran Johnston DPTT. Flowed well (Pumped 300 BBLS 150 deg. water down 9 5/8" x 13 3/8" annulus). Pumped 150 BBLS hot oil 120 deg. doten annulus 9 5/8" x 13 3/8". SI well on bottom w/Otis. Pumping prod fluid do~n 9 5/8 x 13 3/8 annulus. 6/26/84 - 6/27/84 Nippled up and tested BOP. Killed well. Laid down tbg and jewelry. 6/28/84 - 6/29/84 Set 7" 325 cmt retainer @ 12380'. Mixed & pumped 125 sx class "G" cmt w 3~'CFR2, .3{ Halad 9, .1~ HR-5 followed by 12 BBL water. Dis- placed 25.BBL water outside. Squeezed 5 BBL water & 3 BBL cmt below retainer. Dropped 22 BBL cmt on top of retainer. Est. top of cmt @ 11890'. CIP Slurry wt. 15.8 to 15.9 PPG. RIB to 1750' O/E to lay plug 75 sx permafrost. WOC. Cmt firm @ 1648'. Held 100005, witnessed by l~fS Representative. Pumped 75 sx Permafrost II cmt, wt 15 PPG. Circ. hole clean. Dumped 15 sx CaC12. .Installed tbg hanger. Removed test equipment. ND and removed BOP equipment. Installed top flange and valve on well. Released rig. 6/30/84 RECEIVED JUL 1 6 Alaska Oil & Gas Cons. Co~mission Anchorage Shell Western E&P Inc. A Subsidiary of Shell Oil Company 200 N. Dairy Ashford P.O. Box 527 Houston. TX 77079 June 20, 1984 Alaska Oil & Gas Conservation Commission ATTN Mr. C. V. Chatterton 3001 Porcupine Drive Anchorage, AK 99501 U.S. Department of the Interior Mi neral s Management Service ATTN Mr. Brian Schoof Supervisor, District Oil & Gas Office Offshore Field Operations 411 West Fourth Avenue, Suite 2A Anchorage, AK 99501 Gentlemen' Enclosed for your information is a Sundry Notice for Seal Island Well OCS Y-181 No. 1. Approval is requested for temporary abandonment of the well. Since we are preparing to proceed with these operations immediately, I would appreciate your contacting me in Houston at (713) 870-4445 with verbal approval or for any questions you may have regarding the abandonment procedures. Yours very truly, a. G. Hollis Manager Production Administration Pacific Frontier Division RGH:bjh Enclosure RECEIVED JUN 2 5 1984 Alesk~ 0il & Gas Cons. Commission Ano~mra~ (' STATE OF ALASKA (" ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL J~2y, COMPLETED WELL [] OTHER [] 2. Name of Operator Shell Western E&P, Inc. 3. Address 601 West 5th St., #810, Anchoraqe~ AK 99501 4. Location of Well 1530' FSL, 642' FEL, Sec. 11, T13N., R13E, UM 5. Elevation in feet (indicate KB, DF, etc.) 50' KB 12. I 6 . Lease Designation and Serial No. OCS Y-181 (BHL) 7. Permit No. 84-17 8. APl Number 50- 55-201-00005 9. Unit or Lease Name OCS Y-181 10. Well Number No. 1 11. Field and Pool WILDCAT 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 J~] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). See attached request for temporary abandonment. Verbal approval for EZSV retainer at 12600' given by Brian Schoof of MMS on 6/13/84. ... Subsequent Work Reported RE¢. ,,.... JUN 2 5 1984. 14. I hereby oe'i~ify th.at tge forjegoing is true and correct to the best of my knowledge.. Signed ~lasle 0il & ~.. t/- ~for 'NI The space below Commission use Title Prod.' Adm. Mqr. Date 6/20/84 Conditions of Approval, if any: Approved by. COMMISSION ER ~proved Cop~: I~eturned By Order of the Commission Form 10~403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate TEMPORARY ABANDONMENT #0RKSHEET OCS-Y-181 No.1 STATUS:-9 5/8" to 12288'. 7" liner 11997'/13072'. -Intervals perforated; 1.2724'/12738' & 12526'/12576'. -EZSV retainer at 12600'. -9.8 PPG CaC1 brine in wellbore. PROGRAN: 1) Nottfy AOGCC prior to abandonment procedures as they may wish to witness testing and placement of plugs. 2) RIH with EZSV cement retainer on tubing and set retainer at 12380'. Establish injection rate below retainer and pump 30 Bbls. (1200 lineal feet tn ?") of fresh water ahead of 1~ sxs. (90 lineal feet) of Class "G" with 1~ CFR-2, .3~ ItALAD~ 9, and .1~ HR-5 cement below retainer. (See attached squeeze procedure). Unsttng from retainer and displace 110 sxs,, of cement ~O0__!~tneal feet) on top of retainer. Follow cement',, with 12 Bbls',,(1400 lineal feet in tbg.) of fresh water behind. POOH to 11000' and reverse circulate two tubing volumes. POOH and lay do~n stinger. Lay do~n all but 1750'of tubing. 3) RIH to 1750' and pump 40 Bbls. of fresh water ahead of 75 sxs. of Permafrost II cement. Follow cement with 12 Bbls. of fresh water. POOH and #OC for 12 hours. Run back In and tag, plug with 10000 Lbs. of weight. 4) POOH to 325' and repeat step 4. POOH to 135' and revers~ out tubing. 5) Dump 15 sxs. of CaC1 down well. RDMO. BLB 6/84 SQUEEZE PROCEDURE l) Set EZSV retainer at the required depth. 2) Unsttng and pick up 10'. 3) Close valve on floor and pressure test Halliburton lines, : check chart recorders. Bleed pressure off. 4) Open valve on floor, close annular preventer, and circulate approximately 10 minutes through the choke line. 5) Open annular preventer, stab Into retainer, close a~nular preventer and test the back side to 600 pst. 6) Pump down the tubing and get a stabilized pressure and rate: RECORD RATE 2) PRESSURE 3) BLEED DO~ PSI ?) Release pressure on both sides and unsting from retainer. 8) Spot cement 2000' above end of stinger; NOTE: Nhile pumping cement, trap 600 psi on back side using choke. A) Pump 30 Bbls. of fresh ~ater ahead. B) Pump 125 sxs cement. C) Pump 12 Bbls.of fresh water behind. D) Displace with 53 Bbls. of CaC1 brine (puts cement 2000' above stinger and fresh wnter 500' up annulus). E) Stop displacing and close choke line fast. 9) Ntth annular preventer closed, stab into EZSV and squeeze prepad and 15 sxs of cement past retainer. #htle squeezing prepad and 15 sxs of cement, bleed off backside and open . annular preventer in preparation for unsttngtng and displacing the remaining cement on top of the retainer. Total displacement is 12 Bbls. of fresh water and 96 Bbls. of CaC1 brine. ~C~~ 10) POOH to 11500' and reverse circulate. ~~~ BLB 6/84. ~.,as~ Oil ~ ~ Cot~s.~o~s~°n June 13, 1984 Shell Western E&P Inc. A Subsidiary of Shell Oil Company 200 N. Dairy Ashford P.O. Box 527 Houston, TX 77079 Alaska Oil & Gas Conservation Commission ATTN Mr. C. V. Chatterton 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen' Attached are duplicate copies of the May, 1984 Monthly Report of Drilling and Workover Operations for SWEPI's Seal Island Well No. OCS Y-181. Yours very truly, R. G. Hollis Division Production Administration Manager Pacific Frontier Division RGH:bjh Attachment STATE OF ALASKA ALASKA (~". AND GAS CONSERVATION CQ[:"',~IlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATION 1. Drilling well ~X Workover operation [] 2. Name of operator Shell Western E&P, Inc. 3. Address 601 West 5th St., #810, Anchoraqe, AK 4. Location of Well at surface 99501 1530' FSL, 642' FEL, Sec. 11, T13N, R13E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 50' KBJ OCS Y-18.1 (BEE) 7. Permit No. 84-17 8. APl Number so- 55-201-00005 9. Unit or Lease Name OCS Y-181 10. Well No. No. 1 11. Field and Pool WILDCAT For the Month of. May ,19 84 · ;12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded 2/4/84 Depth 5/31/84 - 13078' Footage Drill ed - 1961' [{FT. logging tool stuck @ 12713'. Prepared to fish 5/31/84. 13. Casing or liner run and quantities of cement, results of pressure tests 9 5/8" casing to 12288', with 1450 sx Class G cmt with 1% CFR 2, .3% Halad 9, and. .3% KCL, tested casing to 2500 psi. '.. 14. Coring resume and brief description #1 12300-12361' Rec. 61' #2 12361-12421' Rec. 60' #4.12421-12424' Rec. 3' #4 12424-12466' Rec. 20' #5'12466-12513' Rec. 42½' #6 12513-12534' Rec. 11" 9" 15. Logs run and. depth where run #7. 12534-12549 #8 I2564-12598 #9:12598-12627 #10 12627-12634 #11 12634,-12654 #12 12654-12711 Rec.' 14' 4"' Rec. 48' Rec. 28' Rec. 7' Rec. 20' Rec. 49' #13 12711-12760' Rec. 48 #14 12760'-12812' Rec... 48' .10" #15 12812-12872' Rec' 60 CET 11930-9650'; Gyro 11935-0'; 'Dia-Log Csg Caliper 11.1755-0'; Caliper 11485-0'; DIL/SFL/DHC 13058-12268' ;' LDT/CNL/NGT 13061-8254'; SHDT. 1305.6'; Micro' Proximity LOB; LDT/CL/NGT; Velocity Survey; FDC/RFT. <16. DST data, perforating data, shows of H2S, miscellaneous data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ., RECEIVED ' JUN2 1 191 Alaska 011 & Gas Cons. Commission Anchorage .... .. SIGNED' ~j~/~f ~ TITLE Div. Prod. Adm. Mgr. DATE 6/8/84 .,. NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate.' ' Rev. 7-1-80 SUNDRY NOTICE8 AND REPORI~ ON WELL~ '"~ STATE OF ALASKA J , ALASKA (' _ AND GAS CONSERVATION CO(.' AISSION ~ 1. DR ILLING WELL ~ COMPLETED WELL CT OTHER AK 99501 7. I~m~it me. 84-17 APl ~ ~o- 55-202-00005 _ocs v-,2.82 2. Name o! Shell ~stem E&P, Inc. :3. 10. Wall Nemew Plo. 601_.~st 5th S_t:.,..~810: Anchorage, 4. LOCali~fl M Wldl 1530' FSL, M2' FEL, Sec, ].1, TI3#, R13E, Utl 11. Field and Peal OCS Y-18~ (BHL) ._ ~ ~~ioM ~. To Indimm Nlmm of Nat~, Re~, m ~her Dam ~TICE OF I~EHTION TO: ~EQUENT RE~RT [] mhm 0 [] 5, EJewxion in teat [iqdir4t. 1(8, DF, ~c.) trmbmlt M Triplir, me} Stimvlate O Atlaeelem [] StknulatiDn Pull Tut~el 1'3 ~ ~ Pailful (Note: Report muh~l, c~odetio~# o~ Form 10~07 with s submittmd Form 10407 for Meh · . fee Abandanrr~qt me 20 ARC 25.105-170). See Attached. 14.! i~rd~y MftfJ~ Pm the lek, going is true m~m~'~9~t~ The tlaaee I~ew~fm, t~,ammimmt ale Approved Copy' Returned belt O! my km~wle~e, RECEIVED JUNo ~ 1984 Alaska OiJ & Gas Cons. Commission Anchorage . Title Dry. Prod. Adm. Ngr, · IY Oirdlr of COMMISSIONER the Commir~oe · · · · · . · · Prtlling has been ceepSeted, A c~]tper log has-been run castng to check for wear,' l~.m 7" 1{nar and PaR have been and .:-- -:.,-......-. .... cemeAted, .:Th~..:ltner....lap has..been., p.~.s.su, re...t,e..s..t...ed.....a.n.d., t. nrlo~ tested, The casing and 11n~r are full of dr{11fng '~'~; ...... '"' "' ': "'"'"" ..... ' :::" ...... "" ="'"' ' "' PROPOSED OPE:RAT]ON: The purpose of tlits prognosis t5 to outltne the coRoletion, test end plugback procedures to_be foiler deal for each of the zones to be tested in the SadlerochJt formatlee . PROCEDURE: I, Run ~n hole with 5-7/8' mill and casing scraper on 3-2/~' d~111 l~i.~. ~ slowly etth bit and scra~r through PaR. Clean o~ 7' ~r ~ ~. ~splace ~ f~ ~s~ng and l~ner w~ clean, ftlte~d sea~r. ~n ~tu~s a~ clean, displace sea,ret wtth c1,,, [?lte~d g.7 CaC19 ~r, P~ssure test'cas~ a~ 1trier ~ ~ ~ su~a~ p~ssu~. ~. Rig up Schl~berger.. Run a GR/CBL/CCL lag from PBTO. to 100' abave .. the 7" liner top. ruth 0 pst s.u. rface pressure. Hake a second GR/CBL/CCL log ru~ vtth 1500 ps~_ surface, p~essLi~. Run the Cement Evaluation Tool from PBTD to 100' above ~he 7" l~ner top vtth 0 pst surface pressu..re. Rtg dawn Schlumberger - NOTE: The GR/CBL/CCL log wtll be correlated to the open hole lolt used for_ selecting zones to be tested. T~e GR/CBL/CCL log vi11' then be used as the depth reference far all subsequent perforating and equipment setting depths. 3. Hake up a~ run production equipment es ?ollows free bottom up: ]TEN ~-7/8' EUE carrier for Flopetrol gohnston imcha~lcal pressure recorders vrlth 7-day clocks. _AP_PROX.ZHATE LENGTH_ ],5' CI0 GeoVann perforatfng guns loaded ~th (Ltmg_th to be supp z ~:.7 gram RDX charges, 4 dSPF. gO°phastng later) = ,,, o Ex~ ftr~ng head and no-go " .... "' "·" '"-'"~-318I' "'JUT. tubing" '- sub~," "":'; °' " """" .- ~-3/8" EUE x Z-7/8" EUE x-aver ITEX_ ~-7/B" EU[ .t,.btn~ mib Z-7/8' ~£ GeoVann pressure equalizing perforated sub " . 3-2/2' EUE x Z-7/8' EUE x-over AP_ FROX ZW~.TE LENGTH_' .5. 3..1/2" EUE GeoVann ball type releas?ng sub 3-1/:~" EUE tubtng JoJnt 1t 3-~/2' EUE Otis Type XN se~ttng ntpple /Otis shut tn receptacle ~nstalled ' Xfl Nipple Bore ZD - 2,75', No Go ID - 2.6Z~') 3-1/2' EUE - Tim tubtnG Joints vlth RA tag top col tar 3-Z/2" EUE tubing As requtred for spacing Polished seal bore see1 ~ssmbly (6" ~) and locator $-1/2" EUE tubfng Joint 30' 3-1/2". EUE carrier for Flopetrol Johnston $$DP electronic pressure recorders 20! 3-]/2" EUE tubing Jotnt 30' 3..~/2" EUE carrier for Flopet~ol Johnston 12' ~ Tj~e # mechantca! pressure v~corders with ~ ~- r~ 7-day clocks . ~ ~: 3-U2' £U£ tubing Jo,.: 30' t~ ~ ~ ~ _3-U~.' EUE Otis Type X seating nipple 2' ' ~ (X lllpple Bore m-..z..m..') 3-1/2' EUE tubing to surfmcm Carefully measure all equllint belo~ s.eel assembly 1ocetor to properly space perforating guns. Equ(paflt to be spaced so that guns are on depth kihen l~etor sets dram on PeR. i · *· . '. ·. i,~m" ~. . '. .1o · · . ~..~.% - ~D~S: .... : ~''. '... . .' *" L T'bt--'t~'~'~~' S~ lbS~ft,'~-K A~IBs B~A'O~ ~ift~'K~.' ...... '" TubtdQ {$ ~ ~ d~ft~ on ~]1. ~ Atlls }radfo~ servtce npres~tpttve ts ~ be on the ~g fl~r.~tle tubtn~ ts ~n ~_ Inspect the conn.tt~, .1nibS1 t~ ~~ ~Sngs, app~ htgh p~essu~ '~ad do~ (f7~732) End ~~ ~at the co~Ta~ s~UT~-~ keFt on ~o~tlon' b. -The 7-da~ clocks f. bo~h sets of mchanical pressure recordeT~ are to be started before running in. Note tim clocks are started. 4. Use care when running 5" O0 gu_ns through 6" ID PBR at the 7" liner top. Land locmtor on PB_R. F. ressu, re test,_t_ubi_ng surface pressure.. Run though tublng. GR COL log zo Tubing connection containing the RA tag to verify that guns are on depth. Pick up tubtng and space out for. 2' slackoff after landing locator on PBR. Motes: __ a. If l~e tubing mhd ~R do not pressure 1~st. refer to attached contingency plan for PBR failure. b. Do not allow tubing pressure to exceed casing pressure b~v over ~SOO ps1 mt the PBR, o~ permanent corkscrewing of the tubing To avoid exce~'ing 2500.p. si at the,FBR: the following surface d~ffe~entla! pressure lfrita.t{o, ns [w{~ 9.7. FP.g C"Ciz in mndulu.$) a~e.. pequi~ed: XaxtnwJ, Surf.ce Differential Pressure FI.