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184-093
. v , ALASKA O, ND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG , . 1. Status of Well Clas'sification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED rx] SERVICE ~ '.~~ ,, , 2. Name of Operator~!!,lm4lj~ll..,~ - ' 7. Permit Number Aaerada Ress Co~o~aLion ;~~ 8~-93 3. Address 1201 Lou~s~a~ Su~Ee 700 ~~~ 8. APl Number Eoustoa~ ~as 77002~ 50-029-2~0 4. Locadon of well at surface ~[.5 E~ ES[~ 629 Et E~[~ Sec ~ [~3~ ~ ~ 9. Unit or Lease Name Northstar On~L/Seal Zsland AI TopProduc~n~ Int~rv~l 4912 ft FSL~ 2788 f~ ~ Sec 2.~ ~3N~ ~3E~ ~ ]0'.W~l~ Numb~ BF-57 ~1 (Seal A-3) At Total Depth ~12~ ~: ~SL~ 2613 ~ [, Sec. 24, ~N, ~E= ~ 11. Field and Pool ~:'Elevation in feet (indicate KB, DF, etc.) ~ 6. Lease DesignaHon and Serial No. ~plo=a:o~ 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ~ 15. Water Depth, if oifshore ~ 16. No. of Completions 7/~/~ ~/[2/8~ 7/~0/9~ --~taat _ I I . . Roa~eo~enc 39 feet MSL 0 l'~.TotaIDepth (MD+TVD) 18.PlugBackDepth(MDl.~D) 19. Directional Survey ~ 20. Depd~whereSSSVset 21. Thickness of Permafrost ~55 ~11~605 ~ ~0~ ~ (~ + ~) YES ~ NO ~~ ~o~e fee~ MD 1700 22. Type Electric or O'thor Logs Run A[[ lOgS p=ev[ously submitted s~/cR/o[s~/sacs/a~/~/c~/~/o[~lst[c/s~/~l~z/c~/~ 23. CASING, LI'NER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" 3[~ X-SZ Su:~ace [~9 ' ~ 30" ~[ve~ 80 ~ 20, .... ~3~ [.-55 Se=face [602~ . 26" 3700 SZ ~e~a~=osC [[ 80~ '~3/8" 72~ N-80 Su=Eace 5000'~ ~7-[/~" [950 SX ~m~=St~900 SX G 80' 9-5/8" 53.5~ N-80/~-80 Su~ace Lfi=280'~' ~2-~/~" ~50 SZ Class G 80" 7" 32~ .... L-80 8~27' ~ ~455'~ 8-1/2" ~75 SX Class G 0 24. Perforations open to Productlo~t (MD+TVD of Top and Bottom and 25. TUBING RECORD .... interval, size and number) SIZE DEPTH SET (MOl PACKER SET (MD) ,. . Perforations for DST; s prevEously reported None N~: '30",20", ~-3/8" and 915/8'' cas~ strings ' I severed at 19 ft bel~ original ~dl~ne. '26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. (~80 Et bel~ ~sland surface [G~L.]) DEPTH INTERVAL(MD) AMOUNTaKIND OF MATERIAL USED Squeeze ~obs as re( u[red for d~ole ab~ndO~entf as pre~,[~usly reported.. 27. PRODUCTION TEST Date First Production ~ Method of Operation (Flowing, gas lilt, etc.} I DST Data Submitted PrevEously OateofTest Hours Tested , PRODUCTION FOR OIL-SDL GAS-MCF WATER.BBL CHOKE SIZE GAS.OIL RATIO TEST PERIOD ~ 'Flow Tubing Casing Pressure CALCULATED OIL.BBL GAS.MCF WATER.BBL OIL GRAVITY-APi (corr) Press. 24-HOUR RATE ~ 28. CORE DATA . Brief description of lithology, porosity, fractures, apparent dips and presence o( oil, gas o¢ water. Submit core chips. . RECEIVE ' ORIGINAL A~ska Oil & Gas Cons. Co Anchor~,ge D rlmissi0n Fo~m 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FOI]MATION TESTS NAME { '-' · .. _ Include interval tested, pressur0 data, all fluids recovered and gravity, , MEAS. DEPTH TR~JE VERT. DEPTH GOR. and time o1' each phase. Sagavan£rktok 5428 4763 Test data subm£tted prev£ously Colville 8554 6942 Pebble Shale 11,245 8836 Put/Kupa ruk ]_l, 574 9057 First Sand 11,711 9150 Kingak 12,]'!0 9423 Sag River 14,207 10,866 Shub 1 ik 14,332 10,9z~+ Sad lerochit 14,470 ll, 028 OWC 14,690 11,160 Ivishak Shale 15 ~048 11,370 gchooka 15,205 11)462 Lisburne 15,250 11,490 I'D 13,455 11,605 31. LIST OF AI'TACIIMENTS ,, ... 32. I hereby certify that the foregoing Is truo arid correct to the t)es[ of my knowledge R. C. Gardner_ oigned ,'7 -~- Title iless Corporation __ Date.. 8/23/9z~ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on alt types of lartds and leases Jn 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-sit, u combustion. Itern 5: Indicate wl~ich elevation is used as reference (where not otherwise sl~own) for depth rneasurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well iscornpleted for separate production from more than one interval (rnul~iple completion), so state in item 16, and in itern 2,1 sinew the producing intervals [or only the interval reported in item 27. Submi~ a separate [or'm for each additional interval to be separately produced, showing tile data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Summary of Operations Final Abandonment Well No. BF 57 #1, Seal A-3 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. 1. 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. Wellbore and annulus were filled with CaCI2 solution. 3. Excavated and removed well cellar. 4. Drifted wellbore 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", 20" and 30" casing strings simultaneously at approximately 80 feet below island surface (= 19 ft below original mudline). 6. Cutoff wellhead. . Rigged up vibratory hammer on 30" casing. Vibrated on casing one 'hour without perceptible movement of the pipe. Re-shot casing using spare charge of Composition B, and steamed casing 5.5 hours. 8. ' Re-rigged up vibratory hammer on 30" casing and pulled all four shot-off casing strings together. . Backfil!ed hole left after extraction of 30" conductor as precaution against accidents. R£C£IV£D AUG 2 4 1994 Oil & Gas Cons. Commission Anchorsge ,iOE B.RY HOTEL ID:659-2'752 15:20 No,OIO Po04 ' FAIRWEA'rHER E&P SERVICES, INC. REPORT NO:_ = __ _/ FIELD PROGRESS REPORT DA'TE: JOB NO. 002-O2-400 CLIENT: AMERADA HESS CORPORATION AFE NO. PROJECT: SEAL ISLAND WELL ABANDONMENTS NORTHSTAR/SEAL ISLANDS RECLAMATION AND ABANDONMENT REPORT' PERIOD: O~'~O!,, llrs: ?/..~_~/.?.~_ ..... toCr_~hrs ,.. ,. i . .. ii,-- i Il . m _.. i __ i i · .. imml -- .. _ mi , mm ! P?essure: ~-~ ~ Precipitation:/~ Sky:~. 0~_... Chill Factor: ~ubmitled by: ~ tepreser~alive Wind: k, fNN/'.¢~C?CLVisiblllty: _,~,,C~/~. RECEIVED AUG 2 4 1994 Alaska Oil & Gas Cons. Commission Anchoritic , ,LIE .~i::.t"l'" HOTEL i1:~'659-2752 JUL 2.;'.'94( FAIRWEATHER E&P SERVICES, INC. FIELD PROGRESS REPORT 15:19 No.01.0 P.02 REPORT NO: .... ,~ .._ JOB NO. 002-O2-400 CLIENT: AMERADA HESS CORPOP, ATION AFE NO. ~,~/¢'/'4 _ct~._.o/ PROJECT: SEAL ISLAND WELL ABANDONMENTS NORTHSTAR/SEAL ISLANDS RECLAMATION AND ABANDONMENT REPORT PERIOD: ,. Activity aepoit: k/~/L/t~ .~/,.~,, g,,,,[__~ ~,__p~... T~~ _,~...,~tt~,. ~_/~.~.~_,./_J,,,g~ Weather @ ~hrs Tomp:. ~'~___/' Wind:A/'Z'~_./~..Z'~-'-'~ Visibility.-. Pressure:~, _,~. ~.. Precipitation:/..~.~._ Sky:,.~ ,~'_ ~'~tF..g, .. Chill Facto,': Submitted by, ~_. Representative ...,H~OE .BA.Y HOI'EL 'rD'659-.2752 3'UL '2'";'-~)94 FAIRWEATHER E&P SERVICES, INC. 15:19 No.OIO P.O1 REPORT NO: ...... FIELD PROGRESS REPORT CLIENT; AMERADA HESS CORPORATION JOB NO, 002-02-400 PROJECT: SEAL ISLAND WELt_ ABANDONMENTS NORTHSTAR/SEAL. ISLANDS RECLAMATION AND ABANDONMENT /~ ~ ~~_._.; Tcmp: ~ Wind: ,5 t4/'~/~'~3l Visibility: Woather ~ ~ hrs . ~;ubmilted by: ~ ,dE BI~" HI}TEL ~D'659-Z''' c ''', .~ `- ,, "I JUL 2~.~94 ,, 21'10 No.O!O P.O1 FAIRWEATHBR E&P SERVICE$~ lNG. FIELD PROGiRE$$ REPORT REPORT NO: z./ JOB NO, 002-02-400 AFE NO. CLIENT: AMERADA HESS CORPORATION PROJECT: SEAL ISLAND WELL ABANDONMENTS; NORTHSTAR/SEAL ISLANDS; RECLAMATION AND ABANDONMENT .JilL'I , ,, ,-- I I . I . - I - : n,, _. Ill .. I I .__ iii i i ! Il ! Weatller ~ hrs Pressure: ,2 ~¢,'7 ¢ SubmiHed by: ~ Representative :,.rl'.OE BRY HOTEL ID :659-2?5£ · 3UL '" '?i 94 21'10 No.OlO P.02 FAIRWEATHER E&P SERVICES, INC, FIELD PROGRESS REPORT CLIENT: AMERADA HESS CORPORATION REPORT NO: DATE: JOB NO. 0O2-O2-40O AFE NO. PROJECT: SEAL ISLAND WELL ABANDONMENTS NORTHSTAR/SEAL ISLANDS RECLAMATION AND ABANDONMENT , .. i il, ii ]1 .. i [ , _ nl .. i i · - _ i , . i ..... , Weathor {~ eeee hfs Pressure:, /~/~ ._ Precipitation: -'"" Sky: _/~, ~'g~/.. Chill Factor: ~,,Y Submitted by: ~ <~l~em/ods Representative -) FAIRWEATHER E&P SERVICES, INC, FIELD PROGRESS REPORT CLIENT: AMERADA HESS CORPORATION REPORT NO: ~--~ ,JOB NO. 002-02-400 LL--- PROJECT: SEAL ISLAND WELL ABANDONMENTS NORTHSTAR/SEAL iSLANDS RECLAMATION AND ABANDONMENT Weather ~ g6eO I~rs Ternp: ..... Pressure: P,'edpitalion:ff,:~e..._ Sky: ~//~ ~~},1 Chill Factor:_ ! Submlttecl by: ~;:l~peralor's RepresentutN~ - T i"1 · A '~'f'"ll"l ' Cl~',t "0 ' (~ t':'~ 0.7 -it', r" ':' :" ~ T." ._ ,C ,"' ,3 , ,"r 'r "~ 'q , 'mt I , :.~r'r ..'~,"-,, ~,.~,-,., , ......... ._ .BA'Y' HOTEL ID '659-27'5"' JUL. ,.'>:;¢ 94 21:54 No.Oi5 P.O1 FAIRWEATtiER 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 Prossura: ~'O. ~ Precipitalion: ---' Sky: ~/,~-~¢- Chill Factor: //~/~ ....... Submitted by: ,.,'"'B.q..'Y' HOTEL II) 659-2752 5UL 2, 9,4 ) 2:5:52 No.015 P.O1 FAIRWEATHER E&P SERVICES, INC, FIELD PROGRESS REPORT REPORT NO: JOB NO. O02-02.-400 CLIENT: AMERADA HESS CORPORATION PROJECT: SEAL ISLAND WELL ABANDONMENTS; NORTHSTAR/SEAL ISLANDS RECLAMATION AND ABANDONMENT REPORT PERIOD: ,.,~_O..O__,/ ......... hfs '7 -7--'7'-'ff4 to,_'~....l~_, hfs, 1 T ~,,-/,,¢~ ~L ¢__~__.....,.¢~//,o~. ,-J,-,'¢l-~/ " " #/~ ~1,,~~//-.. ~.~ ~,,, ocs-y-./ Weather ~ 8~10 hfs Pressure: __~_O, 43 ~ Precipilatior~: "'- Sky: ~/e~.,,,- Chill Factor: .,'"'~RYHOTEL ,, · ") JUL 2<L' 9'4 .4'47 No.O02. P.O1, FAIRWEATHER E&P SERVICES, INC. FIELD PROGRESS REPORT REPORT NO: DATE: CLIENT: AMERADA HESS CORPORATION JOB NO. AFE NO. 002..02-400 PROJECT: ;SEAL I~LAND WELL ABANDONMENTS NORTHSTAR/SE, AL ISLANDS RECLAMATION AND ABANDONMENT 11 Weather ~) . 7"gtCO, Temp:. Wind:. Visibility: Pressure: _~::2. ID{ Precipitalion: /I/~4 e., Sky: ., ~emt~l;S Represenlativu -'- ,~ "~Ft'r" HOTEL iD'659-2752 .. ,- JUL 2q.,:)94 2,3'2i 1'1o.022 P,O1 FAIRWEATHER E&P SERVICES, INC. FIELD PROGRESS REPORT CLIENT: AMERADA HESS CORPORATION PROJECT: SEAL ISLAND WELL ABANDONMENTS NORTHSTAR/SEAL ISLANDS RECLAMATION AND ABANDONMENT , REPORT PERIOD: Activily Report; Woatherl~l~rs ~.Z2..~~: Temp: ~'50 Wind: ~__~' Pressure: ~ ~ Precipitali~: -- Sky: .__ C~.~ Submitted by: ~ ~m ~ I.. ~''II HdTEL ID '659-2752 ,,,, . JUL '~,t ' 9/-4 8'09 No.O05 P.01 FAIRWEATHER E&P SERVICES, INC. REPORT NO: m FIELD PROGRESS REPORT DATE: JOB NO. [302.02,400 CLIENT: AMERADA HESS CORPORATION PROJECT: SEAL ISLAND WELL ABANDONMENTS NORTHSTAR/SEAL ISLANDS RECLAMATION AND ABANDONMENT Pressure: ~, ~:~4.. Precipitation: ~ Sky: &~¥,~,~_~_. ,~. _1~/_~_ Chill Factor:_ Submitted b ~ Represer]tstiw ALASKA OIL AND GAS CONSERVATION CO~IMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 27~7542 August 19, 1994 Robert C. Gardner, President Fairweather E&P Services, Inc. Agent, Amerada Hess P 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. Herring recommends Location Clearance for the five wells. Final Location Clearance is hereby approved for these Amerada Hess wells: BF-47-1 ?TD 83-074 BF-57-1 PTD 84-093 OCS-Y-181-1 PTD 84-017 OCS-Y-180-1 PTD 84-220 Colville 25136 #1 PTD 85-278 Chairman c: Blair Wondzell bew/11 ahns 5w MEMORANDUI ! State of Alaska Alaska Oil and Gas Conservation Commission TO: . David Johnston, Chairman THRU: DATE: Blair Wondzell,~ P. I. Supervisor Ofq FROM: Jerry Herring, ~('[~ SUBJECT: Petroleum Inspector August 13, 1994 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-181-1 (PTD 84-017) Wednesday, Auaust 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 and 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 77002-5681 Surface Location: F L, F L Section 11 ,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 BF-57.1 F Section Ins'pec~ion Date: PITS: Filled In: 84-093 North Star Unit Inspection Date: N/A !,.. ~.. ~ 2~].2~ ,, ABANDONMEN~ MARKER,,,,,I Approval Date: Steel Post OD: (4" min) N/A "Length (10' min.) N/A lt. Height Above Final Grade Level (4' min.). N/A It. Top of Marker Post Closed With: N/A (Welded, Cmt., Cap), Set: N/A (On Wellhead, Csg, In Cmt) Distance Below Final Grade Level: 19 It. Side Outlets: All valves and nipples removed ? N/A All openings closed? N/A With N/A ,, iMarker Plate Diameter: N/A "Thickness: N/A "Distance Below Final Grade Level: N/A ff. i Marker Plate Attached To: Wellhead N/A Cutoff Csg N/A Other N/A . .~':.~ ' :~ :':': ". i .~ ' ':.;....ii;.i; : ",:i,;':;::: .......... :'.::.: '.' ;};:[i'::i;;!.;'~;[:;:;:',';i}.;:,!';!;i;[;;l;:jiii.:~ll;{;;;;!}; :!;'i;; .:. '~ ;.i;;'[;i;iil;;i;. :.::;i:::':[;:i'[ ;:;=;~;;;;.i .';; ;. ;!.... .:.;i ! ,.!.;..~.:....;.!~:i..:.'.. ....... :.'i:..~:,.i.; ,,ii';.:';:.:i,';i::;i:!!:l:~i:~i;=.::..;!';:;.~i:..[..=..I, ;:!=.' .:..:......' .. Information Beadwelded Directly to Marker Post or Blind Marker Plate: ( Note when different from file information) Operator: N/A Unit I Lease Name: N/A Well Name: N/A Remarks: Seal Island is bein~l abandon~ed. Casin~l was cut and Surface Location: removed 19 feet below original mud line. No marker ~ L, F ~ L plate was installed due to offshore location. ,T ,R ,M !i:i' 0' " ': ' ~ "' ' ' ' ' ~/~o/94 ! ,., ~..~, ~;~$~.~P ~,,~..O_...,~AT!QN~_:~N~.,.. i Approval Datei N/A Liners Removed or Buded: N/A Debris Removed: Yes SURFACE CONDITION OF PAD AND I OR LOCATION · Contoured ( Rough, Smooth, Contoured, Flat, Compacted ) Clean: Yes Type & Quan. of Debris if any remaining on pad and I or location: None 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 ( Dirt, Gravel, Ice, Other) Clean: N/A 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 ) c - Operator c - Database c - Inspector FI-000 (Rev. 3/93) FINAL INSPECTION: Yes XX INSPECTED BY: 199KHKBD.XLS NO DATE: 8/10/94 MEMORANDUM TO: THRU: FROM: Blair wondzell, P. I. Supervisor Otc,/ Jerry Herring, Petroleum Inspector State of Alaska Alaska Oil and Gas Consei'vation Commission DATE: August 13, 1994 .. FILE NO: i99khjbd.doc SUBJECT: Location Clearance Amerada Hess, Seal Island North Star Unit BF-47-1 (PTD 83-074) ~' " OCS-Y-180-1 (PTD 84-220) OCS-Y-181-1 (PTD 84-017) .... ,, . Wednesday. Auaust 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.., . ....... i'. ..... ' 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 77002.568t Surface Location: F L, F L :Section 11 ,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 BF.57.1 84-O93 North Star Unit Inspection Date: N/A [~,~,,,~t,,,~~,;~,,~..,~,~,,,~N~NM~N~..,~ ~~, ! 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 (Welded, Cmt., Cap), Set: N/A (On Wellhead, Csg, In Cmt) Distance Below Final Grade Level: 19 ff. Side Outlets: All valves and nipples removed ? N/A All openings closed? N/A With N/A Marker Plate Diameter: N/A "Thickness: N/A "Distance Below Final Grade Level: N/A ft. Marker Plate Attached To: Wellhead N/A Cutoff Csg N/A Other N/A ' [ [ t i t ~ Information Beadwelded Directly to Marker Post or Blind Marker Plate: ( Note when different from file information) Operator: N/A Unit / Lease Name: N/A Well Name: N/A Remarks: Seal Island is being abandonged. Casin[1 was cut and Surface Location: removed t9 feet below original mud line. No marker F ~ L, F L plate was installed due to offshore location. Section ,T ,R ,M , , i ' ' L F i ;~L;;U ; ....... '"~ .......... ~ ....... ' ' : ..... :~"' '~"'" .... i ...... i ....... ~ ..... ~ i' ii Inspection Date: 8/10/94 .......... ;! APproval .Date: PITS: Filled In: N/A Liners Removed or Buried: N/A Debris Removed: Yes SURFACE CONDITION OF PAD AND / OR LOCATION · Contoured ( Rough, Smooth, Contoured, Flat, Compacted ) Clean: yes Type & Quan. of Debris if any remaining on pad and / or location: None TYPE AND CONDITION OF SURROUNDING AREA' Arctic ocean (Wooded,Tundra,Grass,Brush,Dirt,Gravel,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 ( Dirt, Gravel, Ice, Other) Clean: N/A 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: Yes XX No ( If "No" See Reason ) orig - Well file c - Operator c - Database c - Inspector FI-000 (Rev. 3/93) FINAL INSPECTION: Yes XX' INSPECTED BY: /~ ~Y~ 199KHKBD.XLS NO DATE: 8/10/94 STATE OF ALASKA Al...'~OIL. ANDOASCONSERVATION COMMIS. ')N APPLICATION FOR SUNDRY APPROVALS 1. Type of Request Abandon .~X Susoend __ Ooera,on shutdown .._ Re-enter suspended w~l AJtef c,a~ng -- Reoar w~ ,__ Plugging __ ~me exmnsfon __ Stimuiat-'~'__ Change aPl:m:~ved program __ Pull lul:,ng __ ' Variance -- Pertoratt __ Other _=. 2. Name ol Operator I 5, Type of Well: Amerada l:less Corporal:ion i Oev~o~nent._. 3. Address ~20~' Louisiana, SU&t& 700 ExoIoratory Rousl:on, 33{; 77002 Stra0graonic .. Se~ce __ 4. Loca0onolwetlatsudace 15z~1.5 fl: FSL, 629 fl: .F~;~., Sec. 11, '~q_Jt~, At top of productive interval ~.912 fl: FST., 2788 fr. [~,~E,, Sec. 2% 13.3N, P,13E, At effective depth Sameas surface location 0 R I G I ~,,,,,. ~,.,~,~ At total depth 4124 ft: FSL, 2613 fl: F-,4~, Sec. 2% T/.JN, R13E, tl~ 11. Field/Pool '~xploratory 12. Present well condition summary Total depth; measured 15,z~55 feet true vertical 11,605 feet 6, Datum elevation (DF or 55 fl: KB 7. Unit or Property name torthstar Unit/Seal Island & Well num0er BF-57 ~1 (Seal A-3) g. Permit number 84-93 10. APl number 50--029-2]3.30 feet Etfective depth: measured 110 fee{ true vertical 110 feet '2 BP @ 14',812", BP @ 14,678, BP @ 14~533' Plugs(measured) BP @ 14,402', 14,402-14~8; BP @ 11,590, 3_1,590-11,200, 8517-8190, 2900-2610,'' 380-110 Junk(measured) BP Fish @ 14,816, mill 'and packer fish @ 12,000' Caang Length ~ze SEuctural 1~9' 30" Conductor 1602" 20" SuHace 5000' 13-3/8" Int~mediate 14,280' 9-5/8" Produc~on - - Uner 7028' 7" Pedoraaondepth: measured 15,250-]-.5,350 ' true vetch11,473-11,529 Cemented Measured depth ~ueverticaldep~ Driven 149' 149' 3700 SX(to surf) 1602' 1602' 2850 SX(to surf) 5000' /-~59' 1450 SX 1~,280' 10,911' 475 SX 15,~55' 11,588' 14,70471~,71~ 14,570-14,620 14,~97-14,522 11,71~-11,763 3-1,163-11,169 11,084-11,11~ Tubing (size, grade, and measured dep*,h) None Packers and SSSV (type and measured depth) Jur~,.ed packer @ 12,000 ft: MD ]-1,0/+1-]_1,056 9153-9186 RECEIVED O UN 2 4 1994 Alaska 0il & Gas Cons. C0mmissio 13, Attachments Description summary o~ proposal __ Oetaled'operations program ~ BOP ske~tgchorage 14. Estimated date for c~T, men~ng opera, on J 15, Statu~ o~ ~1 ~fi~on ~: July ~, 199~ 16, If pro~ ~ ~r~ly ap~ ~1 __ G~ __ Sus~nd~ ~ Name of appr~ Date apm~ S~ce 17. I h~e~c~al ~e f~~ue ~ ~r~t to the ~ of ~ ~~g~ . signed ' ~ [/ - ~R COMMISSION USE ONLY Con~[iom of appr~Notify C~mi~on ~ repr~ti~ mw ~t~ Plug integn~ ~ BOP T~ ~ ~aon deara~e ~ M~~ In[~d~ Te~ ~ Su~nt.f~m r~r~ 10- ..~o~ Date June 16, 199~+ Approved by order o~ the Commission ORIGINAL SIGNED BY RUSSELL A. DOUGLASS Form 10-403 Rev 06/15/88 Commissioner Approved Copy Returned SUBMIT IN TRIPLICATE OPERATIONS PROGRAM FOR SWEPI BF 57-1 (SEAL A-3) 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 77 feet below island surface. Top of plug in 9-5/8" X 13-3/8" annulus is approximately 154 feet below island surface. The 13-3/8" X 20" annulus is plugged at surface by primary cement job. The 20" x 30" 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 reportedly contains 9.9 ppg CaCl2 above the top plug. The 9-5/8" X 13-3/8" annulus probably contains 10.2 ppg CaCI2 fluid. Wellhead is in place. (see Attachments No. 1 and No. 2.) . 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 77 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 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 77 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. ~ E¢ E IV E D JUN 2 4 1994 At~,ska Oil & Gas Cons. Commission Anchorage , , , 10. 11. 12. 13. 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 77 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. Detonate shot and sever four (4) 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. NOTE: 30" drive pipe is already cut off at floor of cellar. 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 30", 20" and 13- 3/8" casing together. Strings are cemented together, but if cement fails, recover casing as it comes and repeat until all three strings have been recovered. It may be necessary to use steam lance to thaw interface between 30" casing and frozen island core in order to pull large OD connectors on 30" drive pipe. If 30" 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. RECEIVED JUN 2 4 1994 Oil & Gas Cons. Commission Anch0ra.qe Attachment No. 1 BF 57-1 (Seal A-5) Present Wellhead Condition (Attached to and made a part of program for final abandonment of BF 57-1 well) 30" Drive Pipe Cutoff @ Cellar Floor 5 1/16" 10K VALVE .. ' , 'l I 2~ ~, 2.000 I ,, 20" 153~, K-$5 ~~ 15 5/8", 72~, N-80 :Su~ace)~,~. 9 5/8", 47~, N-80 (' Island Surface Well Cellar EIVED JUN 2 4 1994 Anchorage I I I I I I I Attachment No. 2 BF 57 No. 1 (Seal A-5) Near Surface Detail (Attached fo and made a part of program for final abandonment of BF 57 No. 1 well) Original KB Elevation = +55' (33' above island surface) 50" DRIVE PiPE CUT OFF AT BOTTOM OF WELL CELLAR TOP JOB CEMENT TO 100' KB ORIGINAL MUDI~INE (-59' MLLW (S4' KB) CASING STRINGS TO BE SEVERED O m 76' BELOW ISLAND SURFACE (15' BELOW ORIGINAL MUDLINE) TOP OF CEMENT PLUG IN g 5/8. CASING e 110' KB (77' BELOW ISLAND SURFACE) (BOTTOM OF PLUG e `380' KB) ,, TOP OF CEMENT PLUG IN 9 5/8" x 1.3 $/8' ANNULUS ~ 187' KB t154' BELOW ISLAND SURFACE) 121' BELOW ISLAND SURFACE) ISLAND SURFACE 9 5/8., 47#, N-80 9.9 ppg CaCI2 13 $/8., 72~, L-80 153#, K-55 ;50", 1" WALL DRIVE PIPE SHOE OF DRIVE PIPE ~ 149' KB (116' BELOW ISLAND SURFACE) RECEIVED I I jUN 2 4- 1994- Oil & Gas Cons· Commission Anchora;~ BOTTOM OF CEMENT PLUG IN 13 3/8' X 9 5/8. ANNULUS ~ 687· KB (654' BELOW ISLAND SURFACE E & P SERVICES, INC. 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 th. ree (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 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 Hess Corporation Cliff Richard, Amerada Hess Corporation 715 L Street Anchorage, Alaska 99501 (907) 258-3446 FAX (907) 258-5557 Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 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-Maunder*(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 u 9 1988 Alas~ 0il.& 8as Cong. Commission '~ Rnchorage SBBH/aogcc. 101388 STATE OF ALASKA ALASK,,. IL AND GAS CONSERVATION COMi, ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate r-1 Pull tubing [] Alter Casing [] Other ~ 2..N. ame of .Operator Snell 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 15/+1.5' FSL, 629' FELs Sec. 11, T13N, R13E /+912' FSL, 2788' FWL~ Sec.24, T13N, R13E 5. Datum elevation(DF or KB) 55' above sea l~vel 6. Unit or Property name Seal Island 7. Well number BF-57 No, 1 8. Approval number 8-597 9. APl number 50-- 029-21130 At effective depth At total depth /+12/+' FSL, 2613' FWL~ Sec.2/+, T13N, R13E 10. Pool Wi 1 dear Feet 1'1. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural 1/+9' 1602 ' Conductor 5000 ' Surface Intermediate 1/+280' Production Liner 7028' Perforation depth: measured true vertical 15,455' feet Plugs (measured) 11 ~ 605 ' feet .. feet Junk (measured) feet Size Cemented 30" 20", 133#, K55 13-3/8% 72#s N80 9-5/8", 53.5#s N80&L80 7",32#,L80,LTC 15250' - 15350' 11/+35' - 11/+67' Measured depth 3700 sx Permafrost II I~D sx ~rmafEost II & ~uu sx L, laSS ~ 1/+50 sx Class G 1/+9' 1602' 5000' 1/+280' /+75 sx Class G 15/+55' True Vertical depth (Previously cemented with "G" cement + additives) Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressuresqueeze 9-5/8" x 13-3/8" annulus with 170 sx (500 lineal ft) of Coldset II cement ¢15.0 ooa. 0.961 cf/ski. Pressure ~ested t:o 1750 nsi. Tested 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 Summary of 0perationss present status 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 i Signed ~~4~'".~.~ Form 10-40~,' Rev. 12-1-85 SBBH/ros. 102~88 · . Title Division Operations Manager Date I("). ~'~ Submit in Duplicate¢ SUMMARY OF OPERATIONS BF-57 #1 1) 2) 3) 4) 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 CaCl2 water. Ran 8-3/8" drift inside 9-5/8" casing to 22' below mud line. Pressure tested cement job to 1750 psi. Tested good. Unofficially witnessed by Randy Howell of MMS. Test squeeze between 9-5/8" x 13-3/8" annulus to 1500 psi for 15 minutes. Tested good. VEU8/101388 SEAL ~3 ['BF-57 ~1) PRESENT STATUS 10/12/88 Not To Scale KB=0' TOP of ISLAND 33' SEA LEVEL 55' 9.9 ppg CaCl2 MUD L~E 94' CMT in 30' to 100' CMT in 9-5/'8' at 110' 30' at 149' CMT in 13-3/8' et 187' CMT in 9-5/'8' lo 380' · CMT in 13-3/8' to 687' CMT in 7' at 11296' SQZPERF11700' SQZPERF 11780" TOC at 12990 9.9ppg CaCI2 9.9ppg CaCI2 9.9ppg CaCl2 10.0ppg CaCI2 10.0ppg CaCI2 10.~3ppg CaCl 10.0ppg CaCl2 10.0ppg CaCI2 CMT at 925' 20' at 1602' CMT in 9-5/8' al 2610' CMT in 9_-5/_8" ARCTIC PAC to DIESEL to 4908' 13-3/8' at 5000' .CMT in 9-5/8' at 8190' 7' SCAB TOP at 8427' CMT in 7' at 8517' CMT at 11200'+ BRIDGE PLUG at 115~)0' PERF at 117~4-11763 MILL&PACK ER FISH 12000' 7' LINER at 13980' TOC in 7' at 14118' 9-5/8' at 14280' BRIDGE PLUG at 14402' PERF at 14497-14522' BRIDGE PLUG at 14533' PERF at 14570-14620' BRIDGE PLUG at 14678' PERF at 14704-14714' BRIDGE PLUG at 14812' BRIDGE PLUG FISH 14816' PERF at 15250-15350' 7' at 15455' August 9, 1988 Mr. L. Smith Alaska Oil and Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, Alaska 99501 Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 Dear Mr. Smith: 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) for 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 1 o 19BB 'Alaska 0il & Gas Cons. Commission ,, Armhorage August 5, 1988 Mr. B. Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 RES ENG I SR ENG ]. SR I ENG _~ SR GEOL SR GEOL I ENG ASST I .E.N...9_.._A.S.s_T_ L STA..T._..T._E_CHI STAT TECHI '-'" E: Dear Mr. Wondzel 1: 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 clarify that Shell Western E & P Inc.'s intent of our Sundry 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~ trulyyours, W. F. Simpson ManagerRegulato~ Affairs WFS/ljm SBBH/aogcc. 080588 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 1541.5' FSL, 629' FEL, Sec. 11, T13N, R13E 4912' FSL, 2788' FWL, Sec.24, T13N, R13E At effective depth At total depth 4124' FSL, 2613' FWL, Sec. 24, T13N, R13E 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural 149' Conductor 1602' Surface 5000' Intermediate 14280' Production Liner 7028 ' Perforation depth: measured 15455' feet Plugs (measured) 11605 ' feet 5. Datum elevation (DF or KB) 55' KB " feet 6. Unit or Property name SEAL ISLAND 7. Well number BF-57 No. 1 8. Permit number 84-93 9. APl number 50-- 029-21130 mmm .mm Size 30" 20", 133#, K55 10. ,Pool Wi 1 dcat true vertical C feet Junk (measured) feet 13-3/8",72#,N80 9-5/8",53.5#,N80&L80 7",32#,L80,LTC 15250' - 15350' Cemented Measured depth 3700 sx Permafrost II 1:~ sx ~rmafl::ost II & SX [.lass la 1450 sx Class G 149' 1602' 5000' 14280' 11435' - 11467' Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) 475 sx Class G 15455' (Previously cemented with "G" cement + additives) 12.Attachments Description summary of proposal WELL D IAGRAN RECEIVED 13. Estimated date for commencing operation August 20, 1988 14. If proposal was verbally approved ?u" '.' :.: .... : Name of approver AUG i © 1988 rti ~1.~,,~,~. ~ ...................... Detailed operations program l~n~g~ketch [] .. II 7 3'~/ Date True Vertical depth Date approved 15. I hereby certify that the foreg/oing is true and correct to the best of my knowledge Signed Title Division Operations Manager Commission Use Only Conditions of approval Notify commission so representative may witness [] Plug integrity FI BOP Test [] Location clearance Approved Copy Returned Commissioner [Approval No. ~) ..-- ,~-~.~ by order of the commission Date Submit in triplicate Approved by ORIGINAL SIGNED BY LONNIE C. SMITH REVISED 8/8/88 Form 10-403 Rev 12-1-85 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 #3 (BF-57 #1) ABANDONMENT PROGNOSIS NOTE: All depths based on 79' from KB to sea level 1) Move rig over well bore. Check all wellhead components for trapped gas. Nipple up annular preventer. 2) Drill out cement in 9-5/8" casing to 141'. Displace 9-5/8" casing with 10.2 ppg CaCl2 water. 3) Pump into 9-5/8" by 13-3/8" annulus with 10.2 ppg CaC12 water just enough to establish an injection rate. 4) Squeeze 500' lineal feet (174 sx) of permafrost cement into 9-5/8 by 13-3/8" annulus; displace with 10.2 ppg CaClz w~~ow mud line (sufficient cement to effectively seal the'~a~-~ulu~-~-p~-~'I per 20 AAC 25.105.i.2 and cement across permafrost must have a low heat of hydration per 20 AAC 25.105.j) 5) Run 1" tubing in annulus to confirm the location and the competency of the cement plug (per 20 AAC 25.105.1). VEU8/O71588a SEAL -~3 (BF-57 -~1) PROPOSED P&A STATUS 7/'25/88 Not To Scale KB=O' TOP of ISLAND 56' LEVEL 79' CMT in 30' Io 100' MUD LINE 118' 10.2ppg CaCI2 CMT in 9-5/.8' at 141' 30' at 149' CMT in 13-3/8' at 168' CMT in 9-5/.8' to 380' · CMT in 13-3/8' to 668' CMT in 7" at 11296' SQZPERF11700' SQZPERF 117807 TOC at 12990 9.9ppg CaCI2 9.9ppg CaCI2 9.91313g CaCI2 10.0ppg CaCl2 10.0ppg CaCl2 10.0ppg CeCI CMT at 925' 20' at 1602' ARCTIC PAC to 2221'_-I: CMT in 9-518' at 2610' CMT in 9-518' at 2900' DIESEL to 4221'+-- 13-3/8' at 5000' ,CMT in 9-5/8' at 8190' 7' SCAB TOP at 8427' CMT in 7' at 8517' CMT at 11200'+ BRIDGE PLUG at 11590' PERF at 11714-11763' , MILL&PACKER FISH 12000 7' LINER at 13980' TOC in 7' at 14118' 9-5/8' at 14280' BRIDGE PLUG at 14402' PERF at 14497-14522' BRIDGE PLUG at 14533" PERF at 14570-14620' BRIDGE PLUG at 14678' PERF at 14704-14714' 10.0pl~g CaCI2 10.0ppg CaCI2 BRIDGE PLUG at 14812' BRIDGE PLUG FISH14816' PERF at 15250-15350' 7' at 15455' CMT in 7' at 1 1296' ~QZPERF 11700' .~QZ PERF 11780" TOC at 12990' SEAL PRE SENT CONDITION 9.9ppg CaCI2 9,9ppg CaCI2 9.9ppg CaCl2 ;.. ;.. 9.9ppg CaCI2 I -- ~.!--~, I--~1--~1--'~, lO.Oppg CaCI2 10.0ppg CaCI2 10.0bpg CaCI lO.Oppg CaCI2 10,0ppg CaCI2 8/3/87 NOT TO SCALE KB--O' TOP OF ISLAND 56" SEA LEVEL 79' CMT at 100' CMT in 9-5/8' at 110 MUD LINE at 118' 30' at 149' CMT in 9-5/8' at 380 CMT at 925' 20" at 1602' DIESEL to 2000'± CMT in 9-5/8" at 2610 CMT in 9-5/8' at 2900' 13-3/8' at 5000' CMT in 9-5/8" at 8190' 7" SCAB TOP at 8427' CMT in 7' at 8517' CMT at 1120'0'+_ BRIDGE PLUG at 11590' PERF at 11714-11763' MILL&PACKER FISH 12000' 7' LINER at 13980' TOC in 7' at 14118' 9-5/8' at 14280' BRIDGE PLUG at 14402' PERF at 14497-14522' BRIDGE PLUG at 14533' PERF at 14570-14620' BRIDGE PLUG at 14678' PERF at 14704-14714' BRIDGE PLUG at 14812' BRIDGE PLUG FISH 14816' PERF at 15250-15350' 7' at 15455' Telegr 1.=.!?? FT. 'U A,~!c~IO?AG]~ ALASKA F.-?-23 !S-'54 ADT P':~ %CTION .~.LASKA OIL AND GAS ..?,OFS~RVATIO~i COMMISSIO~.'- 3Z.01 POP..C'JPIN[. DR Oi 5 - ~ i PDT.Z:-..'P T%'.'O MI-NO? OIL SPILL S'S..NDPIPER GR;-~V1;-'-L ISLANr', BS:AUFOET SE&_ . Ai.ASYA. MPS8'~.~..5~ .~-~ I ~ iT'J "~Ie''' ~, r~ ~ JU5 5~-~S0 ~=~_.~ CCMPL~=n_~.~:~ SImr SURVEY OF ~M~I"'DE~ CF S;.~'~'n TP7~,,. ~.._ ...... ,%z' ~' V.~L,~ I SL& ~,~T. TN. C ~M~ ~['~Y~, _ C=~: ~MCCO _.w~PS~. . I qLAP-~D~ D~ ~STRCY2D ?:ITF SMALL F?RTION OF i6MLIPAD Ab;D DOCK ~'~ -ICI~'L? u~/~vO~C I~;DI~,~=- m'-z ~.V~L~AD;_~ . .,~r'"'. ~< ....... · · .....:. ~ . ~.. z.~. ~:.~S ~..qPV~~a: DA~A'=~. · . i~:~w }{AVM C, CC"~ Y?ICR TC ~'E~ZE-U~ C'~ ~f ~? ~ww'VIOUS POSITIO~: iI,.~;;m ~:Tt,:=0i,: SM~., I' :-~ATI;~ S~r'-E ~' ~ ~=' -- WTD~ AF'D ...................... - z .... 1 ~>'T .... ~.~ ANN~I;~S~ ....I~,' ~.:~I,L ~ D9F5 H~.V~{ ~ COb3C~='T~ FLUC--IT IS NOT. ~ 5~'~zC ~. S"T,~ %~n~r~ ZO~.~. A~ S~"~;n T~,: PC, L5~=- ON~ FOSSI=ILIT~ Telegram LOSS OF LISPOEED ?LUID2 FXTRFHv...':LY SLIC-HT. POTENTI~L HEDIUM SPILL ~.IS ~CT ~XIeT C. COKS~vE~I~,~G PP. ESE~T ICE CO~DITIO~?S~ IT WOULD BE EXTREMELY ~I~ICULT mC ~ET .-_ BAPG~ ON ~;~-~ TO ATTEMPT TO ~;ETER,',INE CO~DITIOK OF ~HE i'~Ln~:~uS THF PRES~h~T SHFE~ ~:EI~.~G E~A~ATED ~/..'OUL~ ~'OT B= RFCOVF~:APLY EV~? [~ F~U[PT ¥.AS 0~ SCENE, AMOCO ~P. TPAT'I~G PLA~: O~ ~.CTIOK FO= PRES~'NT~TIO~.~ NTXT W~E~. THIS PLf~N '; . YILL IN~LUD! PROVISIOt~S !OR LOCATING WELLHEADS :4FD ~'~ .......... ....... TO CIL 7~i~CHAP. GFp, ,.,WTT, r,...~_~. OPE~!TIO~'S~': ~O_ D!~L~ I~flTH THE YELi, i{~*~i:~ ~.~ !.EIt';~ CC~"DVCT~I' D. vSC~ w~p _~L~C,. C'V~FLW[''z.;. _. ~[,.~ ....... CR~V~L ISL~DS I~ Sm:[TE w~m=oS,-,,_~ , Sv'''~ TSLA~.' ~7~1 ~ " · _~.~. E ( L ~D ~.~0P.~ S~.R ~A~EPAD~,-HESS~ BOT~' I~L~.~-~D~ S:~OY SIG"'i~ICAF'~ DA>iAG- mC S-~','~'A' ~ .... · ~,~ ..= 2SRH AYn SE~'ET PILE. T-'Iq .... ~OITM~lo ~', ~'77' .... C_FAVrT..._~ T". SU3jEC:~'_ ~'~ '~IVE ~!Oq!ON ~Y ~w~E~,mc '?MS i~DIC~,q'~r' Tw~S~ ]~z.~,~.~ I~EE~L7 APP:O[ ~-' _j.' ~O~'-'I~O'.,. :_ ~>__ ;ANPz:'PEz' ~U.: ~. ...,~.r ~i% q G.z:S ~C~ERVATT~' OCX~"iSS]O:'.'. . ~.'~,IC_.,.. . .... TES S~W:.L ...~t'.:n~. :'~rZF, DA-TESS..~ ....ARE PRZPAM[N . -. ' '~ ~ '= ' ...... ... .~; ............... 0==~.,~ THF ~ BEDj. _,, , ,3 ~':';, ..~,_'::- ~¥~lL~.. :~_... SUSt'~,, D~_r~. AS'- D'}.SCR~:E7', ~ I~': POL~EP.. fi.t,. ~. Telegram --, F. UPD~.TED INFO ON .~,!OP.T',~ ST..~R WELL STATUS-ONE WELL HAS .B]~EN '%':~- A~AN~ONED THE R~,~..INING W~LL ~..S ~EE~ PLUGGED ~fITH CO~;C~ - ~ ~ELOW SEA~ED ~.~D FILLED ~.ITH CALCIUM CHLORIDE. ~q. ~$ID!S S.~DPIP~, T!~ER! AIF THR~E OTHEP. ~:AN-MAD~ GEAVFL ISL.~NTS O~f TEl O$S-MUILU]~, P-Y-?, AND TERN. MUKLUK ~MD BF-~7 '-~ HAVX ~E~.~ P~MA~W~TLY gB~I"i:ONED (W~.L~ PFR~P. NENTLY ABA~JDONED '" AE D,E~CPIBE!, IN E. ABOVE'. S"~DB~C~/SHFET= PILE P_.O~TIOI~P ~ L~" '] ItqC~IBF!'.~,... INPCLRv~.,_~ Ot,'~..~.. ~lO.. PYPORT OF DAM~..=~. " ~ ' ~Nn' ~" CTL ~'GAS CO~.~S COM~. YOP: YU!TEER INFO. ~ P'LAF ~ A. CO;~TI~:UY TO ~ONITOP SITUATION. -. .... ' ?. °~VItW.~_ ...~CCO. PLA~'.~ ~0~_ _ ~?DPIPER_. . · - ..... ~ C. MAI~.'T.~IM COMT'~'CT WITH ~:[ OIL & GAS CO~S. COF~M. SFELL, ~_ND " ~MFRAI:A-H~S RFGAtI. ING REPAIR ~L~_5~F FOP SFAL ~_ND MORT,{ST~.R . · ~, .... · " ~CGAR: MFO ~FCYC"R~LGE AK TELECOPY NO~ (907) 276-7.542 July 22., 1988 Mr. M. L. Woodson Division Operations Mgr. Shell Western E & P, .Inc. 601 W. Fifth Avenue, Suite 810 ~utchorage, AK 99501-2257 Dear Pete~ Confirming today's telephone conversation with your Ms. Susan Brown, the Con~ission is gratified to learn that you alrea~have underway plans to repair erosional damage suffered by yourd~ · ~W~~artificial 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 visitin§ the site. dlf~l.CVC.43 CC: Jim Eason, Director Division of Oil & Gas Department of Natural Resources James · E. Eason Director, Div Oil & Gas DATE: June 3, 1987 FILE NO.: B .W'v'A'. 33 THRU: W.W. Barn~el~ TELEPHONE NO.: Commissioner FROM: William Van Alen~ · Sr Petroleum Geol~§ist SUBJECT: Release from Confidentiality Shell OCS-Y-181 & She.I'.."l:'~'BF'-;5:7'.':N~:.. .1 · Pursuant tO your May 27, 1987 letter to C. G. Svab, copy to C. V. Chatterton, AOGCC acknowl'edges the following release dates for the reports and information filed under 20 AAC 25.- Well Release Date Shell OCS Y-181 Shell BF-57 May 26, 1987 June 10, 1987 STEVE COWPER, ~DI~.~ 0,~-- ! ! i":-' . ~. ~ox ~ May 27, 1987 ~.~,~ ~ ~?~? ~.::'>~ Mr. L.G. Svab, District Land Manager Pacific Frontier Division Shell Western E&P Inc. P.O. Box 527 Houston, TX 77001 Subject: Shell BF-57 No. 1 Well Termination of Extended Confidentiality Dear Mr. Svab: In my March 6, 1987 letter I extended the confidentiality of the data from the Shell BF-57 well until the federal data from the OCS-Y-O181 well were released. The data from the OCS-Y-O181 well were released to the public on May 26, 1987. Therefore, the data from the BF-57 well no longer qualify for extended confi denti al i ty. By copy of this letl~er I am requesting that the Alaska Oil and Gas Conservation Commission (AOGCC) release the data from the Shell BF-57 well on dune 10, 1987. Sincerely, Eason Director cc: C.V. Chatterton, Commissioner, AOGCC 0412c RECEIVED Alaska Oil & Gas Cons. Anchorage MEMORAN')UM Stat of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION James E. Eason, Director DNR, Division Oil & Gas DATE: FI LE NO.: March 20, 1987 B.WVA.28 TH RU: FROM: Lonnie C. Smith Commissioner William Van Ale~ Sr Petroleum Geolbgist TELEPHONE NO.: SUBJECT: Extended Confidentiality Shell BF-57 No. 1 Pursuant to your March 6, 1987 letter to L. G. Svag, cc to C. V. Chatterton, per 20 AAC 15.537(d), AOGCC has extended the confi- dentiality of data from the subject well until further notice. The accompanying list reflects those wells AOGCC currently holds in extended confidentiality. Attachment 32-001 A ( Rev 10-84~ .... I~EPARTMENT OF NATURAL Ri~SOUR(,I~S March 6, 1987 OlVlSlON OF OIL AND GAS SIEVE COWPER, GOVERNOR RO. BOX 7034 ANCHORAGE, ALASKA 99510-7034 Mr. L.G. Svab, District Land Manager Pacific Frontier Division Shell Western E&P Inc. P.O. Box 527 Houston, TX 77001 ! ": ":' "..'.i ..........."~.~"'~ Subj.ec"["i ...... Shell BF-57 No. 1 "" Request for Extended Confidentiality " Dear Mr. Svab: In your February ll, 1987 letter you requested that tile division extend the confidentiality of tile reports and information from the subject well. The data are scheduled to be released on March 12, 1987. On March 3, Ron Molinari and Ernie LaFlure of your staff made a technical presentation to department staff specifying the reasons why SWEPI considers data from the well to be significant to the valuation of the nearby unleased land. Upon the recommendation of the department technical staff who viewed SWEPI's presentation and under'the departmental delegation of authority, I agree to extend the confidentiality of the data from the Shell BF-57 well. The confidentiality will be extended until 30 days after the first lease is issued as a result of Federal Sale 97 or until the federal data from the OCS-Y-O181 well are.released, whichever 'occurs first. By copy of this letter I am requesting that the Alaska Oil and Gas Conservation Commission (AOGCC) extend the confidentiality of data from the Shell BF-57 well until further notice. ..,~_(~.~/dames E. Eason ~/Director cc: C.V. Chatterton, Commissioner, AOGCC 0392c J / Hatch 6, 1987 D~WS~ON OF OIL AND GAS /.. .. Fir. L.G. Svab, District Land Hanager Pacific Frontier Division Shell ~/estern E&P InC. P.O. Box 627 Houston, TX 77001 Subject: Shell BF-57 No. 1 Request for Extended Confidentiality P.O. BOX 7034 ANCHORAGE, ALASKA ggsfO-1034 Dear Fir. Svab: In your February 11, 1987 letter you requested Utat the division extend the confidentiality of tile reports and tnformatto, front Ute subject.well. '1he data are scheduled to be released on March 11-, 1987, " '"' ',,.: On March 3, Ron Moltnart and Ernte LaFlure of your staff made a technical ' presentation' to department staff specifying the reasons tdty S~/EPI considers data from the well to be significant to the valuaUon of the nearby unleased land. Upon the recommendation of tl~e department technical staff who viewed ''" SI4EPI's presentation and under the departmental delegation of authorlty~ I agree to extend th~ confidentiality of tile data front tile Shell BF-57 well. 1he conftdenUaltty ~tll be extended until 30 days after the first lease is ..' issued as a result of Federal Sale 97 or unttl the federal data from the ,.'' 0cs-Y-0181 well are.released, whichever occurs first. '.'.. By copy of tills letter I am requesting that tile Alaska Oil and Gas Conservation Con~nJsslon (AOGCC) extend tile confidentiality of data from'the Shell BF-57 well unttl further notice. , cc: C.V. Chatterton, ConetssJoner, AOGCC 039;~C ' . RECE!..VI D .... " · . I '°.'J987 · Alqqlm (111 & (~as Cons. CommisSion i : · , .,,. Esther Wunnicke, Commissioner Department of Natural Resources Pouch M Juneau, AK 99811 Dear Commissioner Wunnicke: Shell Western E&P Inc. A Subsidiary of Shell Oil Company October 14, 1985 RECEIVED ocr Alaska Od & 6as Cons. Commission Anchorage I ,"1 ~_ ~'~ '-- .... :~ENG P.O. Box 527 ,.' Houston, TX 770 t~R E~~ ENG 2~ N. Dai~ Ash Houston, TX 770 'BR GEO~ ~gTATTEC~ [~:TAT TEC~ I I SUBJECT: SEAL PROSPECT BEAUFORT SEA, ALASKA Shell Western E&P Inc. (SWEPI), as operator, hereby requests that the Commissioner make a finding pursuant to 11 AAC 83.153 that will permit . the confidentiality afforded to reports and information filed with the Alaska Oil & Gas Conservation Commission (AOGCC) with respect to wells BF-47 No. 1 and BF-57 No. 1 to be extended for a period of 90 days after disposal of unleased land in the vicinity of these wells. This request is also made by SWEPI on behalf of Amerada Hess COrporation, Texas Eastern Exploration Company, Amoco Production Company, and Murphy Oil U.S.A., Inc., all of whom were participants in the drilling of one or both wells BF-4? No. I and BF-57 No. 1, which were drilled from Seal Island and are bottomed .on State leases ADL-312799 and ADL-312809, respectively. Pursuant to AS 31.05.035, SWEPI is required to file certain reports and information with the AOGCC pertaining to said wells. This data is required to be kept confidential for 24 months following the 30-day filing period unless the owner gives written permission to release such data at an earlier date. (AS 31.05.035(c)). This statute also permits the confidentiality of such data to be extended upon a finding by the Commissioner of the Department of Natural Resources that the required reports and information contain significant information relating to the valuation of unleased land in the same vicinity. 11AAC 83.153 provides that if such a finding is made by the Commissioner relating to the valuation of unleased land within a three-mile radius of the well(s) from which such reports and information are obtained, the Commission will, upon request, keep the reports or information confi- dential for a reasonable time not to exceed 90 days after disposal 'of the unleased land. There is unleased land in Township 14 No?.~~~;f<~,~.~.~.,~ ~L~niat Meridian, which lies within a three-mile radi~s ~0~,~,i~i~! .B,...~..-~!~i ~,l~and BF-57 No. 1. A · ~]. '"'~ ''''~' ?' ' :: "j'.:~ '~ "":'" "' '-'t ': '.,.:,," ~i : ,, ," ' ,': .... , .. · . ' .'" . .. .. ./,- ' ~ ; ,. '-. · ., ' . ,. '. .", , ',., I CRC~8528280 Your early response to this request for extended confidentiality will be appreciated. Should you have any questions, please call the undersigned at (713) 870-4'340. Very truly yours, REM:GJ 'OrlginM SISned ~ KEVIN E. HUGHES K. E. Hughes District Land Manager Pacific Frontier Division cc: Division of Oil & Gas Attn Director Pouch 7-034 Anchorage, AK 99510 ~laska Oil & Gas Conservation Commission 3001 Porcupine Drive Andhorage, AK 99501 RECEIVED Alaska Oil & Gas Co.s. Commissmn Anchorage CRCN8528280 ALASKA OIL AND ~ ~,ONSEI~¥ATIO ' Bill Sheffield, Governor 3ool PORCUPINE DRIVE ANCHORAGE.ALABKA 99SOI4-3t02 TEL EPHOHE (007) 270~-1433 RE: We wish to bring to your attention that the Commission has no~" yet received the following required items on the subJ._ect well which our records indicated was completed ~ ~-/~f ~.~'-- -" 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. erelg Chairman lc:C.024 Chemical Transmission Systems February 5, 1985 Mr. Brian Briggs Shell Western E and P Inc. &01W. 5th Ave. Anchorage, Alaska ~50! Mr. Briggs: Re: Our BOSS Gyroscopic Survey Job No. AK-BO-400~9 Wel 1: Seal Seal Exploration Area .~ ~:_~ .~At.~,.sk~ [ ~.~ ~ ~:,.,,, ~ucy~y ~ Da~e: Decembe~ 26. 1984 ~' ~ ~.. ~..,~:.~.~. Please ~ind enclosed the "Original" and twelve (12) copies of our BOSS Syroscopic Multishot Directional Survey on the above nell. Thank you for giving us this opportunity to be of service. Si ncerel y, NL SPERRY-SUN, INC. , Ken Broussard District Manager Enclosures NL Sperry-Sun/NL Industries, Inc. P.O. Box 6207, Anchorage, AK 99502-0207 (907) 563-3430 RECEIVED JUL 17 1985 Alaska Oil & Gas Cons. Commission Anchorage ............................... SPERRY-'SUN' WELL'"SURVEYING 'COMPANY ...... . .................................................... PAGE" '1' ANCHORAGE ALASKA SHELL WESTERN E & P INCORPORATED ................. SEAL"A#3'BF-57-'1'-'¢'$EC1'1T'1'3NR"1'3E) ............................ COMPUTATION DATE SEAL EXPLORATION AREA dANUARY 28, 1985 ALASKA VERTICAL SECTION CALCULATED ALONG AZIMUTH OF 154.10 DEGREES DATE OF SURVEY DECEMBER 26, 1984 ........................... BOSS'GYROSCOPIC'SURVEY ...................................... dOB NUMBER AK-BO-40099 .KELLY BUSHING ELEV. = 55.60 FT. ......... OPERATOR~ d~"SAMEO/SCHLUMBERGER ............................................. TRUE MEASURED VERTICAL DEPTH DEPTH ...... SUB-SEA .............. COURSE .................. COURSE VERTICAL INCLINATION DIRECTION DEPTH DEG MIN DEGREES 0 0.00 100 99.99 .................... 200 ............. 199,98 ..... 300 299.97 400 399.97 500 499.96 600 599.96 700 699.95 .......... 800 ..... 799.95 900 899.95 1000 999.95 .... 1100 1099.95 1200 1199.95 1300 1299.95 ..... 1400 ......... 1399.95 1500 1499.95 1600 1599.94 '-' 1700 "'1699,94' 1800 1799.91 1900 1899.72 ................ 2000 .... 1999,36 2100 2098.70 2200 2197.52 -" 2300 ''2295.64 2400 2392.93 2500 2489.46 ..................... 2600 ......... 2584~'90 2700 2678.87 2800 2771.34 .................... 2900 ........... 2862;53 -55.60 0 44.39 0 '-1'44';'38 .......................... 0 244.37 0 344.37 0 444.36 0 544.36 0 644.35 0 0 N O. 0 54 S 14.36 ' '58 ............. S--10.57 39 S 14. 2 27 S 11.27 43 'N 62.25 13 N'71. 2 25 N 43.62 0 2 ..... 0 19 S 0 I N 0 23 -N 0 5 N 0 13 .... 0" 12 .......... N 0 20 N 0 13 N O' 14 ....... 2 40 S 4 ~ 744.'35' 844.35 944.35 1044;35 1144.35 1244.35 "'1344.35 1444.35 1544.34 1644.34 1744.31 1844.12 ....... 1'943~6 ...........5 ...... 33 ........ 2043.10 7 41 2141.92 9 48 .... 2240.04 ......... 12 ....... 22 ...... 2337.33 14 18 2433.86 16 2 ....... 2529;30 ......... 18 ...... 38 ...... 2623.27 21 20 2715.74 23 22 ...... 2806,93 .......... 25 .....4 .... -S S S S S S S 'DO0-LEO .............................................. TOTAL ....................................................... SEVERITY RECTANGULAR DEG/IO0 NORTH/SOUTH E E E W W W W W 12. 8 E' 41.80 W 59.38 E 36;92 W 33.37 W 51.30 W .... 9;78'-'W 47.77 E 48.30 E 45.52 W 20.27 E 46.16 E 58;'~6'E' " 42.42 E 36.96 E 34.88 E '' 37.92 E 46.25 E 45.21 E ........ 44.39 E 43.88 E 43.58 E COORD I NATES VERT T n~L EAST/WEST SEC .,,~)N O. O0 O. O0 O. O0 0. O0 0.90 0.76 S 0.19 E 0.77 ......... 0;-09 ....................... 2.35 S ..... 0';'55 "E ......................... 2.36 0.47 3.74 S 0.56 E 3.61 0.20 4.67 S 0.35 E 4.35 0.95 .... 4.76 S 0~28 W 4.16 o. so s .o2 w .s2 ,.oe s z. s. '~"~~ '-3. es s 1'.7o'w .............. 2.72- ,~- ,. ~ ~:~= 4.30 S 2.06 W 2.97 ~?.,.~ ........ 3.74 S 2.~ W 2.1~ 3.68'"'S ................... 2, 87 W ................ )5- ,~:t~ 3.30 S 2.69 W 1.'80 ~ ;~="~ 2.97 S 2.32 W 1.66 ...... ';=~""~' 2.99 S' '2;33 W ......... 1;67'* ~"i"?': 5 32 S I 67 W 4.06 ~;'.:t.;' ' ~.'~ m m 2=06 ~ 9.98 S 1.72 E 9.73 1;'77 ............... 15;00"S .................. 8;~1-E '1'7;'16 2.80 22.47 S 17.04 E 27.66 2.27 34.21 8 26.68 E 42.43 · '2~60 ............ 49.80'S ...... 37;92"E ................ 61';'3~* 2.05 68.33 S 51.64 E 84.02 2.78 87.63 S 69.21E 109.06 -2,62 .........108;44--'-S .......... 90;'54--'E 137;I0- 2.71 132.71S 114.61E 169.44 2.04 160.00 S 141.09 E 205.56 ''1:70- "189.65 S '*' 1~9."44'E ....... 244.61 SHELL WESTERN £ & P INCORPORATED SEA~'*A#3'"~'BF~57'1 .... (SECII'T13NR13E) SEAL EXPLORATION AREA ALASKA 'SPERRY~SUN-~WELL*'SURVEYINGCOMPANY ..................................................................PAGE' 2 ANCHORAGE ALASKA DATE OF SURVEY DECEMBER 26, 1'984 ..................... COMPUTA'TIONDATE .......................................... BOSS GYROSCOPIC""SURVE¥ ......................... dANUARY 28, 1985 dOB NUMBER AK-B0-40099 KELLY BUSHING ELEV. = 55.60 FT. .............................................................................................................. OPERATOR~*"'J; ...... SAMECYSCHLUMBERGER' VERTICAL SECTION CALCULATED ALONG AZIMUTH OF 154.10 DEGREES ......................................... TRUE ........... SUB-SEA MEASURED 'VERTICAL VERTICAL DEPTH' DEPTH DEPTH 3000 2952,24 2896,64 3100 3039,95 2984,35 ........................... 3200 ............. 31'25:29 .............. 3069,'69 3300 3208.34 3152.74 3400 3289.13 3233.53 ..... 3500 3368.17' 3312.57 3600 3445.91 3390.31 3700 3520.95 3465.35 " 'COURSE .................. COURSE" INCLINATION DIRECTION DEG MIN DEGREES DOG=LEG ............................. TOTAL' ..................................................................... DEG/IO0 NORTH/SOUTH EAST/WEST SEC . .. 27 19 S 43.60 E 2.25 221.61 S 199.87 E 286.66 30 4 S 42.96 E 2.77 256.57 S 232.78 E 332.48 ........... 32 ........ 45 ............... S--42;42--E .................... -2;69 ............... 2~4;88-"'S ......... 2~87"1"I--E .............. 382;'37'" 34 55 S 42.36 E 2.17 335.99 S 305.65 E 435.75 37 16 S 42.27 E 2.35 379.54 S 345.30 E 492.25 '" 38 16 S'41.94 E 1.02 .... 424,98'S 386.37 E 551.06 39 40 S 42.33 E 1.42 471.60 S 428.56 E 611.43 43 4 S 42.89 E 3.42 520.23 S 473.31E 674.72 ........................ 3800 3900 4000 '" 4100 4200 4300 4400' 4500 4600 ......... 4700 4800 4900 ............~000 5100 5200 5300 5400 5500 .... 5600' ~700 ~800 5900 "3593;'26 ............ 3537;66 ................ 44 3664.64 3609.04 44 3736.00 36~0.40 44 "'~$07.59 ........ $751,99 .... 44 3879.31 3823.71 44 3951.30 3895.70 43 4023.64" 3968;04 43 4096.18 4040.58 43 4168.91 4113.30 43 4241.90 "'4186.30 43 4315.11 4259.51 42 4388.35 4332.75 42 58 4461,49 ......... 4'405,89 ........ 43 ..... 1 4534.17 4478.57 43 45 4605.72 4550.12 44 52 4676.23 4620.62 45 27 4746.44 4690.84 45 21 4816.45 4760.85 45 46 ..... 4885:72 ......... 4830.12 ........... 46 .... 32 4954.63 4899.03 46 20 5024.27 4~68.66 45 23 5094.77 5039.17 44 56 -18 .......S 43, 11' E ...... 1;24 .......... 570; 36 S 43.13 ~ __~'~. 30 621. 21 S 43.13 ~ ,..~'- '25 672. 43. s 42.88 =:::';131~ ..... 723;774. 42.82 48 S ="~ 32 825. 31 ' ' S 42';88 ~=~28 ........ 876. 2e s 43. 2~ :" ' ~25 977. 13 S 42.97~ "1 ..... S 42, 89~:"'~ ::-:'?:~ 21 .... 1027; 51 S 42.88~.;~ ........ :~ 17 1077. S 42.75 'S 42; 41~ ~i~.~'.. 4 .... 41.52 E ~ 0.96 1228. 41.55 E 1.12 1280. 41.52 E 0.59 "1333. 41.52 E 0.11 1386. 41.52 E 0.42 1440. 41.52 E '0;77 '" 1494. 41.72 E 0.25 1548. 41.61E 0.95 1602. 41.69 E 0.45 1655. 73"S 520.43 E'*' 740.73 84 S 548.30 E 807.62 97 S 616.20 E 874.53 98 S 663.87' E ......... 94'1;24 99 S 711.34 E 1007.86 88 S 758.55 E 107a ~6 50'S 805;50 E 114~. JO 87 S 852.40 E 1206.10 07 S 899.22 E 1271.71 10 S 945;78 E ....... 1337.06" 01S 992.14 E 1402.20 95 S 1038.42 E 1467.34 16 S ..... 1084;'57 E ....... 1532,'66 23 S 1130.50 E 1598.66 51S 1176.82 E 1665.93 58 S 1223;85 E 1734.21" 89 S 1271.06 E 1802.79 34 S 1318.40 E 1871.55 33 S' 1366;'22"E ............... 1941.00 49 S 1414.36 E 2010.75 10 S 1462.07 E 2079.82 08 S 150~.21E 2148.06 .................................. SPERRY~SUN"WELL"SURVEYING"ICOMP~N¥- ..................................................................................... PAGE SHELL WESTERN E & P INCORPORATED SEAL A#3'BF-57~iI"($EO11T13NR13E) SEAL EXPLORATION AREA ALASKA VERTICAL SECTION CALCULATED ALONG AZIMUTH OF ANCHORAGE ALASKA DATE OF SURVEY DECEMBER 26, 1984 COMPUTATIONI'DATE ......................................... BOSS'GYROSCOPIC-SURVEY ............................. JANUARY 28, 1985 dOB NUMBER AK-BO-40099 KELLY BUSHING ELEV. = 55.60 FT. ................................................................. OPERATOR- J, SAMEC/$CHLUMBERGER 154.10 DEGREES .......................................................... TRUE ............................. SUB-SEA .................. COURSE ................ COURSE ................... DOG~-hEG ................ F .................. TOTAL MEASURED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTiCaL DEPTH DEPTH DEPTH DEO 'MIN DEGREES DEG/IO0 NORTH/SOUTH EAST/WEST SEC .iN 6000 5164.99 5109.39 45 51 S 41.55 6100 5234.24 5178.64 46 29 S 41.42 &300 5374.74 5319.14 44 50 S 40.97 6400 5445.88 5390.28 44 27 S 40. 5 ................ 6500 ....5517.45 .... ~ ..... 5461.85 ....... 44 .......... 8 ............ S'"',39.66 0.92 1708.30 S 1556.50 E 2216.59 0.65 1762.33 S 1604.29 E 2286.08 ....... 1'J42 ................ 181~;"12'*S .........1651';'-~4-'E ................. 2355';-15 .... 0.31 1869.34 S 1698.12 E 2423.32 0.76 1922.77 S 1743.77 E 2491.32 ........ 0J42 ........... 1'976,38 S "' 1788:53 E ............. 2559.10 &600 5589.09 6700 5660.94 ........................ 6800 ............. 5733~18 6900 5805.25 7000 5876.67 .................... 7100 ........... 5948.24 7200 6019.98 7300 6090.72 .................. 7400 .......... 6'160~57 7500 6229.70 7600 6298.69 ................ 7700 ........ 6~67;~1 7800 6436.43 7~00 6503.82 5533.49 44 20 S 39.25 E 0.35 2030.24 S 1832.88 E 2626.92 5605.34 43 48 S ~-~~=~ 0.57 2084.19 S 1876.77 E 2694.63 ....... 5677,58 ........... 43 ..... 41................. S~~ ........ 0~'28 ............2138,06 S .......... 1'920;'1'1-"E* -2762';02' 5749.65 44 5 S~~'~=,~ 0.61 2192.47 S 1963.07 E 2829.73 5821.07 44 45. S ~1_ _~ 0.68 2247.75 S 2006.00 E 2898.21 ...... 5892;64 ...... 43 ....... 51 .......... S ~Z~'~E~,,~ ........... 0';-~0 ............. 2303.01 "S ........ : ..... 2048;"72'"'E ............. 2966;57- 5964.38 44 27 S~~~ 0.61 2358.12 S 2091.32 E 3034.76 6035.12 45 30 S~.'7~6~ 1.04 2414.05 S 2134.54 E 3103.95 ......... 61'04;96 ............ 45---53 .......... S~~ ........ 0;.42 .......2470;78-S........ 21'Tev'16'-E ..... 317 )3 .... 6174.10 46 38 S~~."~&-Z~ 0.76 2528.06 S 2222.19 E 3244.80 6243.09 46 7 S,'_~~_~-~-~-] 0.53 2585.32 S 2266.49 E 3315.65 ......... 6312;'30 .......... 46 ..... 16 ....... ~~'- '0; 15 ............. 2642;34-S ............ 2310';"74-E ....... 3386;'27- 6380.83 47 12 9--~5,E~ 0.94 2699.85 S 2355.41E 3457.52 6448.22 48 3 S 37. gl E - O. 84 2758.16 S 2400.78 E 3529.78 36 ................. 49 .......... 8 ........... S"'37;94'-E ............ I;09 ......... 281'?;'31S ......... 244~;-89--"E ...... 3603;1~" 46 48 5 S 37.83 E 1.05 2876.52 S 2492.97 E 3676.53 60 45 59 S 37.86 E 2.10 2934.30 S 2537.86 E 3748.11 98 .......... 46 ...... 8'-' S 37.52-E .... 0;29'"---'--2991;'29'-S ....... 2581.88 E ....... 3818;6I' 17 46 18 S 37.36 E 0.19 3048.61S 2625.78 E 3889.35 94 E 0.58 3106.46 S 2669.63 E 3960.54 82 E ................ 2;00 ........ ~I65';69-S ........ 271'~;'08-'E ..... 4033;-.2~'- 57 E 0.72 3225.69 S 2758.79 E 4106.74 13 E 1.92 3285.23 S 2801.83 E 4179.10 '2 E -3.86'' '3344;00 S .......... 2840;-90""E ............... 4249;03' ...................... 8000 ........ 8100 6636.07 6580. 8200 6704.20 6648. ......... 8300 ........ 6773,59 ....... 671'7~ 8400 6842.77 6787. 8500 6911.55 6855.95 46 47 S 36. 8600 ...... ~978~-73 ....... 6~23;-1-2 ........... 48 ..... 47 ...... S 36; 8700 7045.07 6989.46 48 5 S 36. 8800 7112.89 7057.29 46 29 S 35. .................... 8900 ......... 71'83.71 ........ 71'28;li ...........43' 19"' S 32. ..................................................................................... ~ ............................... SPERRY~5;UN'WELL"SURVEYING'"COMPANY ...................................................... PAGe"4 ANCHORAGE ALAS;KA SHELL WESTERN £ & P INCORPORATED DATE OF SURVEY DECEMBER 26. 1984 ............ 5;EAC-'"~#3'"'"'BF~57='l ...... (5;£CI'~T'I"$NRI'3£} ......................................... COMPUTATION DATE .............................. BO$5;-'GYROSCOPI'C-5;URVEY .............................. SEAL EXPLORATION AREA dANUARY 28, 19985 dOB NUMBER AK-BO-4009999 ALASKA KELLY BUSHING ELEV. = 55.60 FT. ................................................................................................................................................................ OPERATOR~'d' ...... SAMEC/SCHLUMBERGER VERTICAL 5;ECTION CALCULATED ALONG AZIMUTH OF 154.10 DEGREES .................................................. TRUE ..................... 5;UB~SEA ...................... COURS;E ............ T'COURSE' MEASURED VERTICAL VERTICAL INCLINATION'DIRECTION DEPTH DEPTH DEPTH DEG MIN. DEGREES DOG'CEO ........................................... TOTAL ..................................... SEVERITY RECTANGULAR COORDINATES VERTiCaL DEO/IO0 NORTH/SOUTH EAST/WEST 5;EC ~N 9000 7256.41 7200.81 43 25 S 31.72 E 0.23 3402. 9100 7328.997 7273.37 43 32 S 31.699 E 0.12 3460. ....................... ~200 ........... 740I;36 ................ 7345;'75 .................. 43 ......... 43 ............ S 31.'72'E ................ 0¥18 .............. 3~19; 9300 7473.43 7417,83 44 3 S 31.66 E 0.33 3578. 9400 7545.20 74899.60 44 13 ........ 9500 7616.'61 ...... 7561';01 ..... 44 .... 38'' 9600 7687.66 7632.06 44 48 9700 7758.95 7703.34 44 16 ...................... 9800 .......... 7831;'37 ........... 7775;77 ........... 42 ........ 57 ..... 99900 79904.01 7848.41 43 52 31.80 E 0.199 31.77 E' ' '0,42 .... 32. 0 E 0.23 299.72 E 1.68 '23; 83"E ................ 4;-27 ..... 22.55 E 1.27 10000 · ...... 10100 10200 10300 ................ 1'0400 ...... 10500 10600 ................... 10700 79975.43 799199.83 44 57 S 2~~ ~ 1.20 8045.34 '7989, 74 ......... 46' 199 ..... S "2~~ ~' --1'; 42 8113.8'6 8058.25 47 11 $ 2{):;~4~ ~~ 10; 06 8181.58 8125.98 47 33S lp~: ' ~~"~ 52 ........ ....... .... ........... ....... o; .... 8318.11 8262.50 46 28 S 1~,7-~; ~='~.'~'~,:; O. 58 8387.1~ 8331 55 46 11 S 1:~:~ 'E:":'..':':~t O. 56 ..... 8456;'20 .......... 8400~ 5~ ...........4~ ...... 2~ .......... S 'I~?~"~E'~"';;.:;'~; .... O. 43 ...... 3637. 36997. 3757. 3817. '3878, 39941. 4006. 4073;' 4141. 4210. 42799, 4348. 4416. 4485, 31 S 55 S 53 S 76 S 01 S 20 5; 70 'S 87 S 17' 'S 25 S 32 S 46"S 25 S 899 S 76 2877.15 E 4317.32 29913.32 E 4385.78 ....... 299499;599 E ........... 4454.43 29986.01 E 4523.399 3022.64 E 45992.67 30599.51'E 4662.30 30996.68 E 4732.28 3132.66 E 4802.14 ...... 3163.'75"E ..... 4871.05' 31990.80 E 49399.699 3217.22 E 50099.52 ..... 3243;47 E '" 5080.80' 32699.38 E 5153.36 32~4.73 E 5226.57 ........ 33199734'E ....... 5299' '~" 3343.03 E 5371./4 3365.84 E 5443.45 ....... 3388ZOl"E ................. 5515.0~'- 10800 8525.34 84699.74 46 1 S 11~.11~.Ei~' 0.60 4554. 10~00 85995.34 85399.74 4~ 7 S 1~-~ .E.~i ..... ~ 1.01 4623. ................ 11000 ....... 86~;'15 ..........861'0;"55 ........... 44 ..... 43 S'"-Ii,,~.i~'i~> ...... 0;78 ....... 46990; 11100 8736.82 8681.22 45 20 S 14.~.E~.~.- 0.85 47599. 11200 8806.45 8750.85 46 23 5; 13.83 E 1.22 4828. "'~ '- - 11'300 ...... 8874,58 ' 8818.98 ......... 47' 43 S 12.'66'-E ........... 1.58 ........49900; 11400 89941.8~ 8886.25 47 43 S 10.997 E 1.25 49972. 11500 99008.92 8953.32 48 3 ................ 11600 ............ 9075;96 ..........9020;'36 ............ 47 ' 45" 11700 9143.17 99087.57 47 47 11800 99210.57 99154.997 47 27 ...... 119900 '"~278.80 .... 9223.20" 46 299 70 06 94' 24 79 04" 5; 10.57 E 0.45 S 10;60' E ............. 0¥30 ........... 5; 10.66 E 0.06 S 11.13 E 0.47 5;'10.699 E · · 1;02' "' 45 5045.32 51-18;25' 5191.03 5263.57 5335,35' S 34099.58 E 5586.53 S 3430.22 E 5657.04 S ........... 3449;'67""E ..... 5726;59 S 3468.11E 57996.099 S 3485.799 E 5866.38 · 5; ...... 3502;5~-'E .............. 59937;-7~' S 3517.72 E 6009.55 S 3531.599 E 6081.16 ~ .......... 3545;'22"E .......... 6'152;72' 5; 3558.88 E 6224.16 S 3572.8~ E 62995.51 5; 358~;69'"E .............. ~366.13 .............................................................................. SP~,E-Rf~-SUN WELL '*SURVEY I NG'""'COMPANY .................................................................................... PAGE ' ,.~.~,-~:~ ~.~**% ANCHORAGE ALASKA SHELL WESTERN E & P INCORPORATE~.:~;~,.',* ~.',~..,***~' DATE OF SURVEY DECEMBER 2~, 1~84 ~:~.~..~:.~;~ ~,' '* . ............... SEAL*'** A~3-*BF~57~1 ..... (SEC I'IT'I3NR 1~=.~ '**~*-* COMPUTATI'ON' 'DATE .................................. BOSS" GYROSCOP I'C--SURVEY SEAL EXPLORATION AREA ~*'~C~ ~'T~ ,JANUARY 28, 1985 dOB NUMBER AK-BO-40099 ALASKA "~"'~"~:~ ~ '" ~.-,,,~.~.,~.~ KELLV BUSHING ELEV. = 55.&0 ~T. ................ f ....................................................... ~.~.~ '.. t~ ,.~. '. '.....~ ........................ '~'-~ '"'.-' ' ............ ' .................................................... OPERATOR- ~." SAMEC/SCHLUMBERGER VERTICAL SECTION CALCULATED ALO~:.,"'AZI'~H OF 154.10 DEGREES ............................................................. TRUE .................... S~B-SEA' · ~~' '~8.H~E .............. COURSE* ............... DOG-L~G ........................................... TOTAL ....... MEASURED VERTICAL VERTICAL ~L~~ON DIRECTION SEVERITY' RECTANGULAR COORDINATES DEPTH DEPTH DEPTH ,~~N. DEGREES DEG/IO0 NORTH/SOUTH EAST/WEST ........................................... 9347.13 9291.53 47 18 S 9415.16 9359.56 46 58 S .............. 9483~"35 .................. 9427.75 .......... 47 .............. 3 ............ S 9552.42 9496.82 45 34 S 12000 12100 ................ 1'2200 12300 12400 9622. ............... 12500'" 9694. 12600 9767. 12700 9842. ............ 12800 .......... 9919, 12900 9996. 13000 10070. ...... 13100 -'10142. 13200 10212. 87 9567.27 44 51 S 53 ..... 9638.93 43" 35 ...... S 64 9712.04 42 26 S 55 9786.95 40 31 S 41 ......... 9863.80 39' 1 ......... S 15 9940.55 40 43 S 70 10015.10 42 55 S 70 .... 1'0087a10 44 ....... 50 ........ S 70 10157.10 46 20 S 9.13 E 7.66 E ....... '6~'30'-'E "' 4.92 E 2.67 E ''0. 2E' 2.35 W 2.86 W · 3~7~ W 4.96 W 5.39 W "4,38 W 4.47 W 13300 10281. ......... 13400 10348. 13500 10413. 13600 10479. --* 13700- 10544. 13800 1O610. 13900 10676. ............. 14000.- 10739; 14100 10801. 14191 10857. ........... 14200 10863. 14300 10924. 14400 10984. ................ ~4500 .......... li043; 14600 11101. 20 10225.60 10 ...... 10292.50 80 10358.20 10 10423.50 50 ......... 10488.90' 70 10555.10 10 10620.50 14700 11160.60 11105.00 '-14800 .... 11219,60 ...... 11164.00 ' 47 15 S 4.82 ........... 48 ..... 39 .... S-" 6~33 49 13 S 8.61 49 14 S 9.55 "49 6--' S" 9.41 47 57 S 10.69 50 22 S 12. 7 20 ...... 10683~'60 .......... 51 ..... 21'. ........ S 50 10745.90 51 38 S 60 10802.00 52 8 S 20 ...... 10807,60 ......... 51'' 56 ...... S' 20 10868.60 52 46 S 40 10928.80 53 15 S 20 ....... 10987~'60 ...... 54--46 .......... S 50 11045.90 53 46 S 53 50 S .... 53-' 48 S 12;91 13.88 14.89 15. 0 14.89 14.80 '"14;-t~ 13.10 12.60 W W W W W W W W W W W W W W W 1.40 5407.27 1.12 5479.77 "-1-~01 ............ 5552.37 1.78 5624.32 1.75 5695.11 2.24' 5764.81 1.99 5833.00 1.95 5899.16 *-1~60 .... 5963.01'- 1.87 6026.92 2.22 6093.31 '-2;05' "61'62;36 1.50 6233.58 0.95 6306.23 "'1;80 ........... 6380,12 1.82 6454.87 0.70 6529.65 ..... 0~'17 '-6604.28 1.49 6678.05 2.62 6752.21 t;18 ......... 6827.~3 0.81 6904.05 1.04 6973.4O ........ 2';-27 ....... 6980~2~ 0.82 7056.76 0.50 7133.97 .... 1;59 .......... 721'2z30 1.33 7291.19 0.41 7369.87 0.73 " 7448.78 S. S S S S S S S S 'S S S S S VERT?~L SEC 3599.26 E 6436.31 3609.97 E 8508.21 3618;86"E .... 6575.40 3625.95 E 6643.22 3630.66 E 6708.96 3632.33 E 6772.39 3630.96 E 6833.13 3627.95 E 6891.33 3624~27 E ........ 6947.16 3619.39 E 7002.52 3613.37 E 7059.61 3607.47 E" 7119,15' 3601.96 E 7180.80 35~6.05 E 7243.58 '3588;83'-E ........ 730( ~0 3579.01E 7389.~5 3567.06 E 7431.89 3554.59 E ..... 7493.58 3541.51E 7554.23 3526.56 E 7614.41 $ ...... 3509~77'E ............... 7675;19' S 3491.64 E 7735.75 S 3473.84 E 7790.36 S 3472~'01-"E ........ 77~5~"73 S 3451.58 E 7855.62 S 3431.11E 7916.14 "S ....... 341'OzS~-'E ...... 7977'.-75- S 3391.70 E 8040.34 S 3373.75 E 8103.2~ S .... 3356~'76 E ........... 8166;85 SHELL WESTERN E & P INCORPORATED SEAL A#3 BF-57-1 ¢SECllT13NR13E) SEAL EXPLORATION AREA ALASKA SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION DATE'- dANUARY 28, 1985 VERTICAL SECTION CALCULATED ALONG AZIMUTH OF 154.10 DEGREES PAGE DATE OF SURVEY DECEMBER 26, 1984 ........ BOSS-GYROSCOPIC-SURVEY ................. dOB NUMBER AK-BO-40099 KELLY BUSHING ELEV. = 55.60 FT. 'OPERATOR- d.'SAMEC/SCHLUMBERGER ................. TRUE MEASURED VERTICAL DEPTH DEPTH SUB-SEA .......... COURSE '"COURSE DOG-LEG ..... TOTAL' " VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES DEPTH DEG MIN DEGREES DEG/IO0 NORTH/SOUTH EAST/WEST · . 14900 11277.90 11222.30 54 55 S 11.69 W 15000 11334.40 11278.80 56 15 S 11.30 W ................... 15'100 · 11389~70 ..... 1'1334¥'1'0 ................... 56 ....... 30 .............. S"'11';'~O"W' ' 15200 11445.20 11389.60 56 6 S 13.19 W 15300 11501.20 11445.60 55 4~ S 13.30 W 15350 1'1529.20. 11473.60 56 5 S 12.89 W VERTT~AL SE~ 1.11 7528.36 S 3340.28 E 8231.24 1.38 7609.20 S 3323.83 E 8296.77 '0;35 ............ 7690';82"S ........... 3307;'30'E ......... 8362.'98 1.39 7772.08 S 3289.44 E 8428.27 0.35 7852.72 S 3270.45 E 8492.52 0.92 ..... 7893.0& S' 3261,06 E 8524.70 HORIZONTAL DISPLACEMENT = 8540.20 FEET AT SOUTH 22 DEG. 26 MIN. EAST AT MD = 15350 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD. SHELL WESTERN E & P INCORPORATED SEAL"A#3 BF-57-1 ¢SECllT13NR13E) SEAL EXPLORATION AREA ALASKA ............ SPERRYaSUN WELL SURVEYING 'COMPANY ANCHORAGE ALASKA "COMPUTATION DATE dANUARY 28, 1985 ...................... PAGE 7 DATE OF SURVEY DECEMBER 2&, 1984 dOB NUMBER AK-BO-40099 KELLY BUSHING ELEV. = 55.60 FT. 'OPERATOR~ d; SAMEC/SCHLUMBERGER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH ...... DEPTH .................... DEPTH ........ NORTH/SOUTH ........... EAS'T/WEST 'DIFFERENCE ........... CORRECTION ....................... 0 0.00 -55. .... : .................. 1000 .........999;95 ............ 944; 2000 1999,36 1943, 3000 2952,24 2896, ...................... 4000 ....... 3736,00 ....... 3680, 5000 4461.49 4405. 6000 5164.99 5109. ..................... 7000 ............ 5876;67 .............. 5821; 8000 6569.96 6514, 9000 7256;41 7200· ................. 10000 ............ :'7975,43 ............ 791'9~ 11000 8666,15 8610. 12000 9347.13 9291, ...................... t'3000 ........... 10070;70 ....... 1'001'5; 14000 10739.20 10683, 60 0.00 0.00 35 ......................... 4;~0'-'S ................. 2;06 76 15.00 S 8.41 64 221.61S 199.87 40 ............. 672;97"-S ...... 616.20 89 1177·16 S 1084.57 39 1708,30 S .. 1556,50 07 ........... 2247';75"'S ................. 2006,00 36 2817.31S 2446.89 81 3402.31S 2877.15 83 .................. 4006';"67-"S ...... 3217;22' 55 4690.94 S 3449.67 53 5407,27 S 3599,26 10 ....................... 6093;'3'['-~ ............. 36'I'3;'37' 60 6827.93 S 3509.77 06 15000 11334,40 11278,80 .7609.20 S 3923. ............................... 15350 ............ ~-1"529';'20 ......... 1'1"473'c60 .......... ~ ..... 7893;'0&"'S ............... 326'1'; W E 0,64 0.59 E 47,76 47.12 E ............... 264;00 .... 216.24' E 538.51 274·51 E 835.01 296.50 E ....... 1123,33 ................288.'32 ....... E 1430,04 306.71 O. O0 ....................... 0 ;"05 ........................... 0; 05 ....................................... E 1743, 59 313.55 E ............... 2024; 57 .......... 280','98 .............................................................. E 2333.85 309 · 29 E 2652 · 87 319 · 02 "E .............. 2929;-34 ........................ 276;-47 .............................. .- ........ ( '" E 3260.78 331,44 E 3665, 62 404 · 84 'E ............ 3820;'78 ........................... 155';"16 ..................................................... THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD· ;. . ', ..: ~,~!' : :~, ,, t ', . ,.~,..,' ... ................................................ i .......... ? , .'. _.,.: ......................................................................................................................................................... SPERRY~SUN WELL'SURVEYING-CGMPANY ................. ANCHORAGE ALASKA SHELL WESTERN E & P INCORPORATED SEAC--A#3"BF=57=l--(SEClIT1'3NR13£) .................. COMPUTATION'DATE- SEAL EXPLORATION AREA dANUARY 28, 1985 ALASKA .. · . . ........... PAGE 8 DATE OF SURVEY DECEMBER 26, 1~84 dOB NUMBER AK-BO-40099 KELLY BUSHING ELEV. = 55.60 FT. ................. OPERATOR- d; .... SAMEC/SCHLUMBERGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL ( DEPTH ........... DEPTH ............... DEPTH....... NORTH/SOUTH....... EAST/WEST ........DIFFERENCE .......... CORRECTION ............................................. 0 0.00 -55. ............................ 55 ................... 55c60 ....... : ........ 0;' 155 155.60 100.00 255 255.60 200.00 · ........... 355 355.60 ......... 300'.'00' 455 455.60 400.00 555 555.60 500.00 ........................ 655 ............. 655;-60 ..... 7 ........... 600;00 ........ 60 0.00 O0 .......................... 0:12--S ............... 1,62 S 0.00 0.00 O,03"'E .................... 0';-00 ............. 0.41 3.24 S 0.67 ......... 4.'32' 'S ......... O. 42 4.47 S 0.84 .................. 4;31 ..... S .............................. 