~ 4n Tub' a ~ (T~ing to Annulus)-- '"'- ...... '"- - - - . ,, c VED ' ~9.7 pp C~l 25~ psi. . ' ~S · {Oil' ~P with n{t~. ~x~ ~u~Ace p~ssu~ ~i~d ~ ~ p{i. N{~, vol~ ~{~d ~11 ~ ~4~ gm]Ions plus ~ d~ vol~. ' If n_ttrogen ts not'av, atlable due _to' transportation 11at~attons, dtsl)lace entire tubing string #1th dlesel. Kaxtmm smYace pressure requtred krlll be 1700 pst wtth g.7 ppg Cae1z tn the well. Lower tubing'and sttng tnto PBR. Slack. off .2', Land tubtng hanger tn tubtngs _ppol and lock do~m hanger ~th se~ screws: Bleed tubing p~es~ure to 0 pst. Pressure. test.aT, au.los to 3000 psl, ' o 7, Install back _pressure.vel;ye tn tubing h~nger. Remove BOP assembly.'" · In$1mll 10,000 p~t llp Xmas tree. Remove BP¥. Pressure test - 'b~n~e~ and tubing'-s.pool trlange connect-ton to. lO,OOO ps1 .~Jth 8~ Notes: hydraulic 6t1:' P~essure test X-ms tree to 30,000 ~1 fftth water.. Re-check al~ surface test factllt?es and al~r~ all personnel, that rforating'ts to conmnce, l~sta11 20' lubricator for 18' x. detonator bar, Drop bar to fire guns, D~p bar so that ~ntttal flow ~sts can be done tn cl~yltght. bB Ce If' tubing'was displaced with diesel (underbalance - -+ 1160 pst), pressure up annulus ~o 2000 ps~, Drop detonator bar. If guns do not fire, refer to attached p~cecture fatlure. g. Bleed pressure off gradually .to b. ring well tn. Follo~ procedure outllned In the detafled production testing plan to be supplied. I0. After ~e11 has cleaGed up, shut in at surface until pressure stabilizes. If flo~ was clean and stable, ~ig up to run do~m hole ressure transducer wtt~ Otis dowflhole shut tn two1. Test ubricator to 5000 pst. Run teols tnto ~ell and rake gradient -stops every 1000'. Postt$on above recepticel. A11w-pressure- transducer to stabilize t9 assure proper functioning. Lcwmr tools and latch ~nto recept1.caT. Coptt~ue teel~ test as per production test plan. 11. ~en testtng is cmplete, pull pressure transducer from recepttckl. ..... - ..... .~e- ~r~.,pared--to..pump..M~. _-. ~t~..t. ng../~..equali.ze_.?e~s.ure a. cros.s..,. recepttcal tf needed. F.O.O. fl. #~th pres~bre transaucerd~, t~sn detonator bar. Dispose of produced flutds by pumptng dean tubtng, I bullheadtn do~n tubtng #1th mud_ or . if necessary. Xtll ~el b_~ -be ed on:test results, Oo not. · CaCI~ ~ater, wfght to be~~tn~ed _ · excel~d frac grMtent ~st/~'tf possible, gaJntalfl castng pressure at ZS(NT--~',~,,' pstand O0 . or ~. ~t ~ lO, fl p~ flutd tn the tubtng,. ' ' ' · . ~ :~-~-:.~-~'~.--,* .~-.. ~. .. .. '-- t~e, ~ ~,s~11 and ~st ~0,0~ pst BOP ass~ly. ~ve BPV f~ han~; ~" ~' .- - .., ,: t~'&.~ ...... .$~n.b.3-.l/2.' ~ ltT. tfng jotnt t~.to.hang.er and back ou.t..s..et screws. Connect' ctrcul~tfng 1the'to t~btng. Pull up unttl'~esl assimbly out of PBR and circulate unttl well i$ stable: l~. PO(~H wtth 3-1/Z" tubing and stand tn"derrick. Use care ~hen j111ng5' OD guns through E' ZD ndle carrters and furntsh data tore, Remove pressure D, Severson, .11~8 goodcreek, along wtth an accurate ttnm log of operations, Run 7" Baker Iqodel Il-! brtclge plug on wtrellne' and set above the _ ~,,b~..~' ,;~._~..x.~,~.. top perforatl.nn (depth to be. supplied), Test bridge plug ~o 3000 ~:~:~,',..'"'~'"~' ~'?'' pst. Be cautzous whtle running brtdge plug through the PBR. Run' t~ hole wtth open ended dr111 ptpe and circulate es ~eeded to clean up wellbure flutd._ Repeat. s~eps 3-~5 for each test interv&1. Upon completion of ~s_tlng, a plan #fll be prepared for further dtsposit?~ of the WET1. ....... "' ""-- '" Approved Date __ DA~::Jc RECEIVED JUNO 5 1984 Oil & G~s Cons. Commission Anchorage - dropping tim detonating bar. ther~'ha~' b~e. M tdlcatt~ ~at Va~guM hav~ fl~, ~ follw~q p~cedu~ Should.~ follY: slt~t!~ ove~la~d..MI ~ slt~ line ~tt and ~e' fo11~iflg sl?~ 11~ ~ls~.. ' ' ' ' . a ~-VZ~' bJ. t~ss~ block · 2. Test lubricator to SOO0 pt; rill t~ the to_ol string far t~e first faa with the overshot to catch the detonatSng bar. ':B. Pay r~r~1' aU~e'~t~ .~i~f' ~" t~ei'~°le'~ aetermIM, the"exact field level In the tubing. t=_. ,,- a.,.~atfn, bar ts'4reached, latch o.~ ~ ... t of ~ tool d~ at ~e bot~ aT Repot-~ts p~u~ a mn~ pT. ~~ t~ -,~- · ~. 1: ~ g~ 7]~ --'-T~ '-:~' ----'"-- tS e~,altzd. 6. If ~ ~tt11 ~ve ~ t~f~t~ ~at ~d guns ~ve ftC. fish ?;" ~ ~ 3-V~ ba1]~ ~'~t '~t5e~ Po]at' ~a~ dp.-. ~t~1 oint ~11er, Jar d~ ~ ~ssl~le _ _ ._.._ _..k. k~**~ of ~e st~ke In case 9. h ~ trip ~ of ~e hole ~1~ ~ hasler, c~fu11~ ' ~lW pla,' ~ w,- . . ..... · . I I I i I ! I . ti ~ · i I II iq iii I i i ~ ~ I .i . . · · -- · i I m . . .~ . ..-~,.. ,.r+.:~f~_t~~ , . ~ . ._, ,,,. .,.~ ~,.~.~c-.. · . .... , . ~ . . _ _ ~ . ~' ~, -~~w ~ -~e~ -~- .., . . , ~ ~_~ , ~J &_ ~_~,,~ ... . · . · · ~- ~".-~" ;-'-- -----~ ~---~~ ~ *~ ~ fill ~t W ~ -~-:; .'- .... ' -" .' b &Mtlq W ~.~ .~r.~ r~__ ~_.~ ~..tells1 .d ~'-' '"" . . ...'. ~**_~~ ~~~: ~~.~e~ ~ ~.~ ~- - . -- · _ " "~*~"-'"'-""~ '~ ~ '" ' ' '~ · ' ~ ~e~m1~ · ' '-- "----" ]1, ~TI~ ~1~ ..... ~-- "- "-'---!1,' "-' '*" " . .. ...... .~ : -'. '~ '~ ~-- ~-~'. ' '~'' ' .'~ _ -' _ -- _ AL~ fluid IMI .... · · . "'R.ECE:/'VE'D 'JU.No ]9e4 Alaska'Oii &. Oas Cons. Commissfon Anchorage $) _l~cker ~]O' above the perfs. Csrcul.u for .25 jtnutas clama item i~ound packing elman~s. o, . o 4) Set packer and PreSsure test the .annulus to ~O0'ps~- ' S) ~stIbli~ _ _-~ ____.~ . nm mm raT~. ~ ~er~"-,'~'~- ..... . . · ,.~1~~ IITi3 pa .. : ~'II~ .... . ' . - .- : ' ..': - · .' ' · i ' ,mB, m'. · . ~ . ' .. . . .- . . - . . . ' :' . .. .... ' · i ' I I I' I I I I ~I ~ I iI il l I i i I i I d * ~o 'Ii om d fi ,mm, ' · ,-,, _.. . · .. ~ i I · II .. i f, . . · .Ii .ii, · I ql,I ~. .~......-~,.~_.~,~._-a.._ .~ ,~,~j~ ~ ; ,~' - ~e ~' ~ ',' '-~ ~ -'~ .m... . - ., ,,-. ...~ '~:~ ~ ~ ~.~ { I ' ' ' : ' ]liklll 'w{~m m, . -- - - · ~ m s ~ ~j~ ~ ~-~ ~.m . m ~', · . . ' - -- let ~p~;;u ... _-. ...... ~1.. ~ mt . -. --,. ----= -- ~tm{nd ~m.~n$ ..- ..- mm imm ' ' "- ~= ...... ' l) If m ~n{q s~~e -' ~.~ f~ m~17iM ~ ~ut~m ~nl~.. .. ., .~ . . . ' .. -d --' ' ' · a~ Afhr dtspTaclq cunt ~ ~,q1~_~1 Jfspt,~) . . ~1~ ~ R~, s~t ~ for ~e m~... b) ¢) d) f) g) ''k) ,,i) .t) '1) .). l) .) SI~' dram one minute. 51~ doms tM) mS n~eS. Start dram f~r minutes. : Slut don slx mJmites. · · Slut diBS seven ,~iff, ei..'- .i · - 'RECEIVED.. .- - JUNO 5 ]984 ' Alaska Oil &. Gas Cons. Commi~sion Anchordgd . ".. · .. . (m, ,4, qm''sm' . · . ~ i. ~. l, ' .--.'~,--~"'.?~"-'"':"-.-'dl,~~~ '~"~ .,,?_;.~,~'.'& m~-q,,~-'m.-~_'e.'..'.~L~/~...~_ .?.' ~1 · ' -., . I .x ,_-..- .- .' ,~_ -_-~,~_..",m~r. Jm'.m~--~--.~_"~_~~ml _'--~m~'- m.,~'-.----~,~.'mLl-'~, --_.,~_ '""~ '__'" .~ .,I .., ~'" .~'-- · '~m_,l~'-,- -"'--~ ;.',. . - · · · . ~, ,r, It,,,,; . ,-.p. .. ~...-,...,,~, .. . . .. ~ ~.,_ .,,~ ... · · ... ~-',,~{~~~~~--: ¢,,.. ~.r'~SCh, :.,, .. ,., ....~ ~-..~._..,.., .;. ... ,..,. · · · .,mm · al~ Imm· · mm ~ - ~,m .- ~ mm.. .- · ' . . ~. · ~.. · . . · ~" v'" -- "~~,.~"""'-..~'..~---~-"'" ' ,,.,,,,.~ --.- ,L.,,,u,-. lJl~r~lJlJ, li,W~'J Jl .J ,.A' ". - F: .... ~. i=:-~:e--~.%'-~_L&_Ar_j &~di{nllC3~ ~ IILII ~ we~ ~---__ ~-- _~e_-q.-- J ..... ~ .£ -, - JPi)Wdilli~lliI J~s"u''_l''--~.- . ........ &1 dldb ~ O~pr~ll$JlJ; -.--- ol', .~' · '~2"~-'-" 'q' _______,L ' ffddg" W~I~P. ~ ~,~1~ M mm ...~--~ q. ,m~ ...,, La_d_' '-- ' . ' - ~~ ~m~%r.~~.~.-~- .. --. :~ -~.~--b_-~'~-~7.'~..-.~ .~'- .- · '" ' -, . - · _q~*- ;~..~'_*_~pe=_~.s.,.,G,4L.~'-~_d.,,~, ~_&_ "-" - ..., -,.._* ----*j~.~--",-'~'. - . ..... o. · ~.. ·- mu~_~...us.~J.--.~_~ll~, --~,:,"W"~"q,m~ · ~ . - m do'& ' .,S~ .'- ~"---. u. 0~,, ~..~o. 0. -- : ' -d "'q,~"._'~""e,'~'~ ~_.,'~' ~ib.~ "f~'~'--~ '"--"~*r ' ' '--~'- **'': '~'-~*""" ' ~.:~--'.* "' ..... -- · , ' '' ~'-'l'oo-.d' ,dm- . qm,-~-'m --' ,~ J,d 'o . II .-- .-,.4m -- ; ~ o .o ,m . o . ,-.,, .......~.=. ,......_~.4.)-~~....~:.,',._- - ___L...--..,,,m ,,.,~,.,~ - ·-,,... .- . ~*dl ~ m,~m u T~"._--_ ruuiI ism ~ " . _~_.. ~... ~IY ~ tod iS be3ov .J, m~;, .... ._ .. . . ~_irl.~lllmlll~ Jig "~'-"--- m . ,. . ,m. , -- -' 4, ' ] ~, - · · m-rog --~---- -- -- amm, m~.I ' ' ' 'd'lm' · '" ~ "~"' 6 m, . · o...Im. 6-m~'"' ~ . e ..m, . . . . ~r~ I~fm"~ mm~ ~£.-...--:-.~' ~-------.- ----. ; '-.' · . . ' '.-, ,,,, u,,; ,.,,s,.. ,,,,,o,._,,:,.,,.., 'vl"ml above {nftfalobreakd~ i~ressure; ~esqueeze ? ~ , .. [--. _ _ &d&- I, · . "~d" .''' ' '--~''' ' · · . ,o~ pressm'..._,~.-__ -:: '--:-..... ' - .-. · ' ' '" b i G-~L lo2-~M ~T 1~ ocros~ U~. , il) Rig up lu.b.r _. _, Jhld ~000 Dst above bmakdc~n pressure oa . s~eeze jn~er.:*-.-.-- -=--.-- - - - the caslng uhtle running the aog.. . . · · . . . ·. · · ,,m, · . imm -- ' . . .I, · ~ · M~i% ~ d i dm* I I mi I I · RECEIVED JUNO Alaska' OiL & Gas Cons. Commissign ~, Anchorage . I i~ am& i. · · · · · mom ~1 · I'"m"I'lid~lPq"l~Ip · . .,. ......... · -'.r,.-,. '1-.~- A', '','- .~.~.-.-,"~' . . -,..,',..,,,) .! ~':~f.:.', ... .............. · . ~,.,-..~ .. .. · · ,I · v ~ · iib FD11o~'IMs ~~edure Sf'tubfno/PJR w111 .not press, u~e test~ Step 4 of · · o. the completion '~"*'*~"-'*~;°'~'~-~- ':-*:'**'~"":**'"'?'~'"'"'-":~'::":** ": ':""* ::*'*" ' prpgn, osJs: · .-. -.,..: ~, ..*.::F.~.... ,',. :.- ...... ,'--: · . - ' . . ..... ... . .... -'~""*' .......... :"" Px'lu tn the X*n~pple ~ the 1. Ri up ~?rel~:ne unit_and set Bt sea ~ssemM~. ~ressure tesT, tUD~ng ~0 g~uu ~, &-- *~--,u · '. P 1 ' , Use. drotest ~ns~de test equ!nt · T,O IOClT, e ~UDlilJ t I ' ' wtth c~!et~on flutd fr~ surface, pres.s'dl~ testtng perSo~tc.11~ · '~o find the leak. " - .". ' .' - '"' "" :~, 'If tubing t~sl~ kn~n.-o_~.~~_ v."_'........~ el nfs and rewnntng spacer seal units. ~ons~a~r re~Va~.-¥ -""' -ema. . .ti~?ng. .... -.;.,::.:.,.. ~...~],,;..~.;,;..~; ',...:.... .~ ~. .-.', '.,.;,.. . .-,. .; -- .. -;:-'. ,:. -- 3. If tt t~ ...... ----- --.q ---L-r on ~trallne and se~ I , ~e ~ac&e~' ..snoulO ~lve i o,~I '&cue a~ve ~e 11~r ~P, _ : _ --' O' snl bo~ ~ ~ e ~tllo~ exbns4on a~ a ] ~, ~nd b~_~ p~.,__ ~.._~_-uSde. ContTnue the p~gnosls, ustn~'~e 6" packer bo~ tn place of the FBR. RE'CEIVED · · · · . · :' .." · · ".:10NO5:1984 · -"' ' '.::.." ' ' Alaska' bii & ea~ :Commission · " "'" ' ' Cons ' ' ' · I%" - · ' ::. .-. - - Anchorage . · i,, '" .m $- . · . i i I I I ~I II I i i · I~ · · · .~,., -I ".'- :" f ;'* .... ·" ' ' " '.''' ' ' " · $ · . . . · ~ q, · mI .' -' · m ,. · · · . · d · ! ~2. 2-318" £U[ Tub[fig Subs.' 20' . 23. Extended Ftrt3g Hea. d and I~ 8'. 24. $", 4 .~P;F'P~rror~tl.ng Guns end.S, pace.rs. (es .needed) ~. ~_-7/e" EUE: _Pressure Recorde_~s2.~.....~,~s* ' . [4 ... .(Ptec~antmT)R I: L t i'V ~. U · * ' ' ' · Afl,borage 7 13 "16.. 3-3/2" TuM?9 ~'olnt 30' ~4 16... 3-2/2" k11 ?~pe Release Sub ~5 ' 17.3-3/2" ELIE X 2-7/B"'EUE x-over 16 37 .18, ~-7/8" £UE Tubt.n9 Sub 18 19.. 2-7/8" Pressure £qualtzt.ng · P~ltshed Seal ~e 'c:.~,. Seal .AssembTy ~ .... .,'" g-5/8", S3.5t, L-80, LTC R~d~oacttve ~rker Liner 'l~nser and Tte Sack Recept.fcaT Baker G-22 'Locetor ' ' · 33. 3-I/2e Tubing Ootnts 14..Otts ."Xfl~ ~l'lppl'e with Otts_ · . $~ut '~n Recept.tca~ t;pstalled · Pressure Reco~;derS' CT.VpB .K Hechan~l) · i 30' 30' 4D' 6' I . ' , I~ .-~-~ · , ~ r ~ ~~, ~ . - ~..~ ~ ,:g.:;L ~,:,.~,-,,.' ~ =- ~,.- .. _ . ~ ~-~ :,.-.,~ .;. · ..... ..'~.... .... ~.' ' F t'~' ~ ' ''- ~ -~ · .~--''' ':' ~ · ;, '- ~6 · ' · ; ~.~ ~ ,. , ~ ~,,~,...~. ., .r · . , ~. ,' ~ ;~ ~:' I~ ~ .~' · ~i- "~'- ~ '~.' '", ~- '1"~- ~ ~ ~' L- -~L~ i ~r ~ I /i l J . ! ii I ' ' . ~, -.;~ ,. , -~ w ~I , %,, · ~ ,~ ~ II .~ .'- I ~ ...... ~-:'~,:~.~'. ~.. ~ I! ~ · ~ fl ,,,...'--' .. :. ~ /I :' ; ' ! · '"'~:~.-"~"~' ;' .~ II S,'--' ,-' -... .... _ .. ', ._ ~ "' · . ..- .-:- ..~ :.....~ ....... ,..., .,, ,,,-.,.-.-,. ,. "~ -..--. ·= ~/I~' · -"l~'""' "'--~'-- ' ' .... ' I! ~ · ' -- ~ · rL /- t /U i I · :. '"~ ' ' · ~" ~1 il ~ _/1 ~ _ J~.-~-- ~ ..~' .. ~ .... . ~ ~~1,1~ ~~ ~~ '~ L · r . - ..... ; ' ~, . ........· ....... __ · _.,--~ ~, ~ ~ ~ " . ._... · ...' -......; , ..,,.. . ~f ~~ I ~ ~ "· ' ~.'.,~. :' ' ' ' '' ' ' " --/--* I . · . .-.. ' ~~,~ ~-~.¢ 1¢~" ' ' ' ',. i; '.'. ': · "¢':-' 'l" :" J "~~ ~,~',,,~, · e',-~"/'~ I . ' ' ... v' ' ~ ~'"- ' · ''* ' ...... . ' i · ' ' ''~ ..... '' I ' ' ,.~_ .. . .....; · . -.. .--., . · . · .. ... · - " I . .....~. '.....T ' ' ' ' .e " '~ '-'- .' ~ ' * ' · *'! '.% "-~--.""~'" '" ." · .I · ' ... .-[. J ¢¢*.y .'..-:-,.-.. .~: ·. . . ~ '/ · .-- · . . . ~ - . · ~ [. . .............. ---,~- "" :'' ...... . I . -I - ' I~,~ . . . . · - . . ";"'" ' ' .' . '1 >"-' '1 ' '. " · . ~ ~~ ' "'. ~ · · .~';- '~ .' ... ' '- ' ': .'!:' ' ' i "! ~ '. · . · -~:"! % · ~ I I - - · ~ ~ ~l · i , J I ' ':- ~ ' ' · - ~,,;~ .- ... ..... .._. ~... 6 ~ * l~ , ' . .. . .- ~. * , ·~~/.,... - ....... . ~ ,'~"~ ,~ ,:. .:~:~ : ;.... . '.... ~ ..:;:' _ .. .~ · ~. .' . -./- ~'~"~ ~ "._..~1 I ,..;.~,~ . , : ?'~..' :.': .. '"' . ,:~ ' . f ~ .'I~. · :-1 I ' " . '--t ~ . . ~ . . .;' ..' , . , · ~j ~ ' , ~ i ;'..-I di.~ .~, . .. ' s;i .. -.. . 1 I'l '1 ; ._! ~~, _- ' ' · - ' - 'T;'"'':. ;...' --- -I ~' .., ~ ,. '' ~ .l' ' ''l - ':' ~ '' ...~'. .' .... · " · qJ m " ..' - d ... ~_ . ~ ~ ~ & J ,~ ~l . ~. .~ ~4... ~tAS]NG ~ ""..-. ,~ z. · -'- · · · .... · -- .- .-.~ .~,-.~.., .~'--. :'~ .~ - . -~. · : .... ~' -, . ,, · " ,' "' ;. ..~:.~,~, ..... - --- . 4~'..mmo.. .~.- romp . ''~ ' ........ · .... ,~ ..... ~.2,'5 .. ~": 2 ~' ' ' "~ ~518",. 5~,5 lbs/ft,' L-~ .':, '.'--~.'.~.'.,- ' . .:-.': .-,. ..... -:..':"' "...:- :' '~'" ' Nontna] ID - 8.535' Drtft.lD .' 8.37~" " Cap~ct~ - 0.707 bbls[ft,, .... : ,.- ..- :.., ::. .. , Ltm~t' LU~3;ce casfhg_ pressure to 4S~ pst du~ ~o drlliJne wear ~1 i~r Log gesulq:' ' ' .:- . il Burst Rating wlth {.33 _$. F. (Xo,Braxtal~ Effects) · Depth 'R_ .egetfltng ~all ' 2630' - · &TS 32500 8311 4995' 803 6256' · . ' 771~ · . · · · d,- 4.0 ps! 4950 ps1 4950 pst 4770 ps.t 4590 ps~ Collapse = 8600 pst I'UBIN6 $-3~2". 