1';--24 E 0.01 E O. 03 'E ....................... 0;'03 ....... E O. 04 W O. 04 -'W ................................ 0;05 755 755.60 700.00 3.83 S 1.70 W O. 05 1055 1055.60 1000.00 4.25 S 1155 1155.60 1100.00 3.75 S .................... I255 ............ 1'255;60 ................ 1'200';'00 ...... : ................... 3;~4--~S .......... 1355 1355.60 1300.00 3.83 S 1455 1455.60 1400.00 3.48 S ......................... 1555 ............ 1'555.60 .......... 1500','00 ................................ 3:'09'.S "' 1655 1655.60 1600.00 2.87 S 1755 1755.60 1700.00 3.80 S 855 855.60 800.00 3.92 S 1.72 W ......... 955 ........... 955,'60 ............... 900."00 ............................. 4.'30""'S ...........2.07 W ........ .... 0;00 ............................................................ 0.01 0.01 0.01 ....... O. O0 0.01 0;'00 ...................................................... O. O0 O. O0 0'; O0 ............................................... O. O0 O. 05 ............ 0.05 2.08 W 0.05 2.46 W 0.05 0.00 /' '2;'57'-'W ......................... 0;05 .............................. 0';"00 ............................................ ( .. - 2.84 W 0.05 0.00 2.87 W 0.05 0.00 '2.'45 ' 14 ....................... O. 05 .............................. 0 ;"00 ..................................................... 2.21 W 0.06 0.00 2.19 W 0.06 0.01 SHELL WESTERN E & P INCORPORATED SEAL'A#3 BF-57-1 (SECllT13NR13E) SEAL EXPLORATION AREA ALASKA .. SPERRY-SUN WELL SURVEYING COMPANY ............................... PAGE'9 ANCHORAGE ALASKA DATE OF SURVEY DECEMBER 2&, 1984 COMPUTATION DATE ........................................................ dANUARY 28, 1985 dOB NUMBER AK-BO-40099 KELLY BUSHING ELEV. = 55.60 FT. OPERATOR~ d. SAMEC/SCHLUMBEROER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH 'DEPTH ................ DEPTH " NORTH/SOUTH .... EAST/WEST ..... DIFFERENCE'~ CORRECTION 1855 .................. 1956 2056 2157 .......... 2259 2361 2464 ........................... 2569" 2675 2782 .... . .............. 2892' 3003 3118 ....................... 3234 ............... 3357 3483 ............................. 3612" 3747 1855.60 1800.00 7.81S 0.49 1955~'&0 .......... 1900,'00 .......................... 12;-77--S ................ 4;85 2055.60 2000.00 18,65 S 13,20 2155.60 2100.00 28.47 S 22.34 2255.60 ..... 2200.00 ...... 42;-95 $' 33.08 2355.60 2300.00 60.82 S 45.79 2455.60 2400.00 80.88 S 62.50 2555;60 ............ -2500;00 .................... 10'1';68"-S .................... 83i'68 2655.60 2600.00 126.35 S 108.36 2755.60 2700.00 155.10 S 136.38 "2855.60 ............. 2800.00 .............. 187,30 $ ......... 167.21 2955.60 2900.00 222.88 S 201.08 3055.60 3000. 3155~0 ............. 3'100~ 3255.60 3200. 3355.60. 3300. · 3455.60 ..................... 3400; 3555.60 3500. O0 263.28 S 239.01 O0 .................. 309;"27--'S ................. 28'1;'26 O0 360.70 S 328.18 O0 417.60 S 379.74 O0 ..................... 477,'.61'S .................... 434;05 O0 544.03 S 495.45 W 0.17 0.10 E ........................ 0;'44" 0i'27 ................................. E 0.96 0.53 E 1.87 0.91 E 3,48 1~62 .................. E 5.87 2.39 E 9.23 3.36 E ..................... 1'3~55 ............... 4~"32 ................................................... E 19.48 5,93 E 27.25 7.77 'E .............. 36';"75 ................................. 9.50 .............................................................. E 48.19 11.44 E 62.53 14.34 · E ................. 80;-44 .......................... 17";'~ ....................... ~ E 102.30 21.86 ~ E 128.39 26.09 E ......... 157;05 ............................ 28;'6'6 ............................................................. E 191.91 34.86 3887 3655.60 3600. O0 615.33 S 562.20 E 231 . 70 3~. 79 ........................................................................... ................................ SPERRY~SUN'WELL SURVEYING COMPANY ........................................... PAGE 10 ANCHORAGE ALASKA SHELL WESTERN E & P INCORPORATED DATE OF SURVEY DECEMBER 2~, 1984 SEAL"'A#3~BF~57=l~(SEC11T13NR13E~ .......................... COMPUTATION'DATE ............................................................... SEAL EXPLORATION AREA dANUARY 28, 1985 dOB NUMBER AK-BO-40099 ALASKA KELLY BUSHING ELEV. = 55.60 FT. OPERATOR='J. SAMEC/SCHLUMBERGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH . . TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL 'DEPTH .............. DEPTH ...... DEPTH ........ NORTH/SOUTH ~-EAST/WEST-' DIFFERENCE ...... CORRECTION 4027 3755.60 3700.00 686.95 S 629.29 E 271.81 40.11 41~-6 ............ 3855;'~0 ............ 3800;00 ...................... 758~'1-4'"'S ............ 695';'~9-E ................. 31I'";36 ............................. 4305 3955.60 3900.00 828.91S 761.35 E 350.36 39.00 4444 4055.60 4000.00 898.73 S 826.15 E 388.47 38.11 ....... 4581' "4155.60 '4100.00 ..... 967;92 S 890.69 E .... 426,14" 37.67' 4718 4255.60 4200.00 1036.47 S 954.49 E 463.14 37.00 4855 4355.60 4300.00 1104.56 S 1017.71E 499.64 36.50 ................................ 499I ............... 4455';'60 ............. 4400,'00 .................. 1173.10"S" '1'080;-86 E'' '536;34' 36.70 ......... 5129 4555.60 4500.00 1243.59 S 1144.10 E 574.07 37.73 5270 4655.60 4600.00 1317.89 S 1209.95 E 614.99 40.92 ............... 541'3 ........ 4755;60 ............. 4700.00 .................. 1'3<~:3';83"'S ........... 1277.21'E ........................ 657.44 ............... 42,45 .......................................... 5556 4855.60 4800.00 1470.56 S 1345.17 E 700.64 43.20 5701 4955.60 4900.00 1549.25 S 1415.03 E 745.80 45.16 ............ 5844 "5055.60 ........ 5000;00 ......... 1625,82 S ......... 1483.'16"'E ......... 789.00 ........ 43~20 ................................... 5986 5155.60 5100.00 1701.06 S' 1550.08 E 830.~I 41.91 6131 5255.60 5200.00 1779.20 S 1619.18 E 875.42 44.51 .......................... 6273 ......... 5355,60 .... : ..... 5300,'00 .......................... 1854;'.97'S 1685,'63'"E .......................... 917;40 .......................... 41.98 .................................................. 6413 5455.60 5400.00 1930.07 S 1749.91E 958.02 40.61 6553 5555.60 5500.00 2004.92 S 1812.16 E 997.58 39.56 SHELL WESTERN E & P INCORPORATED SEAL A#3 BF-57-1 (SECllT13NR13E) · SEAL EXPLORATION AREA ALASKA SPERRY=SUN'WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION'DATE dANUARY 28, 1985 DATE OF SURVEY DECEMBER 26, 1984 dOB NUMBER AK-BO-40099 KELLY BUSHING ELEV. = 55.60 FT. OPERATOR- d. SAMEC/SCHLUMBERGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE MEASURED VERTICAL DEPTH ......... DEPTH" SUB-SEA TOTAL. VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL ...... DEPTH ..... NORTH/SOUTH .... EAST?WEST'-'DIFFERENCE ......... CORRECTION 6692 5655.60 5600.00 2080.21S 1873. .......................... 6831 ........... 5755';'60 ....... 5700;00 .............21'54~79-'--S ................ I933'; 6970 5855.60 5800.00 2231.23 S 1993. 7110 5955.60 5900.00 2308.60 S 2053. ................ 7249 ..... 6055~60 '6000,'00 .................. 2385;87 S 2112, 7392 &155.60 6100.00 2466.72 S 2175. 7537 6255.60 6200.00 2549.78 S 2238. ..... 7~82 ............. ~355;'60 .............. 6300;'00 ................. 2632~I8""S .............. 2302; 7828 6455.60 6400.00 2716.20 S 2368. 7978 6555.60 6500.00 2804.22 S 2436. .................. : ............ 81'29 .............. 66~5~60 ............... ~00;-00 .................. 2893~'71"-S ............. 2506. 8274 6755.60 6700.00 2976.44 S 2570. 55 E 1037.00 39.42 48"'E ....... 1075;40 ..................38,'40 ............................................. 23 E 1114.73 39.32 04 E 1154.61 39.88 78 E 1'194~"39 ....... 39;78 ....................... 05 E 1237.27 42.87 95 E 1282.12 44.86 85-'E .............. 1'32~;'60 .............. 44;47 ............................................... 12 E 1372.62 46.02 68 E 1422.45 49.84 31'E 49 E .................. 1"473';'~4 .................... 51";19 .............................................................. 1518.44 44.80 8418 6855.60 6800.00 3059.28 S ...................... 8~64 ........... 6955';~0 ................... ~00;-00 ..... . ...... 3'I'~4;'56-~ ........ 8715 7055.60 .. 7000.00 3235.12 $ 8860 71.55.60 7100.00 3321.19.S ........ 8998 .................. 7255;60 ................ 7200;00 .................. 34'0'~;~'~'-"S ............. ~136 7355.60 7300.00 3482.38 S 9275 7455.60 7400.00 3563.86 S 2633.93 E 1562.97 44.53 '2698';-25'-'-'E ............... ~6'09';-30 ....................... 46.-33 ................................ ( ..... 2765.78 E '1660.17 50.87 2826.28 E 1705.36 45.19 2876~75'"'"'~ .............. 1'743;29 .............................. 37;'93 ......................................................... 2926.62 E 1781.13 37.85 2976.96 E 1819,59 38.46 SHELL WESTERN E & P INCORPORATED SEALA#3--'BF=ST='l-TSECI'IT1-3NR13E) .... COMPUTATION-~TE SEAL EXPLORATION AREA dANUARY 28, 1985 ALASKA SPERRY=SUN'WELL"SURVEYING-COMPANY ........................................ P~GE 12 ANCHORAGE ALASKA DATE OF SURVEY DECEMBER 2~, 1984 dOB NUMBER AK-BO-40099 KELLY BUSHING ELEV. = 55.60 FT. OPERATOR='~'-SAMECZSCHLUMBERGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH MEASURED .......... DEPTH ................. TRUE SUB-SEA TOTAL VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL 'DEPTH ................ DEPTH .............. NORTH/SOUTH ........... EAST/WEST ...... DIFFERENCE .......... CORRECTION 9414 ................. ~554 9695 9833 ............. 9971 10114 10261 ......................... 10408 10554 10699 ....................... 10843 10985 11126 7555.&0 7500.00 .............. 7~55;60 ......... -7600;-00' 7755.60 7700.00 3814.36 S 3131. 7855.&0 7800.00 3899.34 S 3172.86 ...... 7955,60 .......7900.00 .......... 3988,29 S" '3209','86" 8055.60 8000.00 4083.18 S 3247.36 8155.60 8100.00 4183.61S 3285.06 ..... i ...... 8255';'60 ............. 8200~00 ......................... 4285~'6'1-'S '3321'~'4~" 8355.60 8300.00' 4385.61S 3355.62 845~.&0 8400.00 4485.16 S 3387.82 .... 8555;"~0 ........ 8500.00 ...................... 4584.64'""S" 341'8~'79' 8655.60 8&O0. O0 4680.88 S 3446.88 8755.60 8700.00 4777.62 S 3472.94 3646.36 S 3027.97 E 1858.91 3~.32 3730';-0'I"-S ............. 3079;8:2'-"E .......... -1-899;22 .......................... ~0';'30 ................................................. 04 E 193~.73 40.51 E 1977.51 37.78 · 'E ............ 201'6;37 ............... 38.86 ........................... E 2059.2~ 42.88 E 2105.91 46.66 "E ................ 2153.33 ....................... 47,42 .................................................. E 2198.80 45.48 E 2243.54 44.73 'E .... 2287;95 ........................... 44';'41 ............................................... E 2329.55 41.61 E 2371.12 41.56 ................... 11'271 ........... 8855;~0 ........... 8800;'00 ................... ~879,68'--'S ............. 3497;'98""E 11420 8955.60 8900.00 4987.29 S 3520.60 E 11569 9055.&0 9000.00 : 5096.23 S 3541.09 E .................. 1'1'71'8 ........... 9155;'~0 ............... 9100,00 ............ z"5204;'~9'**"S .............. 3561";*'42'E' t186& 9255.60 9200.00 5311.34 S 3582.16 E 12012 9355.&0 9300.00 5416.33 S 3600.71E .............. 24'I'&';"1'~ '45';'07 ............................................ ". (' .... 2464.83 48,&4 2514.12 49.29 ........... 2562';'~0 ................................. 48;'78 ............................................................ 2610.70 47.80 2656.89 46.18 .( SHELL WESTERN E & P INCORPORATED SEAL A#3 BF-57-1-(SEC11T13NR13E) SEAL EXPLORATION AREA ALASKA .. . · SPERRY-SUN WELL SURVEYING COMPANY'** ANCHORAGE ALASKA -"COMPUTATION'DATE dANUARY 28, 1985 PAGE' 13 DATE OF SURVEY DECEMBER 26,'1984 dOB NUMBER AK-BO-40099 KELLY BUSHING ELEV. = 55.60 FT. OPERATOR-'d;'*SAMEC/SCHLUMBERGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE MEASURED VERTICAL 'DEPTH ............... DEPTH ...... SUB-SEA TOTAL· VERTICAL RECTANGULAR COORDINATES MD-TVD "' DEPTH NORTH/SOUTH ....... EAST/WEST .... DIFFERENCE VERTICAL CORRECTION 12159 9455.60 9400. 12446 9655.60 9600. 12583 9755.60 9700. 12846 9955.60 9900. 12979 10055.60 10000. ..................... 13118 .............. ~0'155;60 .......... 1'0'100; 13262 10255.60 10200. 13411 10355.60 10300. 13563 .... 1'0455:'60 ............ 1'0400'~ 13716 10555.60 10500. 00 5522.75 S 3615.58 00 ............... 5627~55-'$ ........... 36'26~22 O0 5727.55 $ 3632.08 O0 5822.00 S 3631.42 00 ............ 5910:'30'*S ............ 3627~'40 O0 5992.40 S 3622.30 O0 6079.38 S 3614..68 00 ..................... ~175~'1'3'''S .............. 3606~49" 00 6278.67 S 3598.38 O0 6388.57 8.. 3587.89 O0 ..................... 6502~"75'"-S ............... O0 6616.93 S $552.49 E 2703 '"E .............. 2748 E 2790 E 2828 E ..... 2861 E 2891 E 2923 E 3006 E 3055 E ................... 3108 E 3161 .68 46.79 ;~5 ......................... 45-;"27 ............................................. .50 41.56 .08 37.57 .07 29.50 ,84 32.77 .74 44.19 .72 48.98 ;39 .......................... 52;"67 ............................................................ .37 52.98 13868 10655.60 10600.00 6728.35 S 3531.56 E 3212.55 51.18 .................... 1'4026 ............ 1'0755;'60 ........... 10700;'00 .................. -6847-~89""8--' .......... 3505;'19"-E .................. 3270';'63 14187 10855.60 10800.00 "6970.86 8 3474.52 E 3332.07 61.44 -' 14351 10955.60 10900.00 7096.73. S 3440.96 E 3396.30 64.23 ' ..................... 14521............ 1'--I'0551~'60 .......... 1'1'000'~00 .............. '-7229;'39""'S ........... 3408;54""E............... 3465;97 ................................... 69;"'G'~ .............................................. 14691 11155.&0 11100.00 7363.21,S 3375.24 E 3535.95 6~.98 14861 11255.60 11200.00 7497.31S 3346.71E 3605.65 69.70 ............. SPERRY~SUN WELL SURVEYING COMPANY ..................... PAGE'I~ ANCHORAGE ALASKA SHELL WESTERN E & P INCORPORATED DATE OF SURVEY DECEMBER 2~, 1984 .......... SEAL--A#3'BF~57~"I-'(SECIIT13NR13E) ....................... COMPUTATION DATE .............................................................................................. SEAL EXPLORATION AREA dANUARY 28, 1985 dOB NUMBER AK-BO-40099 ALASKA KELLY BUSHING ELEV. = 55.60 FT. ............................................................................................... OPERATOR~'j~ .... SAMEC/SCHLUMBERGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL ........ DEPTH ............ DEPTH ..... DEPTH "' NORTH/SOUTH ....... EAST/WEST' DIFFERENCE ....... CORRECTION 15038 11355.60 11300.00 15218 ....... 11455';'60 ......... ~'1400';00 ..... 15350 11529.20 11473.60 7640.36 S 3317.61E 3682.61 76.96 -'-7787;'I'5"'"'S ............. 3285';"91'E ............. --3763;'04 ............................... 80;43 ................................................... 78~3,06 S 3261,06 E 3820.78 57.74 THE CALCULATION PROCEDURES USE A LINEAR' INTERPOLATION'BETWEEN ................. THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS .0.00 3000.00 · 6000. O0 .. '., 9000.00 5CRLE :- 1 INCH 'TO 3000'.00 7 3000.0 5E~L EXPLOraTION R~EA '$N~LL'WESTE~N ~ & ? INCO~ SERL R=3 BF-5~-I ~$ECllT13 ,, OECEI'tB'ER 26. 1984 9K-80-40099 .... i2000.00~ VERTICAL SECTIOI~ IS es24. ?0 I%L'OaG AZ. 4. 49 ~obo' oo eob.o, oo 15350 ~ob°.oo V'E"'R-T ! CRL · ,..., .. P FIO.JE C T T_ ON TRUE NORTH SCALE :- 1 'TNCH' TO 2000.00 / 2000.0 SEAL E×PLOI=IAi'!OI~i AREA SHELL WESTERN E & SEAL A~,3 8F-57-1 {SECIIT13 DECEHBER 26. i984 .q~-eo-40099 ~.00 ! --8000.00 950 H OR 'f Z ON T i::::1 L, PROJ,ECT ! ON OIL ,4NIl 8AS ~ONSEIIVATION.~,OMMI,ISION Bill Sheffield, Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA gg$ol.l-31O:a TELEPHONE (90./) 2'/0,-1433 We wish to bring to your attention that the Commission has no~'" yet received the following required items on the subject well which our records indicated was compl.eted _ ,-.~,--/_/~-- ~'- 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. C. V. Chatter Chairman '1c:C.024 V~ ' ~F' ,: . , :, .-~,.. , - ~,' ....... ~i ~' ,.~ "" ": .... ~' '."~. ~ :;,! i~ f:! ",. '~. ~' ,',., .! t~ i~.'. [.'. '., ,' · ' i ~ f,4 ,.' ~: ~:.. ~,; ~ ,, .,. , ;, ., : ; ·: ,,. ,~..,.. ,. ~'~ ~, ,[4 .:,, : ,. ,' .',..: ,' .... ' :~ , '%,,:.,:~' '{ ..... i;..' :':.. :' .'.. . ...... ! ,. · ..,.:, , ..... .. , ', ..: ' ., .'.',,,,,. ;i: "'" !:i ?.'.:.. ': ""'" :" "': '" ::. ~'. ;:7 "ii' .'. ...: : .... .:. ",i:" ~" ':'" :;.:'"":' ';.": ..... ;.: ..., !':.... ;....,, EP-1048 (REV. 2-84) SHELL WESTERN E&P INC. PACIFIC DIVISION TO: Alaska Oil and Gas Commission ATTN Mr. Bill Van Allen 3001 Porcupine Dr. Anchorage, AK 99501 P. O. BOX 527 I~OU~]-ON. 3'EXAS 77001 . m. z~gan 1376 WCK Date Transmittal No. PD- Subject: DTNA 4/8/85 6454 We transmit by the following: .QUANTITY_ DESCRIPTION OF ITEM REG. NO. I Composite Tape with Listing Tape #70079, Runs 2-5, 1,572-15,546' DISPOSITION Above items received, except as noted: //'' - ~.~,77~'/.'~-~ I.. ~'~/~'~.e Date, Gas Cons, Commission Anchorage WHITE (ORIGINAL) YELLOW (1ST COPY) PINK (2ND COPY~ --ADDRESSEE (RETAIN) mADDRESSEE (SIGN AND RETURN TO SENDER) mSENDER'S "HOLD" FII F' EP-1048 (REV. 2-84) TO: Alaska Oil & Gas Commission ATTN Mr. Bill Van Allen 3001 Porcupine Dr. Anchorage, AK 99501 SHELL WESTERN E&P INC. PACIFIC DIVISION P. O. BOX 527 HOUSTON, TEXAS 77001 DTNA Date 4/2/85 Transmittal No. PD- 6432 Subject: (C°mpos ite Logs )" U. S. Mail We transmit by the following: QUANTITY DESCRIPTION OF ITEM REG. NO. See .attached list DISPOSITION Sender' ure AND RETURN COPY OF THIS MEMORANDUM Above items received, except as noted: Date WHITE {ORIGINAL) YELLOW {/ST COPY) --ADDRESSEE (RETAIN) --ADDRESSEE {SIGN AND RETURN TO SENDER) Transmittal #6432 to Alaska Oil & Gas Conservation ATTN Mr. Bill Van Allen SUBJECT: BF-57 No. I well (Composite Logs) Commi ss i on I Sepia and I BLP of the following' LOG TITLE RUN NO. DEPTH SCALE ) A-16) .¥17) ) 22) ) 30) 32) 3) Dual Induction-SFL Dual Induction-SFL (TVD) Dual Induction-SFL Dual Induction-SFL w/Linear Corr. Dual Induction-SFL w/Linear Corr. Dual Laterolog/MSFL BHC Sonic BHC Sonic BHC Sonic (TVD) BHC Sonic Waveforms (TVD) Comp. Neutron Fm. Density (Porosity) Comp. Neutron Fm. Density (Porosity) Comp. Fm. Density Log (Raw Data) Comp. Fm. Density Log (Raw Data) LDT/CNL Poro. (TVD) Litho'~Dehsity/Comp. Neutron (TVD Raw) Micro-Log Micro-Log Micro-Log Aux. Measurements Natural Gamma Ray Spectroscopy Natural Gamma Ray Spe. ctroscopy Log GST Inelastic GST Capture Cyberl ook Cyberlook Cyberdip CNTG-Epi thermal Porosity Dual Dipmeter Dual Dipmeter Borehole Geometry Log w/GR GCT Gyro Well Survey Temperature Log Cement Bond Log 2,3,5 1,596-15,454' 2,3 1,596-11,685' 2,3,5 1,596-15,454' 2,3 1,596-11,685' 2,3 1,596-11,685' 4 14,298-14,880' 2,3,5 1,596-15,010' 2,3,4,5 1,596-15,010' 2,3 1,596-11,649' 5 14,516-15,010' 2,5 1,596-15,457' 2,4,5 1,596-15,457 ' 2,5 1,596-15,457' 2,4,5 1,596-15,457' 2 1,596-4,994' 2 1,596-4,994' 2 1,596-4,949' 2,4,5 1,596-15,091' 5 14,298-15,091' 5 14,298-15,107' 2,4,5 1,596-15,107' 1 11,650-12,050' 1 11,650-12,050' 2 1,600-4,950' 5 14,304-15,440' 5 14,298-15,243' 14,280-14,870' 4 14,298-14,889' 5 14,298-15,243' i 146-1,606' I 0-1,590' I 0-14,206' 3 8,350-15,380' 11 2" 5" 2" 2" 2" 2" 5" 2" 5" 2" 5" 2" 5" 2" 2" 2" 5" 2" 5" 5" 5" 5" 5" 5" 5" 5" 5" 5" 5" 5" 5" 2II RECEIVED APR ]985 Alaska Oil & Gas Cons. Commission Anchorage March 19, 1985 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, Alaska 99501 Gentlemen' Attached are duplicate copies of the Completion Report for Seal Island Well No. BF-57 No. 1, Well Hi story and Depths of Interest. A1 so, attached are duplicate copies of the Sundry Notice of Temporary Abandonment of the above wel 1. Yours very truly, R. G. Hollis Manager Production Administration Pacific Frontier Division RGH'ff Attachments RECEIVED N~ ~ 7 1985 Alaska 0il & Gas Cons. Commission ..... Anchorage °* '; .¥ STATE OF ALASKA ALASK" )IL AND GAS CONSERVATION £, MISS'ION fELL COMPLEYII N OR RECOMPLETIOi f,!. .PORT AND LOCI OIL.~ GAS [] SUSPENDED J~[ ABANDONED [] SERVICE [] Classification of Service Well 2. Name of Operator Shell Weste_~n E&P !nc. 3. Address 601 West 5th Ave., #810, Anchorage, AK 99501 4. Location of well at surface 1541.5' ESL, 629' FEE Sec 11 'rZ3N R13E ~s-T At TOp Producing Interval qx~/~ ' · s s ~--t. VFRI~IED J 10. Well Number 2788' FWL Sec 24 T13N RZ3E No 1 ~' 491Z' FSL, , . , , Is,,~.'?_f_<~ · 4124' FSL, 13' FWL,, Sec. 24, T13N, R13E ! .H:.____~. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease D~ignation and Serial No. WILDCAT 55' KB I ADL 312809 12. Date Spudded 113. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 7/9/84 I 11/12/84 2/10/85 I feet MSL 17. Total Depth (M D+TVD) 118. Plug Back Depth (MD+'rVD) 19. Directional Survey I 20. Depth where SSSV set 15455/11605 I 110/110 YES~ NOD I _ feet MD 22, Type Electric or Other Logs Run SP/GR/DISFL/BHCS/NGT/LDT/CNL/ML/DIL/BHC/SGT/DCl,/CET/CCL/CNT 23, CASING, LINER AND CEMENTING RECORD 20mm 13-3/8" SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP I BOTTOM ]33# K-55 0 I 1602 72# N-80 0 I 5000 I 9-5/8" ' 53.5# N-80&L-8( O I 14280 7" 32# L-80 LTC .- 8427 I I~4BB 24. Perforations open to Production (MD+TVD of Top. and/Bottom and interval, size and number) 15250-15300' MD /(-~ = ~ 11435-11467' TVD 200 Hol es 7. Permit Number 84-93 8. APl Number 50- 029-21130 9. Unit or Lease Name BF-57 11. Field and Pool 4 JSP 22.0 gram RDX Charges 27. 16. No. of Comple 0 21. Thickness of Permafro 1700' HOLE SIZE .. ?Ri, , 17~" 12~" 8½" 25. .SIZE 26. CEMENTING RECORD AMOUNT PULLED 37n0 Sx P~_~mafro_~t? 1950 Sx Permafrost 900 Sx Class G 1450 Sx Class G 47B Rx £1a,::s R TUBING RECORD -0- -0- -0- DEPTH SET (MD) I.PACKER SET (MD) I ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL. (MD) AMOUNT & KIND OF MATERIAL USER PRODUCTION TEST Date First Production 1/22/85 Date of Test I Hours Tested l:)/~n/R4J 18 F'ig'~ 'h;~i~-g ' Press. 0 28. J Method of Operation (Flowing, gas lift, etc.) Well did not unload load volume. PRODUCTION F-0R Io~L:BBL- -- G-A-S:~C[=' "I-V~ATER-BBL TESTPERIOD m~ J 0 - / -J J- - CALCULATED ~JOIL-BBL GAS-MCF IWATER-BBL JOILGRAVITY-API (corr) 24-HOUR RATE / 0 - / - ICasing Pressure 0 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or ware r. Submit core chips. i .CEiVED MAR 2 7 1985 Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in d NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ! See Attached Lo Depths MAR 2 7 ]985 Alaska 0il & Gas Cons. C0mmissi0a Anchorage 31, LIST OF ATTACHMENTS ~'Je11 History, Geologic Markers & Corin_q Depths 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/~~ Title Nar_ Prnd_ Adm_ Date ~/lCl/RR 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 s ..h~.,U).d. shew, t;he..d,etail,s'o?,;:ar~y~,~n ultiple stage cement- ing and the location of the cementing tool. ::.: ' ,.'." ":'.'i.':'... i' ~.. '~ i . ... .... '." :" .'-: ,";"~. il Item 27: Method of Operation: Flowing, Gas Lift, R'~3d Pu Id; ubmersible, Water In- jection, Gas Injection, Shut-in, Other-explain. !! '. '. Item 28: If no cores taken, indicate "none". .., Form 10-407 STATE OF ALASKA ALASKA '";L AND GAS CONSERVATION C '"-~4MISSION WELL C)OMPLETI, J4 OR REOOMPLETIOk IEPORT AND LOG , , , , 1.6titus of Wall Clmsific~tion of Service Well OIL ~ GAS r-I SUSPENDED [~) ABANDONED I"1 SERVICE I-1 , , 2. Name of Operator 7. Permit Num. ber IM..Q.~ ~h~11 W~ctG~--~ F&P Tnt , 3. A-cl~rms .............. 8. APl Number 60! blest Sth Ave., d810, .Anchorage, AK 99501 . sO.-029-21130 4. Lo~tion of Mil at Iurfece B. Unit or Line Name 1541.5' FSL, 629' FEL, Sec. !1, T13N, R13E BF-57 At Top Producing Interval 10. Well Numbe~ 4912' FSL, 2788' FL, Se¢.24, T13H, R13E No, ~ At TotJI Depth 11. Field end Pool 4124' FSL, 2613' FILL, Sec. 24, T13N, R13E , -B. Eievntion in feet (indicate KB, DF, etc.) I 6. Lmse Designation Bad Serial No. WTLDCAT 7/9/84 11/12/84 2/10/85 , feet MSL 0 i T. TotBIDepth(MD+TVD) 18. Plug Back Dapth (MD+'rVD)19. Dirm:tionalSurvey I 20. Depth where SSSV set 121. Thickness of Permafr°st 15455/11505 110/110 YES~ NOU , . f.tMO 22. Type Electric or Other Logs Run SP/GR/D!$FL/BHCS/NGT/LDT/¢NL/t4L/0!L/BHC/SGT/0CL/CET/CCL/CNT 23. CASING. LINER AND CEMENTING RECORD SETTING DEPTH MD CASINO SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED , 20" 133# K-55 O 1t~02 Pti" _':17111~ _~ P~na~=rn~t~ 13-3/B" 72# N-~O 0 5000 17~." 1950 SX Permafr0St-E - 900 Sx .Clas.s G -0- 9-$/B" 53.5# N-BO&L-B( 0 142B0 12~." 1450 $x Class G -0- 7" 32# L-B0 LTC 84_~? 1_;4;; I~_" 47~ _qx ~lm~; ?, -0- 24. Perforations open to Production (MD+TVD of Toro. and/Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 14704-14714 ' I~ID 11117-zzz23' TVD /(0~(~l' ~) ~J~l~ ~,~-~r,-[~ ['~,~- 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. - DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 40 Hol es 4 JSP 22.0 g~am RDX Charges 27. PRODUCTION TEST D,te Fir. Production I Method o~ Operation (FIo. ing, gas,ft, etc.~ F1 or;ed 81.26 BBLS of 1 oad vol ume. 1/22/85ID~d not recover re.~_rvn~r ~"l,~d; rin~nho!e Date of Test Hours Tested PRODUCTION FOR I OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO as 1/15/85 51 'TEST PERIOD I~ 0 .... Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Pr--s.13 0 ~4-HOUR RATE I~ .... , 28. CUR E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. See Attached Co~e Depths . ';' ~",'~ ,. -., ....~"~ ~i~:. '.: ,.. .. ~. ~:, i'~ .: ..,:.. .... '....: . /".....;! '... MAR 2 .,' ,/., ~... · ..."'.. ;.. ' ":~.-z.-.-.. ~ .; ",~ ~: ..~.. N~$ka Oil & Gas Cons. Commission .... Anchor,,ge Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate STATE OF ALASKA ALASKA "~L AND GAS CONSERVATION C~MMISSION WELL COMPLETE,,.N OR REOOMPLETIOk REPORT AND LOCi 1. Status of Well Clmification of Service Well OIL I~! GAS D 8USPENDED i~ ABANDONED I-! SERVICE I~ ,, , ,,. i 2. Neme of ~)peretor 7. Permit Number 3. A~rm~ .................. 8. APl Numar 60[ Nest 5th'Ave., fbi0, Anch0rage~ AK 9950[ K-029-2[[30 4. L~tion of MIl at ~rfe¢e 9. Unit or ~m Name [54[.5' FSL, 629' FEL, Sec. [[, T[3H, R[3E BF-57 At T~ Prancing Interval 10. Well Number 4912' FSL, 2788' F~, Sec.24, T[3H, R[3E Ho. [ . At To~l D~th 11. Field and Pool 4124'. FSL, 2613' FHL, Sec. 24, TZ3N, R[3E i S. EIMtion in f~t (indicate KB, DF, etc.) J 6. ~se Dmignation and ~rial No. HZLDCAT 55' ~I ADL 3[.2809 12. Die, ~udd, 13. Date T.D. fleKh-- 14. Date Comp.. Bu,. or Abend. 115. Water D,th. if offshore ! 16. No. of Complete°ns 7/9/84 [[/[2/84 ~/[0/85 f,t MSL 0 I~.TotaIO,,h(MO+TVD) 18. Plug BackO, th~WO)lg. Dir. tionalSurvey ! 20. Depth where SSSV --t 121. Thickn's of permafrost ~5455/~605 ~0/~0 ., YES ~ , NO ~ . ~MD ~700' 22. T~e EIKtric or Other Logs Run SP/GR/0ZbFL/BHCS/NGT/LOT/CNL/ML/0]L/BHC/SGT/0CL/CET/CCL/CNT ~. CASING, LINER AND CEMENTING RECORD , SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE .TOP BOSOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED i [3-3/8" 72e N-Rn 0 5000 17~" [950 Sx Pe~afrost E ~ 900 Sx C;ass G -0- , 9-5/8" 53.5f N-80&L-BC 0 [4280 [2~" [450 Sx C;ass G -0- 7. 3Z~ L-80 LTC ~4~7 15455 ~,' 47R Rx Cla~; R -0- 24. Perforations open to Production {MD+TVD of To~.and~Bottom and 25. TUBING RECORD interval, size and number) ~ SIZE DEPTH SET (MD) PACKER SET (MD) [[037-11067 TVD 2e. AC,D. FRACTURE. CEMENT SOUEEZE. ETC. IOq%~)iOI~ ~ DEPTH INTERVAL(MO) AMOUNT a KIND OF MATERIAL USED 200 H0~es 4 JSP 22.0 gram RDX Char~es 27. PRODUCT ION TEST Date First Production I Method of Operation (Fl~ing, gas lift, etc.) [/22/85I F~o~inq [/2~/85~/,' T~mOD ~ 420 8[4 54 20/64I [937 Flow Tubing C~~sure ~CAL~ OIL-eSL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) P,,-.[580 0 ~H~UR ,ATE~ 900 -- [743 -' ~"~:~:' 4[. [. 28. CDR E DATA ~rief d~ription of lithology, porosity, fracture, apparent dips and pre~nce of oil, gas or water. Submit core chips. ,?~.~ ?,.. . .. :.. .... ..'. ., ~ .,.,,. .. ,. , . , ~/ See Attached Core Depths ~' './/' .. 2 7 1985 ~,.,.':" .'~..~~ . '~..~./~. :: :~',~ ~-- ~ --,0ii & ~ch0rageGas Cons. Commission Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate STATE OF ALASKA ALASKA"~L AND GAS CONSERVATION C"~MISSION WELL COMPLETi.N OR RECOMPLETIOI , iEPORT AND LOCi 1. Status of Well Cb#(licit(on o! Service Well OIL ~) GAS D SUSPENDED [] ABANDONED [~ SERVICE [] , 2. Name of Operator ?. Permit Numar ~hell Western F~P ~nc. 3. Addrms 8. APl Numar 601 Hest 5th.Ave., f810, Anchorage~ AK 99501 K-029-21130 . 4. L~ltion of ~11 It ~KI 9. Unit or Lease Name 1541.5' FSL, 629' FEL, Sec. 11, T13N, R13E BF-57 . . At T~ Pr~ucing Interval 10. Well Numar 4912' FSL, 27~' F~, Sec.24, T13N, R13E No. At Total ~th 11. Field and Pool 4124" FSL, 2613' FHL, Sec. 24, T13N, R13E 5. EIMtion in feet (indicate KB, DF, Itc.) I 6. L~se D~ignation and Serial No. MZLOCAT 55' ~I ADL 312809 12. Dlta ~udd, 13. Date T.D. Reach, 14. D,t, Comp.. au,. or Ab, nd. ! 15. Water D,th. '+ offshore 116. No. of Completions 7/9/~4 11/12/84 ~/10/85 f~t MSL ~,.TotalD, th(MO+TVO) ,8.PIugBackD,th~O) ig. Dir. tionalSur.y ! 20. O,,hwhereSSSVset 121.ThicknHsofPer~'afrost 15455/11605 110/110 , YES~ NO~ ,,. ~.~MD 1700' ~. Type EIKtric or Other L~s Run SP/GR/DZSFL/BHCS/NGT/LDT/CNL/ML/D]L/BHC/SGT/DCL/CET/CCL/CNT ~. CASING, LINER AND CEMENTING RECORD i i SE~ING DEPTH MD CASING SIZE WT. PER FT. GRADE .TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 72~ N-8~ 0 5000 17~" 1950 Sx Pemafrost 900 Sx Clas.s G -0- 9-5/8" 53.5~ N-80&L-8{ 0 14280 ~2~" 1450 Sx Class G -0- 7" 3gl L-80 LTC RaPT 1R4RR ~" 475 ~x ~la~; R. '0- 24. Perforations open to Production (MD+TVD of T~.andxBottom and 25. TUBING RECORD . interval, size and number) SIZE . DEPTH SET (MD) PACKER SET (MD) 14570-14620' ~ID 0~ ~- 11037-11067' TVD 2s. ACID, FRACTURE, CEMENT SQUEEZE, ETC. (0q~- ll~{ ~ ~ DEPTH INTERVAL(MO) AMOUNT & KIND OF MATERIAL USED 200 Holes 4 JSP 22.0 gram RDX Charges 27. PRODUCTION TEST Date First Production Method of Operation (Fl~ing, ~s lift, etc.) 1/22/85 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 1/23/85 20 TEST ,ERmOD ~ 907 1798 16 2"I 1982 Flow Tubing Casing Pressure ...... CALCULATED ~.~tE-BBL. GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) ere,~8 ................. 0 ........ '~:~'0~R "'ATE' ~ ~28~L-':' 5617 46 41.1 28. ~ ...... CORE DATA Brief d~ription of lithology, porosity, fracture, apparent dips a:~~O~:o!l':':~rO+~te~.'~u~il core c (ps. ~-. ~ ,~ .~' ,:. :, .., . ..,... See Attached Core Depths ~ ,? ..:~: ,:~.. :. '. ~'. y~, ~..mm ~..: 7 1985 -.. Alas~ 011 & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE STATE OF ALASKA ALASKA AND GAS CONSERVATION C ..... IMISSION WELL COMPLETI I OR RECOMPLETIOk 4EPORT AND LOCi 1.6ta(us of Well Cleesificetion of Service Well OIL I~ GAS I'! SUSPENDED [:] ABANDONED [::] BERVICE I"1 ..... i i , :2. Nlme of (3~trltor ?. Permit Number _~h~11 b/~.~n I~,D Tnt 3. A~cJr~-s ................... 8. Alii ~u-mber 60! Nest 5th Ave., ts!0, Anchorage~ AK 9950! Bo-029-2!!30 ,, '4. Locetion of Well et surface D. Unit or Lease N.me !54!.5' FSL, 629" FEL, Sec. !!, T!3H,. R!3E BF-57 At Top Producing Interval 10. Well Number 49!2' FSL, 2788' FklL, Sec.24, T!3N, R!3E No, ~ At Total Depth 11. Field end Pool 4!24' FSL, 2613" Fk/L, Sec. 24, T!3N, R!3E i i B. Elevation in feet (indicate KB, DF, etc.) I B. Lease Designation end Serial No. Ii~]:LDCAT 55' KBI ADL 3!2809 , 7/9/84 11/12/84 2/10/85 feetMSL 0 17. TotIIDepth(MD+TVD) 18. PIugBackDepth(MD+TVD, 19. DirectionalSurvey ! 20. Depth where SSSV let 121. Thickness of Permafrost 15455/11605 110/110 YES ~ . NO [] . feet MD 1700' 22. Type Electric or Other Logs Run SP/GR/D!SFL/BHCS/NGT/LDT/CNL/HL/DTL/BHC/SGT/DCL/CET/CCL/CNT. 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 133# K-55 0 1602 ~R" R7OO RX Pe~ma~_~_n_~? .n. i3-3/8" 72# N-nO 0 5000 17~" 1950 Sx Permafrost ~ ~ 900 Sx Class G -0- 9-5/8" 53.5// N-80&L-8[ 0 14280 12~" 1450 Sx Class G -0- 7" 32# iL-gO LTC n,~:)2 154.55 R~" 47R ~ Clac:~ R -0- 24. Perforations open to Production (MD+TVD of To~o. and/Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) , TVD - I ~ q 5~ - ~ ~o~ ~.(~ $~ :26. AC~D. FRACTURE. CEMENT SOUEEZE. ETC. DEPTH INTE;VAL <MDI AMOUNT & KIND O; M^TER~^L USED , 100 Holes , 4 JSP 22.0 gram RDX Charges 27. PRODUCTION TEST , Date First Production I Method of Operation (Flowing, gas lift, etc.) 1/22/85I Flowin9 ' Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 1/28/85 7 TEST PER ~OD I~ 570 11 _~Z~ ?~ _~"I ___~n~. Flow Tubing Casing Pressure CALCULATED'.- I~, .~OLL-BB.L GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Prin.250 0 '" '2;~-HOURR^T,E~,.~ 1650 '~ 3340 20 41.7. 28. ~ "---"~CORE DATA Se~ gtt:~ched Core Depths ..... ... ..... '?:.; .... ":'~ ..... ii ':.~'." .. ? . :, ...: .~ '". '"//' ' MAR2?1985 .... ' / · Naska 0il & Gas Cons. Commission " '/ ,~ .'.,." ... Anchorage i,i ... .., ., __ Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate STATE OF ALASKA ALASKA '~"~1. AND GAS CONSERVATION CC ~MISSION WELL COMPLETI.,# OR RECOMPLETIO# ,tE RT AND LOCi 1. Status of Well Cle#iflc~tion of $~rvice Well OIL {~ GAS I-I SUSPENDED ~) ABANDONED r-I SERVICE [~] .... 2. ~lme Of Operator 7. Permit Number ~h~ll kl~ct~n i:JLD Tar P'A-9~ , 3. Addrbs-s .................. 8. APl Number 601 blest Sth Ave., #810, Anchorage~ AK 99501 so-029-21130 4. Loc~tion of well et surface S. Unit or Leese N~rne 1541.S' FSL, 629' FEL, Sec. 11, TZ3N, R13£ BF-57 . · At Top Producing Interval 10. Well Number 4912' FSL, 2788' FblL, Sec.24, T13H, R13E N0, 1 At Total Depth 11. Field end Pool 4124' FSL, 2613' FILL, Sec. 24, T13H, R13£ , , $. EIMtion in feet (indicate KB, DF, etc.) . J B. Line Designation and Serial No. I~/ZLDCAT 7/9/84 11/1E/84 2/10/85 ~,t MS[ 0. 15455111605 110/110 v~s ~ ~o ~ . ,~M~ 1700' 22. Type El~tric or Other L~s Run SP/GR/D~SFL/BHCS/NGT/LDT/CNL/r4L/D~L/BHC/SGT/DCL/CET/CCL/CNT ~. CASING, LINER AND CEMENTING RECORD , SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD ~AMOUNT PULLED 20" ]33~ K-~5 0 16~2 ~. ~7n~ ~= Pe~f~o~_? -n- 13-3/8" 72~ N-Re 0 5000 ]7~" 1950 Sx Pe~afrost ! ~ 900 Sx C~as,s G '-0- 9-5/8" 53.5~ N.80&L_8( 0 14280 12~" 1450 Sx Class G -0- 7" 32~ L-80 LTC na~7 15455 ~" 47~ ~ ~la~ ~ -0- 24. Perforations open to Production (MD+TVD of T~.and~Bo~ and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 10986-11001' TVD ~,.~" =~, ACID, FRACTURE, CEMENT SOUEEZE, ETC. ~ ' (~ ~ DEPTH INTERVAL(MD) AMOUNT & KIND OF MATERIAL USED 100 Holes 4 OSP 22.0 gram RDX Charges 27. PRODUCTION TEST , Date First Production ~ Method of Operation (Fl~ing, ~s lift, etc.) 1/22/85~ FlowJnq Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO 1/30/85 8 ;EST~E;,O= ~ 525.4 ~n73 ~ ~7 ~"~ ;0~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL O1.~ GRAVITY-APl (corr) P~,-. 250 0 '24-HOUR R~TE ~ ~0 3390 35 4].7 ~8. CORE DATA Brief d~ription of lithology, porosity, fracture, apparent dips and pre~nce of oil, ~s or ware r. Submit cpre chips. ~,"% <~ .~ ? ':~". -.~..... ~ .... . -~'..;~ ;. ~ . .,. ~, ..., .... ~ '"'Y., , ~ b-- ~ . - ~ ' .. . ~ ~il ~ ~as Cons. Commission gnchora~e Form 10-407 Rev. 7-1-80 cONTINUED ON REVERSE SIDE Submit in duplicate STATE OF ALASKA ALASKA -iL AND GAS CONSERVATION C-"~MISSION WELL COMPLBTbv# OR RECOMPLETIOK EPORT AHD LOG , , , 1. ttltus 0~. Well CIIIsificttion of Service Well OIL ~ GAS ;'1 SUSPENDED ['! ABANDONED I-! SERVICE I-I , 2. Name of Ol~retor 7. Permit Number Sh~_)! W~__~?~_r.n Ic'_~P !~c. IM.q.~__ , $. Addr~l B. APl Number 601 Hest 5th'Ave., #810, Anchorage, AK 99501 . . ~o-029-21130 4. Location of well et surface 9. Unit or L~se N~ne 1541.5' FSL, 629' FEL, Sec. 11, T13N, R13E BF-.S7 .. At Top Producing Interval 10. Well Number . 4912' FSL, 2788' FWL, Sec.24, T13N, R13E No.~l At Total D~pth 11. Field and Pool 4124' FSL, 2613' F~L, Sec. 24, T13N, R13E S. Elevation in feet (indicate KB, DF, etc.)I6. Lease Designation end Serial No. WILDCAT 55' KBI ADL 312809 12. Date Spudded7/9/84 13. Date T.D. Reached, 11/12/84 14' Date Comp" Sump' °r Abend' 115' Water Depth' if °ffsh°re ] 16' No' °f Completi°ns2/10/85 . ,eat MSL , 0 ' 7. Total O,th (MD+TVD),B. Plu. Back Depth (MD+TVD)19. Directional SurveY15455/11605 110/110 YES ~] . NO I-I I20' Depth where SSSV set. f~et MOI21' Thiclmess Of PermafrOst1700' ,.. 22. Type Electric or Other Logs Run SP/GR/D[SFL/BHCS/NGT/LDT/CNL/HL/DIL/BItC/$$T/PGL/CET/CCL/CNT :23. CASING, LINER AND CEMENTING RECORD , SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED , 20" 133~/ K-~E O 1~0~ ?fi" ~7NN _~ pe~mafrO_~t? -N- 13-3/8" 72~ N-AN 0 5000 17~,, 1950 Sx permafrost E . 900 Sx Clas.s G -0- 9-5/8" 53.5# N-80&L-8( 0 14280 12~4" 1450 Sx Class G -0- 7" 32# L-80 LTC A4:~2 1.r;455 ~" 475 ~x Cla~ P, -0- 24. Perforations open to Production (MD+TVD of To, p. andiBottom end 25. TUBING RECORD interval, size end number) SIZE ~. DEPTH SET (MD) PACKER ,SET (MD) 11714-11763' /.1D 9100-9133' TVD ~. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ' O/~/~ .,C~01,~0 C.~;;> DEPTH INTERVAL (MD) AMOUNT & KINDOF MATERIAL USED 196 Holes 4 JSP 22.0 gram RDX Charges 27. PRODUCTION TEST .,, Date First Production I Method of Operation (Flowing, gas lift, etc.) 1/22/85I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 2/6/85 12 TEST PERIOD I~ 0 0 10:~9 32/64I - Flow Tubing Casing Pressure CALCULATED.k OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 261 0 24-HOUR RATE ~ 0 0 2500 - .. 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. See Attached Core Depths ;;,..,. .... ' ...... ?' :'"' ; ":;" E C E IV E D ./~,.., :' MAR 2 7 1985 'Naska Oil & Gas Cons, C0,%'~ission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE (' STATE OF ALASKA (r ALASKA OIL AND GAS CONSERVATION COIvlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL J~ COMPLETED WELL [] OTHER 2. Name of Operator 7. Permit No. Shell Western E&P ];nc, 84-93 3. Address 601 West 5th Ave., #810, Anchorage, AK 4. Location of Well 99501 1541.5' FSL, 629' FEL, Sec. 11, T13N., R13E 5. Elevation in feet (indicate KB, DF, etc.) 55' KB I 6 . Lease Designation and Serial No. ADL 312809 12. 8. APl Number 50- 029-21130 9. Unit or Lease Name ;' BF-57 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 ' [] 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 for Temporary Abandonment I(ECEIV£D MAR 2 7 19B5 At.aS.,,~Oll & Gas Cons. Commission 14. I hereby~,~ertify that the foregoing is true and correct to the best of my. knowledge. ...... Signed Title Mgr. Prod. Adm. The space below for Commission use Date, 3/19/85 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. '7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports"in Duplicate LOG DEPTHS Sagavani rktok/T5 PRIVATE AND CONFIDENTIAL SWEPI ET AL BF-57 NO. SEAL ISLAND PROSPECT BEAUFORT SEA AREA NORTH ALASKA MD TVD 5,428' 4,763' -4,708' Col vi lle 8,554' 6,942' -6,887' Pebble Shale 11,245' 8,836' -8,781' Put/Kupa ru k 11,574' 9,057' -9,002' First Sand 11,711' 9,150' -9,095' Ki ngak 12,110' 9,423' -9,368' Sag River 14,207' 10,866' -10,Bl1' Shubl ik 14,332' 10,944' -10,889' Sadl eroch i t 14,470' 11,028' - 10,973' OWC 14,690' 11,160' -11,105' Ivishak Shale 15,048' 11,370' -11,315' Echooka 15,205' 11,462' -11,407' L i sbu rne 15,250' 11,490' - 11,435 ' TD 15,455' '~11,605' -11,550' PUT/KUPARUK CORE DEPTHS (DRILLER'S) (To get log depths, add 16') Core f/ 1 Core # 2 Core ~ 3 11,699-11,760' 11,760-11,794' 11,794-11,808' Cut 61' Rec. 55 5' Cut 34', Rec. 33' Cut 14', Rec. 10' Core # 4 Core # 5 Core # 6 Core # 7 Core # 8 Core # 9 Core # 10 Core # 11 Core # 12 Core # 13 Core # 14 12/7/84 SADLEROCHIT CORE DEPTHS (DRILLER'S) (To get log dept'hs, add 20') 14,475-14,488' 14,488-14,494' 14,494-14,508' 14,508-14,548' 14,548-14,583' 14,583-14,644' 14 ,644-14 ,668_,,!..~ .,.,. ,,, ,,CU~--r~24!.-~ Rec., .~3~', 6" 14,668-14,68))' ~i"' ~!~'~.'''~'Cu't'i i'7', Rec. '14.', 6" 14,685-14,710..' Cut 31', Re.c. 2~llm;, 3" 14,716-14,721' Cut 5' Rec · 8II 14,721-14,741' Cut 20', Rec t9', Cut 13' Rec 8' 3" c~ ~ Cut 6' Rec 2' 5" r-~ Cut 14' Rec. 11' 9" ~ (~ Cut 40' Rec 32' 10" ~ r~ r-~ , . ~ Cut 35' Rec. 26' 9" ~ ~ Cut 61' Rec. 60' 11" ~ ~ ~ ~P-57 NO. 1 bELL HISTORY 7/ 9/84 - 7/10/84 SPUDDF, D. DRILLED AND SURVEYED TO 1510'. 7/11/84 DRILLED AND SURVEYED TO 1609'. OPENED 17 1/2'* HOLE TO 24" FROH 150'-298'. LOST TOTAL RE1/IRNS. NIXED & PUPIP- ED 300 SX PE3tHAFROST CHT, DISPLACED #ITH 1.5 BBL'S #ATER CIP SLURRY MT, 14,9 TO 15 PPG. #OC, 7/12/84 - 7/13/84 TAGGED FIRPI CHT AT 1~', DRILLED CHT F1tOH 148' TO 495'. OPENED 17 1/2" HOLE TO 24" HOLE FROH 495' TO 1080'. SURVEYED AT 470' (1/2 DEG), $64' (1 1/2 DEG), 654' (2 3/4 DEG). REAHED FROH 470' - $64'. SURVEYED AT $64* (1 DEG). 7/14/84 DRILLED AND SURVEYED TO 1280'. RAN SPERRY SUN GYRO 0-1100'. 7/15/84 - 7/17/84 DRILLED TO 1609'. RAN SPERRY SUN SINGLE SHOT GYRO SUR- VEY FROH 1100-1550'. OPENED HOLE TO 24" TO 1609'. RAN OPEN HOLE CALIPER SURVEY. RAN 20** CSG TO 155'. PULLED. #ORKED THRU TIGHT SPOT AT 155'. ItU TO RERUN 20" CSG. 7/18/84 RAN CSG TO 1602' FLOAT COLLAR @ 1558' , · PUre'ED 3400 SX PERHAFROST XX CHT, tit 14.9 PPG, YIELD .94. DROPPED #IPER PLUG. DISPLACEHENT tilTH HUD, tilTH 135.5 BBL AtiAY, PRESSURE INCREASED UNABLE TO DISPLACE REHAINING CHT. EST. TOP OF CHT IN 20" 400* & IN ANNULUS 925'. #OC. CLOSED ANNULAR PREVENTER & PUHPED 300 SX PERHA- FROST I! CHT, tiT 14.9 PPG BETWEEN 30** & 20'*. tiOC. 7/19/86` - 7/20/84 NU TESTED BRAIDENHEAD TO 800 PSI, RAHS TO 2000 PSI, HYDRIL TO 1500 PSI & NANIFOLD TO 2000. 7/21/86` TAGGED CHT @ 407'. DRILLED C~T TO 1572'. TESTED CSG TO 1500. DRILLED CHT TO 1609'. CIRC. & COND. ITu'D. 7/22/86` DRILLED TO 1650'. RAN LEAK OFF TEST. TESTED LINES TO 2000 PSI. LEAK OFF @ .656 GRADIENT. ENti - 12.6 PpG. DRILLED TO 1700'. RAN GYRO IN 20*' CSG. RIH ORIENT DYNA-DRILL tilTH SPERRY-SUN SINGLE SHOT GYRO TO $/E. DRILLED & SURVEYED TO 1793'. 7/23/86` - 7/25!84 DRILLED & SURVEYED TO 4059'. 7/26/86, DRILLED TO 5000'. CIRC & CONDITIONED HOLE FOR LOGS. RAN LOG ~1: SP, Git, DISFL,' BHCS LOGGER DEPTH 4996 *. RAN ~2:. NGT, LDT, CNL, HL, & CALIPER. 7/27/86` - 7/29/84 OPENED 12 1/4" HOLE TO 17 1/2" TO 5000'. RAN TELECO SURVEY EVERY 300' TO CONFXRN ANGLE AND DIRECTION. 7/30/86` '-7/31/84 RAN CALIPER LOG 3825 TO SURFACE. RAN 13 $/8", 72# N-80 CSG TO $000'. NIXED & PUNPED 1950 SX PERKAFROST TYPE '*E" CHT tilTH .17#/SX HR-15, .17#/SX SOD CIT AND H-6`. tit 12-12.2 PPG, YIELD 1.97, FOLL0..ti~... ,.B~..,900~SX ~,. CLASS "G" NEAT, 15.8 PPG, YIELD? I"..iS..: :'nTSpLAcED' 742 BBL t~JD #ITH RIG PLq~. DID",NOT BU~tP PLUG. OVER ".'. DISPLACED 8 BBL. CIRC APPS 300 BBL CONTAHINATED CHT TO PIT. DISPLACED CHT AT 8.5 BPH, FINAL 'CIRCULAT~ lNG PRESSURE 1600 PSI. INSTALLED CSG SPOOL AND TESTED TO 2000 PSI. INSTALLED & NU 10000# 13 3/8" BOP STACK & RISER ASSY. TESTED BOP. TESTED ANNULAR PREVENTER TO 2500 PSI. TESTED PIPE RAHS, BLIND RAHS, LE 8/ 1/86` 8/2/84 ESL..'').. COCES, FLOOR VALVES, CHORE SAB..i~)LD & LI~S TO SO00 PSI, TEST #ITNESSED BY AOGCC PEP, TAGGED OST @ 4931*, MILLED TO r~956~, TESTED CSG TO 2~ Psi. ~ILL~ TO ~978t. ~ SCHL, G~0 S~VEY, ~ILL~ TO 5010'. ~ST~ F0~TION TO 12,6 PPG, ~ILL- ~ T0 8/3/8~ - 8/ 4/8~ mlLL~ TO 6566'. ~ DI~OG ~IP~ L~. INST~L~ DP R~B~S ON 3000* DP, 8/ 5/84 - 8/ 6/8~ ~ILL~ & S~VEY~ TO 8055~. ~ H2S ~ILL ON RIG FLOOR a FIRE ~ILL IN ~. 8/ 7/84 - 8/ 8/84 ~ILL~ & S~VEY~ T0 8826'. TEST~ ~~ PREVE~ER TO 3500 PSI. TEST~ PIPE ~S, BLI~ ~, ~LLY C~, FLOOR V~VES, ~0~ ~IFO~ & LINES TO 5000 PSI, D~A ~ILL~ 8763-8826'. 8/ 9/84 -8/13/84 DRILL~ ~ S~VEY~ TO 10720'. ~ H2S/FIRE DRILL MITH ~L P~SO~EL ON IS~ & SAFETY ~ETING ~I~ 8/14/84 . DRILL~ TO 10935' .' LOST 500 PSI P~ PRESS~E. C~C~D EqUIP~NT. BACK ON BOTTOH LOST ~0~ 500 PSI. POOH LO0~ FOR ~HOUT. 8/15/84 FO~ SECO~ST~ BOX C~C~D. TI~T SPOTS 0 9511' 9320'. TEST~ BOP ~~ PREVENTER TO 2500 PSI & ~L ELSE TO 5000 PSI. DRILL~ & S~VEYED TO 11230'. RE- PAIR~ ~HOUT IN ~ LINE. 8/16/84 - 8/17/84 DRILL~ TO 11699'. 8/18/84 - 8/20/84 CUT ~ORE ~1 1~699-~760'. REC 55.5'. CUT CORE 11760-11794'. REC 33.0'. CUT CORE ~3 11794-11808'. REC 10'. ~ILL~ TO 11828'. ~LD H2S ~ILL, 8/21/84 ~ILLED T0 121~'. TEST~ BOP E~UIP~NT. 8/22/8 - 8/2 /8 2IRCCU~T~ BOTTOHS UP. ~ DISFL/SHCS/~/SP 115~5000'. N~HED ~ R~ED 11500-12000'. CIRC BOTTOHS ~.. ~ DISFL/BHCS/~/SP. STOPPED e 11691'. M~ & a~ ~662-~2000'. c~ac BOTTOHS ~ & C0~- TIO~ ~ (~ISED MT T0 10.5). RI~ ~ SCHL~G~. 8/25/84 ATT~TED TO R~ DIL/BHC/SGT COU~ NOT ~ BELOM 11694'. CIRC ~ BUILT ~ WT T0 11.2 PPG. R~ HOLE 12000- 12065'. 8/26/84 a~ TI~T HOLE 11994-12050. P~ED HI-VISC. PILL. R~D TI~T HOLE 12050-12131. CIaO & P~ HI-VISC. GEL SMEEP. R~D TIGHT HOLE 12131-12146'. ~ILL~ ~2~6-~226~'. ~ISED ~ MT TO 11.5 PPG. 8/27/84 ClaC & S~VEY~. CIRC & a~ TO 12260. RE~IEV~ S~VEY TOOL ON MIRELINE. DRILL~ TO ~2270'. 8/28/84- 8/29/84 DRILLED T0 12560'. a~ 12400-12560'. DRILLED TO ~26o5'. 8/30/84 DRILLED TO 12757'. P~ HI~ VISC GEL S~EEP e 12730'. 8/31/84 DRILL~ TO 12881'. R~D TO BOTTOH. 9/ 1/84 P~~ HI~ VISC. GEL SMEEP e 12875. R~ TO BOTTOH. DRILLED TO 12935'. 9/ 2/84 - 9/ 3/84 TEST~ ~. R~ TO BOTTOH, 5" FILL. DRILL~ TO 13255 '. 9/ 4/84 - 9/ 7/84 DRILL~ TO 13340'. TEST~ BOP ~ RE~T~ E~UIP~NT. DRILL~ TO 13705 ' . ~" 9/ 8/8~ DRILLED ~ S~VEY~ T0 1377~'. C :~=~ ','... " 9/ 9/84 REPAIRED ~ P~. DRZLL~ TO 14000~ .=.:. '.,'"',,~ :. 9/10/81 - 9/13/81 DRILLED ~ S~VEY~ TO li086'. HELD'a2S" DSZLL PSSS0~SL. DS~LL~ r0 ~228'. ]NC~ ~ ~T"T0 9/li/81 CIRC BOTTOMS UP. DRILLED T0 11280'. "CIRC ~ CO~ HOLE T0 R~ CSG. 9/15/84 SU T0 R~ 9 5/8" CSG. aE~ R~ING CSG. 9/z6/8 , JTS 55. ,-80, 232 2TS 53.:,')L-80.'* COL~ 0 14194~, SHOE S 14280~. C~~Z~S 10' SHOE ~ ~ ~S 3-43, LOST RE~NS (350 BBLS ~) R~ING CSG (0 11955'), LOST 50 BBLS ~ ATT~TING TO ~T~LISH CIRC. ~~ 25 BBLS ~A~ ~. P~ 1450 SX C~S 'G' ~I~ 1~ C~-2, .3~ ~ 9, .1% ~-~. SLaY ~ 1~.8 PPG. DIS~. MI~ 5 BBLS ~AT~ 1020 BB~ ~ (920 ~ & 100 MAT~). B~~ PLUG. SET CSG SLIPS M/450~. INST~L~ & ~S~ ~0N ~ SP~L & S~ ~S~LY. 9/17/8~ - 9/20/8~ TEST~ BOP. RU S~L~~ & RIH M/DIA-L~ CSG ~G. T~L FAI~. RU & ~ S~L~G~ GST LOG,~G~O S~VEY, CET, ~~~E LOG, & DIA-L~ CSG 9/21/8~ - 9/22/8~ ~CSG TO 3000 PSI FOR 15 NIH. HI~ a DISP~C~ ~CL2 ~ 2000' · 9/23/8~ - 9/25/8~ HONITOR~ ~ES & HISCEL~OU$ RIG R~AIR. 9/26/8~ ~ T~ S~VEY ~I~ SCHL~~. 9/27/8~ - 9/30/8~ HONITOR~ ~E$ & HISCEL~EOUS RIG REPAIR. 10/ 1/8~ -10/10/8~ HONITOR~ ~E$ & HISCEL~EOUS RIG REPAIR. S~T FOR ~E 10/11/8~ .-10/13/8~ PREPPED RIG FOR ST~T-UP. ~$TED EQUIP~T. 10/1~/8~ RIH TO 701~'. CIRC CACL2 MAT~ OUT OF HOLE & DISPOS~ OF MAT~ ~ ~LU$ OF S~ 2. RIH TO 10000'. CIRC 10/15/8~ BE~ ~LG e ~:30 PN. DRIL~ TO 1~298'. ~ L~ OFF TEST. EQUIV~T ~ MT 0F 16.7 PPG. 10/16/8~ -10/17/8~ DRIL~ TO 1~7~'. HE~ S~ETY ~ETING. ~0/~8/8~- ~0/~9/8~ CORE ~, ~5-~88', REC. 9'. CORE ~2, ~488-~9~', REC. 2' 10/20/8~ -10/21/8~ CORE ~3, 14~9~-1~508', REC. 11' 9". ~ S~ETY ~ETING 10/22/8~ -10~2~/8~ CORE ~, 1~508-1~5~8, REC. 32'. CORE ~5, REC. 26~ 9". 10/25/8~ -10/26/8~ CORE ~6, 14~83-146~3', REC. 60' 11'. 10/27/8~ -10/30/8~ TEST~ ~, V~VE$, KILL LINE, CH0~ LI~, UPP~ LO~R ~LLY V~VE, FLOOR S~ETY V~VE, CHO~ ~IFOLD TO 5000 PSI. TEST~ ~~ PREVENTER T0 3500 PSI. CORE ~7, 1~6~3-14668', REC. 23'6'. CORE ~8, 1~668-1~685t, REC. 1~~ 6". CORE ~9, 1~685-1~716t, REC 29' 2". 1~626-1~716' · 10/31/8~ CORE ~10, 1~716-1~721', CUT 5', REC. 6'. 11/01/8~ -11/02/8~ REPAIR~ RIG. 11/03/8~ CORE ~11, 1~721-1~7~1, REC. 19'8". TEST~ BOP, ~0~ LINE, ~IFO~, KILL LI~, WPER & LO~ PIPE ~S, UPPER & LO~ ~LLY COCKS, TLOOR S~ETY V~VE, BLINE ~S ~ ~~ PREVENTER. 11/04/8;4 11/05/8;4 -11/06/8;4 11/o7/8;4 11/o8/8;4 NASHED & REAHED 14721-14741 '. DRILLED TO 14865 '. RAN DLL/PISFL. LDT/CNL/NGT/HL LOGGING TOOLS STUCK @ 11745'. #0RKED LOOSE. HOT @ 1;4478'. TOT 14410'. TOT STUCK @ 142;4~'. #0RKED LOOSE. POOH. REPLACED 4 JTS. GRADE "E' DP. RIB TO 14865'. DRILLED TO 14867'. POOH TO RUN LOGS. 11/09/8;4 11/lO/8;4 11/11/8;4 11/12/84 11/13/8;4 -11/1;4/8;4 RU SCHLUI~BFAGER. RAN DIL/BHC/GR/SP @ 14350'. RAN RAN DIL/GR/SP AND LDT/CNT-G/GR OK. RIH WITH BHC LOG RAN LDT/CNL/LGT/I!.L AND SHC/OR/$P RIH TO 14867'. CIRC & COND HOLE. I~q~.~SHDT/G'R';' . ......... " .. - ?.. , :-." . : . .. DRILLED TO 1;4900'. ..-'~ .... DRILLED TO 15097' ' DRILLED TO 15176'. TESTED HOPE. DRILLED TO 15355'. HELD SAFETY HEETING. DRILLED TO 15;455'. POOH FOR LOGS. KELD H2S 'DRILL. "' CO~.-~)MOT GO BELOM 14330', RAN DIA t.~,~ ~J~ING ~,J,.IPER 14250-8000 AND 8000-SURFACE. CIRC. 11/15/8;4 -11/16/8;4 BAN SHDT/GR 1510~'. RAN NGT/PCD 15118'. RAN BHC/GR 15108. REAPIED AND MORKED TIGHT HOLE. TESTED BOP. 11/17/8;4 -11/19/8;4 TESTED BOP AND RELATED EQUXPHENT, RAN VELOCITY SURVEY 14207-1600*. INSPECTED BHA. REPAIRED RIG. #ASHED TO BOTTOH, 11/20/8;4 -11/21/8;4 NIXED & SPOTTED GEL PILL ON BOTTOH. RAN DIPKETER TO 151;47'. RAN SONIC M/ALL STANDOFFS ON TOOL TO 14335'. LOGGED 15150-1;4;457'. TOOL STUCK. MO FISHXNG.TOOLS. 11/22/8;4 -11/.23/8;4 RECOVERED FISH. 11/2;4/8;4 -11/25/8;4 RAN 36 JTS, 7'*, 32~ L-80 LTC CSG. LINER STOPPED @ 7925* HANGER RUNNING TOOL PARTED @ GAUGE RING. MO FXSHING TOOLS. RECOVERED FXSH. 11/26/8;4 -11/27/8;4 CIRC & COND @ SHOE. RERAN 36 JTS 7** LXNER. TXH TO BOTTOH M/LINER. CHT #/HOWCO, 50 BBL PREFLUSH, 375 SX CLASS G, W/l% CFR2, .3% HALAD 9, .2% ER7, AND ;4.2 GAL/ 10 BBL$ HR6L. DISPL W/ 300 BBL 9.7. 14UD. CXP SHUT bELL IN W/300 PSI. MOC. 7*' LINER, 32~,. L-80 LTC 8RD, 1;452.83'. SET @ 15;455'. SHOE @ 15;452'. FLOAT @ 15;413' 11/28/8/4 CLEAN OUT LINER TOP. TAGGED CHT @ 13789'. DRILLED CHT FROH 13789-13980** TREATED HUD FOR CHT CONTAHINATION. SET RTTS. PERFORHED DRAM DOWN TEST. LOST FLUID. TEST NO GOOD. RESET RTT$ TO SQUEEZE LAP. 11/29/8;4 -11/30/8;4 TESTED LINES TO 3000 PSI. PUHPED 100 SX CLASS G CHT W/ ADDITIVES. PUI4PED 15 BBL H20 AHEAD. TESTED LINES TO 3000 PSI. PU14PED 20.5 BBL CHT, 5 BBL H20, 211 BBL HUD. SHUT DOWN CLOSE BY-PASS. PUI4PED 28 BBL$ HUD. SHUT DOWN @ 3000 PSI. STAGE IN LAST 2 BBL, 1/2 BBL AT A TINE. 18 BBL C]4T DOWN LAP, 2.5 BBL CHT IN 9 5/8** CSG. FINAL SQZ. PRESSURE 800 PSI. CLEAN DP. LAID DOWN PIqR & PLUG CATCHER. 12/1/8;4 TESTED LINER LAP. 12/2/8;4 PERFED 1' W/;4 SHOTS AT 11780' FOR BLOCK SQUEEZE. 12/3/8;4 PUI4PED 5 BBL H20 AHEAD OF 20.5 BBL CLASS **G** CHT M/ADD. PUHPED 5 BBL. H20 CHASE CI4T W/176.5 BBL HUD. SD. CLOSED BY-PASS. PUI4PED 30.5 BBL HUD. SD W/3.5 BBL CKT IN 9- 5/8*' CSG. FINAL SQZ PRESS-850. BLED BACK 3.5 BBL. SI PRESSURE BUILT TO 700. PUHPED 3.5 BBL HUD. SI W/650. HELD 30 HIN. BLED BACK 2-3/;4 BBL.. PRESSURE FELL TO 0. NO FLCFd. ND BOPE. CHECKED 9-5/8** CSG. NU BOP & TESTED 12/;4/8/4 TESTED BOPS TO 7500 PSI. TESTED SQZ JOB TO 800 PSI. DID NOT HOLD. RU HALLIBURTON. PUI4PED 5 BBL H20. PUI4P- ED /41 BBL CLASS 'G' CHT W/I~ CFR2 + .3% HALAD 9. PUHPED 5 BBL H20. CHASED CHT 14/15;4 BBL HUD. SI CLOSED BY- PASS. PUI~ED ;48 BBL HUD. SI STAGED IH 3 BBL HUD. FINAL SQZ PRESSURE 1700 PSI. BLED BACK 3 BBL HUD. 12/5/8;4 TAGGED CHT TOP AT 11536'. DRILLED HED-FIRH CHT TO 11750'. PERFED @ 11700*. 12/6/8;4 SET RTTS e 11;468'. PU ED 7 BBL H20. HIXED & PU ED ;41 BBL CLASS *'G*' 14/ 1% CF 2, .1% BBL H20. CHASED CI4T W/150.5 BBL HUD. !iS~~ "PUl?ED HUD. SI #/2000 PSI. BLED BACK $ BBL ~, ." PUHPED 5 BBL HUD BACK IN. PUI4PED 1/2 BBL. WAITED 5 HIN PUI4PED 1/2 BBL. 14AITED 15 NIH. PUHPED 1/2 BBL'. MAITED 30 HIN. BLED BACK 1 3//4 BBL HUD. REVERSED: CZP~C 300 HUD. TAGGED CHT @ 11;473'. DRILLED GOOD CHT TO 11750'. TESTED PERS @ 11700' TO 1300 PSI FOR 30 HIN. DRILLED TO 11808'. TESTED PERS @ 11780 TO 1300 PSI FOR 30 HIN. OK 12/7/8;4 RAN CET LOG FROI4 12000-1 l, 200'. POOH TO RUN SCAB LINER. 12/8/84- 12/9/84 12/10/84-12/15/84 12/16/84-12/17/84 12/18/84 12/19/84 12/2o/84-12/21/84 12/22/84-12/24/84 12/25/84-12/26/84 12/27/84 12/28/84-12/29/84 12/30/84-12/31/84 1/1/8~- 1/2/8~ 1/3/8~- 1/4/85 1/$/85- 1/6/85 1/7/85- 1/8/85 1/9/85- 1/10/85 1/11/85-1/12/85 1113185-1114/85 1/15/85 ItU t~ l~k3 JTS 7", LT&C & BT&C, ' ~0 S~ LZ~. OBS~U~X~ 0 13914t. P~ W/7" LZ~. ~FT 2 1/~ C~I~S IN HOLE. FZS~ M/~~T,' FIS~ M/~~T. ~ID ~ ~~T. ~O~ ~ B~T. ~ ~ETY ~TING. CONTI~ ~ING ~ B~T, RIH M/HILLS. CL~ OUT ~ B~ ~PTI~. P~H aU TO R~ 7" S~ LI~. ~ ~ FIRE ~ILL ON 16~, ~ 1~2 JTS 32~ ~0, S53~.16' TOP OF TIE BA~ S~ 0 13909'. TOP OF REC~TI~ 9 8~27'. TOP OF IST LZ~ RECEPTI~ 9 13993'. ~T ~/ 10~ BBL C~S "G" 1% C~2, .3% ~ 9, .1% ~GL. DISP~ MI~ 10 BBL H20 & 336 BBL 11.~ ~. B~ PLUG ~/2500 PSI. FLOAT ~. FIN~ CIRC PSI 1800. ~C TIH TO 8388. ~~ ~ TO 8626'. ~T ~ FOR ~T CONT~INATION. TEST~ CSG ~ ~GER TO ~000 PSI. TA~ ~T ~ 1380~'. ~IL~ ~T FLOAT EQUIP, CIRC BOTTO~ ~ & ~T~ ~ FOR ~T CONT~INATION ~ 1~002. SET P~ ~ 8071'. ~~ TEST~ ~D. DRILL~ ~T TO 15369'. CIRC & R~D CSG SC~ ~U ~ ~E P~S ~ILL BE SET ~ CSG P~FO~T~. DIS- P~ 900 BBL ~ IN HOLE TO PITS MI~ $~ ~AT~. CLUED PITS. HI~ 10.0 PPG ~CL2 H20 ~/100 PPH SODI~ NIT~TE ~C~. DISP~C~ S~MAT~. ~ CET/CCL/~& ~ s~y_ s~ .~o~ ~o. PROD. SnLY S e0u P. ~~ ' ~'t~ST~ TBG TO 2500 PSI. ~ ~ ~Y & lNG COL~ L~TOR TO V~IFY ~ DEPt. DISP~C~ ~CL2 MATER IN TBG M/NI~OG~. ~ BOP. ~ ~ ~EE. ST~LED FLOM LI~ ~OH ~EE TO CHO~. TESTED TREE, V~VES & NORELCO LINES TO 10000 PSI. ~LD $~ETY ~ETING. DROPPED GEOV~ DETONATOR B~. TESTED MELL. COU~ NOT OP~ FLOPE~OL CIRC V~VES. ~ ~ BOP & TEST. ~ BOP & TBG SPOOL. INST~L~ PLUG TBG ~G~. ~ BOP. TESTED BOP. C~G~ RING OUT ON ~t' KILL LINE V~VE. TESTED BOP. RIH M/~T RETAINER. SQZ ~T (~ BBL H20 .~ OZ ~6L ~ OF 9.2 BBL C~S G ~T M/.3% ~9, 1% C~2, .&% ~6L FOLLO~ M/5 BBL H20 ~ 187 3/~ BBL ~CL2 MATER. PIPE S~CK IN RETAIN~ ~T~ SQZ. RIH & FREE POINT. ~T S~E INSIDE PIPE. S~CK e 16852'. RIH MO~D TORQUE ~ HOLE & SHOT AT 1~82~'. POOH ~E W SHOT. RIH MOR~ TORO~ & SHOT ~ 14800'. MOR~ PIPE. N~ BACK OFF. PULL~ MIRELINE. REC 70 S~S 3 1/2" DP. TOF ~ ~7~2'. J~R~ O~ ~.~ CONTI~ FISHING. TOF ~ 14711'. ~ :.: ..~..'~ .... ~ .~ '.. · ~ ~ ,... ..~, . . . : · FIS~. CCL/~ 1~820' ~ HILL~. CIRC HOLE CL~ M/HI~ VISCOSi~Y R~I~ OF BP ~ 1~806'. RIH M/CSG $C~~ 0N DP TO 168~ '. SET ~ e 1~0~'. MOU~ NOT HO~ PRE'SS~E'. "':RESET l&08&'. MOU~ NOT HO~. TOOH M/ RTTS. RESET ~ l&700'. FAILED. RU $~L~G~. ~ ~AGE RING & ~ BAS~T TO TOF ~ 1~816'. REC P~TS OF RUBBER OFF RTTS. SET BP 1~812*. TEST~ CSG TO ~000 PSI. SET B~ HODEL F-1 PACER ~ 1~683'. ~ G~ ~Y TO CORRE~TE G~ DEPTH. TESTED PAC~ TO 2000 PSI. ~ ~Y & CCL 3 TI~S T0 C~CK DEPTH. DISP~C~ DIESE RU & DISP~C~ ~CL2 M/DIESEL. PERFED 1~70~-1~71~. 1/18/85-1/19/85 SURVEYED PRESSURE BUILD' UP. INSTALLED AND TESTED BOP. SET BR'rl)GE PLUG @ 1~678'. TESTED CSG TO 4000 PSI. 1/20/85-1/21/85 SET BAKER HODEL F-1 PlOt ON SCiiLUI~ERGER MIRE LINE, Rill #/TBG AND TESTED TO 2500 PSI. TESTED EQUIPHENT. HELD 1/22/85 SAFETY HEETING. PEItFED 1/23/85 TESTED bELL 1/24/85-1/25/85 SI FOR PRESSURE BUXLD UP. FILLED TBG AND CXRC. 1/26/85 TESTED BOP. TOOll 1/27/85 RAN GUAGE RXNG. SET BRXDGE PLUG @ 14533* AND TESTED TO 3500 PSI. SET BAKER HODEL F-1 PKR .@ 14409*. TXH #/ 3-1/2'* TEG. 1/28/85-1/29/85 TESTED PKR TO 1500 PSI AND TBG TO 2500 PSI. RAN GAHNA TO veex v GUS ne TS. TS6 a/ nLS DXeSe . HELD m eTXS . TESTED bELL. . 1/30/85 SI FOR PRESSURE BUILD UP. PUNPED $ BBL AI~IONIUH CHLORXD. 9.5 BBL XYLENE, 9.5 BBL 10Z HCL, 24 BBL 7-1/2% HCL, 18 BBL APIPIONIUI"I CHLORIDE AND 12:3 BBL DIESEL. FLObiED bELL. 1/$1/85 TESTED. SI RU TO TEST BOP. 2/01/85 TESTED BOP, UPPER PIPE ILqHS, BLINDRANS & CHOKE MANIFOLD TO 5000 PSI & ANNULAR PREVENTER TO 2500 PSI.' RU SCHLUM- BERGER & RAN GAGE RING. SET BP @ 14/402' AS PER VERBAL PERHISSION FROI~! BEN LENORHAN. TESTED CSG TO :3500 PSI. 2/02/85 TAGGED BP @ 14;402. HIXED & PUNPED 50 SA CLASS **G** #/ 1% CFR-2, .3% HALAD-9 AND .2% HR6L. SLURRY #T. 15.8. RAN GAGE RING TO 11,750'. SET BAKER PER @ 8910' PRE- Id~ATURELY. 2/0:3/85 ATTENPED TO PULL PKR. PKR & 19'* OF HILLING SllOE XN llOLE 2/04/85 HILLED ON PKR. CHASED PKR TO 12000*. RIH #/CSG SCRAPER ON DP TO 12000** REVERSED CIRC ll0LE CLEAN. 2/05/85 FISHED. PtADE :3 RUNS W/GAGE RING/JUNK BASKET. THIRD RUN #AS CLEAN. RIH SET EAKER PKR F-! @ 11600'. RAN :3-1/2'* TBG. 2/06/85 - 2/07/85 TEST'ED TBG TO 2500 PSI AND ANNULUS TO 1500 PSI. DIS- PLACED CACL2 #/NITROGEN. TESTED ALL SURFACE EQUIPNENT & LINES. DROPPED DETONATION BAR. FLObi TESTED i~ELL. SI FOR BUILDUP. FLOb'ED #ELL FOR TEST. SI FOR PRESSURE BUILDUP. 2/08/85 - 2/09/85 TESTED BOP. LAID D0biN 3-1/2" TBG. RAN BRIDGE PLUG AND SET @ 11590'. TESTED PLUG TO 2500 PSI. CHANGED RAHS TO $** AND TESTED. 2/10/85 TAGGED BRIDGE PLUG @ 11590'. PUHPED 24 BBL H20 FOLLObiED bi/ 50 SA CLASS G #/ .3% HAl:AD 9 & 1% CFR2 & 2 GAL/10 BBL HR6L FOLL0biED BY 6.5 BBL H20, DISPLACED #/ 150 BBL 9.9 /GAL CACL2. APPR0X TOP OF CHT @ 11296. PLUG biITNE$SED B~Y BOBBY FOSTER (AOGCC). SET PLUG ~2 @ 8517'. PUHPED .~ ~.%. ~ ?. ~..~:..' .... ~',~: .... '.~.:'"~?'~ ':~60 BBL H20 FOLLObiED BY 100 SX CLASS G #/ .3% HALAD 9 & ~ ~ :~.. .. '" :' It CFR2 & 2 GAL/10 BBL HR6L. FOLL0biF, D BY 6.5 BBLS H20. : . .. '~./,:.. ":. '..i'~". .. DISPLACED #/ 96 BBL 9,9 #/GAL CACL2. APPR0X TOP CHT @ ...... 8190'. PLUG #ITNESSED BY BOBBY FOSTER (AOGCC). SET PLUG ~3 @ 2900'. PUNPED 60 BBL H20 FOLLObiED BY 125 SX ~ "~.. 'PERNAFROST 2, FOLLObiED BY 6.5 BBL il20. DISPLACED bi/ 10 BBL 9.9 #/GAL CACL2.. APPROX TOP CHT @ 2610'. SET PLUG #~ @ 380'. PUHPED 60 BBL H20, FOLL01~ED BY 125 SX PERHA- FROST 2, FOLLOL~ED BY 6.5 BBL il20. DISPLACED bi/ .5 BBL 9.9 #/GAL CACL2. TOP OF CHT 110'. REVERSED CIRC @ 110' REVERSED OUT APPROX 2 BBL CHT. ND BOP. ARCTIC PAC SEAL #1 bi/ 230 BBL H20, FOLLObiED BY 33 BBL DIESEL AND 115 BBL 9.5 ~/GAL ARCTIC PAC. 2/ol/85 2/02/85 2/03/85 2/04/85 2/05/85 2/06/85- 2/07/85 2/08/85- 2/09/85 2/lO/85 BF-57 NO. 1 WELL HISTORY TESTED BOP, UPPER PIPE RAHS, BLINDKAltS & CHOKE lqANIFOLD TO 5000 PSI & ANNULAR PREVENTER TO 2500 PSI. RU SCHLUll- BERGER & ILa, N GAGE RING. SET BP @ 14402' AS PER VERBAL PER/IISSION FROH BEN LENORIIAN. TESTED CSG TO 3500 PSI. TAGGED BP @ 14402. HIXED & PUHPED 50 SX CLASS "G" W/ 1l CFR-2, .3~ HALAD-9 AND .2~ HR6L. SLURRY WT. 15.8. RAN GAGE RING TO 11,750'. SET BAKER PKR @ 8910' PRE- I~ATURELY. ATTEHPED TO PULL PKR. PKR & 19" OF HILLING SHOE IN HOLE HILLED ON PKR. CHASED PKR TO 12000'. RIH W/CSG SCRAPER ON DP TO 12000'. REVERSED CIRC HOLE CLEAN. FISHED. HADE 3 RUNS W/GAGE RING/JUNK BASKET. THIRD RUN WAS CLEAN. RIH SET BAKER PKR F-1 @ 11600'. RAN 3-1/2" TBG. TESTED TBG TO 2500 PSI AND ANNULUS TO 1500 PSI. DIS- PLACED CACL2 W/NITROGEN. TESTED ALL SURFACE EQUIPIiENT & LINES. DROPPED DETONATION BAR. FLOW TESTED WELL. SI FOR BUILDUP. FLOWED WELL FOR TEST. SI FOR PRESSURE BUILDUP. TESTED BOP. LAID DOWN 3-1/2" TBG. RAN BRIDGE PLUG AND SET @ 11590'. TESTED PLUG TO 2500 PSI. CHANGED RAHS TO 5" AND TESTED. TAGGED BRIDGE PLUG @ 11590'. PUHPED 24 BBL H20 FOLLOWED W/ 50 SX CLASS G W/ .3Z HALAD 9 & 1% CFR2 & 2 GAL/10 BBL HR6L FOLLOWED BY 6.5 BBL H20, DISPLACED W/ 150 BBL 9.9 /GAL CACL2. APPROX TOP OF CHT @ 11296. PLUG WITNESSED BY BOBBY FOSTER (AOGCC). SET PLUG #2 @ 8517'~ PUHPED 60 BBL H20 FOLLOWED BY 100 SX CLASS G W/ .3~ HALAD 9 & 1~ CFR2 & 2 GAL/10 BBL HR6L. FOLLOWED BY 6.5 BBLS H20. DISPLACED W/ 96 BBL 9.9 #/GAL CACL2. APPROX TOP CHT @ 8190'. PLUG WITNESSED BY BOBBY FOSTER (AOGCC). SET PLUG #3 @ 2900'. PUHPED 60 BBL H20 FOLLOWED BY 125 SX PERItAFROST 2, FOLLOWED BY 6.5 BBL a20. DISPLACED W/ 10 BBL 9.9 #/GAL CACL2. APPROX TOP CHT @ 2610'. SET PLUG #4 @ 380'. PUHPED 60 BBL a20, FOLLOWED BY 125 SX PERHA- FROST 2, FOLLOWED BY 6.5 BBL H20. DISPLACED W/ .5 BBL 9.9 #/GAL CACL2. TOP OF CHT 110'. REVERSED CIRC @ 110' REVERSED OUT APPROX 2 BBL CMT. ND BOP. ARCTIC PAC SEAL #1 W/ 230 BBL H20, FOLLOWED BY 33 BBL DIESEL AND.115 BBL 9.5 #/GAL ARCTIC PAC. RECFIVED MAR 2 7 1985 Alaska Oil J Gas Cons. Commission Anchorage .___] CJ P'OJIMAYII:BdAI, q IYlIIA"3~IIiI,I,. AND PIIOBABLI IsROOfI,IC'FI~'I'Ff OI:U~IIIPT[O~ Oil CIMll£ . Cl4~. &l; re co. red" ~$ '~" BtECO'It'. ~ s'h'z M ~r~s~ ~Sr. : . .. .! · · , · m - COil C oft OITC~ 'r.~or lo s .. i ,, (. .J CUr f~,. RCc:. ._J LLI U') I II IE~OV.i i,N.D i'C AT I I:REI~ jroIIM,A'rI. ONA~ STII'Ub'~UN,AL 41dO iI'II~B&'~LI; PIIIO~4,1~rl. Vlll" o.rr,,~QltiPTION 43,.11' ~,OII1¢ GIL.-- GA~ i. · ,1, 'RECEIVED ,v~ 1' 9 1985' Alaska Oil & Gas Cons. Commission Anchorage , - WEEK ENDINO SHELL WESTERN E&P -INC.. -' . ": .. · · -".. CORE ./RECORD .i./;i....---::'-:.'..-. ' RRER OR FIELD. ~~"?-f'~,,~ "";"":" COMPRNY -.-d~'/~//~J. CORES EXRHINED BY 7'~,r,,,.--~-~,~a.. J--_~,~ :' '" '"'v," "'--'-"-" - ' 'LERSE RND HELL NO . - . ; - · -: : - -' u... --.. ~. -':., . ' · .:. · · - - RE- ' -' ' " · NO. F'ROH TO COVERED . FORHATIONAL. STRUCTURAL AND. PROBABLE PROIXJCTZVITY DESCRIPTION OF CORE · '." ' " ' " .... '~ :::"' ""':":'-" ; :': '" ' i ' "-." - .. - '""" .i" ". . //.~,~,/~.';4'. - · .. ~", ~,~, ~,.-. o-c~,,,2~... (~.-~,~ ..~., y~ ,,.. -' '-: ~'~'~'""'"' :. .. _ " ?' '¢ ....... "" · -- ' - ~"'~, . .' . ' ..' : . ' '..:."..: ':: . . ,~ . .:'~ '~. .'....-.~. t,,fT',:-'-.:. ~:: ........ '.":. :; -:~-.".:! ..' '~...-. . -'~ . -...:. -,ii,~. .....-.. - .,. ~-~ - . '.. ...~:0~.. ~' ~~X.~ · ,~'.~... 'x~ ',". i.". ':";-...:.' · ~ ~\-g.~ ' . ,~, · '. _ ' .' ..~..:-':~.._:. ;-:.'. '_.-. '.-.)...,.~.,..-....,o..¥~..'~_.. ,~',,,,-,k /~.". · ' .' . ""','-,, · ~',~.' "~~ ":.~\',._:.:'.L.'£:"* .... '" .... .~...:¢._.,....... .,.,..,,) . e_..,~,,,,,~_~ _ -....,-.,.- ¢,.:/~ ~._ ~/~---,,,,/~...... C&¢....J-, ~.~,~--: .-.--.-~: ,,'-~.-... .... ,... .... ..,.. A'~%~'v' ' .-- -' -' /-.-' ..' - '~ :....-:.-....-,:.::-::;...: :,~ ~ ?_ ;.,_.: ;;.~< ,. .. ~ :.. -~~.~.,vi,'~r'~ ... ' '"": '.' ':-'. '~T-~~ ~0,~ -~ ~:~. :-~_'-. d~.-..~.O.otO:-2- ~;..,~-~-~.'.:::-,, -_~.'.. :.-,.....? ...-... -- '~"""~'"~;" ':"" "" ':'¢' "' -" ' '"' "'"'; ~'~"~ · ' ,- .. -..-.:..' ': - :.:.-.., ¢,,,. ;.~.-".:'!~..-:.~(:, .-.',~.~../,,~- ~./'~,',~ ,,L~.., - _ :, ¢~..,'./-..r'~ ,~,.-~,~.".:-' ":" '--: .-,--..-'.:~:~-,:~:---..'.-;::-~::---"--:~',,%-.'--:'- ." :- - · --" -' ..._. ..... :.,.~.~.. .. . .....-....:-:....:...~..:.;~._,-:?_.,....:.~::;?..............._...... .. . e'~ ':'";:"- ... ....-..-.. - ' ' - · - . "'/' ~ L~:'_--~.:.:,~ .:.:'.-¥"-~,t,-.'~.¢.,.. ':.~.-,..-~t?:..:~ .~-. ~, ..... - . -.'- .- '-"-;': '."' :. .' :' ZA" '' ' ' ~:~' '~-' ";' -"~ '"";--""1':?- " ::'""-:'-' ::' -:" ~; ;"":"~';"''~' ':' ' "";J" -. A'4~g.~, ~e ~;-:i':2 ' ,,~c,",r r~.,c.,~ ~ -' ' - '-' ,,' -;-.'.~.&... :;:::"}_..¥.-~;-:-?.?'~'~;"._'-".;'-::?;--'?-. :.';,~;!,~ ~i '. '. :.. .: "::-:'," .... '"-' :.."-. '.'i .... - .. :: "' ~?:'/?'.----:::i;';:!~?.¢".-:"??-..i~!f.':;:;!i. ' .. ' .- ." ': ':'.-': .... ' .,., " - :"-' .-. " ' ' '" '-.. -. '-'. '-': ...';. 0,' . :. ' - ' ' ' · ' ' ' '%'~,~, i':," ~ :'-- :'-'..¢ F '"'-': -, -.. :.:: ':---~;. -,f..."%:: -.-';,'% ' -.' ' - . : . - .. ~ ,.--.-~ :. - ..- .:.. . .. ~- -.-.,~ ,.: .-... ~ ;:. . · . · .. . -- . · - .~ ~.... -.~. ,t -, .. ...... -, - - .~ ~...~ - ~ . '--" '-', ' - · - · . · ' -.- :-F.'- ;:.: :-' ¢ '..:- '-- . -'..:";' ;.-;"..:.e .'.~.~'.-;'--;, -', ~ ' -... .. ' :...... ... .: .- .. .. .. ~ .¢;::-":--.'.--. . .. . . , :, -'- -' -- , ,.-,-.--.-:. ;-/':;'L-"i:'i? :'¢ ?--""-.~'~. ,~ . · . . - .". . .- .. " - . . .. '-:'..---,_.~- , f . :.. . · ... ...... . . - .: . . . . . . .. _ - : . - , . . . - -. .. . -'. _ _ ': .. ... · .. . . i..':":' ~- i; ' -.. . : . . · -. .,-. - ', .' · " "" '"-"--" ' '- i:.'-':.: !-'. '" - ... ,. -.. . .. ::.- ..... .'..'-;-:...-'.' . ;-.". :- .. .... --.. -:_ .. "' ' "'- .... -?'--'"-::,': :'-'- i'-:' ? ........ · . . . .... '...-....:. ;-i,!:.!..::¢ ;;i.-'i; i -.: i '.: .. ...... . ' '-. · ..... ' :.:V'. ':'". '.--,' '..,.:¢-:.;- , . .. .' .. .:,. , .. ' .-. $~1 C-CLRY OFt SHRL.E (~ O-S;~). I-CL.R,Y OR SHRL.E; HITH ~ $T~$ (~dt,NO S,-'~). ~. 2-'I~.AY OR ~ R,'4) B/WD ($R/4) ~.-6C,',~). 3--SIWiD NITH ~ STRF,,~$ (SAHO eo--m)',cl. $-SA~I) (eO-lO0]Cl.- - ,-. . .' . .. .: .... ......,. .....- . .. :... '-'" .... NOTEs $140# FLUiO CONTENT-AS- IN STANDARO LEI~ENO. : :: - · .'. . . ? - -' -'" ..... .. .. ' '"' """" -. - "'-: "::-:"i--- i:_-.:-.<~'::.-.i~,;~/:-.i~?~::--;.':;.!'-::.:::.';' ~:.,--. -.. i.'. , -' ' _'.': . " ' SHELL WESTERN E&P INC.' '- · '. .. ... -- .. . .. WEEK ENDING" --CORE"- RECORD "-.-': '" .. .. CORE FRON ' ' TO /".~,,~.Z//' ~,-..-~.....: ... ..... '... ' ,'""~i' ." ~_,_:.-~.~" '.. ,~-. - · =~..... - . . -..,,,;.- :~.'._': . . ,;. ~ . ,~..~,.'. ~, CORES EXRNINED ~r,~,d",~ '-' ' LERSE RED HELL NO,.~'~'~~,~' : ..' . . NO. FROH ..TO COVERED ... FORHATIONAL, STRUCTURAL AND PROBABLE.PRODUCTiVITY DESCRIPTION OF CORE 'e'I'HBek ...--.. - . .. .. . . , - . '.'~..-. - .... . . . : · . , · . . . .- .'.. . . . . . - . . .. .~ - .. · . . . .. . · . .'. . . . .. · . . -.., ...--... :'.. . -. '.',. -.. .. . .' . . ... .. . : · . _ . . . . . ....' .: . . .· . ' ' ' . . - °. .- . ' " . . ' ' · . ' ' ... _... 'i"-'i . . . . . :.'..~':. ' .. .. .. . . . . . . . .o . .. ... .. · . . . . . ~ .... . . . ... . . . _ . . . . -. _. ..- '.. . . . . -.. . .. . .. . .-.?... . . - ...... · ... . . . ... .. · . B ' . . ' ' ' ' ' "" ' ' ' .' .' .... .~° ' '" ':" ' ' . . ' . . '. -. ... '. ' ..... . ':_. .. "~'.. , -. . .' ... .. . ,, - , . . : "' 'i .... . . 3. .. . .. , .' .: ._~ . -~ . '_-:' . : :' . . . . .~.. . .. - .. '.-.. . ~ .. . .:~ .... · .~ ~-~.... . .: SYHBOLSI. C-CLAY 0R SHRI.E (SI'IN.E O-SC), I-CLR'f OR: ~ .HITH ~ S,TRE/tK$.. (8FI/4)1 S-L)S~, 2'CI.A¥ 0R SI'VILE ~ ~qHD (8/IHD ~S-~OXl, ~"8711ID HITH SHItL.E . GTRF..AK$ (GAl'iD 80-80,4). G'SAND (80'-100'4;l. " .,' -.: ...,., ..~.,.._ . .. ' · .---." :- :. .- - ----'-:' .'-"--'i: ~ NOTEs SHON FLUID.CONTENT AS. IN 8TAJ~ARD LEOEHD' ' ....-.. : .. ;....-..- . ._. i.... . .. · . .. .:. ..::., . .. :'.' ,. : . . .... . . - . . - _ . . _ . -. .. .° ::'"~-' : '"'~' ~ '- :;" '" -. ".-' >' ' ' ' '-! ...~ .' .'i::-" ' ' ' ' .-:_-' _. :." - . . . -~ . '~ .-:. ! · . . - - . .. : - "eORE'FROH '/~Fg~" TO ?V~.o,e"-. :':'-:.:7- '~":i-:..'-.. '."-- . .: '. :.-~-:________._ __.:--__ _ ____ ' . . . .- ,~_[..'.: .- . . : ::- :- --.:. -. . - '~ · .... · : :..f"qnc],c'c2 :'~Vf:lLilTId~'l'l ....... - .... .-.:: -. --'.. ". .-. .:.:~le~l~i--~l~ ~.iAflI'I&I~C-L? ~ -.- __: . flREf OR F!ELD COMPflNY ,--¢'/-,~E,,~· LEfSE fiND HELL NO.. ,-, '$YIIB~SI C-CLAY OR SHALE (SHALE O-S~), I-CLAY OR SHAI. E HITH SAHD STItE.~S ISAHI) S-~S.~), Z-CLAY OR SHALE ~ S.'U4D (S~ll) ~S-80~), 3-SAHD HITH SHOE z '-"' ':: GTI~AKG (SAND 80-gO',O. $-8/~1D (80-100',0. '.. - ........ . NOTEI SHOH FLUID CONTENT AS IN STANDARD LEGEND, .. -. · :.. ~ COVERED · .- OIL-OAS :" ~- --::",-:.. :--"-.: :'~:' '-' ::-, " ' , .... '-' CORE OR DITCH ':"'"':'"~:"::' :":"::-""~' ...(::,:.: ::: /~,~,~, /~,~,~¢ //. f¢ t-.. _:.:.:: ;.:-: % :.,,¢,: :"-:: ¢,,..,-,"',- "' -' '- _._ ' '"' !" .... ' ' ": ' 'A ~. r--r-. :'.-.//: ':?::. .':-::..i :. ..'..:.':... . ":'-'...'-.' -.'::. ~ "': ~ :'. .: - >.. :,,:.-/-/:..:: ¢~,,¢,. ,',. ~- . . - . .:~ ~+'~ .~¢,,,; , "-'-.: ' -."' "~-' --:,~,- .,,,,.~-,,.,.:-:~,:~ :..-.., .:t-.--..-.-.--?. .:' '---.':'. i-'-.:,_-:~: .'"-.. ' ,~,-~:,-',:'/,-/'5-0V.'/,0:,,.' ~------.'-.- .... -, ~ .~ ,.2' ""'--, "'¢¢ ' ,=~ ~ ,,,,~ .~.r . ,' "t-: ' -. _. ...' . .:-..'.:. ~ -I '"/',..~'",¢,.~ ' .. 't/ , ,, . ..: ..... ..:-- ,.?..--.- ...~ -- -.. lV.~o / .. ¢". ".::.'i..::.'..-;'-...':!-'. " ' ' - -7 ~- ; ':- -:''~:': ' " · ' ' ' · " -. ' '" - ' ;.,.':..':... :?..,..:.:. - .., ....... .'..- .?..:. :.. . .-:,.-....::, .:.. .- ._... ......;-,, ',~,,., .. . . :.-....-.. :.-.......- .-.. ;~-:.,'.:.::_. ~o~ . . ,,v-.,~ 7'--- f~ e ~..:... :..:..:'-.-:-:ii--- :, "' :.' .. ::..:~::::.: . ;.-. :--:. -.. :.. :.'-.' ..--:..'--:.::.;:-.....;. ,-' . · .',':- t'!:.... -.-> ..:- . ' ' --- -' - ' . . '. - '.' .. . ._: , .:..._,~. :. ~ . .. .:: .. .i'il .. .~.. .-..~ . .-... . h.. ~:!::,.: ~ - -.. '. ' '- . . :.:.:!-~.':-: :'~ '"' .'i'. '.' ". -'. . :'... )i ..-: . _ . .:.:: ?:.-.- · :: .. .... . .... .. . .-' ,':i' - '"' ' °' " .... . .... .. -. .. .. '.. . ::.:: ::.?~ . . .. ... : .'"' '..~ :'~.. .~,-~ . . .... . . ' . ~ ""~"'-:~ :'::~'' ' ' ~:... - · -.i~ --'"~. -. ~':~.'-:'?.':::'::'. '"!'!:'>"_'": : '- "; " . . ...... ' '" ':' "'-' ' .'" 9 198§: :-'.~:_. .~..:...-:.~. ..... . .... M^~ 1 '-. .~...-:.- .:. . .--. , . - .. . % - -. .y. '. .~' . . ' - . , :'.':..:;.:i.:..> ?.': ..i!' ' '! :!'' . . . gla~ka .0ii &:Sa -'Cons. '00hmi~$loi~..:-. · .. . -. . . - .... ..' -'.. :... . · ""--" ' " ';~neh0ra~o'--.' '-:' "- ' ' ii."?::, .. ........ . . .: - .... ~...:-...... :. ...... -.. -.-i,..,:.: .... ~. -.'~-: -...-......., . . . , . . ' ~:" ' · ~...7--.. .'"'-':.}..;~ .... . .. -. '"" -. . . " .:": '-- '- " ' ., ....... ..-~ ...- . . .. '.-_' .. :':,- '-- - "" --" .: :~ ': "-'-'-' :' '.. '.. . ._;; -': . ..-.- ... .'.' :. . .: ,-. . , .- ..-....~...: ... .: .--'~'--'_-:t _'_:' : 'i-:----'!': ':: ".: '..:' i! ! ~: .... :~' :~. · . _ .. .-~-~ . . . .... ':. - .. ":'!""" ':'"-' ~""' " "" ' ' ' ' ' ' :7";;t.:' " ' " · .:':-:: :~-! '.: .