9.3 lbs/ft, L-80. ABC Modified' EiJ£ Nomtnal ID = 2.992" Dr. tft ID- 2.867' Capacttd~ - 0.0087 bbls/ft - - Burst - 10,160/1.33 = 7640 ps1 Tension - 207,000 lbs .. om HOUSTON_ OFFICE_ Bruce Bernard · 1ohn $~sler Gary Sauer Romon Valle.lo Daffy1 Lamb~e Chuck Severson Hans Owens Bt:11 I~ag_nuson Gene I~nly Fram 723-B70-4440 4443 4447 4448 4535 ~477 4463 23S3 4458 4465 o. HC~ 713-497-7033 496-5801 463-.1217 320..2726 358-6801 626-4344 578-7833 443-3429 467-1834 896-92M Anchorage OCfice Kenat Offtce Seal Island Pete I~oodson Hont, y l~ood ~le,yfle Stmpson Brtan Kuehne Brtan Briggs ~lohn Douglas Bill Osbor~ Bob #olf Bob store 907-276-2545 283-3096 659-3185 907-344-8857 344-1420 243-6992 346-335;9 263-42O0 283-7936 262-4529 345-6856 -JUNO ~ ]984 Alaska Oil & Gas Cons. Commission Anchorage · · · · · · · ~eoVA~n -- .. - ., .: ':' · '- ~- - e.-~' ' · · , · . · . . ... '.... ..~..,- · ,., .-:':.:. '.:~,' · "" ... _S_E_RVZCE cD~P~ CONTACTS · · Ga~y Shelton Houston ~?ohn R~de~ . An. cho~age iI ~ II BakeP 713-578-91s'4 907-338-716~ Del Holcombe Anchorage 562.1939 8tll Dean Anchorage. 561-1939 Flopet~ol · 9u.d Ftontgomer. y B s 11 HIses Otto Ooske T~ Young Houston 61enrock, AnchorAge Anchorage 240-7CX)0 307-463-5608 349-9628 349-9628 Bur~ Hidalgo Rob Robertson Bill Be.yes Burton Bates Anchorage Anchorage Houston 562-2254 562-2254 676-5572 747-324O Camrofl A1 lan Bruns Houston 939-3060 · i · RECEIVED · JUNO ~ t.~J84 Alaska Oil & Gas Oon$. ~ommbslon Anchorage Shell Western E&P Inc. A Subsidiary of Shell Oil Company 200 N. Dairy Ashford P.O. Box 527 Houston, TX 77079 May 2, 1984 Alaska Oil & Gas Conservation Commission ATTN Mr. C. V. Chatterton 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen' Enclosed for your information are Subsequent Report Sundry Notices for work on the following wells' Seal Island OCS Y-181 Middle Ground Shoal All- 12 Mi ddl e Ground Shoal A34-14RD2. Yours very truly, R. G. Hollis 'Division Production Administration Manager Pacific Frontier Division RGH'bjh Enclosures RECEIVED MAY 0 71984 Alaska Oil & 6as Cons. O~mmt#~ Anohorage STATE OF ALASKA ALAS · - O'ILAND GAS CONSERVATION O~ MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1-' DRILLING WELL ~ COMPLETED WELL [] OTHER 2. Name of Operator Shell Western E&P Inc. 7. Permit No. 84-17 3. Addr~s 8. APl Number 601 West 5th St., #'810,' Anchorage, AK 99501 s0-55-201-00005 4. Location of Well 1530' FSL, 642' FEL, Sec. 11, T13N, R13E, UH 5. Elevation in feet (indicate KB, DF, etc.) 50' KB I 6 . Lease Designation and Serial No. OCS Y-181 (BHL) 12. 9. Unit or Lease Name OCS Y-181 10. Well Number No, 11. Field and Pool WILDCAT 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 I-I Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ri 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). 4/11/84 4/12/84 4/13/84 Circ, Drilled to 3015'. . - 4/15/84 Drilled to 4921'. Ran wireline survey. 4/16/84 Drilled to 6054', building angle slowly to 5700'. Ran Dia-Log Csg Caliper'Survey. Tested BOP. All OK. Perforated DP 10518- 10510'. Rigged up Howco and equalized 1000 cu. ft. Class "G' cmt with 1%, CFR-2 and .5% Halad-9 thru perfs. Backed off safety joint @ 5431'- Laid down 5 its. of DP. Spotted 885 .sx Class "G" 16.0 PPg cmt plug. POOH to 2000'. Circ'ch°lewo clean. RIH to 2093". Tdp of cmt e'2152'. Drilled soft cmt to 2600'. . Pressure tested csg'to 1800 psi with 9.4 .PPG mud. Fish left in hole. Cleaned out cmt 2600-2663'. .WOC Circ) 2663'. WOC Cleaned out cmt to 2725'. R'E"C..EJ,'V.E,D:-..." ,'., .. , MAY 0 71984 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that, ~e foregoing is true and correct to the best of my knowledge. Signed (~7~~ Title Div. Prod. Adm. Mgr.. The space below for Commission use Date 4/30/84 Conditions of Approval, if any: Approved by COMMISSIONER By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "1 mentions" in Triplicate and "Subsequent Reportt" in Duplicate Shell Western E&P Inc. A Subsidiary of Shell Oil Company 200 N. Dairy Ashford P.O. Box 527 Houston, TX 77079 May 3, 1984 Alaska Oil & Gas Conservation Commission ATTN Mr. C. V. Chatterton 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen' Attached are duplicate copies of the Monthly Report of Drilling and Workover Operations for SWEPI's Seal Island Well No. OCS Y-181. Yours very truly, R. G. Hollis Division Production Administration Manager Pacific Frontier Division RGH-bjh Attachment RECEIVED YoTlg84 Alaska 011 & ;as Cons. Comml~at Anchorage - ' STATE OF ALASKA ALAS~(' )ILAND GAS CONSERVATION. )MMISSION MONTHLY REPORT OF DRILLING AND WORKOVER 1. Drilling well Workover operation [] 2. Name of operator Shell Western E&P, Inc. 3. Address 601 West 5th St., #810, Anchorage, AK 99501 4. Location of Well at surface 1530' FSL, 642' FEL, Sec. 11, T13N, R13E, UM 5. Elevation in feet (indicate KB, DF, etc.) 50' KB 6. Lease Designation and Serial No. OCS Y-181 (BHL) 7. Permit No. 84-17 8. APl Number 50- 55-201-00005 9. Unit or Lease Name OCS Y-181 10. Well No. No. 1 11. Field and Pool WILDCAT For the Month of Apri 1 ,19 84 '112. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks ~__~Spudded 2/4/84 ' ('DePth ~4-- 11117' ~Footage Dril'"'i'~d - 9117' ' )Lost hole back to 2000' while fishing for stuck logging tool and drill '~tracked.and redrilled to 11,117'. k, Fished for packer @ 7565'. Recovered fish. 13. Casing or miner run and quantities of cement, results of pressure tests pipe. Side- 14. Coring resume and brief description 15. Logs run and depth where run Dia-Log Csg Caliper Survey to 12,224'. ..16. DST data, perforating data, shows of H2S, miscellaneous data Perforated DP 10518-10510'. Cmtd. through perfs and set plug. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ' RECEIVED MAY O ? TITLE Div. Prod. Adm. Mgr. DATE 5/3/84 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with th~ Oil and Gas Conservation Commission by the 15th' of the succeeding month, unless otherwise directed. ' Form 10-404 Rev. 7-1-80 Submit in duplicate Shell Western E&P Inc. A Subsidiary of Shelt Oil Company 200 N. Dairy Ashford P.O. Box 527 Houston, TX 77079 April 12, 1984 Alaska Oil & Gas Conservation Commission ATTN Mr. C. V. Chatterton 3001 Porcupine Drive Anchorage, AK 99501 Gen tl emen- Enclosed for your information is a Sundry Notice for Seal Island Well OCS Y-181 No. 1. As discussed in our April 10, telephone conversation, we plan to plugback, sidetrack and redrill from the bottom of the surface casing to the original 'target location. RGH' jc Yours very truly, R. G. Hollis Manager Pro.duction Administration Pacific Frontier Division Enclosure . : (. ,, STATE OF ALASKA ('III ' ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL COMPLETED WELL [] OTHER [] 2. Name of Operator Shell Western E&P, Inc. 3. Address I~01 West 5th St., //810, Anchorage, AK 99501 4. Location of Well 1530' FSL, 642' FEL, Sec. 11, T13N, R13E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 12. 7. Permit No. 84-17 $. APl Number ~o- 55-201-00005 9. Unit or Lease Name OCS Y-181 10. Well Number No. 1 11. Field and Pool WILDCAT OCS Y- 181 (BHL) 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 r-I Repair Well [] Change Plans ~ Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). See attached. C. V. Chatterton gave verbal approval of the attached plan on 4/10/84. St~bseq~zeut ~o~k BepO~et~ n,a F<~:m ~qo. -~ RECEIVED APR 2 0 191i Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby c,e[tify tha~the foregoing is true and correct to the best of my knowledge. Signed Title Div. Prod. Adm. Mgr. The space below for Commission use Conditions of Approval, if any: Date 4/10/84 Approved by IIRl~IN,![ SiSNED lit LOilNI[ IL $IIITA! COMMISSIONER Approved Copy By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports"in Duplicate WORKSHEET PLUGBACK, SIDETRACK AND REDRILL 12-1/4" HOLE , . STATUS- SEAL OCS Y-181 NO. I 13-3/8" casing cemented at 2,650' 12-1/4" hole to 12,498' with 5" D.P. fish from TD to 5,431'+ 1. Run Dia-Log casing caliper in the 13-3/8" hole to check for excessive casing wear. Contact engineering in Anchorage with the results of the log. ., 2. Rill with a screw-in assemb.ly which includes a cut lip guide, skirt, screw in sub, and a bumper sub. Screw in to the top of the fish and re-establish circulation through the bit. Circulate for at least two hours. After circulating for two hours, plug the bit. RIH (inside the drill pipe), with a 10', 2-7/8" Schlumberger Hyperdome perforating gun with 4 shots per foot phased 180 degrees. Position the bottom to the gun at 10,500' and shoot. POOH with the wireline. Note: while per- forating and setting the cement plug {step 3), constantly reciprocate the pipe the full stroke of the bumper sub. 3. Set a 1,000 cu. ft..class "G" cement plug with CFR-2 and 14alad 9 {quan- tities to be determined by tests currently underway) at 10,500'. Cir- culate 10 bbls. of water ahead of and behind the cement. The top of the plug will by at 9,900'_+ (figuring 100%. excess). Release from the fish and POOH. 4. RIH open ended to 3,100' and equalize an 820 cuft class "G" cement plug. The top of the plug will be at 2,600'_+ (figuring 100% excess). POOH and WOC for 12 hours. RIH and tag the top of the cement. If the. cement, l~op is inside 'the 13-3/8" casing (as expected), pressure test the casing to 1,800 psis. If the cement top is below the shoe, tag the firm' cement top andl discuss the next step with Anchorage operations and engineering. Polish off the plug .to 2,750'. Change out the drilling mud to a fresh water dispersed l ignosufonate system. 5. Kick off to the left of .the original hole using Teleco's I~D to orient the dyna-drill. When building angle with a building assembly, use a "Big Eye" (jet} bit to adjust the angle and direction. BDK/dr 6. Drill to the 9-§/8" casing point as shown in the original prognosis. Do not get above the prognosed section line and stay to the left of the original well path. No cores or logs are to be taken in the 12-1/4" hole.' Run. the mud with a 8-10 cc fluid loss to 8,000' At 8,000' lower the fluid loss to 5-7cc and maintain that fluid ~oss to l.D. Maintain the other mud properties as outlined in the original prognosis for the 8-1/2" h° e cEIVE ' · APR2 0 ]984 Approved: Alaska Oil & Oas Cons. Commission II. '~'. Woodson ~z:, r-. Anchorage SAGAVANIRKTOK COLVILLE PEBBLE SHALE CRETACEOUS UNCONFORMITY KINGAK SAG RIVER TD (DRILLER'S) PRIVATE AND CONFIDENTIAL SI~EPI ET AL 0CS-Y-181 NO. 1 .BEAUFORT SEA AREA NORTH ALASKa, MD~. d9~'~- 4980' 7749' 10,058' 10,355' 10,764' 12,448' 12,489' T 4776 6893 8792 9039 9369 10,744 10,777 ~Core # 1 . .;~-Core # 2 :~--Core # 3 10,396-10,411' 10,411-10,468' 10,468-10,508' CORE DEPTHS Cut 15' Rec. 14' Cut 57' Rec. 57' Cut 40' Rec. 37' Final (SEB) 7/30/84 *This hole was lost and plugged back to 2600' and redrilled from 2600' to 13078'; thereby creating two sets of geologic markers. PRIVATE AND CONFIDENTAL SWEPI ~T'"-AL OCS-Y-181 N'O. 1 '- BEAUFORT SEA AREA NORTH ALASKA Col.ville Pebble Shale Cretaceous Unconformity Kingak Sag River Shublik Sadlerochit Ivishak Echooka ki sburne TD (Driller's) MD 7,764' 9,892' 10,262' 10,647' 12,232' 12,348' 12,451' 12,833' 12,924' 12,960' 13,078' TVD 6,903' 8,791 9,032 9,367 10,700 10,796 10,887 11,210' 11,290' 11,322' 11,415' Core # 1 Core # 2 Core # 3 Core # 4 Core # 5 ..... Core # 6 Core # 7 Core # 8 Core # 9 Core # 10 Core # 11 Core # 12 Core # 13 Core # 14 Core # 15 · gore Depths 12,301-12,361' 12,361-12,421' 12,421-12,424' 12,424-12,466' 12,466-12,513' 12,513-12,534' 12,534-12,549' 12,549-12,598' 12,598-12,627' 12,627-12,634' 12,634-12,654' 7" Cut.60, Rec. 58' 7" Cut 60' Rec. 59' Cut 3' Rec. 3" Cut 42' Rec. 40' 10" Cut 47' Rec. 42" 6" Cut 21' Rec. 11" Cut 15' Rec. 14' Cut 49' Rec. 48' Cut 29' Rec. 27' 10" Cut 7' Rec. 7' Cut 20' 7" Rec. 20' 10" 12,654' 7"-12,711' Cut 56' 6" Rec. 48' 6" 12,711-12,760' Cut 49' Rec. 48' 12,760-12,812' Cut 52' Rec. 43' 12,812-12,872' Cut 60' Rec. 60' Final 7/30/84 L',~,.). ' i hole was lost and plugged back to 2600 and redrilled from 2600' to 13078'; thereby creating two sets of geologic markers. April 10, 1984 Shell Western E&P Inc. A Subsidiary of Shell Oil Company 200 N. Dairy Ashford P.O. Box 527 Houston, TX 77079 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen' Attached are duplicate copies of the Monthly Report of Drilling. and Workover Operations for SWEPI's Seal Island Well No. OCS Y-0181. Yours very truly, R. G. Hollis Manager Production Administration Pacific Frontier Division RGH' j c Attachment bc: M. L. Woodson RECEIVED API~ 1 6 Alaska Oil & Gas Cons STATE OF ALASKA ,.., ALASKa' !LAND GAS CONSERVATION (~' ~IMISSION · -.ONTHLY REPORT OF DRILLING AND WORKOVE. OPERA'r,o#Ili · Drilling well J~ Workover operation [] 2. Name of operator She]] Western E&P, [nc. 3. Address 601 West 5th St., #810, Anchorage, 4. Location of Well at surface AK 99501 1530' FSL, 642' FEL, Sec. 11, T13N, R13E, UM 5. Elevation in feet (indicate KB, DF, etc.) 50' KB 6. Lease Designation and Serial No. ocs (_R._L) For the Month of March ,19 84 7. Permit No. 84-17 8. APl Number 50- 55-201-00005 9. Unit or Lease Name ocs Y-181 10. Well No. No. ] 11. Field and Pool WILDCAT :12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded 2/4/84 Depth 3/31/84 - 12498' Fish @ 12485'. Footage Drilled - 2099' DP Parted. Top of fish @ 7025'. Recovered fish. Tool Stuck. Top of.fish"@.12485'. Continued fishing. 13. Casing or liner run and quantities of cement, results of pressure tests .14. Coring resume and brief description #1 - 10396-10411 #2- 104'11-10468 if3 - 10468-10508 15. Logs run and depth where run Rec. 14'. Rec. 57'. Rec. 40'. Logged/Gamma Ray 12123-12225' BHC to 10956' DLL/GR 11606-9069' .16. DST data, perforating data, shows of H2S, miscellaneous data :' APR 1 6 1984 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~,~a~s.,",:aJ (~ii ~, (~.~ ~i, mm.~ ~',;Wz,,rh,,,~;,; .... ....... .. S~GNED,, , T~TLEDiV. Prod. Adm. Mgr. DATE' 4/9/84 .NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate withthe AlaSka- Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Rev. 7-1-80 ., Submit i~ duplicate Shell Western E&P Inc. A Subsidiary of Shell Oil Company 200 N. Dairy Ashford P.O. Box 527 Houston, TX 77079 March 8, 1984 Alaska Oil & Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Commission Gentlemen' Attached are duplicate copies of the Monthly Report Workover Operations for SWEPI's Seal Island Well No. RGH: mh Attachment of Drilling and OCS Y-0181. Yours very truly, R. G. Hollis Manager Production Administration Pacific Frontier Division MAR !. ~ 1984 Al:~ska Oil & Gas Cons. Commission STATE OF ALASKA ALAS~" .31~AND GAS CONSERVATION L~ M~ISSION .,,ONTHLY REPORT OF DRILLING AND WORKOVER OPERATIO 1. Drilling well ~X Workover operation [] 2. Name of operator Shell Western E&P, Inc. 3. Address 601 West 5th St., #810, Anchoraqe, AK 4. Location of Well at surface 1530' FSL, 642' 99501 FEL, Sec. 11, T13N, R13E, UM 5. Elevation in feet (indicate KB, DF, etc.) 50' KB 6. Lease Designation and Serial No. OCS Y-18! (BHL) 7. Permit No. 84-17 8. APl Number 50- 55-201-00005 9. Unit or Lease Name OCS Y-18! 10. Well No. No. ] 1 1. Field and Pool WILDCAT For the Month of February ,19 ,~4 i12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded 2/4/84 Depth 2/29/84-10399' Footage Drilled - 10399' .13. Casing or liner run and quantities of cement, results of pressure tests 13-3/8" casing to 2650' with 5444 sx Permafrost II cmt , tested to 1800 psi · 14. Coring resume and brief description 15. Logs run and depth where run CBL from 2650'; Gyro survey @ 2800' .16. DST data, perforating data, shows of H2S, miscellaneous data ;, 17. I hereby certify that the fore/going is true and correct to the best of my knowledge. DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit iN duplicate 'Rev. 7.1-80 SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL []X COMPLETED WELL [] OTHER [] 2. Name of Operator Shell Western E&P, Inc. 3. Address 601 West 5th St., #810, Anchoraqe, AK 99501 4. Location of Well 1530' FSL, 642' FEL, Sec. 11, T13N, R13E, UM 5. Elevation in feet (indicate KB, DF, etc.) 12. 7. Permit No. 84-17 8. APl Number 50- 55-201-00005 9. Unit or Lease Name 0£Y Y-1 R] 10. Well Number Nh; 1 11. Field and Pool I6. Lease Designation and Serial No. OCS Y-181 (BHL) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data WILDCAT 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). Request permission to use L-80 9-5/8" .casing instead of N-80. Subsequeat Work Repo~te(1 on Fo,,rm No. -- _ Dated --/--./-- FE[~, 2 ;:' D84 Alaska Oil c~. Gas (;0r.~s. ~,omm~ssio,~ 14. I hereby certify that tl~e foregoing is true and correct to the best of my knowledge. Signed C'-'~'2~/1~ TitleDiv. Prod..Adm. Mgr. The space below for Commission use Conditions of Approval, if any: Approved by Approved CoPY Returned Date 2/21/84 Form 10-403 Rev. 7-1-80 By Order of COMMISSIONER the Commission Submit "Intentions" in Triplicate- and "Subsequent Reports" i n Duplicate February 23, 1984 Shell Western E&P Inc. A Subsidiary of Shell Oil Company 200 N. Dairy Ashford P.O. Box 527 Houston, TX 77079 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Mr. Chatterton: Enclosed for your information are the following eleven reports submitted in duplicate: Middle Ground Shoal Field Well No. A12A-01 Monthly Report of Drilling Operations Sundry Notice-Subsequent Report of Perforations & Stimulation Well Completion Report Middle Ground Shoal Field Well No. C24-26RD Sundry Notice-Subsequent Report of Stimulation Middle Ground Shoal Field Well No. C34-26 Sundry Notice-Subsequent Report of Stimulation Middle Ground Shoal Field Well No. A13-12RD Sundry Notice-Subsequent Report of Stimulation Seal Island Wildcat Well BF-47#1 Monthly Report of Drilling Operations Sundry Notice-Subsequent Report of Perforations & Testing Sundry Notice-Subsequent Report of Abandonment Well Completion Report Seal Island Wildcat Well OCS Y-181 #1 Sundry Notice-Notice of Intention to Change Plans (in triplicate) Please maintain the confidentiality of this information. Yours very t.ruly., R. G. Hollis Manager Production Administration Pacific Frontier Division ..... RGH: mh Attachments MEMORANDUM State of Alaska TO: TItRU: FROM: ALAS~ O~L AND GAS CONSERVATION CO}~4ISSION C./V//JCha~erton DATE: February 14, 1984 FILE NO:. lI. 2 Lonnie C. Smith -": .... Commis s loner TELEPHONE NO: Ben LeNorman SUBJECT: Petroleum Inspector Witness BOPE Test on Shell Oil's OCS Y.-181. (Seal Island ~) Sec. 11, T13N,R13E,UM, OCS. Friday.., ..February: !0_, 1984: I departed my home at 6:00 am for a 6:30 am Showup and 7:30 am departure via Alaska Airlines, Flt. #55 for Deadhorse arriving at 9:10 am. Weather: -52°, Clear, Ice fog. Saturday, .... February. 11,_ 1984:' BOPE tests on Conoco's Milne 'Pt. #M-1 were. comp.leted, the subje6~t of a separate report. Sunday, February' 12, 1984: BOPE tests began at 12:20 pm and were completed""at 3:15 pm. 'BOPE inspection report is attached. I departed Deadhorse via Alaska Airlines, Flt. #56 at 5:15 pm arriving in Anchorage at 6:55 pm and at my home 'at 7:25 pm. Tuesday, February 14, 1984: J. L.. Blake, Shell drilling foreman, ~dvised the va~'~e in 'the--dhoke manifold had been replaced and tested. In summary, I witnessed successfUl BOPE tests on Shell's Seal Island ~2. 02-00IA(Rev.' ~01.79) STATE OF ALASKA ALASKA OIL & G~S OONSERVATION CCMMISSION B.O.P.E. Inspection Report Location: Sec_ // T/~R/~'M &;;~ Eri! lin Contractor~Rig Location, General ~/3/~ Wel 1. Sign Ceneral Housekeeping Reserve pit .Rig__ BOPE Stack ., Annular preVenter_ Pipe 8 lind Rams, 2hoke Line Valves_ ~.C.R. Valve. Kill Line Valves- Lheck Valve .~st Results: Failures. Date ~~, /Al /Y~ Representative ._-I5~ ,~J L~ ~-.~ /~~ising Set @_~/_ $O ft. .ACCUMULATOR SYSTEM Ful 1 Charge Pressure ~ Pressure After Closure Pump incr. clos. pres. 200 psig. Full Charge Pressure Attained: _ psig psig ~ _minW O____sec. · Test Pressure ___ Controls: Master ~/~ · Kelly and Floor Safety Valves · / Test Tin~_'. ~epair or Replacement of failed equipment to be made within_ '~ _days and 2nspector/ccmmission office notified. Upper Kelly. Test Pressure Lower Kelly Test Pressure Ball Type . . ~Test Pressure~ Inside BOP Test Pressure Choke Manifoldh Test Pressure_ No. flanges_ ~4D. '. ' ~dj ustable Chokes ~ Hydrauically operated ~oke ,5 istribution rig. - AO&~CC · c - Operator c - Supervisor ' InspectoK .~_~_~,,3 W. S. Davis Division Exploration Manager Amoco Production Company Far West Division 1670 Broadway P.O. Box 800 Denver, Colorado 80201 303 -830-4040 January 23, 1984 Alaska Oil and Gas. Con)~ission 3001 Porcupine Drive Anchorage, Alaska 99501 OCS-Y-181 No. 1 Beaufort Sea, Alaska" Gentlemen. .Please be advised that Amoco Production Company has no objection to the surface or bottom hole location of the OCS-Y-181 No. 1 well as pro- posed by Shell Western E & P Inc. in it's application for Permit to Drill. SWD/WJP/sl N) o 1984. Gas Cons. Corem RMERRDR HESS CORPORRTION January 23, 1984 P. O. BOX 2040 TULSA, OKLAHOMA 74! 0Z 9 ! 8-599-4200 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 95001 Attn.' Betty Ehrlich (907) 279-1433 Dear Ms. Ehrlich- Amerada Hess Corporation has no objection to the suface or bottom hole location (1875'N and 2750'E of SE corner of BF-47) of the 0CS-Y-0181 #1 well as proposed by Shell Western E&P Inc. in its application for Permit to Drill. Si ncerely, C. R. Richard, Manager Beaufort Sea Operations CRR: ssw cc: R. W. Robinson, Jr. - Shell JAN 3 o 1984 Oil & Gas Cons. Commission Anchorage January 27, 1986 Mr. M. L. Woodson Division Operations. Hanager 'Pacific Frontier Division Shell Waster E&P, Inc, 601W. Fifth Street, Suite 810 . Anchorage, Alaska 995'01 OCS Y-181 No. 1 Shell Western E&P, Inc. Permit No. 84-17 Sur. LOc.. 1530'FSL, 642'FEL, Sec. 11, T13N, R13E, Btmhole Loc. apx. 150'~L, 150'~,~, See. Dear Mir. Woodson: Enclosed is the approved application for'permit to'drill the above referenced well. If coring t.s conducted, a one cubic inch chip from each foot o.f recovered'core is required, Samples of well cuttings and a mud log are-required. A continuous directional survey is required as per 20 AAC ~5.050(b.)(5). If available, a tape containing the digitized log infomart, on shall be submitted on ell logs for ¢opying'emcept ~xper'tmental logs, velocity surveys and 4fpaeter surveys. Many rivers in Alaska.and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05..870 and the reg~lat~on.s promulgated thereunder (Title 5, Alaska Admini. strattve'COd~). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Departmen~ of Fish and Game. .Pollution of any waters of the'State is pro'hi.b/ted by AS 46., 'Cha-ter 3 ArtiCle. 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter .0) and by the Federal Water Pollution Control'Act, as amended.. Prior ~o commencing operations you may be'contacted by a representative of the Department of Environmental' Conservation. Hr. M. L. Woodscl~ OCS Y-181 No. 1 "- To aid us in scheduling field work, please notify this office 24 hours prior to co~enctng installation of the blowout ~revention equipment sO that a repre~ntative of the Comlssion m~v be present to witness testing of the equipment before the surface casing shoe is drilled. %~ere a d!.verter system is reqllired, please ~lso not!fy this office Pi hours pr!~r to commencing eguip~ent tnstall~tion so th~.t the Commission ~ay witness test!n~ before dr~llin~ below the shoe of the coDductor pipe. In the event of suspension or absndonment, ~!ease ~ive this off.ice adequate advance notification so that we fda? have a witness present. Very tmily yours, · /,- / ,/' / ': ............ .:~- ............................................... ./' . ~..'..~__. .............. .:.? ....... ~. . ,, ~ [' . . ~" .'. :' ..,/ - .. 'C'~ .... V. Chatterton '.~S¥ oaoge o~ ¥8£ co~s$~o~ Chairman of, Alaska Oil and Gas Conservation C0mmis,ion be En¢'losure cc: Department of Fish & Game, Habitat 'Section w/o encl, Depar, tment o~ Environmental. Conservation ,w/o encl. Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 January 26, 1984 State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen- In response to the telephone request made by your Mr. H. J. Hedland this morning, I am attaching 3 copies of the HpS Continqency Plan, and the Burning, Welding, and Hot Tapping Plan fop Seal OC~Y-I~I No. 1. This material is in addition to our application for Permit to'Drill submitted to you by Mr. B. E. Bernard on January 20. Should you require further information please contact me or Mr. R. G. Hollis in Houston (telephone 713-870-4445). M. L. Woodson Division Operations Manager Pacific Frontier Division MLW/rrp Attachments cc- Shell Western E&P Inc. R. G. Hollis B. D. Kuehne JAN 2 6 2984 Alaska 0il & Gas Cons. Commissiol~ Anchorage 27.032 HYDROGEN SULFIDE CONTINGENCY PLAN FOR SEAL ISLAND DRILLING PROGRAM SEAL EXPLORATI ON OCS Y 181 #1 I. Scope_ This contingency plan is prepared on the basis that hydrogen sulfide is highly unlikely to be encountered in ~quanti ti es dangerous to personnel or equi.pment. Howev~r~ since there is no absolute assurance that hydrogen sulfide will not be encountered, the contingency plan provides for early detection and suspension of drilling operations before hydrogen sulfide would be dangerous to personnel or equipment. Further, the plan provides for orderly evacuation of personnel and protective equipment for those who may be required to shut in the well. Should hydrogen sulfide be encountered in unsafe levels and should it be decided to continue drilling with hydrogen sulfide present, a modified, more detailed plan will be prepared before drilling is again started. II. Physical Properties -' H2S Hydrogen sulfide is a colorless, transparent gas with a characteristic .rotten-egg odor. The disagreeable odor of hydrogen sulfide occurs only at relatively low concentrations. Those who have been rendered unconscious from high concentrations, and survived, report that they did not notice the so-called rotten-egg odor but rather that it had a sickening sweet odor. Others reported that the odor was sweet and not unpleasant. Just exactly at what concentration it becomes sweet-smelling is not known, but some believe it is around 500 to 1000 ppm. It should always be borne in mind that some people cannot detect the odor of H2S. H2S is flammable in the range of 4.3 to 45.5 percent in air. A mixture of two volumes H2S and 3 volumes oxygen will explode violently when ignited. H.~% has a specific gravity of 1.192 (compared to 1.00 for dry air) or a molecular weight of 34.08 as compared to 29 for air. Hence, H S may be considered heavier than air and in concentrated ~orm may collect in low places. However, at a concentration of 2,000 ppm, which may produce unconsciousness almost immediately, the specific gravity or density of the mixture of air and H.S is only 1.003 so that the mixture for all practical purposes has the same density as air. JAN 2 $1984 ,Alaska Oil & Gas tens. Comm/ssior~ Anchora§e H s readily soluble in petroleum hydrocarbons and is soluble in water at temperatures at the rate of three volumes H2S for one volume of water. Such things as heating and agitation of the water will reduce the " . concentration This solubility and the effect of heat can account, for example, for open drainage ditches evolving dangerous amounts of N2S during the heat of the day in cases where there was no significant amount found during the cool morning hours. III'. Information as to the concentrations of H2S that are detectable by smell vary considerable. It is readily detected at~ about 5 ppm; however, it is generally accepted that concentrations as low a 0.025 ppm are detectable, 0.3 is distinct, strong but not intolerable. Above 30 ppm the odor does not become, more intense as the concentration increases, and above 200 ppm the disagreeable odor appears less intense. These figures are based on initial perce~ptions. With continuous inhalation, the odors will appear less, due to olfactory fatigue. It must also be recognized that some other odors will mask even an odor as disagreeable as HpS. For example, the odor of creosols effec- ti. vely masks the odor of H2ST Physiological Effects.