- . -:: ."-: :... ~-?:'. ..,.. . .. .. . . . ..,.:.::::::,:,:-:-. ..... .. .. .. ... . .. .... ....... · :-.,. ': .... " .. ':'..i.. . . :.... . .._..... - .. -.-- .'.- -'-' . _ .. _.. . '~:'::..':-i-:i, . i'-." ' .... '-" ' - ':" :" ::- -'i':' '-.': :' ' ' .... .,-.: - :..-:... - :?-: - . .. .... . !i ' ' :"" '" ' ' ' "' ' · ' L i'. "'":"':" ..... " ' ' -"' ' .... . : . . . . . . . · -.. . . - : ' ..: : '},' ' · - I' ~ · · ' '. :,.' ' . . . ::' ::.}' ':.. i':ii' :.-CORES'.: EXAM I NED BY Z i~J: ~-'J~O_~? ~ t ~ ~_ "~::-:_ ..-- . .?.. :.:-.. ' .. AREA OR' F ] ELD~\-~'~, '~-,;- ~ ~; \ COMPANY.. '~h~>'A": . LEASE AND HELL NO. ~';"~'~"~:~ ~ i ...... :... - ........ :'--.. :': :~. _/-,.;,_.~..i:. "-/.?;-: ~: :'.'..~ .:--~.:'..': ~...::: ........ caRE - RE- ' ' DIP OIL-OAS NO.::'. ~ TO- COVERED :.: -..-.--' .. 'FORHATIONAL-, STRUCTURAL. AND PROBABLE PRODUCTivITy DESCRIPTION OF CORE 8YI~OL. OBSERVED INDICATIONS ',.'--'~ .:::~:i:.: ¥.~.:?::::-'~'-~:- · :: '.'-:---"~;' }i '.i- L~. i'i'~:.'-.' '-~:..,: - :.":'-: ':'-': '::::-'-": '..':'.:::.:'~ CORE OR DITCH ~,~." :::'- -. . i i :"'::'-"":' \~' ':"~"; , .... '"' '".kx':' "" "' "" ""' :"":'"' ~:~'' ..... '"-:' :~ .... ' ' &r~-. ¢~,e.,,,,,,+. -c::-:.:: ::.- "- - - ..'.-:':"' x"-'. -- .'_ ' -,.-.:..%~:--... 'c,.:..-~- : ""'~ ""-"- ': " - -:' -'1 ~. ~7~ ...'~' '~'~:~,' ~ -:~ -~,e~. e.~\~-~- ~. d ~ ~t ~.' .'".i:~:i::}::i' '.'-/.~:::-i/- '"::":'.'. :~..i.' '-" -'.~e~~::.:i'.,,~l '.-.'-cC..-.-.-e.~ ~c~ .- ~~_, '?'' . '~ '+"+"~ ~ ~,,,'lk/~ · -:'~--~:'?'- '::" -: {"-: ' "~ : "',: . ;" ~-~.4'~- .~:.X,.', :-'.'" ':":":-: .-.-~ ::'-~'- .... '?::..... :~ . --. ,'..".. '~-~-~%~.,. -N~.. '~/' ~-'~- ~.~., i:::..'.::,.?._-> ..,.-i.~.?.. ,.-::..'.-;.:.....-.:.:--::. :,. . ... ,,,c~-,.-:~..~~.~w:.:...-~-~\\ .... -. ~ ... ...' :::-?,' '.: : ~- I::fi'(~ '..- .... ' -:'.-' ...... ::- - -.'.' -_' ;-." :-;-:-':'. i'- '-:'-'-,":-.:~: :12:-' .~, - X!. . _' ' . . - ' ' . :~:-:::?:"? -:;'::,,.::-::: ,~gW~' -.-"/:' .~'~'-'~-'~%\~'~?~~'-'-!~! ~;-:?~'-'-'.'~" "','. ~.' -o '.'- , ". " i ..... !:.:./' ! .::':.._.-.i~..-.~ '-:.' :': -~,<- N' ,,. ' --. .... -)~-..' 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""-:",-' ".'- -. '7'~'"'.'k~~\~,~,~'~-:i- -".:~-CL ~:,-' :---e, _ ' . ~ "· :" :"'"'"'"'-' ~':'"'~ -~ .... ":' · -" :'"' .'-' ' ' '- ' ' ' ' : ' - ~' ':'"' ~'A~"~:'\\~-Z~,'~ '¥\O~g. ' :-'.'~::'~!'-~-:~i!i'i?-i'~' :-' !-'-.-.-' . ':'~!-.- '. :-':'.': :.'--..-'- ".". .... . ---::'~:' ":'-.:'.:.'_--' ."-/~':- -':. ::.:":. :'..-.' ' . ' . ' . -.-:-:-~ % ~,:.:::--'-.';~', .. :-:- . ..: ..._. .-i-_-:~ .._.:.. .:..... .. ...... :. . . - . ..- . . · '- ::-:: :~' ~" ,~'~t I! . :.'.i_' .. .c. -': ..'.;'":..-.,i:. ...... ' .'. - - '. - - .... --' -8~t C-Ct. AY OR SHALE (SHALE 0-5%). I-ClAY OR SHAI.E: HI'TH SAHI:) STREAKS (SAHD 5-2S%). Z-CLAY OR SHALr AND SAND (SAND 2S-60'X). 3-SMID HITH SHALE ' z ..... :.: · GTREf~'G (SAND 90-90*4:) S-SAM:) 180-100~) ~ -.':- .: -.-.-: _... · ·, -...'.. ,:::':. ...... ;-:._,, .:~-.:;.:,' '{_'...:......-:.. -. .. ..... . . NOTEI. . ~H0ll FLUID 'CONT£H' AS Ill STAHDARD LEIIEND. ~ a '~~~~ AREA OR FIELD COMPRNY-~-,<;::"T:-~ ,f'e~./ ~ CORES', EXAMINED BY ~k%~.:'~J~ ~.,,,,-~-.~,.~o,.;4~.,v e::'.' ' ';- :-"':':...:"' ' . '- ' · LEASE AND WELL NO.~ ~-~h ~t · - -; - ~,.~-.-'~5'. r,f,,e,..-z(,, q" -- :'0 ~ · ' -- ~ "!"1l" --T I I · . · -:" ' ,'-'-" - "--' - -',':':.i:.:--i~:.':" -'.:::--:-.':-:. · -".. ':'. ' ".- '- .- ' mSERVEO I.OlCATIONS · 1~;'i:. M TO' RE- ': FORHATIONAi., STRUCTURAl. 'I~iO PROBABLE PRODUCTIVITY DESCRIPTION OF CORE ' COVERED -: ..... . . DiP OIL-GAS -::: ' -:'i::: -'"'! *.' CORE OR DITCH .i;' .... ::.i::''':' - ---' , .'.. :: ~ · - :- . ..-. . . .,, . . i . .-'.::ii.::.: - .- i.':: '- - :--" - :.;':.-:-:'~:-:...,_"-'-~i~;: ::--.-'-.:-'-:-:.. -'::--. '.... ..' '- _. . . . . 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'.. .. -.. - . . --. :.:,:.- . :: ." .. ... . .:.,-. .. ... . &~~' ~' ...... . - . - . -. . .. . _,,~.v~ , .-''.- . . - · ~. . . - . . . - _. .- .... - .. .. .- . ~~, ~', , . :.'- ..- ~ ,.. -~: . . - . '- .- . . . . "~' ... .... ... -'~~,~,, ~~,.-.--:-:.- .. _ ..... . :.. .. . .. . .-'.~-~~-. ~,p~~. ~~ ~%~., -;~,.',: "..:" ."".:-:' ..-. ~.. "-.. . ~ - L~,.~&- ..~ ~. .. . .:.- ...:.. , .... ... - .. . ', - _ . ' -"-:'-"-:..-:':.---:-:.-:': '"' .......... Y'~:'-~¢~'Y"~~'~~~- ~ ~,~-L~ ~ '.::,.:..:,:: ,.: :...... - :,.:..: .".:::~.~.'.'.: ~ ,, - . ,..'.. _.~ ..:. -."..:~.-.> .?>... ..:-:~.'.. . . · ,_ - : - .:..--:. .. . . SYllM31.$1 C-CI.AY I~ SHALE (SHALE O--5X). I-ClAY GR ~ HITH ~ $TREAK~ (SAND S--2SX). 2-CLAY OR SHALE AND SAND (SAND 2~"-60X). 3-SAND HITH SHOE ~ .' · GTRERKG (SAND 80-90',0. S-GAHD (80-100',0. NOTEI SHOH FLUID CONTENT AS IN STANDARD LEGEND, -.. -': i?'::i-"HEE~?'ti~-~i'~¢::'KI~111~' &:'~ll~lm~'~"~:~:":i"i"?:!i::-:'-:::.!:i'.::-CORE. i-: RECORD ' ". . .RE~ OR FZ'ELD Se, L- :ES.. BF~5?*I "':::i:::: }{CORE:':':FRON"I~5~ '":"' :'": TO-lq~,q~ .-.-'."::::" m m "i. ".". :.:~:(~ r m ~ ".(::~KC ,/ I(~/~ e i ~ . ~~ LERSE AND HELL NO, I~F-.~-/ ~ ] . CORE~;!!'EX~HINED BY'~':I::~-~i~ P;- t_~-- t~^~i.~:. . . :':i:'.:'--'. ' -- .... 0OSERVEI: INOICATIONS :' HO,"'.:' FROH -TO COVERED :.~.. . ~ . -.-. IrORHATIONAL, STRUCTURAl. AliD PROBABLE' PRODUCTIVITY DESCRIPTION OF CORE 8YI~3L DiP OIL-0AS; ~:::.?.:~,:i-"-"i ::~?:i.--~=:::;:~ .~:k!.g .~::' ~ ..' ':':"~::':~i!ii-::i";'i: -'-' '< :.'- · :.':-h .L ':..-.:C- -'-': ~' '- .... .-':'.', ;" ./:.-' - . .- .. ' .... - .: ' -. CORE OR DITCH i i ..' .. . -... . ~- '- ' ~ . ./ ~=¥~=N F'/..~o~. .... -- .. ... - -. sr~g~ '""::::;~:'""';: .%:.....:. ; -..:."'"~':'"':'"'~":.. .?,:. :....:.:- -',:," .~t~.~t~; TK~<,tc'~Lc~c~=i~N,/~X-~ ~P~P, ITf=.. ~lnt c~ CeK~O~/' fO -I~o vt~~ ~ ~. ~- ::/-:':.-~L : '."-': .... ' -":-" "(~,:~ ~ l~q ~ ) " r~s~~ -.....: .. -.'~ : .. :.-. . . ... . .:._...~.:::.:_.:.... [~S~ :':-:-: -'"~- :::-_ ' " -., :-.'..-.'--. ' : ::"-' -- . ..... .-.-.. :....... .. . .-.-: ........ -...-.....:.-: . .:~:_ '.-..: . ;.. ...... - _.. ..... ... __ ::-:--.:.~,,....-:.. .-:?. ::- ~S~'s .- . ~,~.,,~:' 0~,~--'~'u~,~::':~,~,~~ ~-.~,e_ ~s .'~ ~-. ¢~,r.~~ ~.~ ~~,~,.'~° - ~.~ ~. .... · .--~::~-:v .... .- -:~:::.~lq~q~-~t) ~.cH ~/~. ~~ toro ~ ~~ ~. ~ ~,~ 54~~ ~r~ ~r/~ ~ ro '?':~..::~:;:::~:?. -- .:......- :"::~' : :;'" ..... '" HI~ I -:.:~.: : '::' ' ":'-- -- -.." 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F4~Nr s~r ~< .... ~ , --.-..?. ~ue. uP~K~ F~.:P~B~:~ o~...~~ ~-~,~n~~~ ~lu~ ~ Lo~ . . . i i i ~....._..:... ~'I'~DL.$1-C-CLAY OR SH/~E ISHALE O-SC). I-CLAY OR ~ 'HITH SAI4).$TREAKG (s.q~ S-25%). ~.CLAY OR SH/~E ~ ~ (SAHD ~S-60',C!. ~.SAHD NITH ~..IALE .......~:: ......... . GTREI~'G (GAI~ 80-.00:0. G-SAND IO0-100~I. . .'F~!-'!!:.;': ~'-~iii!'"':ii!iiiii::/i~! : : '.::: . . .. -_ ..--. .. ... . :..:.:.? .:'-'"';'"' NOTEI SHON FLUID CONTENT AS IN STAND/IRD LEGEND, - . ...- . .. : · ... _ "'0 .. . .. .. ' -'. FOIU~TIONAL, 'sTRUCT~" Nil)' pROBABLE PRODUCTIVITY DESCRIPTION '.':/~/.-......} ~..-.~ ..... , ..... . . .:~>:..,,. ~.-.: .... ~'--..-.........-., .... . . , ,~ ~... .... ' ' --~' .o~~v~ ~v~'.. ~u ~...~- ~ ~ ~ P' - ~- ..... ;..:. ~.. '-..-'.: ... .L.' -.. ..-. ':.-::.;.': . '.". '"-. :.-:,:_.:LX-:::: .-. .. . ':&. ~Z~~ ,~:. ~~~'-::~-:~~-~,~e~-'~. ~~.'-... ..'"._~ '... ..... ~: . :'.~...'..... -. : .. .. - .. . · . - ...'.... . ; :~-- -.. ~... ...~: .- - ..:. : .- ,~. ,. ~ .- :-:- -. -: -. . . ._ . ~ . & L:{"~ ; :' ~ , '. .... -.:...... -...: :' ... . ?.. - .. ._ : :} '- :?-.: -.. :::~ · -." ~.: : .. : .... - .. ~,~. . --/ . - .: ...... . . '-. . . :. ::.--'- .-..:-,.... '.. -.: .... . ?~:~:~:'..::'~..-..._:...'..'-:~.....:..:~:.'.:}:_.:...:~.:..-.: ::..-...._? .... --:~.:../.:?./::..:.-........~?::-: ..-' . ..... :..?..-._ :..-~:-_.~_..-.~{-:.:'-.::_-_.. _ '..--:.:?/~:,::.-~': ... ~ ...... :...-..-- .[. ~-;. ~.,' · . }" . ' . . . '.. '. . . · . j'. -, . .. . · RREa OR FIELD-~c~'':-~z' ~$' I~ICATIO~ OIL-OAS CORE OR ~m6 ~ r ~ L~ ¥~L, ~'~L~ Re.~i ~u A' .. · . .- . .- .,.~:.:.._.... :,. ::.:-:. ,.-.. . . :, : .. .- . : r .?:".'{. '::.':':"':'!-' .::"i i~:}"i:'::--.'. ' .... :? ,',' ~{'-- :' -'--?, '-' :. .-" "' -'- ' '- -.: ,~_~ '--'~'---.. .- ..____-___-==... ,.., ;-~,,,. 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Z-CLAY OR ~ AJO ~ (SAND ~-60'A). 3-~ID NITH SHALE .: .... :'-':.-:.,_. · .... :. -': ' - ~TEs 8~N FLUID C~TENT RS IN STRNDRRD LEDEND. . .-- ;-. :. ] -:?-. .- -.: -. . . . - .... .- .-..- .. -} .. .. . .. . - ..~:~..~:...'., . . ~ ..:. :. - ..... - . ' .... . . -: -' " O~ERVED INDICATIONS . .. CO.RED ~ - 'U:':¢.-'~."-~;:-~:~.~:;- .~:'.~:'~-.:-~:'~' .- : : ::J::--'-;'?:;':':":" ...:: '. --' .:- -_:-. :?:~",,": ...... ~-,:--~-'.,. : .. CO~ OR DITCH .. :,.:-.;-.:~: -.--:'-.-.--.. .-.. .- ... ..... _. - .... :- ...'. .. A~ ~ ~..v-' -'-'. ~ j-- · ...... .. -...- . . ...:. -y. . ' . . [.. ~.~ .. ~. ~-~ . ....... '...~ . . ... ': :. ~.~ '?"~..~.' .... ::? .-.- ...--. -..~.. .':... .---' -, .':- -:.....:.: ....:--.,: -.-..-.~ ..- .'.-_.' %-._-~ ....~-... . .... - - .. , - . . . ~ '. .~ .-.. -~- - ..~ - . . . . . . ';': ;;:"-' ' "~";"?::" :'-' ' " -:'::'-- ...... ' --~q~XT~ '~D ': ~F4~ l ~G .-.. ."-i-?i.':;-' -..-i-:;~':':'-' .... ... i' ': :' :"':.' '? . ~--..~?..;: '-"::~j .. . . . -.. ... ... .~.. ...2 . . . . '}~. RRER OR ·FIELD .%E:;~ :ES. ~F-5""/~'~ COHPRNY $-~, F::::."P...~-_... LERSE RND HELL NO. E~F'-f:',5"'/MI ! f I "~[ ],d' ' ' - ' '!' '" .... ' "' ' ' ' ' ... ' '- ', - '... ..~% ·: · :' .' '.-/' .' : .~: ' - · - .- · . C~ ' ' ~ INDICATIONS i'"N0~:¢;-!:: .... :-._" "FRQH:.;' '::' :"'" ~."" T0-" :~'"~'" '"" '- '~ :';" '-" .'~' :~' "F~AT'i~ ~sT~~L'~-A~' ~A~E-~O~T'IVITY DESCRIPTI~ ~ ~RE - . :. COVE~D :'.'_--'-.. DiP OIL-OA~ '-.. . .~: '.:-.'. -,::.'~::.:~:~'-. ~ ~:.--- . :,~.--: ," ':' ". '-"];':. ........ : ~'.---.::':.--~.--:~: ~ .:'¥.-'.': .'-;, : -. ..... CO~ OR DITCH . --. ' - - v, ~ ~, ....~ .. ~. ~1~6~ '":-':--.- "TO ~,8"-~ve~t~ 0,~' ]~ ~t~~ '~6~~~ ~T ~ ~C ~~ :-./.:':-:: . .: ~ .... , · .; - . .:"'~C¢;'" "~'- ":: ."- '- "-;;.--]-.-' ' :" ' ' · · "-' ~ ~.~ .. LT, ~e~. .,,...:,,:::...... -?:;::::':~-.;...,... "?~:..-::~...._...... , -;':'.::,.- TO_SO~A .~E'-':?'A~'~~;%~'~6~o~. ...-. sP~ ~ ~e~;._: , ~~. :...- . . .;.:..<... -:~'~'.~:'~::':' .-....:....;... .- . ";~ ~RI~:~"-'~o~.. ~... .~T' ~C~~ ~oO~S~~. V~ ~~ "-:- ::';': :":'. " "'" -'-- '""R~~-'~ ~L~V"T~AU&eARe~F ~e&~~~ tO~ ~ 15~ ~/~. ::...,. ~.....:.:.?:._. ;~:,~.,.~..'~.? ...:.~.:.~,~,~ ¢-. :.:::.... ..-.'.:-:-. . :-..-.. :... .. '.Le"<;:.' ~-~;:''.';'~:7': "'~6a~ ~) ~]q.3,--.:-;i46~SL~-..'.--¢9¢~ 'q6 ~ =~ o¢ ~¢~. F/~t~ :' ~o F~, ':';:"?-:;'~- -':;~:'.~-~;'- '.~~.~"~;".;.~-¢~"';.:~:~ ~¢'~. ~'~ ~ C~F ¢ ~/O . ..... :;, ~-,~* ~.,:-:.~-'::..- .. : .. .... . . . --.': :.:';.'>:.._., ,...:....'. ," ~;'l';-:....;- ...., :..,~.--,,~,..,.-. ::.' ...-- . ,....:~..-.. . .:' . su~ ~ ~g~]~:.... F&~~~ (~). - ~o.. e~ ~~ ¢~og. flo ¢~ - . · ..;,.,.;.. .........:.,.... .o,~,~-,~e~;~,:~-A.~~.~ ~. n~ve; ~o,~~. s,~,~ ~~ ~ · ~-:-: .... ' :"" ....... ;:'" -G~~% '&~nm~:~~~~ 9RKI~ ~ .Iq~,5, 5~ OR ~S .v~s~ ~ .~~ -:' ..-': .... '.~l "' .' '::-~os~T~, s~y, ~L~ ~~ ~k ~o ~A~ ~0~. ,ve~ " ....... ';'-;:--~ Y~¢ ~ ' ' :(-~:~_?~;. . -. ..... .. . ,,-_ . . ,.. - .......,. . ,.. .... . ._. .. ...:......-. ': :~?.' :' -. .... · . :-..-. ~:.':~ - '~ ::. . '- : ~ .. ?. - . . . ... ..... ...... ? ~'.~'-~ :.-~ ~ ..... ..?: ?~:.,.. ...:~. '~ ~:~::-. ~--~ ~ .' . . . ':" . .. .. . .~ ~. .~...~ .~ :~.::. '~ ....... .. ' - ~" ~ - :r~' ~ .... : } . : ~-%_:~.:~:~ ~, :. ..~ .:~.- .~ :-~.: ~..'.-. ~ .". . ~ ~. . . ._~ ..~ '. .. ...... , :' --.'-....,.. ~.-.~: ..... .::_~; ..-.-' ...-: ... ~ ~ "~.. ' : . ..~.- ~?.-~ ,-,::'-.---.'. SYHSOLSt C-CLAY OR SHALE (SHALE O-SX). I-CLAY OR SHALl FilTH SAND SI'RE~S tSNiD S-2SX). 2-Ct. AY OR SHALE AND SAND (SAND 2S--60X). 3-SAND #iTH SHALE :~ {'.,"!-.!?':'.-;.__ - -: -STnEm<6 (SAte 80-00~). ~.-mmD (8o-ioo*,c). NOTEI FLUID CONTENT AS IN STANDARD LEOEND. - . . - . .. : '.';~. "- :-C' ,-' .'::'¢?'-:.-'¢'ii'-" .. ;'{?_-?-'_-.?..- .-:'.}--/'. -.:-: ...~ -~..---~:.~ . -. - i" '.'-.' -.¢.-i~:-::. 2'/ -.::.-'-! i"./.i - ~-- .._.}-.. }...) ., ..-..:-%.-:-... . . ~..:... · . ..'. -'-.. . · .. 'i'.:/-i} '.'i- '. ':'. . :.;:~:. ... ::...: .':,. ?...:-. .') ~:. :..~. . ~ : J--;!;: . . · . ... -- ..- ~' ... -. ..-:.. .. '"' ~ i-:. · .'. ' :: i'.!::/' f-.?"-'i~'-' .:- ..- . .".:..2 -'.. i.' '- -.. . .--. 0 '~-'' . . "-2 ~'"'i"i' "' -. . ~.. ~ ~ .i'-'. . ' ' ~' ';;::':":i: ':i.;.~:8YHB(X'~I.~ . .STREAKsC'CLAY ORiSNqD~IALEgo_goxiI~IAI.E, $-~qJqDO"5~), I-CLAYiso. IoO.4iOR,MIM.E HITH SAND SI'RE/UtS (~U~D 5-25~), 2-CLAY OR ~H/U.E AND ~ (g,4VJD ~5-60X), $-5JVJD HITH ~IP, I.E -'. .-.:.:.. :' .--' NOTEI ~.ION FLUID CONTENT AS IN STANDARD LEGEND. · .. . . -.. · Il I I I -::~.-'--i;"~ ..... :: "-~' ..... CCN~ '/~:: :¥'-~ . .. ~-:. .... :-~.'.;:. ~:;i.;:.T:--: iii'-::--"-. :!-,.-..-:: ;--.:-"..-':':?-. ?--:;i~ ~! '!'i-,-~ -- :' "- ':-: '~: ":--: " ' - C3BOEXYED INDICATIONS 'NO;'i:.- FROM -'TO' COVERED :-:-'-~;'.-;-'-:', '. :i'.'" FORHATIOHAL'. STRucTURAL AND 'PROBABLE 'PRODUCTIVITY DESCRIPTION OF CORE 8YHSGL DIP OIL-GAS '-.--,' .~:'-:;~:: '" ' :~' .' .?'.'-~i¥:-:.~-, ~'. ':: :- CORE OR DITCH . ......~. ~ -:;':"~:'-'"- · ~.....~ :.~:.- . , · -. .- . .. .. ' i ---.~vc~.~.~. o.,,, -,::.-~,~r,~i' ii's.:.c~:,';s-r' s,p~o,~,, u.'~. ,, F,~-.-.-o ,.~,.,, . . -'-. ..... ii · -: .... ': ' :-" -:'~ '- .... , -. .. -~-.;.~:.~=.?:( .. . .. _... ..... ... ............... .- . .-. : .... ~ .................................. ' " '.~:..'? :;- ~-;~-F:ff; ...... '::':&;;;~-'- .-"':';;;;': ~'~';; ~';'-f'"~".:"- ......... ~ ...... '~"? ....... ~'-'~ ......... ;" ................ ' ........... '"' ' ..................... ~ .......................... - . 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'- . . . ~ . . . .. .. .. . - . .._. . .' . : .. . -. . . .. . . .:.'~ . . - . . .' . .'. . . . . . ... . . . '. ~ .- . . .. .. . . . - . . . . - . - . -. -..' . . ..... . . . ~ .:f.~ . .-.. . L .... . - ~ - :-. "'"' ~ ~ -~,..'. iC~'~- :-i-.> ~,"/-~'*~ ~*',y ',~~ . ~ ~ ~ ~~ ,o~,..'.? - ~ ~- ~ "'~~"°'~ .. . ' ~'*~ "2 .' ---:":':""..... ..'::. ..... ,":~ .... :'-::-'~ :% ~m ~'~ ....~-~'. _.~-~. ~o~. . ~,~. ~. r.~_~,~,~. ,,,,/:: ~ '"' ' -""~~ .... ,:-~~-"~.. . . . .~' ~~,~,.., . ~ ~'1 I- I ! ~'.'::--. .... :::. ~,,, .. -.-. ~~'-' I I I- I :-- '- '-'""'~*~ ~~. - .. ~: -..-- . ~-~?~.: ~.- . '.. . ..... . . . I [ i ' ' ': : ' ' '" . ~- . :'. ' . . :.:~._ - ~ ~. ...%~ ~ . · , -~:~ : . . ..... .. . -. . . ._ -;~¢ .. · . . . - . '. -~.? ~ .: . - -. .. . . -. .. ~ . . -. . , -.: _ ., , ~ I I I ,,,,,, .- : .-' ".. PRIVATE AND CONFIDENTIAL SWEPI ET AL BF-57 NO.(.~ SEAL ISLAND PROSPECT BEAUFORT SEA AREA NORTH ALASKA DEPTHS Sagavanirktok Colville Pebble Shale Put/Kuparuk Kingak Sag River Shublik Sadlerochit Ivishak Shale Echooka L i sbu rne TD 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 3/13/85 MD 5,428 8,554 11,245 11,574 12,110 14,207 14,332 14,470 15,048 15,205 15,250 15,455 PUT/KUPARUK CORE DEPTHS (DRILLER'S) 11,699-11,760' Cut 6~', Rec. 55.5' 11,760-11,794' Cut 34', Rec. 33' 11,794-11,808' Cut 14', Rec. 10' SADLEROCHIT CORE DEPTHS (DRILLER'S) 14,475-14,488 14,488-14,494 14,494-14,508 14,508-14,548 14,548-14,583 14,583-14,644 14,644-14,668 14,668-14,685 14,685-14,716 14,716-14,721 14,721-14,741 Cut 13', Rec. 8' 3" Cut 6', Rec. 2' 5" Cut 14', Rec. 11 9" Cut 40 , Rec. 32 Cut 35 , Rec. 26 Cut 61 , Rec. 60 Cut 24 , Rec. 23 Cut 17 , Rec. 14 Cut 31 , Rec. 29 , 3" Cut 5', Rec. 6' Cut 20', Rec. 19', 8" RECFIVED 10" 9mm , 11" ,6" ,6" 1985 Alaska Oil & Gas Cu~,s. Commission Anchorage TVD 4,763 6,942 8,836 9,057 9,423 10,866 10,944 11,028 11,370 11,462 11,490 ~11,605 Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. oi=rE~TdR, 'WELL NAME D ~UMBER Reports and Materials to be received by: ~5-- /~--~~ Date Required Date Received Remarks ,~:' ~.~ ,,~ :,~ · ,,.;~ ..... ,, , 5': ;'[~" 7', :" '.?' ' ,' "'. '~. / ... .::] .... :.: , ,.......:.:..., ~:,.....,:,,, Samples 7~-~/' -~/-- ~~,t, 0 ~ ! Registered Survey Plat Inclination Survey~ ~ ../_ ....... ,, ~ ' '~,.., "~ ~rectional Survey '" ff t .... ;.'~ , ...... ," :7''~'' ~'.'~::.~a~, .' fi' .- . .~- .... Drill Stem Test Reports .... ,~' ~..,,.,., ff . ;.~' ~..~, ~..-. Production Test Reports ~ ¢~ Run ~ ...~ ...... _/ , -, ~P-1048 (REV. 2-84) SHELL WESTERN E&P INC. PACIFIC DIVISION P. O. BOX 527 HOUSTON, TEXAS 77001 TO: Alaska Oil & Gas Conservation Commission ATTN Mr. Bill Van Allen 3001 Porcupine Dr. Anchorage, AK 99501 Date 3/14/85 Transmittal No. PD- Subject: BF-57 well DTNA 6347 Express Mai 1 We transmit by QUANTITY DESCRIPTION OF ITEM 1 Core Description the following.' REG. NO, DISPOSITION list of 9eologic markers Sepia of all logs (including mudlog) - see attached list (2 pages) BLP of all logs (including.mudlog) - see attached list (2 pages) Senderpnature Above ..... items received, except as noted: ~' ,~~~'~At:~ "///L/'q/~1 < Date, Naska 0it & Gas Cons. Commission Anchorage WHITE (ORIGINAL) --ADDRESSEE (RETAIN) YELLOW (1ST COPY) --ADDRESSEE (SIGN AND RETURN TO SENDER) PINK (2ND COPY) --SENDER'S "HOLD" FILE March 11, 1985 Shell Western E&P Inc. A Subsidiary ol Shell Oil Company 200 N. Dairy Ashford P.O. Box 527 Houston, TX 77079 Alaska Oil & Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Commission Gentlemen' Attached are duplicate copies of the Monthly Report of Drilling and Workover Operations for Shell Western E&P Inc.'s Middle Ground Shoal Wells A44-02 and A34-11 and Seal Island Well BF-57 No. 1. Yours ver~ truly, R. G. Hollis Manager Production Administration Pacific Frontier Division RGH: ff Attachments RECEIVED MAR ! g ]985 Alaska 0~! & Gas Cons. Oommission Anchorage ",r. STATE OF ALASKA ALASKA ~' _ AND GAS CONSERVATION CCI[-- .vllSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ,1. Drilling well Workover operation [] 2. Name of operator Shell Western E&P Inc, 3. Address 601 West 5th Ave., #810, Anchorage, AK 99501 .4. Location of Well at surface 1541.5' FSL, 629' F[L, Sec. 11, T13N, R13E 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 55' KBJ Anl 7. Permit No. 84-93 - 8. APl Number 50- 029-21130 9. Unit or Lease Name BF-57 10. Well No. No. 1 11. Field and Pool WILDCAT For the Month of February ,19 85 2. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded 7/9/84 Depth 2/28/85 - 15455' TD - 110'PB Footage Drilled - 0 13. Casing or liner run and quantities of cement, results of pressure tests 14. Coring resume and brief description 15. Logs run and depth where run 16. DST data, perforating data, shows of H2S, miscellaneous data 11714-11763' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ' ' "S,~NED ~o~ (h¥~oi~ -rrrLE ~gr. Prod. Adm. DA'rE 3/8/85 ' ' ."'NOTE--Repor 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 Rev. 7-1-80 Submit in duplicate Transmittal #6347 to Alaska Oil & ATTN Mr. Bill SUBJECT: BF-57 well LOG TITLE Gas Conservation Commission Van Allen RUN NO. DEPTH SCALE GCT Gyro Well Survey Borehole Geometry Log w/GR GST Inelastic GST Capture Dual Induction-SFL Dual Induction-SFL (TVD) Dual Induction-Sonic Linear Dual Induction-Sonic Linear (TVD) Dual Induction-SFL Borehole Comp. Sonic Borehol e Comp. Son ic (TVD) Borehole Comp. Sonic LDT/CNL Porosity LDT/CNL Porosity (TVD) LDT/CNL Porosity Li tho-Densi ty/Comp. Neutron Litho-Density/Comp. Neutron (TVD) Li tho-Densi ty/Comp. Neutron Natural Gamma Ray Spectroscopy Micro-Log Micro-Log Cyberlook Borehole Geometry Log GCT Gyro Well Survey Temperature Log Dual Induction-SFL Dual Induction-SFL (TVD) Dual Induction-Sonic Dual Induction-Sonic (TVD) Dual Induction-SFL Borehole Comp. Sonic Borehole Comp. Sonic (TVD) Borehol e Comp. Sonic Gamma Ray (TVD) Gamma Ray (TVD) Gamma Ray/CCL Gamma Ray/CCL GCT Gyro Well Survey Temperature Log Dual Laterolog/MSFL Dual Laterolog/MSFL Dual Laterolog/MSFL LDT/CNT-G Raw LDT/CNT-G Porosity Natural Gamma Ray Spectroscopy BHC Sonic BHC Son ic (TVD) RECEIVED (TV~lSka Oil & Gas Cons. Commission (TVD) Anchorage 0-1,590.5' 146-1,606' 11,650-12,050' 11,650-12,050' 1 , 596-4,990' 1,596 -4,990' 1,596-4,990' 1,596-4,990' 1,596-4,990' 1,596-4,956' 1,596-4,956' 1,596-4,956' 1,596-4,994' 1,596-4,994' 1,596-4,994' 1,596-4,994' 1,596-4,994' 1,596-4,994 1,596-4,965 1,596-4,949 1,596-4,949 1,600-4,950 1,561-3,822 0-4,975' Surface- 14,205' 5,002-11,690' 5,002-11,690' 5,002-11,690' 5,002-11,690' 5,002-11,690' 5,002-11,654' 5,002-11,654' 5,002-11,654' 4,462-14,180' 4,462-14,180' 4,461-14,180' 4,461-14,180' 0-14,191' 0-14,205' 14,302-14,884 14,302-14,884 14,302-14,884 10,960-14,881 10,960-14,881 10,960-14,856 14,302-14,882 14,302-14,882 5mm 5" 5" 2" 2" 2'm 2" 5" 2" 2" 5mm 2" 2" 5" 2" 2" 5" 5" 2" Btam Bm, 5" 2" 2" 2m' 2" 5" 2mm 2" 5" 2" 5mm 2" 5'l 1", 2" 2", 5" 2" 5" 2", 5" 2", 5" 5" 2", 5" 2", 5" Transmittal #6347 LOG TITLE RUN NO. DEPTH SCALE LDT/CNL-G Porosity (TVD) LDT/CNL-G Raw (TVD) Micro Log (PCD) Dual Dipmeter Cyberdip Cyberlook Profile Caliper SHDT Dual Induction-SFL Dual Induction-SFL (TVD) Litho Density/Dual Neutron Litho Density/Dual Neutron Litho Density/Dual Neutron Litho Density/Dual Neutron Cyberlook Cyberdip Micro Log/Aux. Measurements Natural Gamma Ray Spectroscopy Profile Caliper CNTG- Epithermal Porosity Dual Dipmeter SHDT VSP Mudl og (Porosity) (Porosity) (Raw) (Raw) (TVD) (TVD) 4 14,302-14,881 4 14,302-14,881 4 14,302-14,840 4 14,302-14,891 4 14,302-14,902 4 14,302-14,887 4 14,302-14,891 4 14,315-14,888 5 14,302-15,458 5 14,302-15,458 5 14,302-15,461 5 14,302-15,461 5 14,302-15,461 5 14,302-15,461 5 14,302-15,410 5 14,302-15,247 5 14,302-15,098 5 14,302-15,111 5 14,302-15,247 5 14,302-TD 5 14,302-15,247 5 14,315-15,104 5 500-14,207' - 350-15,450' 1l ~ 511 2", 5" 2", 5" 5" 5" 5" 5" 2", 5" 2", 5" 2", 5" 2", 5" 2", 5" 2", 5" 5,t 2", 5" 2", 5" 5't 5" 5" 2" RECEIVED 9 ]985 Abska Oil & Gas Anchorage February 25, 1985 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 99502 Gentlemen: Attached please find three copies of the Sundry Notice and attached worksheets for Test No. 4 on Well BF-57 No. i on Seal Island. Yours very truly, /R. G. Hollis Manager Production Administration Pacific Frontier Division RGH:jc Attachments RECEIVED C,. & Gas Cons. Commission AnChorage RGH60562 STATE OF ALASKA ( ALASKA rOIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WE LL .]~ COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Shell Western E&P Inc. 84-93 3. Address 601 West 5th Ave., #810, Anchorage, AK 4. Location of Well 99501 1541.5' FSL, 629' FEL, Sec. 11, T13N, R13E 5. Elevation in feet (indicate KB, DF, etc.) 55' KB 12. I6. Lease Designation and Serial No. ADL 312gng 8. APl Number 50-029-21130 9. Unit or Lease Name BF-57 10. Well Number No. i 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 [] 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). ~.) 'B~e" .................... ~n Verbal approval given for attached procedure by . LeNorm .,'1/31/85. .%]~se~tuent Work l~portecl 14. I hereby c~tify that thej~oregoing is true and correct to the best of my knowledge. ' /7 2/ Signed , Title Prod, Ada. Mgr. ~:j~_ v ,. ~1 --~ -- The space below for Commission use Date 2/20/85 Conditions of Approval, if any: Approved by ~pproved Cof~y ~eturned By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-S0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate PROCEDURES FOR TEST NO. 4' . Make up and strap equipment to be run below the packer. Carefully measure from the top perforating shot to the seal assembly locator shoulder. ITEM APPROXIMATE FURNISHED LENGTH BY 3-3/8" OD tubing conveyed perforating guns loaded with 22.0 gram RDX charges, 4 JSPF,'90° phasing, guns loaded to perforate 25' interval from 14,497' to 14,522' GeoVann Extended firing head and no-go 5.5' GeoVann 2-3/8" EUE tubing subs 30' GeoVann 2-7/8" EUE x 2-3/8" EUE crossover 1' GeoVann 2-7/8" VANNTAGE ported flow sub 1.75' GeoVann 2-7/8" EUE tubing sub 10' GeoVann 2-7/8" Otis Type R nipple with 2. 125" seal bore ID 1' Otis 2-7/8" EUE tubing sub 10' GeoVann Crossover from Baker seal assembly to 2-7/8" EUE tubing sub (if needed) 1' Baker Extended locator type packer seal assembly 20' Baker Pull equipment and stand aside. e Run and set a 7" Baker Model "F-I" packer (with 4" ID bore) on Schlumberger's electric line. Set top of packer at the measured distance, from Step 1, above the top of the test interval (to be furnished later). . Re-run tubing conveyed guns, tubing subs, nipples, release sub and packer seal assembly. Run in hole to packer with the following equipment installed above the packer seal assembly. DAL22921 RECEj\/E'D Alaska Oil & Gas Oofls. Oommisslon Anchorage ITEM FURNISHED BY Crossover from seal assembly to 3-1/2" EUE box (i f needed) 3-1/2" EUE (AB modified) tubing joint Baker 3-1/2" EUE bundle carrier for Flopetrol Johnston Type SSDP electronic gauges (with two gauges installed) Flopetrol 3-1/2" EUE (AB modified) tubing joint Two annulus pressure operated circulating valves set to open at 3200 psi surface pressure (4.75" OD x 2.25" ID) 3-1/2" EUE (AB modified) tubing joint 3-1/2" Otis type XO sliding sleeve (shift down to open). 2.75" ID SWEPI .......... Flop ,, ,, , , ~':, ~,' .... t',,.~ Otis RA tagged pill in top connection of sliding s 1 eeve 3-1/2" EUE (AB modified) tubing to 2000' from surface 3-1/2" chemical injection sub with two 10,000 psi WP check valves Stainless steel injection line to surface 3-1/2" EUE (AB modified) tubing to surface Flopetrol SWEPI NOTES: a. Tubing is 3-1/2", 9.3#/ft., L-80, Atlas Bradford modified EUE. Tubing and subs are to be drifted on location before running into the well. An Atlas Bradford service representative is to be on rig floor while tubing is being run to inspect the connections, install the teflon rings, apply high pressure API modified thread dope (#72732) and monitor make-up torque. Recommended make-up torque is 3200 ft-lbs. It is important that the collars be doped on both sides of the teflon ring to prevent galling during make-up. Extra teflon rings should be on 1 ocation. b. The distance from the packer seal assembly locator to the connection containing the RA tag is to be measured. DAL22921 c. The Flopetrol SSDP electronic gauges in the bundle carrier are to be set for a delay of 30 hours. One gauge to sample at 2 minute intervals and the other gauge to sample at 3 minute intervals. e Run in hole to packer. Land locator seal assembly in packer. Space out for 5,000 lbs. slack off weight. Pressure test tubing to 2500 psi surface pressure. Rig up Schlumberger and run a through-tubing GR-CCL log to verify that guns are on depth. Rig down Schlumberger. . Pick tubing up out of packer and displace CaC12 from tubing with diesel to 500' above the sliding sleeve. Land tubing in packer. Install Cameron Type "AP-FBB" extended neck tubing hanger with dual control line prep. Connect chemical injection line to one control line port (Flopetrol to furnish required connections). Land tubing hanger, screw in locking screws. . Install back pressure valve in tubing hanger. Remove BOP assembly. Install 10,000 psi WP x-mas tree. Connect surface chemical injection line to control line port in packoff flange. Remove BPV. Pressure test packoff flange and spool flange connection to 10,000 psi. Pressure test x-mas tree to 10,000 psi. Pump small amount of glycol down the injection line to be sure injection sub is functional. . Re-check all surface facilities and hold safety meeting prior to perforating. . Rig up GeoVann.' Drop detonator bar to fire guns. Open well for clean up flow period. Follow procedures outlined in the Production Testing Plan. NOTES- a. If guns do not fire, refer to attached procedure for gun failure. b. If acid stimulation is required, acid treat with 5000 gallons of 15% HC1. g. 10. 11. Abandon the zone as follows: Set a CIBP above the packer. Spot 50 sxs cement above the CIBP. DAL22921 When testing is completed, dispose of produced fluids by pumping down tubing if practical. Kill well by bullheading down tubing with 10.0 ppg CaC12 brine (do not exceed frac gradient of 0.83 psi/ft.). ...... Install BPV. Remove x-mas tree. Install and p.~)~e~§~u'..~e~'test".BOP Pick tubing up out of packer and circulate 10.0 p. pg.Ca'Clp Shut down and watch for evidence of inflow. P(~'OH"i'.wlil'.th subsurface equipment. February 19, 1985 Shell Western E&P Inc. A Subsidiary o! Shell Od Company 200 N. Dairy Ashford P.O. Box 527 Houston, TX 77079 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen' Attached are duplicate copies of the Monthly Report of Drilling and Workover Operations for SWEPI's Middle'Ground Shoal Wells No. A34-11. and A44-02 and Seal Island Well BF-57 No. 1. Yours very truly, R. G. Hollis Division Production Administration Manager Pacific Frontier Division RGH'ff Attachments " STATE OF ALASKA ALASKA(~' AND GAS CONSERVATION CO( IlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [~[]X Workover operation [] 2. Name of operator 7. Permit No. Shell Western E&P, Inc. 84-93 3. Address 8. APl Number 601 West 5th Ave., #810, Anchorage, AK 99501 5o-029-21130 4. Location of Well at surface 1541.5' FSL, 629' FEL, Sec. 11, T13N, R13E 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 55' KB ADL 312809 9. Unit or Lease Name BF-57 10. Well No. No. 1 11. Field and Pool Wildcat For the Month of Oanuar~v ,1985 t12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded 7/9/84 Depth 1/31/85 15455'TD - 14678' PB Footage Drilled - 0 DP stuck @ 14852'. Rec. 70 STDS DP. Jarred, milled and fished. Top of DP @ 14816'. 13. Casing or liner run and quantities of cement, results of pressure tests 14. Coring resume and brief description 15. Logs run and depth where run Gr/CCL- 14704-14714 Gr/CCL- 14497-14522 16. DST data, perforating data, shows of H2S, miscellaneous data Perforated 14704-14714 14570-14620 14497-14522 RECEIVED F E B 2 6 1985 ~aska Oil & uas uo.s. C0mmissi011 "-~~. Anchorage' 17. I hereby certify that the foregoi[~g is true and correct to the best of my knowledge. DATE 2/19/85 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 Shell Western E&P Inc. A Subsidiary of Shell Oil Company 200 N. Dairy Ashford P.O. Box 527 Houston, TX 77079 January 24, 1985 State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99502 Gentlemen- Attached please find three copies of the Sundry Notice and attached worksheet to cover the temporary abandonment of Well BF-57 No. 1 on Seal Island. Very truly y. ours, R. G. Hollis Manager Production Administration Pacific Frontier Division RGH :jc Attachment RGH60241 e£CEIV£D JAN 2 9 ]985 'Chorage C°~missioe ALASKA(" STATE OF ALASKA ( ~L AND GAS CONSERVATION COwlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL COMPLETED WELL I-I OTHER [] 2. Name of Operator Shell Western E&P ]'nc_ 3. Address 601 West 5th Ave., #810, Anchorage, AK 99501 4. Location of Well 1541.5' FSL, 629' FEL, $ec, 11, T13N, R13E 5. Elevation in feet (indicate KB, DF, etc.) 55' K.B. 6. Lease Designation and Serial No. ADL 312809 7. Permit No. 84-93 S. APl Number 50- 029-21130 9. Unit or Lease Name BF-57 10. Well Number No. 1 11. Field and Pool WILDCAT 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [-I Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other CJI 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 REC£1vED .LAN 2 9/t985 alaska Oi~ & Oas co~s,. Anchorage 14. I h~rti?/th~J~:~tr~d~t Signed'~/~/'~ /~ Approved by, · lllll!l'l'l,q [ tl.Y I'I)Itl~IE C. SMITH to the best of my knowledge. Title St, Stf. Env. Engr. Date 1/23/85 COMMISSIONER Approved Copy Returned ,.., By Order of the Commission Date /' ~O '-0c~'~ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ! , S?ATU9:~9 6/8" to 14280', ?"'liners 4~0~15¢55,. -Test interval, abandoned - retainer and 50' of cement above uppermost perforations at ll?14,/ll?es' -lO ppg CeCIl brine tn wellboro. PROGRAM: l) Notify the AOGCC prior to abandonment procedures as they may wish to ~ Withes0 placement and testing of plugs. 2) RIH open-ended with drillplpe to 85S0' and pu~p (JO Bble, of fresh water (3000 lineal feet in O 8/8") ahead of 100 exs, (04.0') of Class *G" neat with ~ C~-e followed by 8.8 Sblu, or fresh ,ate~ (1000 lineal teat ~n drillplpe). Displace wl~h 47,1 Bbls. of b~lne for a balanced pluE. ~OH, ,, $) RIH open-ended with drillipe to'1.2900, and pump 80 Bbls, of fresh water (1000 lineal feet In 9 5/8") ahead of 100 axe. (290*) of Claes "0' neat wlth 2~ Cat12 followed by 6.8 Bbl8. of fresh water (~oo0 lineal feet In drlllplpe). Displace with 10.4 Bble, of brine for a balanced plug, POOH to 880, and pump 40 Bbls. of fresh water ahead of lO0 axe. (290.') of Permafrost II cement, Follow cement with 1/2 Bbl, of fresh wares for a balanced plug (does not include cement l~ne displacement). Clean out. surface plug to 110' (20'BNL), 4) ~Dump 15 sxs. of CaCl2 down well and d~splace O 5/8" x 18 ~/8" annulus with 250 Bb,ls. of fresh #atm.,followed by 115 Bb3s. of dlese.l (o000 lineal feet), 5) Rig up lane from cementing unit to 9 5/8" x 15 8/8" annulus on well #~ (0C$-Y-181 No.1) and pump ~$0 Bbls. of water follbwed by aS'Bbls. (500') of' diesel followed by 118 Bbls, (2000') of 9.5 PPG Arctic-Pac. Follow the ease procedure fo~ well #! (BF-4~ No,l), RDMO. 6) Place tags on all wellhead valves to contents of annulus, 8R, DRIBI, ING 8UPBItINTENDBNT m ."~as~,a Oil & Gas Cons. Commi~iofl Anchorage (' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CL~MMISSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL COMPLETED WELL [] OTHER (::] 2. Name of Operator -<;hell We~t~'n F&P /nc 3. Address 601 West 5th Ave., #810, Anchorage, AK 99501 4. Location of Well 1541.5' FSL, 629' FEL, Sec. 11, T13N, R13E 5. Elevation in feet (indicate KB, DF, etc.) 55' K.B. 12. I6. Lease Designation and Serial No. ADL 312809 7. Permit No. R& 8. ~,PI I~t~mber s0- 029-21130 9. Unit or Lease Name BF-57 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 Duplicat6) Perforate [] Alter Casing [] Perforations (-] Altering Casing [] Stimulate ,ri Abandon [] Stimulation [] Abandonment r'l Repair Well r-I Change Plans D Repairs Made [] Other [] Pull Tubing r-I 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 end give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). See Attached RECEIVED JAN 2 1985 Alaska 0il & Gas Cons. C0mmissi~n Anchorage Sign~ 1 Conditions of Approval, iflany/. to the best of my knowledge. Approved by. g~IGiNAI, SIGNED BT LOlt~liE C. SMITil Title Sr. Stf. Env. Engr. Approved Copy Returned ...... By Order of COMMISSIONER the Commission Date 1/23/85 Date _ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ~. 