- Hydrogen Sulfide There are three principal effects from exposure to. H2S: l) the irritant action of high concentrations on mucous membranes, 2) the effects on the eyes which may result from repeated exposures to low concentrations as well as short exposures to high concentrations, and 3) the most signifi- cant effect - paralysis of the respiratory nerve endings from exposure to relatively high concentrations of 500 to 700-ppm or more. Aside from ~he ~rritant effects on the eyes, the principal mode of entry into the body is through the lungs. Skin contact even to high concentrations is not considered significant. It has been reported that a ,perforated ear drum can be a route of significant exposure. There is less resistance to outside atmosphere via the perforation than via the breathing apparatus, and therefore, it is reported, H2S can be inhaled through the ear under such circumstances. Ear wax and ear plugs offer 1 it.tle protection. Persons seriously exposed to H2S but who recover may suffer some lung irritation which can lead to pulmonary edema or bronchial pneumonia. The systemic effects from absorption of H2S into the blood stream via the lungs is by far the most significant effect. Under normal circum- stances, when absorbed into the blood stream, H2S at low concentrations is oxidized rapidly to pharmacologically inert compounds such as thiosulfate or sulfate. When the amount absorbed into the blood stream exceeds that which is readily oxidized, systemic poisoning results in a general action on the nervous system; labored respiration occurs shortly, and respiratory paralysis may follow in~nediately. Death then occurs from asphyxiation unless the exposed person is removed in~nediately to fresh air and breathing is stimulated by artificial respiration before heart action has ceased. In high concentrations of gas, the mechanics of this respiratory paralysis, formerly thought to involve a chemical reaction with the respira- tory enzymes or with the. hemoglobin or both, are now believed to be reflexes resulting from irritation of the carotid sinus. Moderately high concentra- tions on the other hand cause an arrest of breathing, but not respiratory paralysis, after overstimulation of the respiratory center. In such cases, resumption of breathing would probably occur, after removal from exposure, even without artificial respiration. Recovery from acute exposure to H2S is usually considered complete, although sometimes prolonged for as much · as several weeks, unless there has. been damage to the brain due to prolonged oxygen deficiency. Transient and sometimes permanent psychic or nervous changes may be encountered if there has been damage to the brain. It is believed that the presence of alcohol in the blood potentiates the effects of H~S in acute poisoning cases. Those recovering from acute. poisoning anB who have had alcohol during the past 24 hours reportedTy become quite violent. In cases of chronic, or perhaps more properly named sub-acute exposures, symptoms that occur include headache, dizziness, excitement, nausea or gastrointestinal disturbances, dryness and sensation of pain of the nose, throat and chest, and coughing. The followi.ng indicates responses to various concentrations of H2S in the atmosphere:- .. PHYSIOLOGICAL RESPONSE TO VARIOUS CONCENTRATIONS OF HYDRDGEN SULFIDE Response Maximum acceptable concentration for prolonged exposure. (TLV)* Minimum concentration causing eye irritation .Minimum concentration causing lung irritation Slight symptoms after several hours Maximum concentration for 1 hour without serious consequences Dangerous after ½ hour to 1 hour exposure Pulmonary edema or bronchial pneumonia from prolonged exposure Rapidly produces unconsciousness, cessation of respiration and death Unconsciousness at once, with early cessation of respiration and death in a few minutes Concentration PPM lO lO Moderately above 20 70-150 170-300 400-700 250-600 700-900 1000-2000 *TLV - Threshold Limit Value ( '(' Eyes can be affected by H2S exposure.°flt is believed that the effect on the eyes is due to the caustic action sodium sulfide formed by interaction of the H2S and the alkali of. the cells in the presence of moisture in the eyes. Symptoms and effects of exposure to the eyes that have been reported include blurred vision, as though viewing objects through a silk screen; appearance of colored rings around .street or other lamps, car lights which appear to be dumbell-shaped, blurred and surrounded by colored halos; red and inflamed eyes, somewhat resembling the "pink · eye", and there may be a gritty feeling. There may be intense aching of the eyes, and the eyelids may go into spasms and be difficult to open. These symptoms may disappear overnight or may persist into the next day. Hydrogen sulfide may have a slight anesthetic effect on the eyes, as often the symptoms do not occur until the 2nd to 4th day of exposure. Estimates of minimum concentrations of H2S required to cause eye effects are r~po. rted as ranging from 4 to 25 ppm. IV. physical Properties- Sulfur Dioxide Sulfur dioxide is colorless gas or liquid. It has a pungent odor and is not flan~nable. It is formed when hydrogen sulfide is burned. The specific gravity of the vapor is 2.264 (compared to 1.O0 for dry air). ' Anhydrous sulfur dioxide .is non-corrosive to steel or other commonly used metals. In moist environments, it combines with water to form sulfurous acid, but it only very slowly oxidizes to sulfuric acid. In. the presence of water, sulfur dioxide is corrosive to steel and other metals. .. Concentrations of 6 to 12 ppm cause immediate irritation of the nose and throat. A level' of 0.3 to 1 ppm can be detected by the average individual possibly by taste rather than by the sense of smell. V. Phys.i ol Ogi Cal' Effe¢ts'' 'Sul fOP 'DJ O~ i de Sulfur dioxide is intensely irritating to the eyes, throat and upper respiratory system. Its irritant properties are due to the rapidity with which it forms sulfurous acid on contact with moist membranes. An estimated 90 percent of allS02 inhaled is absorbed in the upper respira- tory passages with only sl.ight penetration in the lower,respiratory tract. Sulfur dioxide exerts its toxic influence on humans through acute and possible chronic effects. Acute symptoms of exposure are eye, mucosal and. upper respiratory irritation. Potential chronic effects include naso- pharangitis, reduction of pulmonary function and increased resistance to air flow. · Chronic effects j sulfur dioxide exposure may(..esult from repeated ~ronchoconstriction While bronchoconstriction is not itself a chronic effect, it is believed that continual exposure can lead to substantial permanent pulmonary impairment in excess of the normal gradual decrease in pulmonary function due to the aging process. There are only limited epidemiological studies and a few animal studies which attempt to uncover any chronic effects due to sulfur dioxide exposure. Generally, the' results indicate the possibility of permanent effects from continuous or long-term exposure but are inconclusive. This material is so irritating that .it provides its own warning of toxic concentrations. The TLV is 5 ppm. Fifty to 100 ppm is considered to be the maximum permissible concentration for exposures of 30 to 60 minutes. Four hundred to 500 ppm is immediately dangerous to life. ' VI. H2S .Detection and Mon~tor.ing Equipment · . A. Although N2S is not anticipated, monitoring is needed to alert personnel immediately to the presence of the H2S. To provide necessary warning, International Sensor Technology H~S detectors or the equivalent will be installed to automatically detect the presence of 5 ppm H~S in the air. The. sensors will be wired at the shale shaker, bell nipple, ritJ floor and mud pits with audio and visual alarms placed on the rig floor {drillers c°nsole). A departure is requested .for the requirement to have a. sensing point located' in the living quarters, since the living quarters, are separated .by a sufficient' distance to allow dispersion of any H S concentrations, and' the living quarters are located 'so the prevailing winds w~ll not blow toward the camp. .Th.~..alarms .from the sensing unit will be placed with.in the living quarters on each floor and will be both audio and visual alarms. The sensing unit will be checked and c.alibrated on a weekly basis. The detection equipment will be actuated at a 10 ppm threshold level in air. ,, VII. Personnel Protective Breathing Apparatus . . Self-contained pressure demand air. breathing apparatus' will' be available for each member of drilling crew on duty, Although normally a drilling crew C-onsists of five men, twenty self-contained units will be provided...A departure is requested for the. requirement to .supply 'all personnel on location'with, pressure demand airI' breathing equipment. Essential personnel that are.necessary to shut in the Well.will be provided, with the pressure demand.apparatus. When concentrations exceed 10' ppm, 'the well will be secured as described in Section XIII'~ ' ~' ,, · All' 'breathing air bottl'es shall' be labeled as containing air fit for human' Usage. Location and type of breathing 'apparatus are listed below: 6 ea. 2 ea. 4 ea. 2 ea. 20 ea. 5 minute air packs available on the rig floor '.. 5 minute air paCks available in the' mud checker room 5 minute air packs available in the mud pit room 20 ea. 5 minute air packs available in the mud pump room' 30 minute pressure demand self-contained breathing apparatus See storage locations, Section XII-H Extra air bottles for' breathing apparatus See' storage locations, Section XII-H Because so many. extra air' bottles will" be 'available, ~a recharging system would be redundant. .. ., Other .Equi pmen~ · . · .. . . . 1. Six chalk boa...r.d_.s:.~a_n.d s.~..x_.n.o..te pads .~:;.~ll-be provided on..the rig f~oor,_ shale shaker area, and pump rooms for communication purposes. 2. Two bull horns and flashing' lights shall be provided. 3~ 6~ One Vapor tester (explosimeter); two portable H2S detectors. Resuscitator with spare oxygen bottles. Retrievable ropes with safety harnesses to retrieve incapacitated personnel from contaminated areas. Stokes litter or equivalent. 7. Wind Indicators 8, 10o Windstocks, streamers, or other devices will be positioned around the location Such that they can be seen from the rig 'floor and from any position around the location. Mud Treatment and Checks .in the event the mud becomes contaminated with. sulfides, a supply of H~S scavenger will be kept with mud. materials at the. rig site in s~fficient quantity to treat the entire mud system with'2 lbs. per. barrel. Below protective casing, daily mud checks will, .be made. to.determine the.presence' of sulfides .in the mud using a Garrett Gas Train or. equivalent. ,, ~ Wel I .Site Communication " .Portable twO-way .radios.will be provided on lo'cation in order to. permit .rapid communication between supervisory personnel in case of an' emergency. "Danger-Hydrog~n'Sulfide - H S" a"'vesignsb~) will be displayed whenever . 10 ppm. outs~ide of the rig floor, mud hydrogen sulfide level is pit or shale shaker areas. Each sign 'shall .have a minimum width of eight feet and'a m.inimum h~ight of four.feet and shall be painted a high-visibility yellow color with black lettering of a minimum of 12 inches, in height~ If'20 ppm H~S is encountered, protective breathing apparatus )~ill be worn by all ~orking personnel~ all non-working personnel shall proceed to.t'he designated safe briefing areas for .further instructions.. IX. X. XI. XII. In the e~' L HpS has been determined to ~ e reached an in- jurious level -(50 ppm's), a number of red rectangular shaped flags shall be hoisted in addition to the displayed signs. All non-essential' personnel or all personnel, as appropriate, shall be evacuated at this time. All signs shall be.illuminated under conditions of poor visibility and at night when in use. Briefing Areas Two briefing areas will be designated at each location. The Shell Drilling Superintendent on location will designate which briefing area is to be used depending on wind direction. Ventilation The mud pit, shale shaker area is equipped with explosion proof exhaust fans capable of changing out the air in 5 minutes. Evacuation ' If H~S' concentration reaches 50 ppm, all personnel will be evacuated, exc&pt the Drilling Foreman; Assistant D.F. (man radio communication), Mud Man, Pusher, Driller, and two Floor Hands. These men will remain on the island to secure the well and take action toward removing the H2S hazard. During winter, th'e ice road or a lielicopter will be used - depending on circumstances such as upwind direction - to evacuate the non-essential crew. During summer, a boat or helpcopter will be used. ~Training A. Be All personnel, whether regularly assigned, contracted, or employed on an unscheduled basis, shall be informed as to the hazards of HzS, ,, They shall also be instructed in the proper use of the safety' equipment which they may be required to us.e, informed of H_S detectors and .alarms, ventilation equipment, prevailing winds, briefing areas, warning systems and evacuation procedures. In addition to the above, information relating to these safety measures will be prominently posted on the drilling facility and in the immediate vicinity of the drilling facility. Recbrds of attendence will be maintained on the drilling facility. Self-Contained Breathing Apparatus Personnel who may be required to use self-contained breathing apparatus in the event H2S is encountered will be trained in the use and proper maintenance of the Scott Air Pack or the equivalent. Personnel will also be required at least monthly to don this equip- C. ment to assure understanding in its proper use. Any new employee on the working crew, will be trained in the use of this equipment, upon his arrival at the drilling site. Hydrogen Sulfide Detection Equipment · D. Personnel required to operate permanent or portable monitoring equipment'wi11 be trained in the proper use and maintenance of units. Evacuation Procedures All personnel will be advised of evacuation procedures, alarms, 'reporting areas and steps to take in event of a hydrogen sulfide emergency. Training will be provided permanent personnel to a~,sure effective operation of evacuation equipment and understanding of evacuation procedures. E. First-Aid Course G. All first-aid personnel in the drilling crew will be indoctrinated in basic first-aid procedures applicable to. victims, of H2S exposure. · F. Safety Meetings Safety meetings will be held on a monthly basis, .to promote efficient safety procedures of an on site H~S program. This meeting will include a dril.1 and review of H2S hazards, warning systems, safety equipment and safe briefing areas in the event of an H2S hazard. During subsequent on site training sessions and drills, emphasis will be placed upon rescue and first-aid for H2S victims. Each crew member will be thoroughly familiarized with the location and .use of the first:aid kits, resuscitators and a stokes litter. Records of attendence, will be maintained on the drilling facility. No Smoking ,, Areas where smoking is permitted will be established and identi- fied. Should an alert be called, smoking shall not be permitted during the alert. All personnel shall be informed of no smoking areas and regulations pertaining to smoking. H. Storage Location of Protective Breathing Apparatus 1. 5 units on the rig floor. 2. one unit in the mud pit area. 3. one unit in each briefing area. 4. 2 units in the drilling foreman's office. , 5. all refill bottles will be stored in the drilling foreman's office. Xll. H_oS Emergency Procedures A. If at any time as' much as l0 ppm of H2S is detected, the following steps will be taken: · The person detecting the H~S must immediatelY_ notify the Oriller. He must then notify the Shell Drilling SupervisorI and contract Toolpusher. The Shell Drilling Supervisor and contract Toolpusher will bring portable gas detectors to the rig floor in order to find the source of H2S. .Upon notification of the emergency, the Driller will shul~;'down mud pumps and continue to rotate the drill pipe. · The rig floor and supervisory personnel will immediately put on Scott Air Packs. All other personnel will immediately leave the area and go to the upwind briefing or other safe area. The'contract.Toolpusher will alert all personnel that an ~i2S emergency exists... He should be prepared to shut off the Forced Air Circulation System in the living, quarters. The Mud Engineer will run a sulfide determination on the ¥1owline mud. · A maximum effort must be made by ~upervising personnel to resolve the cause of the H2S and to suppress the H~S as quickly as possible. Drilling must not proceed until-the cause of the H2S is.determined and the well is circulated. Rig floor and mud pit personnel will keep breathing equipment on while monitoring this circulation. · The contract Toolpusher will make sure all nonessential personnel are out of the potential danger area, i.e., mud pit area, mud- logger unit, mud storage room, etc. All persons who remain in the potential danger areas must utilize the "buddy system." The Shell Drilling Supervisor in charge will no.tify the Shell Operations Superintendent of current conditions and actions taken. g· The on-duty Shell Drilling Supervisor will see that all monitoring devices are functioning properly and reading accu- rately and will increase gas monitoring activities with portable Drager units. 10. The Shell Drilling Supervisor in charge will notify all approaching vehicles and helicopters to stay upwind and to be prepared to evacuate nonessential personnel. The(' 11. ell Drilling Supervisor in ch~ ~e will alert the Deadhorse dispatcher to assure continuous radio watch. The U.S. Geological Survey and U.S. Coast Guard must also be notified. Bo If the I{~S concentration exceeds 20 ppm (from an increase in gas cut mud)'and the well is not attempting to flow, the following steps will be taken: The person detecting the HgS must immediately notify the Driller. He must then notify the Shell Drilling Supervisor and contract Toolpusher. ' '2. Driller will shut down mud pumps and continue to rotate' drill pipe . . The rig floor and supervisory personnel will immediately put on air breathing units. Any other personnel in the high con- centration area should hold their breath and evacuate to a safe area. Once air breathing equipment is on, the Driller should: a. Stop rotary. bj Pick up kelly' above rotary table. C, Be ready to hang off and close the BOP's if necessary. d. If well control problems develop, shut in the well, . . The contract Toolpusher will alert all personnel that an HgS emergency exists. He must shut off the force Air Circulation S~stem in the living quarters. All personnel not listed above must report to the upwind safe briefing area oT~-F further instructions from: the off-duty-Tool.- pusher or Supervisor. If you are located on the downwind side of the rig when the alarm is sounded, hold your breath and proceed to the upwind safe briefing area. . Always put on a portable air breathing mask before proceeding to assist one affected by the gas and utilize the "buddy system." If the affected person is stricken in a high concen- trated area, put on a safety belt with 50 feet of tail line and obtain standby assistance before entering the area. Always use the "buddy system" when entering possible con- taminated areas. e 10. C. (f - h(, The 5nell Drilling Supervisor in c rge will notify all approaching vehicles and helicopters to stay upwind and to be prepared to evacuate nonessential personnel. Notify dispatcher to alert heliport and establish 24-hour watch. Notify appropriate state agencies in.addition to USGS and USCG. DO NOT PANIC The Shell Drilling Supervisor and contract Toolpusher will assess the situation and assign duties to each person to bring the situation under control. When the severity of the situation has been deter- mined, all persons will be advised. The Shell Drilling Superv~i..sor and contract Toolpusher wil 1: 1. Direct corrective action. Notify the Shell Operations Superintendent in Anchorage on action' being taken. , GI~NEI)JkL t)UP-hlING, WELDIblG & I~OT TAPPING ?IJ~N FOR -SEAL ISLAND-SEAL EXPLORATION OCS Y 181 #1 The following pa.ues outline the procedure to be used when performing any welding, burning, or hot tapping on or around the rig. · Attached is a drawing of the rig layout for the drilling "~.: - operations on the Island.- As shown' on the rig layout, the designatea " safe welding and burning areas wil~ be the shop, steel rack house, .and' the welding shop. ' ' · .. A copy of the Shell Fire ~; safety ~ork l~emit, which' is to be obtained from the foreman before any ~elding, burning, 'or hot 'tapping is clone outside the ~esignated areas, is also attache~. · , · . .Alas~ 0ii & Gas tons. Commission ' ' OPERATING PROCEDURES FOR SAFE OPERATIONS IN WELDING AND FLAME CUTTING SEAL ISLAND - SEAL EXPLORATION .OCS Y -181 #1 1. Cutting and welding operations near a rig constitute potential fire · hazards and have been the cause of many catastrophies. Welding and cutting operations shall be closely supervised at all times, and shall not be permitted near flammable liquids, near accumulations of crude. oil, near escaping gas nor in locations where sparks, flames or hea~ from a welding to,ch or slag could be a source of ignition. ~' 2. Cutting and welding operations in drilling and well servicing operations require a high degree of skill. Personnel engaged in these operations sh~ll be certified welders and' properly instructed to ins.ute they will be safety conscious and have a thorough understanding of the potentia'!,,~' .hazards to be .guarded against. In all welding and .cutting' operations, the welder shall be briefed on the safety aspects of his specific job before any work i's started. A written safety w0rk permit system covering all welding and flame Cutting operations .shall be required on all offshore operations - platform rigs and mobile units, and Shal.1 be considered prudent and advisable on land and inland barge location~ on critical wells or where hazardous conditions' may exist. B. EQUIPMENT 1. Only approved (FMEC or UL).apparatus, .such a~ tanks, regula.tor~, arc welding machines, shall be used. . , 2. Mixtures o.f fuel gases 'and air, or Oxygen., may be explosive. No ·device to permit mixing ahead of the burner tip shall be allowed.. 3. All cylinders with a 'water weight capacity of .over 30 pounds, shall be equipped .with a valve protection cap or'a collar or'a recess to protect the valve. Va'lye caps shall be in place, except when cylinders are connected for use. ', . 4. Inside Of buildings, .cylinders shall be stored in a well Protected, well ventilated dry location at least 20 feet from highly combustible~ materials Such as oil or excelsior. ., 5. CYlinders .shall be stored in definitely as'signed places aw.ay from stairs, or walkways. They should be' tied or. otherwise fixed to prevent ac¢i. den.tal overturning. ,, 6. Cylinders shall not be kept in unventilated enclosures such as lockers and cupboards. . . 7. Oxygen cylinders in storage shall be separated from fuel gas ~ylinders. or comb.ustible materials (especially oil or grease) a minimum distance. ." 'of 20 feet or by a noncombustible barrier at least 5 feet 'high.. 8. When transporting cylinders by a crane or derrick, a cradle, boat, or other suitable platform shall be used. Slings shall not be used. Also, cylinders shall not be dropped, struck or Permitted to strike each' other 'violently. 9. On arc welding machines, control apparatus shall be enclosed, except for the.operating~heels, levers or handles. 10.' Input power terminals top charge devices and live metal parts shall be .completely enclosed and accessible only by means of tools. · 11. Terminals from welding leads shall be protected from accidental contact by personnel or metal objects. _ .. 12' Oxygen and Acetyline backflow preventors shall be used on welding and flame cutting ·apparatus. _ C. OPERATIONS AND MAINTENANCE 1. Cylinders shall be kept far enough away from the actual welding or cutting . operations so that sparks,-hot slugs, or flame shall not reach them or fire resistant shields shall be provided. .. 2. A jet of oxygen must never be permitted to strike an oily surface, greasy clothes, or enter a fuel or other hydrocarbon storage tank. · . 3. Cylinders shall not be placed where they can become a part of an electrical circuit. Any practice, such as tapping of an electrode against a cylinder to strike an arc, shall be prohibited. 4. A hammer or wrench shall not be used to open cylinder valves. If valves cannot be opened by-hand, the supplier shall be notified. .5. No person, other than the gas supplier, shat1 attempt to refill a cylinder or. mix gases in a cylinder. ' · · 6. If cylinders are found to have leaky valves or fittings 'which cannot be "- 'stopped-by Closing of the valve,'the-cylinder shall be taken outdoors and slowly emptied..' 7. Fuel gas shall never be used from cylinders through torches or other devices 'equipped with shutoff valves without reducing the pressure through a suit- able regulator attached to the cylinder valve or manifold. 8. -The. frame or case of an arc welding machine shall be grounded. 9. Electrode holders when not in use shall be so placed that they cannot make electrical contact with persons,' conducting objects, fuel, or compressed gas tanks. -10. Cables with splices within 10 feet of the holder· shall not be used. The welder should not coil or loop welding electrode cables around parts of his b0ay. - . D. FIRE PROTECTION . 1. If the object to be cut or welded cannot readily be moved, all movable fire hazards in the vicinity shall be taken to a safe place. 2. If the 'objects to be wel~ed or cut cannot be moved, and if all the fire hazards cannot be removed, then guards shall be used to confine the heat, sparks, and slag and to protect the immovable fire hazards. · · . 3-' Wherever there are floor openings or cracks that cannot be closed, pre- cautions shall be taken so that no readily combustible materials below will be. exposed to sparks. '- -- 4. Suitable fire extinguishing equipment shall be maintained in a state of readiness for instant use. 5. Fire watchers with extinguishing equipment shalI be required whenever welding or' cutting is performed in locations other than the designated safe areas. ' ' ,~ '. 6. The.fire watch shall be maintained for at least a half hour after completion of welding or cutting operations. .. 7. Before welding commences,, the floor shall be swept free from combUstible materials for a radius of 35 feet from site of operation. 8. During welding, Combustible floors shall be:kept wet, covered with damp sand, or protected by fire. resistant shields. 