6'r-No. 2, STATU9:~O 5/8" to 14~60'. ?" liners 8427/1645B., -Test intervals abandoned - retainer and 60' of cement above uppermost perforations at 11714'/11703' -10 ppg CaCl2 brine Ln wellboro. PROGRAN.' Notify the AoGcC prior to abandonment procedures as they may wish to wltneso placement and testLnl~ of plugs. 2) Rill open-ended with drillpipe to 85S0' and pump 60 Bbls. of fresh water (1000 lineal feet in O 8/8") ahead of 100 sxs, (84.0') of Clams 'G" neat with l~ CFR-8 followed by 8.8 Bblu. of fresh water (2000 lineal feet, tn drillp.~pe). Displace with 47.1 able. of brine for a balanced plug. POOH. $) RIH open-ended with drillipe to'.2900' and pump 60 able. of fresh water (1000 lineal feet in 9 5/8") ahead of 100 sxs. (290') of Claes "0" neat with z~ CaCl2 followed by 6.8 Bbls, of fresh water (2000 lineal feet In dr/lip/ps). Displace with 10.4 able. of brine for ~ balanced plug. POOH to 880' and pump AO Bbls. of fresh water ahead of lO0 axe. (290,') of Permafrost II cement. Follow cemeut with 1/2 Bbl. of fresh wa~e~ for a balanced plug (does not Include cement l~ne displacement). Clean. out. surface plug to llO' ~ . 4) Dump 15 UXB. of CaCl~ down well and displace O 8/8" x 18 3/8" annulus with 230 able. of fresh water,followed by Il5 able. of dlese} (ZOO0 lineal feet), 5) Rig up 1Lee from cementing unit to g 5/8" x 23 8/8" annulus on well #~ (0C$-¥-18~ No.~) and pump ~$0 able. of water follbwed by ~8 Bbls. (500') of' d~esel followed by il8 able, (8000') of 9.8 PPG Arctic-Pac. Follow the same procedure for well #! (BF-47 ~o,1). RDNO. 6) Place ke~s on al! wellhead valves ~o contents of annulus. JAN 2 9'1985 1/85 TAS~ AlasKa OiJ & Gas Cons. Corrimlssion Anchorage January 9, 1985 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, Alaska 99501 Gentlemen' Attached are duplicate 'copies of the Monthly Report of Drilling and Workover Operations for SWEPI's Middle Ground Shoal Wells No. A34-11 and A44-02 and Seal Island Well BF-57 No. 1. Yours very truly, R. G. Hollis Division Production Administration Manager Pacific Frontier Division RGH'ff Attachments RECEIVED Alaska Oil & Gas Cons. Commissior~ Anchorage '"' 'l STATE OF ALASKA ALASKA (~' . AND GAS CONSERVATION CO{~'' .IISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well~ Workover operation [] 2. Name of operator Shell Western E&P ];nc, 3. Address 601 West 5th Ave., #810, Anchorage, AK 99501 4. Location of Well at surface 1541.5' FSL, 629' FEL, Sec. 11, T13N, R13E 5. Elevation in feet (indicate KB, DF, etc.) 55' K.B, Lease Designation and Serial No. ADL 312809 7. Permit No. 84-93 8. APl Number 50-029-21130 9. Unit or Lease Name BF-57 10. Well No. No. 1 11. Field and Pool WILDCAT For the Month of. December ,19,84 ;12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded- 7/9/84 Depth 12/31/84 - 15369' (TD 15455' - Crnt fill) Footage Drilled - 0 Lost centralizers. Fished w/magnet. Worked junk basket. Mi 1'1 ed and cleaned. 13. Casing or liner run and quantities of cement, results of pressure tests 7" scab liner to 13909' (32#, L-80, 142 its.) Cmtd. wi. th 105 BBL Class "G" with 1% CFR-2, .3% Halad 9, & .1% HR6L. Tested to 4000 psi. 14. Coring resume and brief description 15. Logs run and depth where run CET 1200-11200' CET/CCL/GR @ 15369' CNNF! FNTi^I %,~'~,~1 11 !l,~'[ml ~ I 1~ II~ I,, DE.FINI i ELY ',16. DST data, perforating data, shows of H2S, miscellaneous data Pe'rfed'l' w/4 shots for block squeeze @ 11780' Perfed @ 11700'. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge· SIGNED v ' TITLE Div. Prod. Adm. Mgr. DATE 1/8/85 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 December 20, 1984 Shell Western E&P Inc. A Subsidiary ol Shell Oil Company 200 N. Dairy A~hford P.O. Box 527 Houston, TX 77079 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: Attached are duplicate copies of the Monthly Report of Drilling and Workover Operations for SWEPI's Middle Ground Shoal Wells No. A44-O2=and A34-11 and Seal Island Well No. BF-57 #1. Also attached are duplicate copies of Well Completion or Recompletion Report and Log for SWEPI's C33-26. R. G. Hollis Division Production Administration Manager Pacific Frontier Division RGH' ff Attachments C.ONFID TIAL. STATE OF ALASKA - ALASKA AND GAS CONSERVATION CC( VllSSION MONTHLY REPORT OF DRILLING AND WOR1KOVER OPERATIONS 1. Drilling well J~] Workover operation [] 2. Name of operator 7. Permit No. Shell ~lestern E&P ]:nc. 84-93 3. Address 8. APl Number 60! ~lest 5th Ave., #8:[0, Anchorage, AK 9950:~ s0-029-2:t:~30 4. Location of Well 9. Unit or Lease Name at surface BF-57 [54[.5' FSL, 629' FEL, Sec. [[, T[3N, R[3E ~O. We, No. Nh_ 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. N[LDCAT ~' ~ ADL 312R~q For the Month of November ,19,84 ~12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded - 7/9/84 Depth ~/30/84- ~5455' Footage Dr11led - 734' Logging tool stuck e ~4457' Recovered f~sh. Hanger running tool parted ~ Gauge R~ng e 7925'. Recovered f~sh. 13. Casing or liner run and quantities of cement, results of pressur9 tests ' 7" l~ner to ~5455' (36 ~ts. 32~, L-80 LTC). .Cmtd..w~th 'Howco, 50 BBL preflush, 3.75 sx Class G, w~th ~ CFR-2, .3~ Halad 9, ..2~ HR7 and 4.2 Ga.1/[O BBLS HR6L. Pumped ~00 sx C'lass G w/additives w~th ~5 BBL H20 ahead. Slu~ wt ~5.9. 14. Coring resume and brief description ' ' Core ,,~, ,472~-~474~' , Rec. ,9 '8" CO'N 15. Logs run and depth where run i J ~ m ~ ~' ~ .... DLL/HSFL, LDT/CNL/EGT/HL,. BHC/GR/SP e ~4865' D[L/BHC/GR/SP, D[L/GE/SP, LDT/CNT-G/GR e ~4350' Ran DiD-Log Csg Calip.er ~4250-0'. SHDT/GE ~ ~5~04' ' NGT/PCD e ~5~8'. RHC/~R ~ 1RI~R' .16. DST data, perforating data, shows of H2S, miscellaneous data l't ~, ~ E J ~" ~ [) .." r'~,~:~" ~, '," A~aska 0ii & Gas torts. ', - .. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED , TITLE Div. Prod. Adm. Hgt. DATE 12/12/84 " - . , r NOTE--Report on this form ~s 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 December 6, 1984 Shell Western E&P Inc. A Subsidiary of Shell Oil Company 200 N. Dairy Ashford P.O. Box 527 Houston, TX 77079 L T State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99502 Gentlemen- Attached please find three copies of the Sundry Notice and attached prognosis to cover the testing of well BF-57 No. I on Seal Island. Since we are preparing to proceed with these operations immediately, I would appreciate your contacting me in Houston at (713) 870-4445 with v~erbal appr~oval or any questions you may have regarding the testi~ procedures. Very trulyyours, R. ~. HollOs Manager Production Administration Pacific Frontier Division Attachments RECEIVED DECll~ Alaska Oil & Gas Cons. Commission Anchorage RGH53411 (' STATE OF ALASKA ALASK,. OIL AND GAS CONSERVATION 'LJOMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL COMPLETED WELL [] OTHER [] 2. Name of Operator Shell Western E&P Inc. 3. Address 601 West 5th Ave., #810, Anchorage, AK 4. Location of Well 1541.5' FSL, 629' FEL, Sec. 11, T13N, R13E 99501 5. Elevation in feet (indicate KB, DF, etc.) 55' KB I 6. Lease Designation and Serial No. 12. ADL 312809 7. Permit No. 84-93 8. APl Number 50- 029-21130 9. Unit or Lease Name BF-57 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: (Submit in Triplicate) Perforate J~ Alter Casing [] Stimulate [] Abandon [] Repair Well [] Change Plans [] Pull Tubing SUBSEQUENT REPORT OF: (Submit in Duplicate) Perforations [] Altering Casing [] Stimulation [] Abandonment [] Repairs Made [] Other [] [] Other [] Pulling Tubing (Note: Report muitiple 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 CONFIDENTIAL IND, I ELY RECEIVED DEC 1 11~ Alaska 011 & ~aS Cons. Commission Anchorage . ~rt i~'~i~ ' 14. I hereby, q t the foregoir/g '~'true,end correct the best of my knowledge. ' S~.ned ~~~ ~v~ ~me Div. Prod Adm Mgr The space below for Commissio~ ~W ' ' Date 12/5/8{ Conditions of Approval, if any: ~ ~ss~ ~s ~o 5e ~o~E~ed ~ s~E~ci~ ~ so ~ a representative of the Conmission may witness plugs above-TestS 1, .4, and 5. Approved C~y . ...... "~ ~.,. tllll~:ll/ll. SttllI£1] I~,t,.,~- ,.. ' B![111111£I:. $1111'11 ~~ f ~ By Order of Approved by C~)MMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" i n Duplicate PRIVATE AND CONFIDENTIAL COMPLETION PROGNOSIS BF-57 NO. 1 SEAL A-3 SEAL ISLAND PERTINENT DATA: Elevation (KB): 55' Elevation (GL): 20' TD: 15,455' PBTD: 15,373' CASING: 30" drive pipe to 149' 20" to 1602' 13-3/8", 72#/ft., N-80 to 5000' 9-5/8", 53.5#/ft., L-80 to 14,280' (block squeeze cemented at 11,700' and 11,780') - 9-5/8" is severly worn at 8,812' LINER: 7", 32#/ft., N-80, Primary liner from 13,980' to 15,452' Scab liner from-I~r~B~' to 13,980' ANTICIPATED WELL CONDITIONS ~T~ ~,~c/~':~ .... SBHP g 10,900' TVD = 5320 psi (0.48 psi/ft.) SITP = 2300 psi (0.27 psi/ft, produced oil/gas gradient) SBHT g 10,900' TVD : 235°F Hydrogen Sulfide Concentration in Produced Gas = 5 to 10 ppm ATTACHMENTS: Subsurface Equipment Schematics Pressure Settings of Hydrostatic Pressure Actuated Tools Tubular Sizes, Strengths and Capacities Wellhead Specifications Squeeze Cementing Prognosis for 7" Liner Acid Stimulation Procedures Pacific Frontier Production Phone Numbers Service Company Contacts DAL22921 RECEIVED DEC 1 119 Alaska Oil & Gas Cons. Commission Anchorage CURRENT STATUS: Drilling has been completed. A caliper log run in the 9-5/8" casing showed severe wear at 8,812'. The primary 7" liner has been installed from 13,980' to 14,452'. The liner lap has been squeeze cemented. The 9-5/8" has been block squeeze cemented at 11,700' and 11,780' to isolate the Put/Kuparuk formation. A scab liner has been run and cemented from 8,000' to 13,980'. The 7" liners have been cleaned out to 15,373'. PROPOSED TESTS' It is planned to conduct five production tests as noted- Test //1 - Lisburne Formation - Establish fluid content - Evaluate productivity - Perforated zone1: 15,250' - 15,300' Test //2- Sadlerochit Formation - Water Test - Measure in-situ permeability and skin in single phase - Perforated zone1. 14,787' - 14,846' Test //3 - Sadlerochit Formation - Verify WOC - Test immediately below observed WOC (from cores) - Perforated zone1. 14,704' - 14,714' Test //4 - Sadlerochit Formation - Productivity Test - Measure skin and permeability with downhol~ - Evaluate productivity - Verify fluid content - Perforated zone1. 14,570' - 14,620' Test //5 Put-Kuparuk - Establish fluid content - Evaluate productivity - Define reservoir characteristics - Perforated zone2- 11,714' - 11,763' 1 2 Depths based on LDT-CNT-G 11/13/84 File 5 Depths based on LDT-CNT-G 11/07/84 File 106 RECEIVED DEC ! ,l B4 Alaska u~l m Gas Cons. Commission Anchorage DAL22921 The purpose of this prognosis is to outline procedures for completion, testing, evaluation and abandonment of the five zones of interest. Test No. I (Figure 1) of the Lisburne will be done utilizing conventional subsurface equipment and detonator bar fired perforating guns. Due to the close spacing of the Sadlerochit zones to be tested, Test No. 2 (Figure 2) and Test No. 3 (Figure 3) will utilize perforating guns with hydrostatic firing heads and a limited amount of tubing subs below the packer. Test No. 4 (Figure 4) will also utilize hydrostatically fired guns in conjunction with DST equipment in order to achieve a bottomhole shut-in to eliminate wellbore storage effects during BHP buildup measurement. Test No. 5 (Figure 5) will be conducted utilizing the more conventional configuration of detonator bar fired perforating guns and spacing below the packer. INITIAL PROCEDURES. 1, Run in hole to PBTD with 3-1/2" drillpipe. Displace mud from casing and liner by reverse circulating with clean, filtered seawater. When returns are clean, displace seawater with clean, .filtered 10.0 ppg CaCle brine. .Pressure test casing and liner to $500 psi surface pressuTre. POOH NOTE- CaCl~ is to contain sodium nitrate as a tracer mate~'ial. 0 Rig up Schlumberger. Run a CET/CCL/GR log from PBTD to 100' above the 7" liner top. Run a 5.75" OD gauge ring to float collar. NOTES' a. The quality of the primary cement job is to be assessed before proceeding with completion operations. b. The CET/CCL/GR log will be correlated to the open hole log used for selecting the zones to be tested. The CET/CCL/GR log will then be used as the depth reference for all subsequent perforating and equipment setting depths. PROCEDURES FOR TEST NO. 1: 1, Make up and strap equipment to be run below the packer. Carefully measure from the top perforating shot to the seal assembly locator shoulder. RECEIVED DAL22921 DEC I 1 1!] 4 Alaska 0ii & Gas Cons. Commission Anchorage ITEM APPROXIMATE FURN I SHED LENGTH BY 3-3/8" OD tubing conveyed perforating guns loaded with 22.0 gram RDX charges, 4 JSPF, 90° phasing, guns loaded to perforate 50' interval GeoVann Extended firing head and no-go 5.5' GeoVann 2-3/8" EUE tubing subs 60' GeoVann 2-7/8" EUE x 2-3/8" EUE crossover 1' GeoVann 2-7/8" VANNTAGE ported flow sub 1.75' GeoVann 2-7/8" VANNTAGE hydrostatic pressure actuated tubing release sub 1.50' GeoVann 2-7/8" EUE tubing sub 10' GeoVann 2-7/8" Otis Type X nipple with 2.313" seal bore ID 1' Otis 2-7/8" EUE tubing sub 10' GeoVann Crossover from Baker seal assembly to 2-7/8" EUE tubing sub (if needed) 1' Baker Extended locator type packer seal assembly 20' Baker Pull equipment and stand aside. . Run and set a 7" Baker Model "F-I" packer (with 4" ID bore) on Schlumberger's electric line. Set top of packer at the measured distance, from Step 1, above the top of the test interval (to be furnished later). e Re-run tubing conveyed guns, tubing subs, nipples, release sub and packer seal assembly. Run in hole to packer with the following equipment installed above the packer seal assembly. ITEM FURNISHED BY Crossover from seal assembly to 3-1/2" EUE box (if needed) P ~.~ ~ :$~ '"'"-"" '",. 'ELY DAL22921 Baker 3-1/2" EUE bundle carrier for Flopetrol Johnston Type SSDP electronic gauges {with two gauges installed} Flopetrol 3-1/2" EUE (AB modified) tubing joint SWEPI 3-1/2" Otis Type XD sliding sleeve with 2.750" ID ('Shift down to open) 3-1/2" EUE {AB modified} tubing joint 3-1/2" Otis side pocket gas lift mandrel with casing pressure relief valve pinned for 3500 psi surface pressure Otis SWEPI Otis 3-1/2" EUE (AB modified) tubing joint SWEPI RA tagged pill in top connection of tubing joint GeoVann 3-1/2" EUE (AB modified) tubing to 2000' from surface 3-1/2" chemical injection sub with two 10,000 psi WP check valves SWEPI. Flopetrol Stainless steel injection line to surface 3-1/2" EUE (AB modified) tubing to surface Flopetrol SWEPI NOTES: a. Tubing is 3-1/2", 9.3#/ft., L-80, Atlas Bradford modified EUE. Tubing and subs are to be drifted on location before running into the well. An Atlas Bradford service representative is to be on rig floor while tubing is being run to inspect the connections, install the teflon rings, apply high pressure API modified thread dope (#72732} and monitor make-up torque. Recommended make-up torque is 3200 ft-lbs. It is important that the collars be doped on both sides of the teflon ring to prevent galling during make-up. Extra teflon rings' should be on location. b. The distance from the packer seal assembly locator to the connection containing the RA tag is to be measured. c. The Flopetrol SSDP electronic gauges in the bundle carrier are to be set for a delay of 30 hours. One gauge to sample at 2 minute intervals and the other gauge to sample at 3 minute intervals. DAL22921 me Run in hole to packer. Land locator seal assembly in packer. Space out for 5,000 lbs. slack off weight. Pressure test tubing to 2500 psi surface pressure. Rig up Schlumberger and run a through-tubing GR-CCL log to verify that guns are on depth. Rig down Schlumberger. . Pick tubing up out of packer and displace CaC12 from tubing with diesel to 500' above the sliding sleeve. Land tubing in packer. Install Cameron Type "AP-FBB" extended neck tubing hanger with dual control line prep. Connect chemical injection line to one control line port (Flopetrol to furnish required connections). Land tubing hanger, screw in locking screws. . ® Install back pressure valve in tubing hanger. Remove BOP assembly. Install 10,000 psi WP x-mas tree. Connect surface chemical injection line to control line port in packoff flange. Remove BPV. Pressure test packoff flange and spool flange connection to 10,000 psi. Pressure test x-mas tree to 10,000 psi. Pump small amount of glycol down the injection line to be sure injection sub is functional. . Re-check all surface facilities and hold safety meeting prior to perforating. . clean up flow period. Follow procedures outlined i_n_th, e Testing Plan. NOTES' a.gunIf gunSfail duOrenOt fire,_ refer to atta dll~r! b. If acid stimulation is required, aci 5000 gallons of 15% HC1. Rig up GeoVann. Drop detonator bar to fire guns. Open well for · .:-; .''. ;~'." ,': .. · f~,,~,~ ': . . '~ .-. (,, . ~Cl~,.'re t~ :" " t wi th 9~ When testing is completed, dispose of produced fluids by pumping down tubing if practical.. Kill well by bullheading down tubing with 10.0 ppg CaC1 brine (do not exceed frac gradient of 0.83 psi/ft. ). 2 10. Install BPV. Remove x-mas tree. Install and pressure test BOP's. Pick tubing up out of packer and circulate 10.0 ppg CaCI?. brine. Shut down and watch for evidence of inflow. POOH with tUbingand subsurface equipment. 11. Abandon the zone as follows: Set a CICR above the packer. Squeeze below the retainer until the squeeze pressure begins to increase or with a cement volume equal to 150% of the casing volume between the retainer and bottom perforation. Spot 100' of cement above the retainer. DAL22921 12. RIH to top of cement. Clean out to 100' above retainer. Circulate in clean, filtered 10.0 ppg CaC12 brine with sodium nitrate tracer. POOH. PROCEDURES FOR TEST NO. 2: le Make up and strap equipment to be run below the packer. Carefully measure from the top perforating shot to the seal assembly locator shoulder. ITEM APPOXIMATE FURNISHED LENGTH BY 3-3/8" OD tubing conveyed scalloped perforating guns with 22.0 gram RDX charges, 4 JSPF, 90° phasing wi th Time Del ay (TDF) fi ri ng heads top and bottom. Guns to be loaded to perforate an interval of 59'. 2-7/8" ported flow sub 63' GeoVann 1.5' GeoVann 2-7/8" ported EUE tubing sub 2.0' GeoVann 2-7/8" hydrostatic pressure actuated tubing release sub (1.81" ID) 1.5' GeoVann 2-7/8" EUE tubing sub 2.0' GeoVann 2-7/8" EUE Otis Type X nipple with 2.313" ID seal bore 1.5' Otis Crossover from Baker seal assembly to 2-7/8" EUE (if needed) Baker Extended locator type packer seal assembly 20' Baker Pull equipment and stand aside. e Run and set a 7" Baker Model "F-I" packer (with 4" ID bore) on Schlumberger's electric line.. Set top of packer at the measured distance, from Step 1, above the top of the test interval (to be furnished later). 5 Re-run tubing conveyed guns, tubing subs, nipples, release sub and packer seal assembly. Run in hole to packer with the following equipment installed above the packer seal assembly. DAL22921 c. The Flopetrol SSDP electronic gauges in the bundle carrier are to be set for a delay of 30 hours. One gauge to sample at 2 minute intervals and the other gauge to sample at 3 minute intervals. d. The GeoVann TDF firing heads to be pinned to fire at 9000 psi BHP. e . . 7. . ge Run in hole to packer. Land locator seal assembly in packer. Space out for 5,000 lbs., slack off weight. Pressure test annulus to 2000 psi. Rig up Schlumberger and run a through-tubing GR-CCL log to verify that guns are on depth. Rig down Schlumberger. Pick tubing up out of packer and displace CaCl2 from tubin§ with diesel to 500' above the sliding sleeve. Land tubing in packer. Install Cameron Type "AP-FBB" extended neck tubing hanger with dual control line prep. Connect chemical injection line to one control line port (Flopetrol to furnish required connections). Land tubing hanger, screw in locking screws. Pressure test tubing to 3000 psi. Install back pressure valve in tubing hanger. Remove BOP assembly. Install 10,000 psi WP x-mas tree. Connect surface chem)cal injection line to control line port in packoff flange. Remove BPV. Pressure test packoff flange and spool flange connection to 10,000 psi. Pressure test x-mas tree to 10,000 psi. Pump small amount of !ction~u~ ....~s.. ~ glycol down the injection line to be sure inj,r functional. ~~! "J nr~,n J' ~'!.~, ,t.~,~,~ ~. ~ressure annulus to 2000 psi. Pressure up ~n~t~ate ~eo~ann time delay hydrostatic f~r~n~ system. Immediately bleed off surface tub~n~ pressure. ~uns should fire ~th~n 5-7 minutes. NOTES: a. If guns do not fire, pressure up to 6000 psi surface tubing presure and bleed off. Repeat if guns do not fire. If guns still do not fire they will have to be pulled and re-run or dropped to perforate through-tubing. b. If acid stimulation is required, see attached Acid Stimulation Procedures. When testing is completed, dispose of produced fluids by pumping down tubing if practical. Kill well by bullheading down tubing with 10.0 ppg CaC1 brine (do not exceed frac gradient of 0 83 psi/ft.). 2 · DAL22921 10. Install BPV. Remove x-mas tree. Install and pressure test BOP's. Pick tubing up out of packer and circulate 10.0 ppg t~aCtl~b brinaen,d Shut down and watch for evidence of inflow. POOH wi ing subsurface equipment. 11. Abandon the zone as follows- Set a CICR immediately above the packer. Squeeze cement below the retainer until the squeeze pressure begins to increase, or with a cement volume equal to 150% of the casing volume between the retainer and bottom perforation. Reverse circulate out excess cement. Clean out to retainer with mill or bit prior to the next test. Circulate in clean, filtered 10.0 ppg CaC12 with sodium nitrate tracer. PROCEDURES FOR TEST NO. 3' The equipment and procedures for Test No. 3 will be identical to Test No. 2 except that; 1) the perforating guns will be loaded to perforate an interval of 10', and 2) the ported tubing sub between the tubing release sub and flow sub will be 10' long (see Figure 3). PROCEDURES FOR TEST NO. 4: lm Make up and strap equipment to be run below the packer. Carefully measure from the top perforating shot to the seal assembly locator shoulder. ITEM APPROX I MATE FuRN I SHED LENGTH BY 3-3/8" OD tubing conveyed scalloped perforating guns with 22.0 gram RDX charges, 4 JSPF, 90° phasing with Time Delay (TDF) firing heads top and bottom. Guns to be loaded to perforate an interval length of 50'. 2-3/8", EUE tubing sub 2-7/8" EUE x 2-3/8" EUE crossover 2-7/8", EUE VANNTAGE ported flow sub 2-7/8", EUE tubing sub Crossover from Baker seal assembly to 2-7/8", EUE pin 10' 1' GeoVann Baker DAL22921 /, . Locator type packer seal assembly 4' Baker Pull equipment and stand aside. e Run and set a 7" Baker Model "F-I" packer (with 4" ID bore) on Schlumberger's electric line. Set top of packer at the measured distance, from Step 3, above the top of the test interval (to be furnished later). 3, Re-run tubing conveyed guns, tubing subs, ported nipple and packer seal assembly. Run in hole to packer with the following equipment installed above the packer seal assembly. FURNISHED ITEM BY Crossover from seal assembly to 3-1/2" EUE box (if needed) Baker 3-1/2" EUE bundle carrier for Flopetrol Johnston Type SSDP electronic gauges (with two gauges installed) Flopetrol Hydrostatic Reference Tool (HRT), (4.75" OD x 1.5" ID) Flopetrol Pressure Controlled Tester (PCT) annulus pressure operated valve with electronic pressure/temperature gauge installed. (4.75" OD x 1.5" ID). Valve set to open at 1500 psi surface annul us pressure 3 - 4.75" OD x 2.25" ID drill.collars Two - annulus pressure actuated circulating valves. Both valves set to open at 3200 psi surface annulus ipressure. (5" OD x 2.25" ID) RA tag in top connection of top circulating valve Flopetrol SWEPI GeoVann 20 - 4.75" OD x 2.25" ID drill collars SWEPI 4 - Slip Joints (5" OD x 2.25" ID). Each joint has 5' Of stroke Flopetrol 3-1/2" EUE (AB modified) tubing to 2000' from surface SWEPI DAL22921 me Chemical Injection Sub with two 10,000 psi WP check valves Flopetrol Chemical Injection Line to surface. Flopetrol a. May want to stop RIH after drill collars and slip joints are in the well, fill with CaClp brine and pressure test to 3000 psi prior to running the entire tubing string. The PCT valve 'will be closed while being run and can be used to pressure test equipment above it. b. Tubing is 3-1/2", 9.3#/ft., L-80, Atlas Bradford modified EUE. Tubing and subs are to be drifted on location before running into the well. An Atlas Bradford service representative is to be on rig floor while tubing is being run to inspect the connections, install the teflon rings, apply high pressure API modified thread dope (#72732) and monitor make-up torque. Recommended make-up torque is 3200 ft-lbs. It is important that the collars be doped on both sides of the teflon ring to prevent galling during make-up. Extra teflon rings should be on location. c. Flopetrol/Johnston is to furnish all required cross-overs from their equipment to 3-1/2", 9.3#/ft., L-80 EUE (AB modified) tubing. d. The Flopetrol SSDP electronic gauges in the bundle carrier are to be set for delay of 30 hours. One gauge to sample at 2 minute intervals and the other gauge to sample at 3 minute intervals. e. The PCT valve will be in the closed position while the tubing is being run. f. The distance from the packer seal assembly locator to the connection containing the RA tag is to be measured. g. Drill collars are to be cleaned and drifted to 2.25" ID prior to running. Run in hole to packer. Land locator seal assembly in packer. Slack off 20' to close slip joints. Space out to slack off an additional 10,000 lbs set down weight. Install Cameron Type "AP-FBB" extended neck tubing hanger with dual control line prep. Connect chemical injection hose to one control line port (Flopetrol to furnish required connections). Land tubing hanger. DAL22921 0 Fill tubing to surface with diesel. Fill surface lines with 10.0 ppg CaClp brine Run Schlumberger through tubing CCL/GR log to connecti~Fn conta'ining RA tag to verify that the guns are on depth. POOH with Schlumberger. e Pressure test tubing (with water at surface) to 3000 psi - hold for 15 minutes. Bleed off tubing pressure. Pressure up annulus to 2000 psi to test packer. Bleed off pressure. o Install back pressure valve in tubing hanger. Remove BOP assembly. Install 10,000 psi WP x-mas tree. Connect surface chemical injection line to control line port in packoff flange. Remove BPV. Pressure test packoff flange and spool flange connection to 10,000 psi. Pressure test x-mas tree to 10,000 psi with water. Pump in small amount of glycol down the injection hose to be sure injectiun sub is functional. . Re-check all surface facilities and hold safety meeting prior to perforating. . Pressure up annulus to 2000 psi to open PCT valve. Maintain 2000 psi annulus pressure during flow testing to keep PCT valve open. Pressure up tubing to 5500 psi to initiate .GeoVann time delay hydrostatic firing system. Immediately bleed off surface pressure. Guns should fire within 5-7 minutes. NOTE' If guns do not fire, pressure up to 6000 psi surface pressure and bleed off. Repeat if guns do not fire. If guns still do not fire, the tu~>j~tg,~~~,a~~p~e~t and guns will have to be pulled~ '~ ~=~'~.~.i ~,. ~ ~ ~ ~.:~ ~ I I ;,.. ':', 10. Open well up for clean up flow period. ~l~,~~.~a~,o~ned in the Production Testing Plan If aci~?..S?~i~~~'~¥&-~red see attached Acid Stimulation Procedure~}~~ ~ ~' 11. When testing is completed, slack off on electric line to un-jay the Flopetrol overshot connector. POOH with line and connector. NOTE. If FI.petrol overshot connector can not be disconnected, kill well by' 1. Bullheading down the tubing with 10.0 ppg brine, and/or . Pressure up annulus to 3500 psi, bleed off and re-pressure to 3500 psi to open reversing valve and reverse circulate with 10.0 ppg brine. Attempt to pull Schlumberger electric line out of rope socket. If unsuccessful, drop line cutter or pull and part electric line. Install BPV. Remove x-mas tree. DAL22921 Install and pressure test BOP's. Pick tubing up out of packer and circulate with 10.0 ppg CaCl~ brine. Shut down and watch for evidence of inflow. POOH'with tubing and subsurface equipment. 12. Dispose of produced fluids by pumping down tubing if practical. Kill well by bullheading down tubing with 10.0 ppg CaC12 brine (do not exceed frac gradient of 0.83 psi/ft.). Pressure up annulus to 3500 psi, bleed off and re-pressure to 3500 psi to open reversing valve {to avoid pulling "wet string"). Bleed off pressure and watch for evidence of inflow. 13. Install BPV. Remove x-mas tree. Install and pressure test BOP's. Pick tubing up out of packer and circulate 10.0 ppg CaClp brinaen,d Shut down and watch for evidence of inflow. POOH with tdFbing subsurface equipment. 14. Abandon the zone as follows' Set a CICR above the packer. Squeeze below the retainer until the squeeze pressure begins to increase or with a cement volume equal to 150% of the casing volume between the retainer and bottom perforation. Spot 100' of cement above the retainer. RIH and clean out to 100' above retainer. Circulate in clean, filtered 10.0 ppg CaC12 with sodium nitrate tracer. PROCEDURES FOR TEST NO. 5' . ITEM Make up and strap equipment to be run.,:..~,,,:-~:~'" ' ~ ~ l l'~:'. :"~" V measure from the top perforating shot shoulder. LENGTH BY 3-3/8" OD tubing conveyed perforating guns loaded with 22.0 gram RDX charges, 4 JSPF, 90° phasing, guns loaded to perforate 49' interval GeoVann Extended firing head and no-go 2-3/8" EUE tubing subs 2-7/8" EUE x 2-3/8" EUE crossover 2-7/8" VANNTAGE ported flow sub 2-7/8" VANNTAGE hydrostatic pressure actuated tubing release sub 5,5' 60' 1' 1.75' 1.50' GeoVann GeoVann GeoVann GeoVann GeoVann 2-7/8" EUE tubing sub 10' GeoVann UAL22921 2-7/8" Otis Type X nipple with 2.313" seal bore ID ! Otis 2-7/8" EUE tubing sub 10' Crossover from Baker seal assembly 1' to 2-7/8" EUE tubing sub (if needed) GeoVann Baker Extended locator type packer seal assembly 20' Baker Pull equipment and stand aside. e Run and set a 7" Baker Model "F-i" packer (with 4" ID bore) on Schlumberger's electric line. Set top of packer at the measured distance, from Step 1, above the top of the test interval (to be furnished later). Re-run tubing conveyed guns, tubing subs, nipples, release sub and packer seal assembly. Run in hole to packer with the following equipment installed above the packer seal assembly. ITEM FURNISHED BY Crossover from seal assembly to 3-1/2" EUE box (i f needed) Baker 3-1/2" EUE bundle carrier for Flopetrol Johnston Type SSDP electronic gauges (with two gauges installed) Flopetrol 3-1/2" EUE (AB modified) tubing joint 3-1/2" Otis Type XD sliding sleeve with 2.750"ID (Shift down to open) 3-1/2" EUE (AB modified) tubing joint 3-1/2" Otis side pocket gas lift mandrel with casing pressure relief valve pinned for 3500 psi surface pressure SWEPI Otis SWEPI Otis · ] ,iDEFjNi'i'ELY 3-1/2" EUE (AB modified) tubing joint SWEPI RA tagged pill in top connection of tubing joint GeoVann 3-1/2" EUE (AB modified) tubing to 2000' from surface SWEPI DAL22921 . Be . 3-1/2" chemical injection sub with two 10,000 psi WP check valves Flopetrol Stainless steel injection line to surface Flopetrol 3-1/2" EUE (AB modified) tubin~ to surface SWEPI NOTES: a. Tubing is 3-1/2", 9.3#/ft., L-80, Atlas Bradford modified EUE. Tubing and subs are to be drifted on location before running into the well. An Atlas Bradford service representative is to be on rig floor while tubing is being run to inspect the connections, install the teflon rings, apply high pressure API modified thread dope {#72732} and monitor make-up torque. Recommended make-up torque is 3200 ft-lb_bj. It ~ _tm~t~l~,tm l~hjt the collars be doped on botq~~i~):-~O,,~.f~!~=~=l~¥~ng to prevent ~allin~ duri~g~'~J~~~)~~ rings should De O~ ~ocati~.~ ~' '~"~ ~ ~ .... · "" ~' ' '~ b The distance ~,~'~~l m6aJ~sembly locator to the . c:Ton"'"c~a~n~ng ~he RA tag is to be measured. c. The Flopetrol SSDP electronic gauges in the bundle carrier are to be set for a delay of 30 hours. One gauge to sample at 2 minute intervals and the other gauge to sample at 3 minute intervals. Run in hole to packer. Land locator seal assembly in packer. Space out for 5,000 lbs. slack off weight. Pressure test tubing to 2500 psi surface pressure. Rig up Schlumberger and run a through-tubing GR-CCL log to verify that guns are on depth. Rig down Schlumberger. Pick tubing up out of packer and displace CaC12 from tubing with diesel to 500' above the sliding sleeve. Land tubing in packer. Install Cameron Type "AP-FDB" extended neck tubing hanger with dual control line prep. Connect chemical injection line to one control line port (Flopetrol to furnish required connections). Land tubing hanger, screw in locking screws. Install back pressure valve 'in tubing hanger. Remove BOP assembly. Install 10,000 psi WP x-mas tree. Connect surface chemical injection line to control line port in packoff flange. Remove BPV. Pressure test packoff flange and spool flange connection to 10,000 psi. Pressure test x-mas tree to 10,000 psi. Pump small amount of glycol down the injection line to be sure injection sub is functional. DAL22921 , Re-check all surface facilities and hold safety meeting prior to perforating. 8. Rig up GeoVann. Drop detonator bar to fire guns. Open well for clean up flow period. Follow procedures outlined in the Production Testing Plan. NOTES: a. If guns do not fire, refer to attached procedure for gun failure. b. If acid stimulation is required, acid treat with 5000 gallons of 15% HC1. When testing is completed, dispose of produced fluids by pumping down tubing if practical. Kill well by bullheading down tubing with 10.0 ppg CaC1 brine (do not exceed frac gradient of 0 83 psi/ft.). 2 ' 10. Install BPV. Remove x-mas tree. Install and pressure test BOP's. Pick tubing up out of packer and circulate 10.0 ppg CaClo brine. Shut down and watch for evidence of inflow. POOH with tdl~ing and subsurface equipment. .., 11. Abandon the zone as follows: Set a CICR above the packer. Squeeze below the retainer until the squeeze pressure begins to increase or with a cement volume equal to 150% of the casing volume between the retainer and bottom perforation. Spot 100' of cement above the retainer. 12. Begin well P&A procedures as outlined in the Drilling Prognosis. APPROVALS: 'PR)3DUCTION SUPERINTENDENT SR. DRILLING SUPERINTENDENT DATE DATE DAL :jc DAL22921 mmm ~, ' ' ~ ~,o~o pr), wi, ¢~r.~ VAt, YES. ~~ AT' ;.om I): 37&', q. ,'?, T'M~OG OT/S l'qP~ A 2.r?..q" O'tT& ~,3q?' ,~.3f3" I. qeJ" · . ,~1 '1 I &'rMW.[~ STTrtl. ¢~'MIC4~L IlJJEcrlld; 37&', q.& W/~r, fl'R. Gu, f~l)(,.E~ 01'7.1, 'FMPE'/'RO~ VU720 SUBSURFACE SEAL R-3 EQUXPIIENT SCHrlIRTXC g g L]NER TOP PLANNED AT 13,48'7' 1/2", 9.3./FT, L-80 EUE (AB MOD) TUBING 4-FLOPETROL SL]CK JOINTS - S' STROKE EACH (5' OD X 2 1/4' 9 5/8', 53.S#/FT, L-80 CASING TO 14,280' 20-4 3/4" OD X 2 1/4" ID DRILL COLLARS CIRCULATING VALVES (5" OD X 2 1/4" ID) 3-4 3/4' OD X 2 1/4" ID DRILL COLLARS 4 3/4" X ] 1/2' FLOPETROL PRESSURE CONTROLLED TESTER (IE, ANNULUS PRESSURE OPERATED VALVE) WITH ELECTRONIC PRESSURE/TEMPERATURE GAUGE 4 3/4" OD X I 1/2" ID FLOPETROL HYDROSTATIC REFERENCE TOOL 3 ]/2" FLOPETROL PTR BUNDLE CARRIER 7" BAKER MODEL "F-l" PACKER (4" ID BORE) WITH LOCATOR TYPE SEAL ASSEMBLY (HITH CROSS-OVERS) ]0'-2 7/8' EUE TUBING SUB 2 7/8" GEOVANN PORTED FLOW SUB 2 7/8' EUE X 2 3/8" EUE CROSSOVER ]0'-2 3/0' EUE TUBING SUB 3 3/8# OD GEOVANN PERFORATING GUN§ LOADED'WITH 22.0 GRAM RDX CHARGES, 4 JSPF, 90 PHASING. TIME DELAY HYDROSTAT/C PRESSURE F]RING HEADS AT TOP AND BOTTOM N-80 LINER 32#/F T, SAMPLE' CHAMq N~ COMPENIATING PISTON AT 8U#PAC:E NUPTURII DISK HUNNING IN PLOWING 4000 CLOBEO (0) _./ ,/ #VDROBYAY~ MUD PREESI,~E REFERENCE VALVE #YDRAULIG ?HdE DELAY GONTROL VALVE ~.r BY-PASS VALVE OPEN GLOBED OPEN CLOSED OPEN GLOB, ED RUNNING IN TESTING Hydrostatic R~ferenee Tool q ~/i fl~)~ I I ,"l J'~# M 5u~ gPZ . . ... ?.~G7 ' 2.3q7~ G~'r'E'Ubeb F~I~t,Y, p#J ~EM) 4,N)) #0-~o I. 'te$" PRESSURE SETTINGS OF HYDROSTATIC PRESSURE ACTUATED TOOLS GeoVann Time Delay Firing Heads Firing Heads Shear Pinned for 9000 psi Hydrostatic Pressure of Diesel + CaCl~ Brine -- 4700 psi Surface Tubing Pressure Required to Fire Guns 4300 psi ~-066 psi ,F, 1 opetrol PCT Val ye Valve Set to Open at 7150 psi Hydrostatic Pressure of 10.0 ppg CaCl~ Brine = 5650 psi Surface Annulus Pressure to Open Valvb = 1500 psi ~ psi Flopetrol Reversing Valves Valves Set to Open at 8850 psi Hydrostatic Pressure of 10 0 ppg CaCl~ Brine = 5650 psi Surface Annulus Pressure t~ Open Valvbs : 3200 psi l~ psi DAL22921 SEAL A-3 CASING 9-5/8", 53.5 lbs/ft, L-80 Nominal ID -- 8.535" Drift ID = 8.379" Capacity -- 0.0707 bbls/ft Assuming no casing wear from drilling - Burst -- 7930 psi/1.33 -- 5962 psi Collapse: 6620 psi LINER 7", 32 lbs/ft, N-80 Nominal ID = 6.094" Drift ID = 5.969" Capacity -- 0.036 bbls/ft Burst = 9060/1.33 = 6812 psi Collapse = 8600 psi TUBING 3-1/2", 9.3 lbs/ft, L-80, ABC Modified EUE Nominal ID = 2.992" Drift ID : 2.867" Capacity = 0.0087 bbls/ft Burst - 10,160/1.33 : 7640 psi Tension = 207,000 lbs Collapse : 10,530 psi DAL22921 3 3 2 & 2 Shell W~t.m Exo~al~ ~ i 13 15 '~1 12 1' 11 .. A . . ...:..: .:- :*. .. ..;. '" S~lu~;e'C~mentlng P~ognosts' f~r.7; Ltner" .. ' '. .. Liner .Lap - ' -. ie ]) ]f tt ts determined ~htle testtng 11ner top that a leak ts present, ptck up RTTS packer on 3-]/2' drt11Ftpe. Packer to be for 9-5/8", 53.61 castng. 2) Set the packer 200' above the liner top. Pressure the annulus to 2000 pst. .--._ 3) Establish a breakdown pressure and Injection rate by pumptn9 · tnto. lag..Do _not exceed 2 BPH pump rate. I~o M½ exceed 4) Proceed to Step 7 below and conttnue squetq~,.~'~:~'~ n Primary Cement Repair ._ .. ,~:~%, T~*f~.~k ]) Engineer on locatton ,t" analyze the CBL squeezing. 'is necessary for zonal tsolatton*~"~" " 2) 3) Rtg up Schlumberger and shoot four :1/2" holes using 22 gm charges phased gO° t a one foot long. gun, The shooting depth wtll be determined I~jf the field engineer, Correlate depth ustng the CCL. · Run tn hole wtth RTTS packer on 3-:1/2" D.P. Posit-ion the packer 200' above the perfs, Circulate for IS mtnutes to clean area around packtng elements, 4) Set packer and 'pressure test the annulus to 2000 pst. S) Establish 'a breakdown pressure and Injection rate by pumptng . tnto. pe.rfs; D.o not e..xceed 2 .BPI4 pump rate, ~o M'/e~ca=4/ ,j~--rLc'h4, T'e 6) Open the circulating v~lve ~nd begtn pumping squeeze cement. Pump ~0 bbl fresh ~ter ~he~d of class "~' cemnt ~Jth ~ CFR-~, 0.3~ ~1~4 g, ~nd ~ ~R-5 (S~me ~s use4 for 7' l Jn~r. Ce~nt to be ~lre~ teste4 b~ ~11Jburton ~s outline4 tn the 7' 1trier p~g). T~tl the cement ~t~ .S bbl fresh ~ter sp~cer. The squeeze volum ~tll be 4etemJne4 f~ the CBL ~n4 bre~kdo~ pressu~ ~nd r~tes. 7).~ Shut the circulating.valve ~hen the cement ts"1000' above the RTTS packer. ;After shutting circulating valve, pump tnto · · ".:' ' "~ per~ at ~' BP~"~httl cement top fs dfspl_&c~d.to 40' _' . .' · . (1-1/2' bbl displacement) below the RTTS. Atte?pt to_get a. "' - ~unntng'squeeze. The destred squeeze pressure is )000, .ps1 'above the Intttal breakdown pressure. After ¢lostng the circulating val~ve, put 500 pst on the backslde of the RTTS tool. Do not let the pressure differential across the RTTS tool exceed 2000 ps1. :if a squeeze ts obtatned whtle cement ts tn tubtng, unseat RTTS end POOH. · e) If a running'squeeze ts not obtained, begtn a hesitation .squeeze. Use the example pumptng schedule below as a · reference for applying the hesitation technique. Base actual schedule on well conditions. a) After displacing cement to 40'-(1-1/2 bbl displaced) below the RTTS, shut down for one minute. b) Pump ~/2 bblo c) d) Shut down one mt nute. Pump 2/2 bbl, e) Shut down one minute. f) Pump 2/2 bbl. g) Shut down one m~nute. h) Pump t/2 bbl. t) Shut down two m~nutes. ~i) Pump 1/2 bbl. k) m) n) Shut down four m~nutes. Pump 1/2 bbl. Shut down six m~nutes. Pump 1/2 bbl. o) 'Shut down seven mtnutes. p) Pump 1/2 bbl. q) Shut down etght mtnutes. · '' · . · m) · 3 ' Xf destred squeeze pressure ()000 p$1 above breakdo~m} obtained, bverdtsplace c~nent #1th 5 bbls and resqueeze. second squeeze att~npt Is not successful, do not overdtsp, lace_ .cenmnt.. Unseat packer, POOH and I/C)C for 20 hours as descFtbed ~ ~'- After a s'qu_eeze' Is obtain'ed, unseat p~cker end rever~e circulate (tf c~t top ls belm~ R1TS}. POOH and klOC for 20 hours before Il:IH.. ' · RIH and dr111 out cenmnt. P~essure test perforations to 3000 pst above tntttal breakdoam pressure. Resqueeze If perfs do not pressure test. 11) Rtg up lubricator. Run a GR-CBL log~nd CET log across the squeeze Interval. Hold 1000 pst above breakdo~m pr~ssu~ on the castng whtle runntng the log. Procedure for Vanngun Failure '-' If,' after dropptng the detonating b~r, there has been no Indication that the Yannguns have fired, the following procedure should be followed: sltghffi~ overbalanced · up s~tck line unit and the following s11ck 11ne tools: An overshot to catch a standard 7/8" i.D. ftshtng neck a 1-:~/2" O.D. batler a chtsel potnt batler bottom for the'l-I/2" batler a 1-1/2" O.D. Impression block 2. Test lubricator to 5000 pst; rig up the tool string for the ftrst run wtth the overshot to catch the detonating bar. 3. Pay careful attention going tn the hole 'to determine the exact flutd level tn the tubing. · 1 When the detonating bar ts reached, latch onto the bar and spud down as hard as possible. NOTE: Have the slick line operator leave the wetght of the tool down at the bottom of his stroke. Repeat thts procedure a minimum of three (3) times. 5. If the guns fire when spudding down, the tSsliCk l the tools should remain on bottom until 'the well pressure equalized. Then pull out of the hole with the well shut in. If you stt11 have no indication that the guns have fired, fish and remove the detonating bar from the hole. 7, Rig up the 1-1/2" batler with the "Chisel Point" bailer bottom. NOTE: Carefully dress the chisel point bottom to a very clean and sharp edge. 8, I/hen reaching bottom with the chisel point bailer, ;jar down as hard as posstble to bat1 to the firing pin, make certain that on e~ch stroke the operator holds at the bottom of the stroke in case the guns fire. . g. On ea. ch trip out of the hole with the bailer, carefully ins. pect_the leading edge of the chtsel point..]f-t.he bailer is striking the ft~ing pin, there will be a clear 1" d~ameter impression in the · le%ding edge of the chisel point 'bailer bottom.~,~. ~:~,~., ~ .~"m~..m · LUt ;., ~. · Matert~l ~ken'"from '~h~ bailer on each 'run should be c~refully Inspected tn order to determine the type of ftl1 that may have kept-- the detonating bar from the firing ptn. If the guns have fired, .. you wtll also normlly ftnd a very ftne black powder mtertal and wtll nottce a burned cordite smell. ' . .. Conttnue runntng the chtsel point batler untt1 you'have ~letermtned that the bailer.Is striking, down on the ftrtng ptn. 12. On each trtp tn and out ~f the hole, keep a careful watch on the flutd level tn the production string_tn order to observe any. tncrease or decrease tn the flutd level . 13. If the bailer bottom appears to be striking any hard material ~tnher than the firing pin', an impression block_.~ihould then be run order to determine the obstrbction that is keeping the batler from the firing pin ttself. 14. If you have determined that the firing pin has been struck and there is no indication of the Vanngun firing, come out of the hole and rig down the sltck 1the unit. A decision wtll then be made to either pull and rerun the guns or drop the guns and perforate through tubing. REH:mh ACID STIMULATION PROCEDURES The following acid stimulation procedures are based on a perforated interval length of 50', the fluid volumes can be adjusted proportionally for longer or shorter intervals. . . Flush surface lines with 3% NHaCL (Ammonium Chloride brine). Pressure test surface lines to~5000 psi. Pump into tubing with 3% NHJCL and establish injection rate and pressure. Do not exceed 1 to~1.5 BPM or fracture gradient of 0.83 psi/ft. Pump acid treatment as follows. 400 gal 1 ons of xylene 400 gallons of 10% )iCl acid containing 14 lbs/lO00 gallons of citric acid as an iron sequestering agent 1500 gallons of 7-1/2% HC1 + 1-1/2% HF acid 15 bbls of 3% NH4C1 Displace treatment fluids with diesel. Acid should be pumped into the perforations at 0.25 BPM. Do not exceed fracturc gradient of 0.83 psi/ft. Overdisplace acid into perforations with 6 bbls of NH.C1. Maintain 2000 psi on the annulus to' provide "back-up" pressure and keep PCT valve open. NOTES' a. Use fresh water for mixing brine and acids. b. Use ammonium chloride with no anti-caking agents. c. Inhibit all acid mixtures for corrosion. d. No chemical additives other than citric acid should be used. e. Filter all fluids pumped into the perforations. One-micron filter is preferred, but two-micron is acceptable. f. Record 1SIP, 5 minutes, 15 minutes, 30 minutes and one hour SIP. . Open well to flow on a 20/64" choke. Flow well until displacment and treating fluids are recovered. Proceed with testing beginning with Step 13 of Completion Prognosis No. 1. DAL22981 PACIFIC FRONTIER PHONE NUMBERS HOUSTON Bruce Bernard John Sisler Gary Sauer Ramon Val 1 ejo Darryl Lambie Greg Koehler Hans Owens Bill Magnuson Gene Manly Joe Fram OFFICE 713-870-4440 4443 4447 4448 4535 2477 4463 2353 4458 4465 HOME 713-497-7033 496-5801 463-1217 320-2726 358-6801 563-7833 443-3429 467-1834 896-9254 ALASKA Anchorage Office Kenai Office Seal Island Pete Woodson Monty Wood Wayne Simpson Brian Kuehne Brian Briggs John Douglas Bill Osborn Bob Wolf Bob Grote 907-276-2545 283-3096 659-3185, 86, 87, 88 907- 344-8857 344-1420 243-6992 346-3359 283-4100 283-7936 262-4529 345-6856 DAL22983 SERVICE COMPANY CONTACTS Flopetrol Bud Montgomery Otto Jaschke Tom Young Houston .Anchorage Anchorage 713- 785-1480 907-349-g628 907-349-9628 GeoVann Gary Shel ton Ed Colle Houston Anchorage 713-578-9124 907-338-7168 Baker Del Hol combe Anchorage 907-561-1939 Schlumberger David Glass Rick Stickle Anchorage Anchorage 907-562-2654 907-562-2654 Cameron Allan Bruns Pete Thompson Houston Anchorage 713-939-3060 907-562-2332 Hal 1 i burton Bill Kemp Max Fritzel Paul Preston Houston Anchorage Anchorage 713-493-1211 907-562-2100 907-562-2100 DAL22g82 November 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 Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen: Attached are duplicate copies of the Monthly Report of Drilling and Workover Operations for SWEPI's Middle Ground Shoal Well No. A44-02 and Seal Island Well No. BF-57#1. Also attached are duplicate copies of Subsequent Sundry Notice for Workover Operations for SWEPI's Middle Ground Shoal Well No. A23-12. Yours very t}ruly, / , R. a. Hollis Division Production ^dministration ~ana§er Pacific Frontier Division RGH'ff Attachments Gas Co~s. t;~"~s~t~n INDEfiNITELY STATE OF ALASKA ALASI<' DILAND GAS CONSERVATION(' MMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [~ Workover operation [] 2. Name of operator 7. Permit No. Shell Western E&P Inc. 84-93 3. Address 8. APl Number 601 West 5th Ave., #810, Anchorage, AK 99501 50-029-21130 4. Location of Well 9. Unit or Lease Name at surface BF-57 1541.5' FSL, 629' FEL, Sec. 11, T13N, R13E lO. We~No. No. 1 11. Field and Pool WILDCAT 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 55' KBI ADL 312809 For the Month of. October ,1984 ,.12. Depth at end of month, ,footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded- 7/9/84 ' Depth 10/31/84- 14721'. Footage Drilled - 441' 10/01/84 - 10/14/84 SI~ for whale migration 13. Casing or liner run and quantities of cement, results of pressure tests · 14, Coring resume and brief description ' Core #1, 14475-14488.', Rec. 9' C. ore #7, 14643-14668' Rec. 23'6" Core #2, 14488-!4494' Rec. 2' 5" , Core #8, 14668-14685' Rec 14'6" , Core #3, 14494-14508' Rec. 11 '9" , Core #9, 14685-14716' Rec. 29'2" Core #4, 14508~14548' Rec. 32' , Core #10, 14716-14721"., Rec. 6'. Core #5, 14548-14583' Eec 26'9" , Core #6, 14583-14643', Rec. 60'11" .. 15. Logs run and depth where run .:16. DST data, perforating data, shows of H2S, miscellaneou.,~l:~t~j~jr[~! !![ ~ :~ ~ F OV l g 1.98¢ Alaska Oil & Gas Cons, c0mmissmn' Anchorage , 17. I hereby certify that the fore,~oing is true and correct to the best of my knowledge. ~LE Div.Prod Adm M r DATE,11/5/84 I '; month, regardless of the status of operations, and must be filed in duplicate with the Alaska NOTE--Report on this form is required for each calendar 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 MEMORA, IDUM State of Alaska TO: THRU: FROM: ALAS~IL AND GAS CONSERVATION COMMISSION C.V./~~erton DATE: October 15, ~ ~-¢ D.31.68 Lonnie Smith . ' ...... ':'/ TELEPHONE NO: Co~issioner '-'~' ......... ~ ~ Bobby Foster ~/~ SUBJECT: ~etroie~ Inspector 1984 Witness BOPE Test on Shell's BF 57-1, Sec. 11, T13N,R13E,UM, Permit #84-93. WednesdaY, October 10, 1984: I traveled this date to Shell's BF 57-1't0 Witness the uphoming 10,000 psig BOPE test. The test began at 11:00 pm but was stopped at 2:30 am due to several leaks. Thursday, October !1, ...!.~84: Standing by to test. Friday, October 12, 1984: The test began at 1:00 am and was StoPped at 3:L00 a~ because of a flange leak on the stack. The test began again at 9:30 am and was concluded at 11:30 am. This test was on the BOPE stack only. The choke manifold and choke line test began at 6:00 pm and was concluded at 7:30 pm. 'In summary, I witnessed the BOPE test on Shell's BF 57-1. Attachment 02-O01A(Rev. 10/79) o&G 5/84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector ~) ~ /"-Q ~,."i',L;/'" Well . ~., i .~. i /' ' , ~ , /. ' /0 "' /~. tfl . Operator z: :z'~ o~.. Representative ~ ~ ~ ~ ./ - / ~' w :~,*"..~-__./ . .,, ..'.... Well.. .i.-. , ~.'~ " ,' Permit (/ ~.'- ~:-' Location: Sec // T~R/Z~ M ,U ~ Casing Set _ ~'" .[~) ft. Drillin~ Contractor ~,z~4ft:~'~://'"~ Ri~ (~ / Representative .... )~'.W.'.zlv": ~ ../ ~M~~)'"(~'Y~ "' Location, General ~ [' Well SignO~ General Housekeeping fO/" Rig Reserve Pit /~..~./~. ' Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves ~ Check Valve Test Results: Failures Test Pressure ACCUMULATOR SYSTEM Full Charge Pressure ,-~",~D-~ psi~ Pressure After Closure /~.5- psiK Pump incr. clos. pres· 200 psi~ ~ mind. sec. Full Charge Pressure Attained: miu~%--sec. Controls: Master ! Remote~~ Blinds switch coverr~z~ Kell~ and Floor Safet~ Valves Lower Kellx / Test Pressure /~,,~ Ball Type / Test Pressure /~.~-~ Inside BOP / Test Pressure Choke Manifold~~ Test Pressure ~o. V~w~ No. flanges ~ Adjustable Chokes ~" Hydrauically operated choke Test Time .. ~- hrs. Repair or Replacement of failed equipment to be made within days and Inspector/ Commission office notified. R ! ? , ~ , ~ ~,1 ) -- ~ ' r ~o V '~ ,~ ~ ' ' ' '' ' '' ~" ' - , ~,,~ - .. · . Distribution · .~ .,') .. ~., .,, . , cc Opertto~ ~ ~ ti.,. !!' ''~':''')'' ~ ~ cc Supe~~ · ~"~'" :''''~ ~ '~ ~.~.:,....; .,.. ~.~.,.~ ~. :.~. ~'.~. ,.) October 8, 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, Alaska 99501 Gentlemen: Attached are duplicate copies of the Monthly Report of Drilling and Workover Operations for Shell Western E&P Inc.'s Middle Ground Shoal Well A 44-02 and Seal Island Well BF-57 No. 1. You~rs very ~ruly, R. G. Hollis Division Production Administration Manager RGH: ff Attachments RECEIVED OCT,. lfll Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ~_~ · ' ALAS~" OIL AND GAS CONSERVATION( flMMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATION$ (; 1. Drilling well ~ Workover operation [] 2. Name of operator 7. Permit No. Shell Western E&P Inc. 84-93 3. Address 8. APl Number 601 West. 5t.h Ave., #810, Anchorage, AK 99501 50-029-21130 4. Location of Well 9. Unit or Lease Name at surface B F- 57 1541.5' FSL, 629' FEL, Sec. 11, T13N, R13E ~O. We, No. No. 1 11, Field and Pool WILDCAT -~. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 55' KB ADL 312809 For the Month of. . September ,19 84 ,.12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks _ Spudded- 7/9/84 Depth 9/30/84 - 14280' Footage Dril 1 ed - 1399' 13. Casing or liner run and quantities of cement, results of pressure tests ' ' 9 5/8" csg to 14280' (123 j. ts 53'.~5# N-80 & 232 its 53.5# L-80). Cmtd. with 1450 sx Class "G" with 1% CFR-2, .3% Halad 9, .1% HR-5. Slurry w.t. 15.8 PPG. Tested csg'to 3000 psi. 14. Coring resume and b'rief description .... . . , 15. Logs run and depth where run . : . GST/Gyro Survey/CET/Temperature Log/Csg Caliper - 5000-14280'. r .r....,..:, " OCT Z 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. - SIGNED TITLE Div. Prod. Adm. Mgr. DATE 10/8/84 ,., · I1,1¢'~'"r~ I~ .... ~ __ ~1_:_ z ...... · , ~ , , .... ;)TN--Report on this form ~s 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 September 6, 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, Alaska 99501 Gentlemen- Attached are duplicate copies of the Monthly Report of Drilling and Workover Operations for Shell Western E&P Inc.'s Middle Ground Shoal Well A 44-02 and Seal Island Well. BF-57 No. 1'. Yours ver. y truly, R. G. Hollis Division Production Administration Manager RGH' ff Attachments SEP i o Alaska 0ii & Gas Cons. Comm~ssiori Ar..chcrage " STATE OF ALASKA /- ALAS( . OIL AND GAS CONSERVATION[._..)MMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONSx:,, 1. Drilling well ~ Workover operation [] G 2. Name of operator 7. Permit No. Shell Western E&P Inc. 84-93 , 3. Address 8. APl Number 601 West 5th Ave., #810, Anchorage, Alaska 99501 so- 029-21130 4. Location of Well 9. Unit or Lease Name at surface S F- 57 1541.5' FSL, 629' FEL, Sec. 11, T13N, R13E. 10. WellNo. NO. [ 11. Field and Pool ~. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. W'i ] dcat 55' KB Ar)l .312809 For the Month of AU_ClusJ; ,19 84 .. ~12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded-7/9/84 Depth 8/31/84-12881' Footage Dri] ]ed-7881' 13. Casing or liner run and quantities of Cement, results of pressure tests ~ ' ., . 14. Coring resume and brief description ~ ~'!~ ~ ~!li #Z 11699-11760', rec. 55.5' ~~1"~ .:.~.~'~,,, #2'11760-11794', rec. 33.0' ' .' rec. 10.0' il :" ! ,. 15, Logs run and depth where run ' " - Dialog Ca]iper Log 6566-5000' DISFL/BHCS/GR/SP 11535-5000' 11691-5000' DIL/BHC/SGT 11694-5000' ,iR C '""": '. ~','"'. ..... ;~, ~,i i~,,,. ~' , !.. ~-~ .~ .,.., ~. ,,:" ..16. DST data, perforating data, shows of H2S, miscellaneous data <~: ' -' ' ' ' '~' ,...,~ ! _ [ ..~. ;-- ;, ,'! ,,, (,,,,. , ,,,j. ~.."-..~t:.z 0ii ~;.. ~'"" C'" :'S '''~ ~"~ ~.-;.. ~...; .~,.,., ,...~:-;;.~ 17. I hereby .... certif~ that the fo/egoin9 is true and correct to the best of my knowledge, 'SIGNED )'~~~~ TITLE Div. Prod., Adm. M,qr. DATE 9'6'84 " · · ,. . i~ i/l~-r- i- r-i ...... i_? ~ . . .... NOTE-Report on this form ~s 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 Shell Western E&P Inc. A Subsidiary ol Shell Oil Company August 2, 1984 200 N. Dairy Ashford P.O. Box 527 Houston, TX 77079 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: Attached are duplicate copies of the Monthly Report of Drilling and Workover Operations for Shell Western E&P, Inc.'s Middle Ground Shoal Well A 44-02 and Seal Island Well BF-57 No. 1. Yours very truly, ~nGa~eHr°~lr~ucti on Administration Pacific Frontier Division RGH: ff Attachements AUG1 0~-~ AlaSka Oi~ & Gas Cons. c, ommission Anchorage STATE OF ALASKA I ' ALASK1 ,ILAND GAS CONSERVATION ~ AMISSION ¢ {~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERA'I'IONS i 1. Drilling well [~ Workover operation [] 2. Name of operator 7. Permit No. Shell Western E&P, ]:nc. 84-93 .. 3. Address 8. APl Number 601 West 5th Ave., #810, Anchorage, AK 99501 s0-029-21130 4. Location of Well 9. Unit or Lease Name at surface BF-57 lO. Well No. 1541.5' FSL, 629' FEL, Sec. 11, T13N, R13E No. 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. WTLDCAT 55' KB ADL 312809 For the Month of July ,19 84 .'.12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded 7/9/84 Depth 7/31/84- 5000' Footage Dril,led - 5000' 13. Casing or liner run and quantities of cement, results of pressure tests 11 . 20" csg @ 1602'. Cmtd with 3400 Sx Permafrost I.I, wt 14.9' PPG, yield .94. 300 sx , Permafrost. II, wt 14.9. PPG between. 30" & 20". Tested to 1500 psi, 13-3/8" csg to 5000'. Cmtd with 1950 sx Permafrost Type "E" w/ 17#/sx HR-15, .'17#/ :" sx SOD CIT and' .4#/sx H-4, wt 12-12.2 PPg, yieid 1.97, followed by 900 sx Class "G" Neat, .15.8 PPG, yield 1.15. Tested csg to .2000 psi, . 14. Coring resume and brief description ' '. " 1~. Logs run and depth where run ~.~ ,.~ ~-~,. ~. ~'~ ~" ~ ~,~ ~ ii ~ ~ii? r'~ 1~ ,., %~'.~ ' " Sperry Sun Gyro Survey 0 1100': 1100-15 0 [~ ,1~ : :{~J: ~{t SP, GR, DISFL, BHCS, NGT, LDT', CNL, ML liper @ 49 i~.~- Csg Calliper 3825' to surface. ~16. DST data, perforatling data, shows of H2S, miscellaneous data ' RECEIVED AUG ! 0 ]984 Alaska Oil & Gas Cons. Con~mission 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. - ..... NOTE--I~,~port on this form ~s required for ea, calendar month, regardless of the status of operations, and must be filed in dupli'cate 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 MEMORA,qDUM TO: THRU: FROM: State of Alaska ALASKA OIL AlqD GAS CONSERVATION COMMISSION C.V.~~e~on Chai~ ~ //, Lonnie C. Smith ,, Corem $ s s loner Petroleum Xnspector DATE: FILE NO: August 1, 1984 D.31.37 TELEPHONE NO: SUBJECT: Witness the BOPE Test on Shell's BF 57 #1, Sec. 11, T13N,R13E,UM, Permit No. 84-93. Wednesday, August 1, 19~4: ~0ncluded at 2:30 am.~S there were no failures. The BOPE test began at 1:00 am and was the attached BOPE test report shows, In summary, I witnessed the 5000 psig BOPE test on Shell's BF 57 #1. At tachment 02-00IA(Rev. 10/79) .. .... ,. .. STATE OF ALASIq\ AIASKA ,?L & 'CAS ODNSERVATION C~SI(~N. { 3.P.E. Inspection Repo~ ~ Ope ratQr ,~ "~,' .~...':,;' ' Location: Sec 1/ TI3/R ?~'~M L) Orillin~ Contractor 8Z~z~z~'~~ Rig ,~ Location, General · ~,,:..' , Well Sign C~- Cenera 1 Housekeeping Rmserve pit i'~/" :,>b.,'"',.. Annular Preventer,:, Blind Rams / Choke T.~ ne, Valves / H.C.R. Val Kill L~ne Valves-.. -J . Check Valve Test Pressure ~'-~o o Pressure After Closure /qo O' Pump incr. clos. pres. 200 psig, Full Charge Pressure Attained: ps'ig psig ~-. min~ sec. l-/' .min/~ sec. Controls: Master ~_~c~.~ RemoteL~,<z~iP Blinds switch cover / Kelly and Flo~r Safety Valves · Upper Kelly ,/ ~r Kelly /. Ball Type ' / Ins ide BOP / Test Pressure ~-~-~ Test Test Pressure ~..~','.'~ <' 0 ~":~-~ Test Pressure Choke Manifold~--<~, Test Pressure ~....~/?.:~ No. Valves /~ No. flanges ~ ~/ ~%djustable Chok'~'~ ~ l~fdrauically operated choke ~' Test Tims' / ~9.~"' ,hrs. Test Results: Failures, ~ ' :Repair or. Replacement of failed equipment to be made within --- days and Inspector/Ccmmission office notified. Remarks: Distribution orig. - AO&G2C . cc - Operator cc - Supervisor July 18, 1984 Mr. R. G. Hollis Manager Production Administration Pacific Frontier Division Shell Western E&P Inc. 601W..Ftfth Street, Suite 81.0 Anchorage, Alaska 99501 Re: BF-57 No. 1 Shell Western. E&P Inc. Permit No. 84-93 ' .Sur. Loc. 1541.5'FSL, 629'FEL, Sec. 11, T13N, R13E, UM. Btmhole Loc. 4500'FSL, 3040'~U~, Sec. 24,T13N, R13E, t~. Dear Mr. Hollts: Enclosed is the approved revised application for permit to drill the above referenced, well. The provisions of the cover letter, dated June 25, 1984, accompanying the original approved permit are in effect for this revision. Ver~v~truly y.~r,s, . . ~ ,. ..-~.~',. ~..,. ~ ~*.':' C. " ~'i~ Oi..,~"~:i'~ ~.~:' "~'~"~'" Chairman of Alaska Oil and'Gas Conservation Co~tss!on be Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department .of Environmental 'Conservation w/o encl. 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 Commission ATTN Mr. Harold Hedlund 3001 Porcupine Drive Anchorage, AK 99501 Gen tl emen' In response to your telephone request of July 5, we enclose an additional Form 10-401 in triplicate, which indicates the revised surface, producing interval and total depth locations for BF-57 No. being drilled from Seal Island. Yours very truly, R. G. Hollis Manager Production Administration RGH' lb Enclosure RGH51942 ~ ~i'''~ ~, ~... ~ ~...,,.~ '~ JUL Z 6 & Gas Cons. Commission Anchorage ( ' STATE OF ALASKA ALASKA -- .~_ AND GAS CONSERVATION C~ PERMIT TO DRILL 20 AAC 25.005 ,MISSION la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY E~ DEVELOPMENT OIL [] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC I'-] SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator Shell Western E&P, Inc. 3. Address 601 West 5th Ave., #810, Anchorage, AK 99501 4. Location of well at surface 1541.5' FSL, 629' FEL, Sec. 11, T13N, R13E At top of proposed producing interval 4920' FSL, 2850' FWL, Sec, 24, T13N, R13E At total depth 4500' FSL, 3040' FWL, Sec. 24, T13N, R13E 5. Elevation in feet (indicate KB, DF 'etc.) 55' KB I 6 . Lease designation and serial no. ADL 312809 9. Unit or lease name BF-57 10. Well number 11. Field and pool WILDCAT 12. Bond information (see 20 AAC 25.025) Statewide - INA Shel 1 0084 Type 0i 1 & Gas Surety and/or number 11C !36503 13. Distance and direction from nearest town 14, Distance to nearest property or lease line 21 mi., N.W. Deadhorsees 1178 feet 16. Proposed depth (MD & TVD) 15500 MD 11850 TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 1700 feet. feet 17. Number of acres in lease 5301.38 20. Anticipated pressures MAXIMUM HOLE ANGLE45' 3° I(see 20 AAC 25.035 (c) (2) SIZE CASING AND LINER Casing Weight Grade 7" 32#, L-80 22. Describe proposed program: Proposed Casing, Liner and Cementing Program SETTING DEPTH Length MD TOP TVD I I 3437 ~, 10398 $500,000 Amount' $10n nnn 15. Distance to near~s~t-d~l'[ing or completed we,. 6190 feet 18. Approximate spud date dully 1, 1984 3~,~0 psig@.~ Surface 5~/~0 psig@~ft. TD (TVD) MD BOTTOM TVD 100~I 100~ ! 1600 11600 5000 14465 13737 ~0610 14675 ~1270 QUANTITY OFCEMENT (includestagedata) 'Drive Pipe 3000 Ft.3~ 5200 Ft. 600 Ft.3 * 280 Ft 3 Full Length 500' minimum over' hydrocarbons .23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED (~,~ TITLE Div. Prod. Adm. Mgr. The space below for Commission use DATE 6/13/84 Samples required ~[YES []NO Permit number Form 10401 Rev. 7-1-80 CONDITIONS OF APPROVAL Mud log required Directional Survey required i APl number I~LY ES DNO {~YES r-]NO 1 50_ Approval ~ate / SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE..T1]'] 7 _r by order of the Commission Submit in triplicate /. ,. .., RMERRDIR HESS CEIRPORRTION June 25, 1984 P. O. BOX 2040 TULSA, OKLAHOMA 74102 918-599-4200 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Telecopy information. Betty Ehrlich 907-279-1433 Re: BF-57 #1 PL-4037 Seal Unit Beaufort Sea, Alaska Dear Si r: Amerada Hess Corporation has no objection to the surface or bottom hole location of the BF-57 #1 well (Seal #3) as proposed by Shell Western E&P Inc. in its application for Permit to Drill. CRR-ssw C. R. Richard, Manager Beaufort Sea Operations cc: D. G. Stevenson *Note: Telecopy was sent on 6/25/84. RECEIVED JUN2 9 191]4 Alaska Oil & ~as Oo.s. Oommis$io~l Anchorage June 2.5, 1984 Mr. R: O. 'Hollis Shell Western E&P I.n.c. 601 West 5th Avenue, "~810 Anchorage, Alaksa 99,501 Re: BF-57 No.1 Shell Western'E&P Inc. Pemit No. 84-93 Sur. Loc. 1.541.,5'. FSL, 629' FEL, Sec. 11, T13N, R13E, UH Btmhole Loc. -5~' FSL, 2950' FWL, Sec. 13, T13N, R13E, UM Dear Hr. Hollis: E~closed is the ,.approved applicat~on for p~r~it to drill the above referenced ~ell, If coring is conducted, a one' Cubic in'ch chip from each foot of recovered core ts required. Samples of well cuttings, a minimum of four tablespoons, and a mud log are required. A cor;tinuous directional sur~...ey is required as per. 20 AAC 25.050(b)(5). If available, a tape containing the digitiZed log information shall be submitted on'all logs for copying except experimental logs, velocity surveys and dipmeter sur~.eys. 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 regulations'promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department' of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by tile. Federal Water Pollution Control Act, as ~ended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 ,hours prior to commencing installation of the blowout prevention equipment so that a representative of the Com~ission may be BF-57 No. I ................................................... : .................. ' ................................. present to witness testing of the equipment before the surface casing shoe i~ drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencin§ equipment installation so that the Co-wission m~__y witness testin~ before drillin§ below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, Chairman of Alaska .Oil and Gas Conservation Commission lC Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. June 25. 1984 Alaska 011 & Gas Conservation C~lsston 300! Porcupine Drive' ~chorage, N<: 9950! Telecop~ info'nation: BeCky Ehrlich 907-279-1433 8F-57 #1 PL-4037 Seal Unft , Beaufort Sea, Alaska Bear Str: O. BOX ~040 OKLAHOMA /~merada 'Hess Corporat.ton has no Ob;~ection ~.o the surface or ,bottom ho.le locatton-.of the BF-57 #! ~etl (Seal 43) as proposed by Shell ~stern E&P Inco $1 ncerely, C. R. Rtchard, Nanager Beaufort ~e~ .Oper&~ions CRR :ssw ,r..c'.. D. G. Stevenson *]~]ota.' Telecopy waa sent ou 6/25/84. TOWNSHIP RANGE COUNTY STATE REMARKS: COMPANY -._._i ...... [.. .~, ............ J ..................... ~ ........... & _ L i J, ,,} I ' L i , , , ~ · 1 ; , , : I i ......... i ................ ~ ............ I ~........... : ..................... i' ........................................ r ................. '(f i~ ......... ................... ! .............. q , i i "''i I --q---' -' ? ........ "-!--'.'' ---?- ' ~- , ......... -~ .................... ,' ....... , , I I ~ '. . ', 17- , , ! I ~ I t : /;9i ................................................ ? ................................................. I . l .................. __, .~ ............ .,:, .................................................................... . : , /., :~ __~ ................. ,'__ ...... L___74~1,,.'.'i , ~, ~ _y_..:~,~i , I :, i :; ' - ' : i' - ....... ~, ............. ~t ..... 't:~" i""-t-'T' ...... ' ................ ! ......... j ........... : ................... ~. ! I ' ~ ( :"I i , ~ .................................................... I .................................... i .... '"i ........... /"I ................... i ......... , , I i ' ' .... I ; 'l ' : , . I ,? , ; j ; ,, I ' , ...... .,, : ] ' / t i i I ' ~./ i , ........... ': ........": ................................ !" ............................................. il i~ ........................................ ~'""-'-tl ~ ....... ~' ....... I ........ ti~" ~:'1! '" "1 ~'i~' ............ : '~J~' ~l~i!l: ........ ~ .............................. .L_... i F I f I ' ' ' / ' · ....................... ~ __ . ' . ; . i ~ : '. , i i ' , ~=~'::"~'~';~'=, ~~ ~ ...............: ............ : ................ ............................., , ' ............. i'i ..... "'. .............................................. : ............. ! ............................... i' ", : . .. ! ; .... 