9. Before.cutting or welding is Permitted, the area ShalI be inspected by the individual responsible for authorizing .cutting or welding operations. He shall designate precautions to be followed in granting' autho~rization to proceed preferably in the form'of a written permit. In confine~ areas, inspec'ti0~ shall be made with gas'detection equipment in .addition to visual. Working area shall be rechecked wi'th a combustible gas indicator before restarting operations discontinuedover 30 minutes. ... 10'. Cutting or welding shall not be permitted: '~n the following situations: ,. a. In areas not authorized by the Supervisor. " · , b. In the presence of explosive, atmosphere or where.such atmospheres may. develop. c. In areas near the storage of large quantities of exposed readily ignitable materials such as fuel oil or lubricants, baled paper, etc. .d. Where ignition can be'caused by heat conduction, such as oN metal- walls or pipe in contact with combustibles on other side. e. On used containers, such as drums or tanks,, until they. have been 'cleaned thoroughly of flammable materials or vapors. Any pipelines or connection to the drum or vessel shall' be disconnected or blanked. f. When wind conditions are such that sparks could be carried .to combustible materials. .. E. PERSONNEL PROTECTION '.1. Eyes .. a. Helmets or hand shields shall be used during all arc welding or arc cutting o~erations excluding submerged arc welding. 'b. Goggles with proper shade selection shall also be worn during arc welding or cutting operations to provide ~rotection from injurious rays from adjacent work and from flying objects. - ' c. Goggles or other suitable eye protection shall be used during all gas welding or oxygen cutting or brazln~ operations. d. Hell, ers or attendants shall be provided with proper' eye protection. e. All filter plates used in helmets and goggles shall meet the test for transmission of radiant energy prescribed in ANSI Z 87.2-1968 American National Standard Practice for Occupational and Educational Eye .and Face Protection. .. 2. Clothing . .. .. a. Except when engaged in light work, all welders should wear flameproof gauntlet gloves. , . b. Flameproof aprons made of 'leather, asbestos, or .other suitable material may. also be desirable. c. Cotton Clothing, if used, Should be chemically treated to reduce 'its c0mbustibility. ' · , d. Clothing made from synthetic, materials such. as nylon, rayon, or orlon should not b~ exposed to welding work. .. e.. All clothing should be reasonably free from oil. or grease. · . f. For heavy work, fire-resistant leggings, high boot, or oth'er equivalent protection should be used. F. VENTILATION 1. .Mechanical ventilation at the minimum rate of 2,000 cubic feet per minute. per welder shall be provided when welding is done. a. In confined spaces or where the welding space Contains partitions, . hal'.conies, or other structural barriers to the' extent that they sig- nificantly obstruct cross ventilation. ' ' .. b. 'Where the nature of the welding, cutting or brazing work'is such that the release of toxic fumes or gases is possible. This includes, work on stainless steel, zinc, lead, degreasing or cleaning compounds containin~ hydrocarbons. ' c. In circumstances where it is impossible to provide ventilation, air breathing apparatus may be used. FIRE and SAFETY .WORK PERMIT '' · SHELL ~ TERN E & P INC. PACIFIC FRONTIER DIVISION 3~'~e of Work- ,. · · · 5AFL"TY · I~] ADDITIONAL. }'lF~. I&'ATCH TO STAJ~D BY AT AL.I.. TJAqF'q. f~J FJR£ ~'ATCH TO O~'07~.~:Alq TO APPROVE AF, F.A, D}'OR~L:~ TO. ST~_~D ! t .~uptrv~or._ ...... "'"--"''"' ..... 1" * -'*-o------*oo--- ----,- ., · - . o 2'" mNll Im _ · liN·# mmm - ;,me ' · mm ., .J '0 8HELL WIZ'3TERN ~ & p OCl y 81'rAL EXPLORATION /.'SEAL ISLAN. O AS BUILT vi:co January 20, 1984 I' Shell Western E&P Inc. A Subsidiary of Shell Oil Company 200 N. Dairy Ashford P.O. Box 527 Houston, TX 77079 State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen- Attached please find three copies of an AppliCation for Permit to Drill the first Federal OCS well from Seal Island, Seal OCS Y-181#1, on the North Slope, 21 miles northwest of Deadhorse. Although data from nearby wells indicate only normal pressures (.465 psi/ft gradient) should be expected, a sufficient supply of required drilling fluid materials will be kept on location to allow for increasing the drilling fluid weight to a 12 ppg density (0.625 psi/ft gradient). A 10,000 psi BOP and wellhead will be used. After cementing the 13-3/8" casing, the BOP stack will be tested to 5,000 psi for the ram preventers and 2,500 psi for the annular preventer. Tests will be conducted weekly, and all tests will be noted on the tour sheets. After cementing the 9-5/8" casing, the BOP s~ack will be tested to 10,000 psi for the ram preventers and 3,500 psi for the annular preventer. Subsequent tests will be to 6,900 psi for the ram preventers and'3,500 psi for the annular preventers. Please note we plan to drill the well to 14,615'MD/12,700'TVD, but we seek approval to drill as deep as 16,000'MD/13,850'TVD. As noted in the drawing of the diverter, both 6" mechanical valves will be kept in an open position until the preventer is closed. The' mechanical valves will be wired open and tagged with instructions concerning proper procedures for closing a valve in the event that the preventer is closed. Attached is our draft in the amount of $100.00 for the APD fee. We would appreciate your usual expeditious handling of this application. B. E. Bernard Division Production Manager Pacific Frontier Division RGH'mh Attachment L STATE OF ALASKA , ALASKA' ,LANDGAS CONSERVATION C wM~SSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [] lb. Type of well EXPLORATORY [~ SERVICE [] STRATIGRAPHIC I--J REDRILL [] DEVELOPMENT OIL [] SINGLE ZONE [] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator Shell Western E&P, Inc. 3. Address 601 West 5th St., #810, Anchorage, Alaska 99501 4. Location of well at surfaceJ~_~'~O/~'~Z'"'-/~ ~ ~ j i? ~,/ ___ ___ /~.~'.. /- . ~C:;~'~ / ~--z;j ~.hCr~ /6 ~-~/2//~//j ~)3~'' 9. Unit or lease name ~-----L~=67¢:F3'1-~-3~2~--.,-~-A~~ 0/~"]. OCS Y-Z8Z (BHL) At top of proposed producing interval 10. Well number x=664,680 y:6,030,045 AK Zone 4~D #1 Attotaldepth /~PX XS-O'/'AIL, 1-50'FU"L 11.Fieldandpool -x.=6'65-~925--~9~700 ..-~K-_Zcn,,e C__ ~ Ui,~£~ 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. WILDCAT 50' KB OCS Y-181 (BHL) 12. Bond )nformat~on (see 20 AAC 25.025) Statewide- 1NA Shell 0084 $500,000 Type Oil and Gas Surety and/or number 11C 136503 Amount $100,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 21 ...... Mi. NW Deadhorse mimes 2000' @ Target feet well 2 Mi. (BHL) feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 16000'/13850' feet 5242.64 2/1/84 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures ~r~b0 psig@~ Surface KICK OFF POINT2800 'feet. MAXIMUM HOLE ANGLE34' 5°J (see 20 AAC 25.035 (c) (2) 5905 psig@12700 ft. TD (TVD 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) zO" 20" 154# 0 ~ 100+. ~ Drive vipe i I 1/~" 13-3/8" 72# N-80 BT&C 2600' 0 ~ 2600'I 2600' 3000 ft.3 (to surface 12~" 9-5/8" 53.5# N-80 LT&C 12155' 0 ' 12155'1 1. D670' 120r) ft.3 , 8~" /,"liner 32# N-80 LT&C 2760' 11855' J10425' 14615'! 12700' 350 ft.3{cmt full' I I ' 22. Describe proposed program: 1 I 1 ength See attachmen,t. JAN2 4 * (500' min. over hydrocarbons) ,~,,..~.-',Ot!&"' cas Cc:'~S. C0 ~3. I hero, by ce hat the foregoing is true and correct to the best of my knowledge · The space below for Commission use - ' ~' ' /' - -- CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required I APl number ~ji~YES []NO [ LYES YESI Permit number Approval date ~..~¢~ ,~/,,"~,~27~4~ SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVEDBY(~~//~__~ ,,COMMISSIONER DATE January 27. 1984 L_ _ ..~ ~/' ~' L ..~'~~~--'~~ by order of the Commission " -- 10-401 Rev. 7-1-80 Submit in triplicate Attachment OCS Y-181#1 is a proposed deviated exploratory oil well located 5-1/2 miles north of Kup Delta 51-2. A 20" pipe will be driven to refusal (100±) and a diverter system installed. A 17-1/2" hole will be drilled to 2600'± where 13-3/8" casing will be run and cemented to surface with permafrost cement. After drilling out and performing a formation fracture gradient test, a 12-1/4" hole will be drilled to 12155'±. After running and cementing 9-5/8" casing and drilling out, a formation fracture gradient test will be performed. A 8-1/2" hole will be drilled to TD where a 7" liner will be cemented in place. A separate completion prognosis will be provided by means of a sundry notice prior to testing. The formation pressure gradient is expected to be normal (.465 psi/ft.). Maximum BHP is expected to be .465 x 12700'= 5905 psi. Maximum surface pressure assumes a full column of 0.8 S.G. gas (4150 psi). The well will be drilled in compliance with the Alaska Oil and Gas Conservation Commission's regulations issued July, 1981. Please find attached a copy of the graphical prognosis, survey plat and a diagram and description of the BOP equipment and diverter system. ( N.I'. $) 1T FROIRACTED SEC I!, ! . TISN,RI~,UM II 14 IZ 15 SEA'._ ISLA.ND --BEAJFORT SEA LOr:G f ISLANP T; = N,RI3E,UM VIC :'.NITY MAP BF-47 No. 1: WELL-I Y= X= LAT.= L CNG.= ELEV.= £O31326.64 65S$50. Z5 7COZ9'31.661" 14 $ "41'35.05Z" ~_i.10' 0CS Y-.181 No WELL-2 Y: X: LAT.= L, ON$.-- . 1' G"',31505.05 G59825. ZI -0° 29'51.455" 148 o41'55.805'' ELEV~ ~_I.I 2' NOIE' ELE¥S. ARE TO N.W. COR. CELLAR BOX ! HEREBY CERIIFY ~AT i H~VE ~ADE A SURVEY ' ............ OF THE ABOVE DESRIBED PROPERTY AND THAT ~.,- ' THE IMPROVEMENTS SITUATED THEREON ARE'"'; WITHIN THE BOUNDARIES OF SAID TRACT AND DO '- ....... NOT OVERLAP OR ENCROACH ON THE PROPERTY LYING ADJACENT THERETO. EXCEPT AS 'INDIC'AT ED HEREON. MONUMENTATION REPRESENTING Inc. BOU.D~RY CO.TROL BY PLAT ~S SUOWN ~N DETAIL AND IS ACCURATE TO THE BEST OF MY KNOWL EGE. ,- ._ ~ JD~,~'[ 4-14-83 SHELL OIL r7':. ~.~ -- I COMPANY 5,~EE T SEAL ISLAND' I · CONDUCTOR ASSUILT 1 ...... P&C PACIFIC DRILLING ~I:~L: SHELL et al. OCS Y-]81 No. 1 FRONTIER PROGNOSIS LOCAT ION:X: 436,896[.1 ¥: 7,821,464M OBJECT ] VE :X= 438,438M y= 7,820,971M EVALUA1 ] ON E L E C. HUD IRES SURVEYS LOi~I~ER S]I3N]F ]CANT FORMAT IONS NELL DEPTH TVD MD CAS I NO P, ND CEMENT AFE NO: F]ELD'SEAL EXP. AREA EST. ELE'.'P,T ] ON ' 50' OR]LL]NO H~LE DEV. HOLE ~,';O D]R. SI ZE CCNTROL KB --' MUD PRO[~RAI' C, ' '1 13-3/8"csg 2600' KOP 2800~ SAGAV SAG COALS COLVILLE 7200' PEB. SHALE 8700' KUPARUK KINGAK T/LINER 3850' 3890' __ 5250' 5575' 9050' 9300' SAG ]0630' 9-5/8"c~g 10670r SAD 10820' LISBURNE ITKKILY KEKIKTUK BASE 0 o 2600' i~800" ., 7945' 9762' 10185' 10490' 10425~1855' 12105' 12155' 12335' ,, 11240' 12845~ 11640' 13330' 12150~3945' ]2700' 14615' I I I I I ~'1 ...jI .....J ! ol - I 17½" ! 12~" · PROPOSED WELL. PATH 'H~'".L et OmlRl~ OCS/Y~i81 .N~., .1' ~$EA .~XPL T:O. EAL 18i .ND · ..... i" ~ el' II,.il~l. .-'' · fei II I i I I I | I i I I i i Ifil · Y. I ~4. ~ 14 Ii1' ILL .1,14 I' II I IL... Lil* I~"llf 311~1' !'l'1... II~4. U II · I,,/IT /'C~ I~' ]l 4Idl T I'~ I, I IIIg. VII . · SHELL WESTERN E & P SEAL EXPLORATION / lEAL ISLAND ~" -- A~ BUILT vtcO DRAWING AND CHE'CK LIST 107 SHELL CLASS 10MR 10,000 psi Working Pressure SHELL MINIMUM BOP STACK REQUIREMENTS Min. Min. No. Item I.D. Nominal 1 Flowline 2 Fill up line 3 DrilTing Ni~)/e I. 4 Annular P~cventer° 5 Two single or one dual hydraulically operated rams 6a Drilling spool with'-2"" and 3" min. outlets - or 6b Use ram outlets as alternate to 6a 7 Gate Valves - Power operated 3-1/8" 8 Line to choke manifold 3" 9 Gate Valves 2-1/16" _ 10 Check Valve 2-1/16" 11 Single hydraulically operated ram 12 Water flange or bushing 13 Casincj Spool 14 Gate Valves 1-13/16" 15 Flanged control plug or valve I 1-13/16" 16 I Compound pressure guage I 17 I Kill line to rig mud pump manifold j 2" _ OPTIONAL -- :18 Rotating blowout Preventer'* I ,, 19 Power operated valve c, late 6" 20a Drilling spool with 3" outlet 20b 3" Outlet in ram preventer 21 Gate valves 3-118' 22 Auxiliary choke line 3" 23 Roadside connection to kill line 2" 24' Shear ram blocks for blind rams ,,~NNULAR ~REVENTER BL:ND RAMS O ®® PIPE RAMS 0 LING SPOOL 'NOTE: Il design c~iteria indicate 7,000 psi or greater, a 10,000 psi w,13, annular preventer should be used, otherwise a 5.000 psi unit ,s satisfactory. °°3,000 psi rating · '2O" P~EVENTE P-.. (C-OD Ps~ "1 · DVTIZ. SPOOL I NOTE: .. ALL THI~EE 6" \%,LVE$ · l JILL R>E IMSIDE P..Iq E NIcLOSI.,JIe F_,. 'TO i~,E CO}~J',.IECT£E> 50 THAI' VALVE OPEN UNEN PP..EVE NT ER IS CLOSED . TO / BoTH G" tlECHA, NJlCAL \ALVES GOO PSI DIVEETEP.. A53 EFIIbLY' I.JILL bE 'KEPT I~J A, lq OPEM ...... ,, . · I /% ':'"' 'J ' ~'~,' "~ POSlTIOkl DINITIL klELL i$ ';";,. ';:.. '.~ ~.:/-.::.,. SHI~T IN ,A. NO PR~OPER DIVER-TER. LIKIE 15 SELECT~:'I~,I'2 tO "C O~DI,,I CTO P,.. ~Jqo.ITEM I FLOk. ILINE ~ 2.0"A, MIJULA~ pR:EV, ENTER. '5 G" ALITOI"I,n~TED VALVE (,.,,/G'LllgE") 4- DIVEIP. TEI:?. sFODL __ 5 (:," 1,1ECHANICAL VALVE _ · · · o .i itI ! ii I.!, -e ,i.i~ · · · · · · · · · · i .Ii e.. · · · · i · · · . · - · · · · · I · · · . · · · · i · · · '. · · · · · · ' · -' -'' ~.-.. '. :' .':. ~ . ,.~ ' ,, 10 JO I0~ 9ZI.bOSZ RMEtRI::IDI::t HESS CORPOR!::::tTtON danuary Z3, 1984 P. O. 80X 2040 .,..Alaska Oil and Gas Conservation Con~ission 3001 Porcupine Drive Anchorage, Alaska 95001 :Att~n.: Betty Ehrlich ~907) 279-1433 ,. l]ea~..~lS, Ehrl icbm. · ",,Ame'raua .Hess Co'rpora~ion has no objection to the suface · or?bettom hole location (.1875'fl and 2750'E of SE corner of · BF-"4~~) of the 0CS-Y.-'01~81 ~I well as proposed l)y Shell ..weste'rn E&P' Inc,..in its application for Permit to Drill. "'CRR: s $ w S i ncere ly, ,C. R.. Richard, 14anager Beaufort Sea Operations 'c.c':... R.. W... 'l~obins.o.n.. dr. - Shel 1 [CEIYEID JAN~. ~ 1984, Alaska Oil'& Gas Cons. Commission AnChorage :. .. TEXAS EASTERN Exploration Co A TEXAS EASTERN COMPANY January 20, 1984 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Seal Unit Beaufort Sea, Alaska Gentlemen: This is to advise that Texas Eastern Exploration Co. has no objection to the surface or bottom hole location of the OCS-Y 0181 No. 1 Well as proposed by Shell Western E&P Inc. in its application for Permit to Drill. Regards, ~~;erO: NSi. i.s'~~':horL Land BOS:SLR:lm cc: Amoco Production Company Amoco Building Denver, Colorado 80202 Attn: W. R. Francis Amerada Hess Corporation P. O. Box 2040 Tulsa, Oklahoma 74102 Attn: D. G. Stevenson Murphy Oil USA, Inc. 200 Peach Street E1 Dorado, Arkansas 71730 Attn: L. A. Lewis Shell Western E&P Inc. P. O. Box 527 Houston, Texas 77001 Attn: R. W. Robison E'£EIVED JAN2 Alaska Oil & Gas Cons. Commlssio~ Anchorage P.O. BOX 2521 HOUSTON, TEXAS 77001 (713) 759-3131 January 20, 1,98q Alaska Oil 'and Gas ConservatiOn Commission 3001 Po.rcupine Drive Anchorage., Alaska 99501 Beaufort Sea, AIaska OCS-Y-O].S1 No. 1 Well . , Gent iemen: Murphy Oil USA, inc. (formerly Murphy Oil ck)rporatton) is a participant in the drilling of the aboxTe subject ~vell and owns an interest in. 0C$-Y-0181. Murphy has no .objection to the surface or bottom hole location of tho OCS-Y-OIS! No, 1 well as proposed' by Shell %?este. rn E&P Inc. in its application for Permit to Drill. cw J /c c TELECOPY Shell Western E&P Inc. :' I..11 A Subsidiary of Shell Oil Company · ]~ I! ,.~.,-.,.,..~.~,.~,.'-'~Tff 200 N. Dairy As~for~ P.O. Box 527, ~"-~, ,, ~ Houston, TX 77~ ~'~;, ':~' ~"'~ ~ Oanuar5 13, 1984 ~ ..,......~ ..... Alaska 0~] & Gas Conservation Commission ] ..... I ..................... "'-~ . 3001 Porcupine Drive ': Anchorage, AK 99501-3192 -:..:~.,[.[[~, Dear Mr. Chatterton: This letter is further to our conversation on January 9, during which I mentioned that Shell has submitted to the MMS this week an application for Permit to Drill (APD) the second well from Seal Island. As discussed, the well will be drilled starting from State lands, but it will bottom in Federal acreage and, therefore, will be subject to MMS regulations. We very much appreciate not also having to submit an APD to the Conservation Commission. As we agreed, this would cause additional work for both of our staffs. Nevertheless, if you should have any concerns or questions about our plans or activities for Seal No. 2, please let me know and we will quickly address them. Yours very.truly, R. G. Hollis Production Administration Manager Pacific Frontier Division RGH: mh cc: Rodney A. Smith, Minerals Management Service, Anchorage, AK ~nECK LIST FOR NEW WELL PERMITS Company Lease & Well No. iTEM APPROVE DATE -, , · (1) Fee .... (2) Loc ... '.- ....... '- (2 thru 8) (8)., I ' , (3) Admin (9'i thru 11) (10 and 11) (4) Casg ;-'.'..'.,C// ?',:"~,-f'Y (12 thru 20) (21 thru 24) YES NO _ 1. Is the permit fee attached .......................................... / 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line ................... 4 Is well located proper distance from other wells .. · ellll.eeleleeeee®e ,..r'~ 5 Is sufficient undedicated acreage available in this pool ............... .. 6. Is well to be deviated and is well bore plat included ............... ~.. 7 Is operator the only affected party ................................. , ¢~'. ..... 8. Can permit be approved before ten-day wait ............................. ..~..~ 9. Does operator have a bond in force .................................. 10. Is a conservation order needed ...................................... 11. Is administrative approval needed ................................... 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. Is conductor string provided ........................................ ~z~ Is enough cement used to circulate on conductor and surface ......... ~ Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... ~d-~ Will surface casing protect fresh water zones ............... ~ Will all casing give adequate safety in collap~e~ ~en~ a~d burst..~i~ Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... ~.,~' Is a diverter system required ....................................... ~4'~ Are necessary diagrams of diverter and BOP equipment at~ached . ~ Does BOPE have sufficient pressure rating - Test toS~r~l//~,FF~ p~i~'il Does the choke manifold comply w/API RP-53 (Feb.78) .................. REMARKS Ceo logy: Engi9~,e r, in, g: rcs B .w HJH ~,~m ~./~JAL' ""' ~ JKT~,iZ ~ v/,,,L,_.' .MTM .. .... / · ,: ~2/08/83' 25. Additional requirements ............................................. Additional Remarks: /~, ..."'-.,~ C. ~ z...~ .... ,'c'~.e.J"c.~'.~'~"!'. ,t¢..,..,,?~:!:... ~" . ,~.~,b.~ ,,.,'.~i.~, N ..... ~"~'."''~" ~-~'~ "'"d'~t "--~ ,~ ~' ~ [" ~', ~ ' .... ' .... ~ ' .~ , ' d~f'/ V,,. gyN y ~ ,4~ ~' INITIAL I GEO. UNIT ON/OFF POOL CLASS STATUS ~ AREA NO. SHORE .........'"""' i' ....... ' Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPE .N. DIX~ ,. No-special'effort has been made to chronologically organize this category of information. 'LIS T~PE VER!=~C~T!ON LISTING .V~ 310.~0~ VE~i~ICITl]~ ~ISTiN3 ':RVIrE MA;l= ,~ ~ : ,AT: :~5/05/11 iRI31N : :F_.=~ N ,5 '4~ :142761 'ONIINJ~TI3N .~ ',OM ~,~NT 5 :LIBRARY t4TE :,~6/05/11 ~RI3IN :0000 'AP~ N~M~ :150i :2q~INJ~T!~N ~ :01 'REViOJ~ T~PE : ',OM~ENTS :LibRaRY TaPE :$ FIL= HmAOER " .... :I LE NA~E :EDIT .00i ;ERVICE NAME : )ATE : tAXIMUM LENGTH : 1024 :ILE TYPE : 'RE¢iOJ5 FILE : iNFORMATION RECORDS '~ ~NEM CO~TENTS mm,mm mmmmmmm-- ~N : SH ~N : OC :N : SE ~AN3: 13 FOWN: 13 ~ECT: 11 :OUN: N. ~TAT: AL :TRY: US ELL WSSTERN E $-Y-181 .i~l ~/~] E. XPLORATIO~ E N SLOP-' ~SKA qNEM CONTENTS ,.mm,,. ~RES: E ,.* OMM~NTS ~o-~ INC. UNIT JNIT Ill-- TYP: mm m m 000 000 O00 000 000 009 000 TYPE 0 '0 0 C4TE 000 O00 000 0OD 3O0 000 20 0 000 4T'E 000 026 020 004 002 012 006 003 SIZ= ImII 065 055 065 065 065 065 065 065 065 C ODE .V: 310.H02 VERIflC&Ti]!4 LiSTi~.~3 P&G: Z O~ r-L OU T,~ 05 .DP : .qZS& KRUWF-LL ,. ;AS 'yp CZS 'H -'LJ 1AT ING : 9.$25" 2 lO?46.B' .=i FLJI3 : _ISN]SULFO~f~ SITY : 12 L5/C. ?'3SiTY : ~6 S = 10.5 ID LOSS : 3.8 '-3 RIX S~N3STO,M.~ - BiT = 1.25 ~ 53 OF : 1.92 @ 53 DF : .3!1 ~ 234 DF ¥~ O13.MOZ VE2,1SIC~TiD~ LISTi,N3 .UT='. THiS 3&T2 iS ST~ET't C~R:"T:~~-, ih;~_ .' N r~gs, ~'--~T~'_~. .~:;~ TJ. ~: :~,~ ::~ '~THS- ~ T~T 3~A, IS ~¢~!L~L,-_' REF'~ECTS :~. ~ST :~- · ,- }JAL INnJ .... TZ'"N SPH£RZCAI LY Fu ~ JS:~._ ~ L3.$ (~,"',., ,~ ~: D,~T~ ~V~.ILA'3' =: !1~0~' TI 107~9' :'~ · ,-"' P~]XI;~IT¥ Nli.C,$,OLJ$ (~RX) :;: 2AT~ AVAIL.~SLE: 11~+I~' T3 12739' ::: LiTH,3 DENSITY C:3q~.--NS&T~D LOS CLOT) :',: ~: CJMPE,~SATED N-'UTR3N LDq CLOT) :',: .,- D'~T~ AV~iL;~.~_'-: ~i41';~' T~ ~50z,' :~ N&TLJR~L 3~MM~ TClOL (N&T) VP OlO.flOZ VE~IFiC~Ti3~ LiST!N~ ~,~$~ ~ :.",-' DATA F]~MAT NTRY TY~E 2 3 )ATJM IN~ M SPECIFICATION '3L"'KS S~RVI'E S:RV~' ID OR3ER ~ IEPT 1D 091 FT ; F L :J g l L D -i :L:) DZL 'LM DIL 3'-iMM' ;P DZL ;R DZL $~,~i 'E~IS DIL L3 ;ZLO DTL M~iHJ FENS .~HC L3 )T B,qC JSI~ ;R 5HC S~PI ~GR L3T S~PI :ALT. L:)T I.~ ~H35 L3T 3/C3 ),R~O LDT ~R&T LDT ;~NR~ LDI' )P~I LDT pj ~P :-II LOT ~E~ L ,]'l' qCNL LOT C~S :CNL LDT CPS :GR NST $~PI ~3T~ N.ST PJ SiZE 1 1 i 1 '55 "73 55 APl Ami ,APl LJG TYPE CLASS O0 300 OC O0 2ZO O1 O0 !20 ~5 O0 12,3 4g OD 010 O1 O0 310 O1 O0 635 21 O0 222 O1 O0 113 ~5 O0 010 Ol O0 535 21 O0 520 SD O0 310 O1 O0 635 Z! O0 310 Ol O0 2~0 O! 30 350 OZ OD 355 Ol O0 ~20 O1 O0 O00 O0 O0 890 O0 O0 89O O0 O0 358 O1 O0 330 31 O0 330 30 O0 3i0 Ol O0 310 O1 O0 719 50 ENTqY ] · lin ! C33E (OCTAL) 5~ :DOOOOOOOOOOO30 5B O000OODOOOOO00 55 OOO30OOOO00OO0 53 00003000003000 53 O00OOOO0000000 55 OOOOOg3000OO00 5~ OOOOOOOO000000 5~ OO0000DOOODOOO 5~ O000000OO00000 53 OOOO00OOO00OO0 58 O000OO00000000 5~ 00000000000000 58 OOOO00DOOOOOOO 58 OOOO0000OO0000 58 O00000OO000000 63 00000000000003 5~ ODSO~O00000000 58 O00000OO00OO00 58 O00000OO000000 53 OOO000OO00OOOO 58 OOOOOOOOOOOOO0 53 00000030000000 53 OOOOOO00000000 $8 OOO00000000000 69 O00000OO000000 68 000.00300000000 5~ O0000000000OO0 5~ 00000000000000 V~ oi0~ .HO:)_ V=RI'=I'S4Ti3',, ~ i$T"N'_ _ ., '~ASE. ..= ENS N$T ~-~ O0 535 ENS ~X ' ~ ')C, 535 21 S, A.i PRX ' ~ 'JO 2~0 31 RDX PRX ] q>1~i 03 Z70 I~V P~X 3flMM 3G !53 33 'J NDR ~RX, _~MM 90 2~~ EPT 11332.3000 ~D LM -~99.2500 SP FL~ -999.2500 CZ_D T -99-9,2503 S'R ALi 5.3540 R,M3S NRA -27~3304.0030 SPqZ CNL -32753.0000 FCN_ 'BT& -2&,0Z3~ TENS ~NS -999,2503 CALZ NDR -999.2500 EPT 1!~00.0000 MD LM 42.0?42 SP :F~& 189.9375 CIL3 T 56.-9%92 gE ,ALi 8.5555 :NRA 1.0530 DPHI ICNL 7555.2500 ~OT~ -2~.023~ TENS 'ENS 6531.2500 CAuZ INDR 19.5~55 )EPT 11300.0000 MO :LM 7.5531 SP ;FL4 9.0488 CZL3 )T 63.3867 ER :ALi 8.7~10 RH3~ ~NR~ 1.8~50 DPHI 4CNL 5619.2500 PCNk ~OT~ 1.2695 T~NS TENS 6507.2500 CALt ~NDR 11.3~57 )EPT I120~.0000 MO 'LM 9.~55! SP ~FLA 17.3330 CZL) )T 71.0!73 2R :ALI 8.7363 ~H05 ~NRa 1.6583 'OPHZ ~CNL 5759.2500 FCNL ~OT~ 0.7~13 TENS 'ENS 6327.2503 C~Li 130~.7990 SFLj -999.2500 3R -9~9.2500 S° -9~9.2500 TE~S 36.~555 D~q3 -32753.3300 5575.2500 TM]R -999.2500 PR]X 13059.7324 SFLO -2..~138 SR 13,.5~26 SP 120.0895 TENS 2.5979 DRH3 3.15'72 NPHI 7131.2500 SSR 7337.2500 THDR 8,478'5 PRiX 129~4.0505 SFLU -9.4¢3¢ GR ,i95.6B75 SP 58.0898 TENS 2.5565 DRHD -0.3836 NPHI 3023.5000 SGR '7~95.2500 THgR 9.53~8 ~RDX 12827.8555 SmLU -54.3320 !)1.0273 SP S2,.'5117 TENS 2.4531 11,.33.~0 NP~I 3359.5900 SGR 6923.2500 THDR 9.1650 -999.2500 5575.2500 13.EL$~ -1702.3125 -63.9727 I~I.0525 !Z0.03']8 -2.4135 7307.2500 -0.0310 3. 9551 -170 Z. 3'i 2.5 -83.9727 !9.09;36 1!.6270 -9.4~34 7~95.2500 0.0059 13.1:33'5 80.2773 B. 9,853 !5.2%41 17.2705 32.5117 -34.3320 6923.2500 0.0300 12. ,5 .q. 88 67.i523 6. i Z 95 9.5156 SGR fIRST MI~V TENS TENS SGR NR.'.i T CGR UR~Xl MINV ILl TENS TE~S SGR NR~T' PEF CGR UR~N MIN~ iLO TEqS TE~S SGR NR&T PEF CGR URAN O'JOOOOnOOO3~OO 33.300000030003 330000JOgOOOgO 3033330000000~ 033,30030000000 00000030003300 -99g.2500 -99'9.2530 -999.2500 -1702.3125 13.9941 -!a.193~ -999.2~00 73.Z773 5123.2500 612'3.2500 -1702.3125 1.0039 3.7355 -1584.3125 -14.1934 19.~¢2~ 6.8640 6083.2500 6083.2500 89.2773 1.5426 3.5272 55.8242 2.9358 18.9393 9.900~ .5857.2500 5857,.2500 57.1523 1.596'7 2..2893 44.5117 2.7131 7.2~69 Vd 013.H32 VE~IFIC&fI3q LISTiN3 °h'SE 5 5.1531 EPT 11100.0030 LM 7.3540 SP FL& 9.,3410 T ~2.95~3 3R iCNL ~759.Z30J 5NS $153.2500 'ALi IN]R ~5PT llO00.O000 MD ]LM 23.7703 SP 'FL& 30.~205 ~T 65.1323 ;A.I ~.~$29 ICNL 5055,2500 FC'q_ ~ETA ~,2930 TENS 'ENS 5111,2500 C.iLI ~N~R 8,.B965 )EPT 10900.0000 MD :LM 5,1257 SP ;FL~ 10,275~ CIL2 )T 77.5~9B 3R 'ALi 8.5556 ~NRA 2,0!83 D~qi ~CNL 4907.2500 ~DT~ 0.'1~53 TENS F~Ns 6071.2500 C4LZ 4NOR 5.5606 )EPT 10800,0000 MO [L~ 9,5565 SP ~FLA l!,OBO1 CIL3 )T 76.0~95 ~ALI 9.3925 RH'DB ~NR~ 1,9263 '3PHI ~CqL 4859.250~ ~OT~ 0,0977 TENS FENS 61~7,2500 CALI 4NOR 10,5B03 )EPT 10700,0000 40 [LM -999,2500 SP ~FL~ -999,2500 CIL] )T -999.2300 ~'R ;ALI 8.650~ RHO~ ~NR& ~,2127 DPMi qCNL 1533.6~75 ~CN~ ~DT~ 1,~160 TENS 12710.2~52 S=~'j -37.33,.., I~ ~IZ~ S~ 2155.5000 5955· .- a.5382 125~!.19141 S=LJ -57.5977 32,9!80 SP Z7.~93 T=NS 2.~35 9.5??0 NPHi 33!5.5000 SSR 67Z3.2~00 8.72~5 12472.8145 SFLJ -136.1875 GR 917.2773 SP ~1.5430 TENS 2.3537 CRH2 17.~35 NP~I 2459.5000 S'3R 6~Z3.2500 THSR 8.8~57 PR3× 12352,$848 S=LU -~,0195 132,652'3 SP ~9.5117 TENS 2.4729 1.0,7422 NPHI '2355.5000 SGR 6857.2500 THOR '9.9238 PR3× 12233,0~38 SFL~ -999,2500 GR -999,2500 SP -999.2500 TENS 2.5217 DR~3 7.7832 NPHi 3B5,.1~05 SGR 6857.2500 T~DR 33.TZ~.~ -67.5977 0723. 2500 0.0373 13.2B'13 2.5,$~1B 1.8~87 23.50-&9 12.3176 41.5530 -156.1~75 6923.2500 -0.0010 17.4316 38.25i7 2.0842 11.0957 49.5117 -64.0195 6857.2500 -O..OO3~ 15.1357 54.'3Z~2 2.99.44 13.5547 -999,2500 -999.2500 -999,2300 6867,2500 -0.5334 47.0703 52.2517 4.~91~ T~NS CGq MI~V ILl TENS TENS S3.q NR:T PEF m-GR ILO TENS TENS NR&T CGR UR~i MINV ILO TENS. TENS SGt NRET PEF MINV i L 3 TENS TENS SGR NRIT PEF JR&N 7.555" ~69' 2 ZZ. 3~.96 ,,,,i 13.3366 3.7720 30.3543 5535.2500 5535.2500 1.$231 '2.7854 11.5566 1.3252 5.93~2 10.Z7,5~ 5555.2500 5555.2500 38.2617 1.9053 2.2815 2.98'27 4,.9BI0 9,7353 5~27.2500 5~27.2500 54.32,~2 1,B243 2,?~44 13,9941 4.836? 13.1743 -999,2500 -999.2500 -999.2500 52.2617 '3.9~65 -999.2500 ¢1.7930 2.4553 VP OlO.H02 V~q!FIC~7iD~ LIST!N3 P4&5 7 5'~91.2500 CALl 1.9747 Lq -999.2500 S FL,& -999.Z502 CILD T -99R.2500 ALI '~.5566 NRA ~.355~ DPMi 'OT~ 1.3572 'ENS -99).2500 S~LZ INSR )52T 10500.3)00 MD iLM -999.2500 SP 'FL~ -~99.2500 CiLD ~T -999.250~ GR 'ALI 3.5566 q~'5 ~NRA 4.2507 OP~l ICNL 1775.5975 FCN~ 'OT~ 1.4160 TE~5 'E~S -999.2500 CALl ~NDR -999.~500 )EPT 10~00.0000 :LM -999.2503 SP ;FLA -999.2500 CIL] )T -999.2500 ]ALi 8.5556 ~NRA 3.8529 ~CNL 19!~.6875 >OT& !.025~ TENS FE~S -999.2500 CALl ~NDR -999. 2500 )EPT 10300.0000 MD ELM -999.2500 SP ~FL4 -~99.2500 CIL] )T -99:~.2500 ~R ~ALI ~.5566 RH]B ~NR4 3.0~61 OPHi ~CNL 21~5.5000 ~C~., ~OT~ 1.1719 T~NS FENS -999.2~00 CALl qNOR -999.2500 ]E~r 10200.0000 MO [LM -999,.2500 SP ~FLA -999.2500 CiL2 ]T -999.2~00 3R ~ALI 8.5566 R'HO~ RNR~ 4.1798 DPWI ~CNL 1570.5575 ~CN' 12113.5156 S=LO -999.2500 -9)9.2500 SP -99'~.~5~0~ ~: T=NS 2.~202 4~$.1~06 I1992.9~34 SELJ -99~.2500 SR -999.2500 S~ -999.2500 TE~S 2.67~I DRq2 -i,4~88 NPH?. ~ 432.3905 S2~ 6711.2500 T~3~ -999.2500 PRDX i1871.1836 SFLJ -999.2500 -999.2500 SP -999.2500 TE~S 2.70'73 -3.450~ NP!i 455.~90.5 S~R 6623.2500 TH]~ -999.2500 1.17%9.08a0 S~LJ -9}9.2500 GR -999.2500 Sm -'9~9.2500 TENS 2.~35~ OR~3 12.9911 NPqI 6~4.3125 SGR 6511.2500 T~SR -999.2500 PR3X 1!627.072~ S2LU -9)9..2500 Gq -9~9.Z500 SP -999. 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