1 I , , . ' I ! /-,- I ...... f , , .,.! ,~ , , ................. '; ............... i .............................................................. I ................................................. :. ............ ~. . · · ! ' i,i ': '" .......................... _~__ ...... _i L_ _L_ : : '--J ..../ -i ..... ; ..................................... : ............. ............................. ~ ..................................... I .............................. ~ ...................... I ......... 'CONI:ID N'i'IAE. __ PAFIT 1/PATI£NT I~i~oRMATION--Use. sepnrate. , form for each pallen!, . ~ · . .,.--~-,:-.:,;.~-;..~;:.:.-;.i:.~.:-~:-.-.!:.:;...I....~... ..,,~.~,;~;,,.0,..~......,,,. "~.~,~..,,'. : ..... , ...:..;:.: ~ , :...,.~.-~: .... ~PA-rtENT'~NA~dE '..- ..' ":' . .... . 2_~BIFITHDATE ?~ISTHISCLA~v~DUE~O ....... ,.."'-. ~.~ ' ..~..':,,~--, · .'.,..~. FIRST - INITIAL '-'I.AST'' ~;' ' "- ~-~' ~:~-' -- ' 't-JANACClD£NTOnlNJURY? ';'/;'-!YEsL_J '.'.-?:'1¢~101 '..-. _ = .- :... . ; --..-.:'::~.....::....'! -'=.'~. '- ' MO. DAY YEAR ' · ...... · ' ':":"'-' -"~','~ ...... '~'~:~".~:~:'-"-"~.~-','~'J~7.'.'.'.'.'.'.'.'~.~' ..... "~"-"':'° :'. '-'_~ ............ -'_"' ' "?' ..... :--'"": ""-4:~ :'~' ..... .-'.'L .'."" ' .... ' '='~: .....' ...., - ~'",'- DATE:' ....... ':-',, ~': ...... TIME: "": ' '''~ "AM' D -."=;"/"::-..PM' D ': · ' :."' -.' - "-. ,1'-:. -".'-I. -/:: '-^T,WOR~ .... I--1 :,^~,.HC~' ...... E3 AUTO'" l--1 'b'r,~l--l"' ~-'~$Ui3SORI13ER~ ]RELATION TO . ~4 IGROUP .... NUMBER . ~] SUBSCF:[li3ER'$1DENTiFiCATiON NUMBER: ' · '":~'" ' '~'~'": ' ". ? '-" "' ' ~' '" ' :'~ .... :'~" ::- '~" ' ' ' ":" ....... '" ''~''*; ":'"" ::"":~a~:"'~(P ~:~ :"~.'.~'~;~:":?:~':~'~ ...... '"~;' .... ..-..- ..-.. ..... : ....... - ................ · .... -.*,:~,. ~,,'~ ..~'."~: . .: · ..: . - ..... · .: . :.-... ..... :. ,':~-'_.,..-~:.~ . . . ' . -.-..~ .............. ": ..:.~..~. ,,... . ........... . I-1 I-J · E3 .... ' :.... ._ ..... ::.:~:,_.::::.!~i',,:'"!.; ........... ....:~.., ................. - .......... ...., ...... · .- .,. :. ........ , ......... ~ , ~ ,,~.,.-,, ,~, .~.- sE,~ S,ous,_ c,.u~ ... I I t';"~I i":.! i 'i ' " "" "' 6_JSOBSCRISER'E~ NAME. ADDRESS. CtTY; STA'I'E. ZIP .. . . · . . . ........ , ..... : ,'.; ..,[.,.- ;:o;'.'. .: .. ~.-,~, ..~-,~,,q ~1' h'-;:.,4~,; ~.',:,.~:g~;. IF ACCIDENT OCCURRED AT WORK IS ' '".. WAS ANOTHER PARTY RESPONSIBLE *-"~;: CASE COVERED UNDER WORKERS' ...'.-,:'.,. '. '"' FOR THIS ACCIDENT? /" ~ ' '.~.g,, ~'o .:-~;'."'i;:- I ........................ - ." ' "'"" 'i COMPENSATION? ,. , ,' .--.','.,:;..',.=.'".;*'.-'.~".~ .~... ~;':-';~. ;.-'~ .... '. ' .... ;;;'. ...... -'. ......... - ...... ;;.!~';;'.'-.'~"..I = . . .... ~:.'-'"...:.~ ' ...'-.'..'::'..'v,....:',-~..,:,x:.~.,~. .... .', : : ~. .~.~ ..... - ,...,:'..-.,.,.:,:.,.-, ? ,=,, /,. .... .-.;.--~ '- "YESI--I '~.'"NOII ". '"".-=.'-?'. '.YESI-1 NoEl ' '~'-; " ..... ' ' ' ' ' ' ' 8J~ YOU OR ANY bF YOUR DEhI~NDENTS HAVE .~ 2 - ' ' ';*' ~';'" ~' ' ............................................................... -' · · · OTHER GROUP MEDICAL COVERAGE? -, "' :YI~SI I .- . . .., ' ' -- ' ; . .';;.'ZIP CODE ;-5 - ('I'HIS INOt. UDES OTHER BLUE CR0~S COVERAGE.) ' ' ' ' "? ' ' : ',- ...... ' '.' ' ..-:: ';,v" ;..;- :'. :",.. '.. ' 3 ' NAME AND ADDRESS OF OTHER CARRIER: .; .............. ;' ' ' ' '.'. '" '' 3 · *********************************************************************** ',: · . ..,.. . ~ · - '.,: :;"i-'.'{~i.~-?;: Ple~'fill ~ut Pa~ts I and 2 below, a~d'~e~ci ~O'tfi~'Bi~'~roi~; ~lan Cl~ims-~pa~'-P~'a~ ..-~:- .-. -:--:~:- . . ..... . .... .-.~,,.,. . ~.: ::.::~,¢.. ~ m~s~ ~r ~mp~te In~m~ions on-~wto submffto ne Blue ~ss ~n. ~--- :~--- . .....':: ~ -:,;,,,... .% ':. ~; ' . ' 2 :-~ .; :Ji. ' · .;~.. ...... ~,~.~ /. :'-' ... :...... .~,: ,,-... · ...' ;-..' ,,~,.; - - ... ~':~' -. (Itemized Receipts Must BeAffached)--See Reverse Side · .. ..~ ...', . N, : · ": .... :'.'.;./ ' . ' " ' .... "' ' ;::-"' ':' ' ; ..... :' ' 'i"'" · ?,ruoS'PUnCH^S =d ' .... ' ' ..... .. (L~t onl~th~e d~gs 'Wh~ m~t ~ ~,bt~n~y a ~riff~ pres~ption~ . ~. - ,.... ~.;. ~.,: ~,~- , .. ~ . . , ,,...._.; ... '" . : ,. .. ~:.. . ~~,,0- . . .. ..~: ·....~' ...~:....;.:,......'~ ..... P-"-A"-- ~ORE '- O M~ICINE ' R ND ~ "~R~ 0 '-" .: ~*'~".~-~,. '.~ .... ',.-. ~... '[:'~' .'~ ~' ONLY I I :' ~ ,, .:_ :.~:::~:.~:~:;:=..~ x :. . · . ..~ .... ., - .... ~.. ~ ...... , , , ....... . I ! ' ' .... ~ ..... ~. ~- .. I I ' , ,. , . ~ I '~' ...... ~.~ ~-~~ ' , . '" ,~ , I ! ,., ."/' . , ' .... -1 I ,-- "'"" '" ' ':' .. ., - .- ~ ........... ,, ..- ,?- ~ ~ .~ · .. ..' ", . : . I "i"'~ ~ "' .... ~ ~' " ~- TOTALCHARGE ' .' Shell Western E&P Inc. A Subsidia~ of Shell Oil Company June 18, 1984 State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 ~ , ........... "FILF: Gentlemen: ~ · ................................................................... '- Further to our letter of June 15~bm~ ,mitted an Application For Permit to drill Seal Island Wel~B~_F_T_~_,_No,__..]~.])we enclose three copies of our H2S Contingency Plan and~-~'a'~ B~'T'fi~-;:.---~Tding and Hot Tapping Plan, These enclosures are identical to those approved for the previous Seal Island well. Should you require further information please contact me in Houston (telephone 713-870-444.5), 200 N. Dairy .,Yco~-' t ~.o. ~ox~ ~.~ co:~-k~-i ~cb'M,~----,I Houston, TX 770~ .... ~s -~ EN~ , ~ ~0' 7 ~ ~-, ~ '- ~ .... ~ 2,.~oC~ Very truly yours, R. a. Hollis Production Administration Manager Pacific Frontier Division RGH:bjh Enclosures RECEIVED JUN 2 ~ lg84 Alaska Oil & (~as Cons. Commissio~ Anchorage HYDR[ '.~l SULFIDE CONTINGENCY PLAN SEAL ISLAND DRILLING PROGRAH SEAL EXPLORATION BF-57 #1 Scope This contingency plan is prepared on the basis that hydrogen sulfide is highly unlikely to be encountered in quantities dangerous to personnel or equipment. Howev~F-, since there ts 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 eva~cuation 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. lhe 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. H2So. is flammable in the range of 4.3 to 45.5 percent in air. A .mixture of two volumes H2S and 3 volumes oxygen willI explode violently when ignited. has a specific gravity of 1.192 (compared to 1.00 for dH~; air) or a molecular weight of 34.08 as compared consid'ered heavier than to 29 for air. Hence, H2S may be air and in concentrated lorm 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 1.0_O'.~e the mixture for all practical purposes has the sam RECEIVED ~'~ ~ JUN ~ 5 Affchora~e III. NoS is readily soluble in petroleum hydrocarbons and is soluble in water at ~.o(~'' temperatures at the rate of ~a'" ~ee volumes H2S for one volume of water. Such .things as heating and gitation 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 H2S during the heat of the day in cases where there was no significant amount .found during the cool morning hours. Information as to the concentrations of H~S that are detectable .by smell vary considerable. It is readily detected a about 5 ppm; however, it is generally .accepted that concentrations as low a 0.025 ppm are detectable, 0.3 is distinct, 3 to 5 is strong and 20 to 30 ppm is 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 H?S. For example, the odor of creosols effec- tively masks the odor of H2S~ Physiological Effects - Hydrogen Sulfide There are three princip.al 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 70D-ppm or more. Aside from the ~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 ana ear plugs offer little 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 imnediately to fresh air and breathing is stimulated by artificial respiration before heart action has ceased. In-hioh concentrations of gas,I the mechanics of this respiratory paralysis, form( y thought to involve a chem(~' 1 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 higli 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 ifrom acute exposure to fl;~S 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 14~5 in acute poisoning cases. Those recovering from acute. poisoning ano 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 following indicates responses to various toncentrations of HgS in the atmosphere:' .. PHYSIOLOGICAL REsPoNsE TO VARIOUS CONCENTRATIONS OF HYDROGEN 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 ~ hour to 1 hour exposure Pulmonary edema or bronchial pneumonia from prolonged exposure Rapidly produce's unconsciousness, cessation of respiration and death Unconsciousness at once, with early cessation of respiration and death in a few minutes Concentration PPM lO Moderately above 20 70-150 170-300 400-700 250-600 700-900 10DD-2DDO *TLV- ThFeshold Limit Value IV. Ve Eyes-c~n be affected by HgS exposure.. It is believed that the effect on the eyd is due to the caustic action~I : sodium sulfide formed by interaction of the HgS and the alkali of. the cereus 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 Mlk 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. ~lydrogen sulfide may have a slight anesthetic effect on the eyes, as often the s~nptoms do not occur until the ~?nd to 4th day of exposure. Estimates of minimum concentrations of Hg5 required to cause eye effects are r~po. rted as ranging from 4 to g5 ppm. P_~gsical Properties - Sulfur Oioxid~ Sulfur dioxide is colorless gas or liquid. It has a pungent odor and is not flammable. It is formed when hydrogen sulfide is burned. The, specific gravity of the vapor is 2.~64 {compared to 1.C)D 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 $ to lg .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. ~i Cal' EffeCtS ' ' 'Sul f~ 'DJ Og 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 per. cent of allS02 inhaled is absorbed in the upper resp~raa~t. tory passages w~th only sl.ight penetration in the lower.respiratory tr 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, of sulfur dioxide exposure m~(~v resulL from repeated b'ronchoconstriction. While( .... 'onchoconstriction is not it ~ a chronic effect, it is believed that continual exposure can lead to substantial permanent pulmonary i~npairment in. -xcess 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 $ 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. ~S Detection and Monitor.lng Equipment Ae Although FI2S is not anticipated, monitoring is needed to alert personnel immediately to the presence of the H~S. To provide necessary warning, International Sensor Technology H~S d~tectors or the equivalent will be' installed to automatically detect the presence of 5 ppm 14~S in the air. The sensors will be wired at the shale shaker, bell nipple, ri),floor and mud pits with audio and visual alarms placed on the rig floor (driller-s console). 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. The alarms from the sensing unit will be placed within the living quarter, s on each floor and will be both audio and visual alarms.' The sensing unit ~-Jill be checked and calibrated 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 ~ill be available for each member of drilling cPew on duty. Although normally a drilling crev~ consists of five men, twenty sel,.f-contained units will be provided. A departure is requested for the requirement to°'supply all personnel on location with pressure demand air breathing equipment. Essential personnel that are necessary to shut in the well will be provided with the pressure demand apparatus. When concentrations exceed l0 ppm, the well will be secured as described in Section XIII. All' breathing air bottles shall be labeled as' contain.lng air fit for human usage. Location and type of breathing apparatus are listed below: 6 ea. 5 minute air packs available on the rig floor 2 ea. 5 minute air packs available in the mud checker room 4 ea. 5 minute air packs available in the mud pit room 2 ea. 5 minute air .packs available in the mud pump room 20 ea. 30 minute pressure demand self-contained breathing apparatus See storage locations, Section. XlI-tt 20 ea. Extra air bottles for breathing apparatus'.,~,.~lr,~.~F_~~ See storage locations, Section XII-H r~ ,, ... ~f~ ,..~i. ,~ ~!~.. redundant. ~'~ ~ki~, 1~ ~,~ .. VIII. Other Equi pme~,f. · 1. Six chalk boa_r.d_.s=a_n.d six.n..o..te pads will .be provided o_n. the rig fioor,_. '" shale shaker area, and pump rooms for con~municaltion purposes. 2. Two bull horns and flashing lights shall be provided. . 4. . 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. Wind Indicators 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. 8. Nud 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 sbfficient quantity to treat the entire mud system with 2 lbs. per barrel. . 10. 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 1 Si te Commun i ca ti on 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-I4ydrogen Sulfide - 14 S" signs will be displayed whenever hydrogen sulfide level is above 10 ppm outside of the rig floor, mud pit or shale shaker areas. Each sign shall have a minimum width of eight feet and a minimum height 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 will be worn by all ~orking personnel, all non-working personnel shall proceed to the'designated safe briefing areas for further instructi.ons. IX. X. XI. XlI. In the'e¥~nt H~S has been determined torkave reached an in- jurious' ~ ?el ~(50 ppm's), a number of t J rectangular shaped flag's 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. . ..i Ventilation The mud pit, shale shaker area is equippe.d with explosion proof exhaust fans capable of changing out the air ~n 5 minutes. · ~ Evacuation ~. If'H2S' concentration reaches'50 ppm, all perE6nnel will be evacuated, except the Drilling Foremanj Assistant D.F. (man radio communication), Mud Man, Pusher, lOriller, 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, the ice road or a I~elicopter 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. All personnel, whether regularly assigned, contracted,' .or employed on. an unscheduled basis, shall be informed as to the hazards of. H2S,. They shall also be instructe, d )n the proper_ use .of.t.he_sa.f.ety. -n,,(nment which they mav be required to use, informed o? Mos aetectors ~'~larms, 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. Records of attendence will be maintained on the drilling facility. a. Self-Contained Breathing Ap'paratus 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- ment tb (' Jure understanding in its pr(" r use. Any new employee on the working crew, will be trained tn the use of this equipment, upon his arrival at the drilling site. C. Hydrogen Sulfide Detection Equipment Personnel required to Operate permanent or portable monitoring equipment will be trained in the proper use and maintenance of units, · D. 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 All first-aid personnel in the drilling crew will be indoctrinated in basic first-aid procedures applicable to. victLms 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 HzS hazards, warning systems, ' safety equipment ~nd safe briefing areas in the event of an H2S hazard. During subsequent on site training sessions and drills, emphasis will be placed upon re~cue and first-aid for HgS 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. G. No Smoking Areas where smoking is permitted will be established and identi-I fled. 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. g units in tee drilling foreman's office. m 5. all refill bottles will be stored in the drilling foreman's office, · · XII · H2s Emer§en~y~.i" 'ocedu.res A. If a.t any time as: much as 10 ppm of Hg5 is detected, the following steps will be taken: 1. The person detecting the HZ5 must immediatelY_ notify the Oriller. He must then not~fy the Shell Drilling Supervisor and contract Toolpusher. . The 5hell Oriiling Supervisor and contract Toolpusher will bring portable gas detectors to the rig floor in order to find . , the source of HzS. · .Upon notification of the emergency, the Driller will shut:down mud pumps and continue to rotate the drill pipe. 3. 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.. 4. The'contract;Toolpusher will alert all personnel that an emergency exists... He should be prepared to shut off the Forced Air Circulation System in the living quarters. 5. The laud Engineer will run a sulfide determination on the '~lowline mud. 6. A maximum effort must be made by ~upervising personnel to resolve the cause of the H~5 and. to suppress the HgS as quickly as poss!ble. Orillin§ must not procee.d until the ca. use of the H25 ~s determined and ~he w~'11 is c~rculated. Rig floor and mud pit personnel will keep breathing equipment on while monitoring this circulation. 7.. 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;. potenti al danger areas must utilize the "buddy system." 8. The Shell Orilling Supervisor in charge will notify the $hell Operations Superintendent of current conditions and actions taken. 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 upwi'nd and to be prepared to evacuate nonessential personnel. · B· 11. The Shell Drilling Supervisor in charge will alert the D~a(' )rse dispatcher to assure. COF("" ~UOUS radio watch. The U.S: Geological Survey and U.S. Coast Guard must also be notified. Tf the 142S concentration exceeds 20 ppm (from an increase in gas cut mud) and the well is not attempting to flow, the following steps wtll be taken: · · The person detecting the H2S must immediately notify the Driller. He must then notify the Shell Drilling Supervisor and contract · Toolpusher. 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. Pick up kelly above rotary table. C. Be ready to hang off and close the BOP's if necessary. de If well control problems develop, shut in the well· 6. . The contract Toolpusher will alert all personnel that an Hg5 emergency exists, He must shut off the force Air Circulation S~s.tem in the living quarters. · . All Personnel not listed above must report to the upwind safe briefing'area oT~ 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. JUN 2 ~ Alaska 0il & Gas Cons. Commission Anch~age . "... .............. '..,.. ............. . The,,,m~hell Drilling Supervisor in c~,-rge will notify all app~l ~ching vehicles and helicopte~ to stay upwind and to be prepared to evacuate nonessential personnel. Notify dispatcher to alert heliport and establish 24-hour. watch, tiotify appropriate state agencies in.addition to USGS and USCG. 10. 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 Supervisor and contract Toolpusher will: 1. Direct corrective action. Notify the Shell Operations Superintendent in Anchorage on action' being taken. ' GENERAL B~lRN~rNG, I~ELDZNG & )-lOT FOR SEAL ISLAND-SEAL EXPLORATION BF-§7 #1 The follow~ng pages ou~:~ne the procedure to be used when perfor~{ng any welting, b~~g, or ho~ tapping on or a~~ the r~g. . Attac~e~ ~s a ~raw~g of ~he r~g layou~ for the ~r~11~ng "A.~ ' operations on ~e Isl~.' As ~ho~ on ~ r~g layout, the ~es~gnatea ' safe ~eld~g an~ bu~ing areas w~l~ be ~e ~op, steel rack house, .and ~e weld~g shop. ' A ~py of ~e Shell F~re · Safety ~rk ~mit, which ~s ~ be obta~ed from the fore~ before ~y ~eld~ng, bu~ing,, or hot tapp~g ~s done outside ~e ~es~gnatea areas, ~s also attache~. o. ®, {' OPERATING PROCEDURES FOR SAFE OPERATIONS IN WELDING AND FLAME CUTTING SEAL ISLAND - SEAL EXPLORATION BF-57 #1 .--' 1. Cutting and welding operations near a rig constitute potential fire hazards and have been the cause of many catastrophles. ~elding and · cutting ,ope~.ations shall be ciosel, y .sui~r~ised at al.1 .~mes, and shall not be permzttea near flammable liquids, near accumulations of crude. oil, near escaping gas nor in locations where sparks, flames or from a welding toich 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 shill' be certified welders and properly instructed to insure, they. will be safety conscious and have a thorough Understanding of the potential,~ hazards to be guarded against. In all welding and cutting operations, the welder shall be briefed on the safety aspects of hi's specific }ob before any work is started. 3. A written safety work permit system covering all welding and flame -.. cutting operations shall be required on all offshore operations - platform rigs and mobile units, and shall be considered prudent.an~ advisable on land and inland barge location.s on critical wells or .. where hazardous conditions may exist. 1. Only approved [FMEC or UL) apparatus, such as tanks, regulator~, arc welding machines, shall be used. 2.ltixtures of fuel gases and air, or oxygen, .may be explosive. No device to permit mixing ahead of the burner tip shall be allowed. o. 3. All ~ylinders ~ith 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. Valve caps' shall be An place,' except when cylinders are connected for use. .. 4. Inside of buildings, cylinders shall be stored in a we1! protect'eft, well ventilated dry location at least 20 feet from highly combustible materials such as oil or excelsior· · 5. Cylinders shall be stored An definitely assigned places away from stairs, or walkways. They should be tied or ~~'~~.~.~,.~.~ ~~ent accidental '~,., overturning- ~ ~ _] ~ %!. ~ ~ i:.i ? ~i:{" ~:~ %:...i~ ~ ~ ;~ ~. 6. ~ylinflers shall not be kept in unventilat..~.'.., ehu'l'...c~9~%~=~..~ as lockers · and cupboards. ' i i"' ..... ' ' '"' ~ 7. Oxygen cylinders in storage shall be separated from fuel gas or combustible materials (especially oil or grease} a minimum distance of 20 fee: or by a noncombustible barrier at' leas: 5 feet'~i~.h. 8. When trans~or i . cylinders by a crane or derr ,, 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 a~paratus shall be enclosed, except for the operating ~heels, levers or handles. 10. Input power tendnals top &barge devices and live metal parts shall 'be · completely enclosed and accessible only by means of tools. 11. 'Terminals .from weTding 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. OPEPATIONS AND MAINTENANCE 1. Cylinders shall be kept far enough away from the actual w~e.ld~ng or cuttin~ operations so that sparks, hot slugs, or flame shall not ~r. each them or fire resistant shields shall be provided. o. 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. 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, shall 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 ~ylinder shall be taken outdoors and slowly emptied. ?. 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. 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 m~ke. electrical contact with persons, conducting objects, fuel, or compressed · 10. Cables 'with splices within 10 feet o . e used. The welder should not coil or loop weldi~ ~'~ ~b~,~ a~und parts of 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. If the objects to be wel~ed or cut cannot be moved, and if all the fire hazards canno't be removed, then guards shall be .used to confine the heat, .sparks, and slag and to protect the immovable fire hazards. Wherever there are floor, openings or cracks that cannot be closed, pre- caut~.ons shall be taken so that no readily combustible materials below will be .exposed 'to sparks. " " . Suitable fire extinguishing equipment shall be ma~ntaine~ in a state of readiness for instant use. ' · Fire watchers with extinguishing equipment shall 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 perndtted, the area shall be inspected by the individu'al 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 perndt. Xn confined areas, inspecti0~ shall be made with gas 'detection equipment in addition to visual. Working area shall be rechecked with a combustible gas indicator, before restarting operations discontinued over 30 minutes. 10. Cutting or we~ding shall not be permitted in 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 4gnitable materials such as fuel oil or lubricants, baled paper, e. tc. 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 o_.~ ~o~~ Any pipelines : f. When wind ¢o. .tions are such' that sparks c, .Id be carried to combustible materials.. -. 'E. PERSONNEL PROTECTION a. Helmets or hand shields shall be used during all arc welding or arc cutting operations 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 ob}ects. ; ' ¢. Goggles or other suitable eye protection shall be used during all gas welding or oxygen cutting or brazin~ operations. d. Helpers or attendants shall be provided with proper eye protection. e. AIl filter plates used in helmets and goggles shall meet the test for transmlssion of radiant energy prescribed in ANSI ~ 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 combustibility. Clothing made fr~m synthetic materials such as nylon, rayon, or orlon should not be exposed to welding work. o. -o. e. All clothing should be reasonably, free from oil or grease. f. For heavy work, fire-resistant 1 her equivalent 'protection should be used. v v e ~ .~.~,~.:~ :ii [I/j,,:~:. ~ ,ii '**'" .~' -", · ~-.. 1. Hechan~cal ventilation at the minim~ rate o~ 2,000 ~~ feet per minute ~r welder shall be prov~e~ when welding is done. a. In confined spaces or where the welding space contains partitions, balconies,, 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 containing hydrocarbons. · o :s where it is im~oss~ble to. (' ~vide ventilation, air breathing appara.tus may be used. ,,-' F'IRE and SAFETY WORK o SHELL WESTERN E & P INC. PACt['C FRONTIER DIVISION 7'frae ·.J~. .'7~mr ~,ie . ~.l,___--)Ar, rd . -- p.m. .. · 'J~'jmr of ]:qul;,mrnt: OWe)dJn£: 0 Cultlflf f~ )lord ~'~clflf~: f~ , · 'J')-j~r d Work*_ l~'ol~man 00 ! t ' I'*"--' /' .. ell im .. I · m imllll Bee emil*il · · I · / II m · ., · ~m II ..~ TEXAS ~ EASTERN 'Exldor. Uon Co.,~ .. . . . · 3001 Porcupfne Dr~ve Auc,'mroge, Alaska 99501 '".' RE: Statement of #onob.~ectton ~Lr,,-S7.0....~_ #all (Sea.! _Wp. 3j Gentlemn,'. ,.. · T~$' Euister, n'Esl)lQ'ret~O~' CO; has no"obJ: ctto. ~o the surf'~ce or, bott~hgle ..... .,.. " ....locet~on of t;he' BF-5~ I~," ! ~eTT. {Seat#~.. 3} ~$,.p~o~d,by 5hell ~s~e~ .,~'--'--,.~ , ' .; .," E&P. Jnc~ t0, 1ts ~.licut~ tot Femit tb Drt11., ...... ,., ..... " ' , K. ar~l,"" ' ' · .... " i ~., ' ~/IB~on 0. $~, IZI ~ , ' , ,,~ .~ he~r - b~ ..'" ,.. " ... ~ .., ~ , , " ,", , .. .. e, , ,. } * . , . ,80S':SLq. r . ,, ' ' ' ,, ' " .'.' ,. '". , ,.' , ..' '.' · d n .il .I ..Ifil. ~ll-'I ~11 '1 i. i Il .' B I' I~.I .ig~ e '1f II.e cc: Shell iksterP [~P Inc. ". ~t~..":' ~.' x;. #. I~Ms,em,; Jr. , Shell Western E&P Inc. A Subsidiary of Shell Oil Company 200 N. Dairy Ashford P.O. Box 527 Houston, TX 77079 June 15, 1984 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 third well from Seal Island, Seal BF-57 No. I on. the North Slope, 21 miles northwest of Deadhorse. Please note we plan to drill the well to 14,675'MD, but we seek approval to drill as deep as 15,500'MD. Attached is our draft in the amount of $100.00 for the APD fee. We would appreciate your usual expeditious handling of this application. Very truly yours, B. E. Bernard Division Production Manager Pacific Frontier Division RGH:bjh Attachment RECEIVED JUN2 11984 Oil & Gas Cons. commission Anchorage STATE OF ALASKA ,i. ALASKA ~.,',' AND GAS CONSERVATION CO,,..MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL E~ REDRILL I-i DEEPEN [-1 lb. Type of well EXPLORATORY [~ DEVELOPMENT OIL [] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [-I SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator She]] Western E&P, ];nc. 3. Address 601 West 5th Ave., #810, Anchorage, AK 4. Location of well at surface ~_~1'~ '9 E ,~~' FSL ~_ FEL Sec.' 11, T13N,~Ri~E At top of proposed p~ing interval ~ FSL ~ F~L Sec. ~, T13N, R13E 520' FSk F~k Sec ,113~, 99501 5. Elevation in feet (indicate KB, DF etc.) 55' KB J 6 . Lease designation and serial no. ADL 312809 9. Unit or lease name BF-57 10. Well number #1 11. Field and pool WILDCAT 12. Bond information (see 20 AAC 25.025) Statewide - INA Shel 1 0084 Type0il & Gas Surety and/or number llC 136503 13. Distance and direction from nearest town 14. Distance to'nearest property or lease line 21 mi,, N..W. Deadhorsem~es 11,78'. 'feet 16. Proposed depth (MD & TVD) 17. Number of, acres in lease 15500 MD 11850 TVD feet 5301.38 , 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICKOFF POINT 1700 feet. MAXIMUM HOLEANGLE45.3°I(see20AAC25'035(c) (2) $500,000 Amount $100,000 15. Distance to nearest drilling or completed well 5300 feet 18. Approximate spud date Jul.y 1, 1984 '~,O, ~ FI psig@__ Surface 5240 psig@!!270 ft. TD (TVD) 21 SIZE Proposed Casing, Liner and Cementing Program CASING AND LINER SETTING DEPTH Casing Weight Grade MD 7" 32# L-80 1238... 13437 22. Describe proposed program: TOP TVD I I I 0398 MD BOTTOM TVD inn,-+', !on,+- I 1600' !1600' 5000' 14465' 13737' I. 10610' 14675' 11270' QUANTITY OF CEMENT (include stage data) rlriw Pi~e 3000 Ft. 5200 Ft. 3 600 Ft,3 * 280 Ft.;~ Full Lengt[ 500' minimum over hydrocarbons RECEIVED JUN 2 1 &bska Oil & ~s Oons. Commission ^nchorage '23. I hereby cert/j,f)y that t.h~ fo. reg2ing is true and correct to the best of my knowledge SIGNED ~/~~ TITLEDiv. Prod. Adm. Mqr. The space belov~ for Com~nission use - DATE 6/.13/84 CONDITIONS OF APPROVAL Samples required ]~.Y ES []NO Permit number APPROVED BY Form 10-401 Rev. 7-1-80 Mud log required ~YES []NO Approval date Directional Survey required ~YES r-INO IAPl number a 113o SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE .T~m~_ 25; 1 984 by order of the Commission Submit in triplic' Attachment BF-57 No. 1 is a proposed exploratory oil well located 5-1/2 miles north of Kup Delta 51-2. A 30" conductor pipe will be driven to refusal (100+-) and a diverter system installed. A 26" hole will be drilled to 1600' where 20" casing will be run and cemented to surface with Permafrost cement. After drilling out and performing a formation fracture gradient test. a 17 1/2" hole will be drilled to 5000'MD(4465TVD) where 13 3/8" casing will be set. After drilling out and performing a formation fracture gradient test. a 12 l/&' hole will be drilled to 13737'MD(10610'TVD) and 9 5/8" casing will be set. After drilling out and performing the last formation fracture gradient test. an 8 1/2" will be drilled to TD where a 7" liner will be cemented in place. The formation pressure gradient is expected to be normal (.465 psi/ft.). Maximum BHP is expected to be .465 x 11270'- 5240 psi. Maximum surface pressure assuming a full column of .8 S.G. gas is 3850 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 diagrams/descriptions of the BOP equipment and diverter system. RECEIVED JUN 1 1984 Alaska Oil & Gas Cons. Commission Anchorage PROPOSED WELL PATH 'SHELL W(~ 'TERN E i P"~INC. It.'il('lF"5? NO."1 ' ' b,~AL EXPLORATION/BEAL IlL.,ND I I ,,' P&C { · PRCIFIC FRONTIER DRILL~rN$ PROGNOSIS WELL: SHELL WESTERN E & P INC. et al BF-57 No. 1 LOCATION: ASP ZONE 4 X: 659,838' Y: 6,031,315' LAT. 70°29'31.548'' LONG. 148'41' 35.428" OBJECTIVE: ASP ZONE 4 X: 663,486' Y: 6,024,178' LAT. 70*28'20.596" LONG. 148°39' 52.707" EVALUAT I ON GEOLOGY RECEIVED JUN2 1 Alaska 011 & Gas Cons. Commis RF E NO: Anchorage FIELD: SEAL EXPLORATION AREA EST. ELEVATION: 50' KB DRILLING WELL CASING ELEC . MUD SIGNIFICANT DEPTH AND CORES SURVEYS LOGGER FORMATIONS TVD MD CEMENT HOLE DEV. HOLE AND DIR. SIZE CONTROL MUD PROGRAM NO LOGS IN KINGAK. UNLESS HOLE COND. WARRANT ,,, '120' 600' KOP ANGLE BU'IL1~ T5 COALS 1600'__ 16(] 1700'_ LTO0' 3736' )965' m 4465'__5000' 4700'~ ~335' COLVILLE 7450' PEBBLE SHALE 8710' P~T/KUPARUK 8900'. KINGAK 9200' SAG RIVER 10610' SHUBLIK 10710' ,.9245' '~I036' '.!i733' 13737' :'-'t3879' 26" C~ m~o ,, 642 SEAL ISLAND BEAUFORT SEA LONG WELl- I: ISLAND .T I~,H,RI~E,UM. ViC INITY M AP Y-6051526. 64 ASPZOWa"f X' 659850.25 LAT.' 70*?.9':~1.661" LONG.= 14 8'41'$5.052" -~ ', ELEV.' ?.1.1 O' - - Y= 60:51:50;5.05 I ~5PZO~~X= 659825.2 I I.I PROTRACTEDI SEC II, 14 LAT.=7~29'~.4~' Ti~N,RI~.UMI L 0~= 148 '41'~5. 8~" ELEV~21'I2~ SOVF~ 80V~A~R 'OCS ~ZoC~ .~/~ NOTE: ELEVS. ~E TO N.~. ...... COR. ~~AR BOX UTA't ZOI~IE ~ COOl:lOS'., · WELL-:5 BF-5? NO.I ~~.A! P: "FIVED ASP ZONE 4 X =659838 Y= '~[~1~}','"~=~ t~ JUN2 119~ LONG 148° 41' 35.428" . I RECEIVED Oil & Gas Co~s. Commissio. Anchorage t)'eE~JS ~" LINE 7'0 $0" 'PiT O~TtL RECEIVED JUN2 ! ~g84 Alaska Oil & ~t$ C~$, O~mmissi~ Anchorage ~ Hc'K , ~.~ , ::~ '.~., . ,,~ 5E SHELL OIL COMPANY DRAWING AND CHECK LIST NO. 102 SHELL CLASS 2MR 2,000 psi Working Pressure SHELL MINIMUM BOP STACK REQUIREMENTS Min. Min. No. Item I.D. Nominal I Flowline ,. 2 Fill up line 2" 3 Drilling nipple 4a Two single or one dua~hydraulically operated rams* or 4b Annular Preventer -5a Drilling spool with 2" and 2" outlets or 5b 2" and 2" outlets in ram or annular preventer. Run kill line and choke line from these outlets. (Alternate to 5a above.) Gate I~1 2-1/16" 6 Valves Plu9 I~'1. 7 Line to choke manifold 2" Gate R1 2-1/16" 8 Valves Plug [] 9 Line to rig mud pump manifold 2" 10 Casing spool Gate [] 1-13/16" 11 Valve Plug [] . 12 Wear flange or bushing For well servicing -- not mandatory to be hydraulically operated. ® ANNULAR I --' ~ ' PREVENTER I [BLIND RAMS I ~> PIPE RAMS I?1, NOTE: Second wing valve on choke (6) and kill (8) lines not mandatory unless drilling below 2,000'. R£C£1V£D JUN Anchorage 59 SHELL MINIMUM AUXILIARY EQUIPMENT REQUIREMENT Master control with pressure regulating valve (If annular preventer used) Hydraulic BOP operating unit. See below for detail. (Not mandatory for well servicing.) Upper Kelly cock. Kelly Saver sub with protector rubber. Inside BOP, surface type, for each size drill pipe. Full opening ball valve for each size drill pipe in use. Labelled crossovers for each different connection in drill string. OPTIONAL AUXILIARY EQUIPMENT Lower Kelly cock. -- Unit Remote control. Cup or plug type BOP tester with spare seals. SHELL MINIMUM HYDRAULIC OPERATING UNIT SPECIFICATIONS Accumulator volume - sufficient to make one position change on all hydraulically operated units and retain 1,000 psi (but not less than 200 psi above precharge) without pumps. Pump capacity to recharge in 10 minutes from 1,000 psi (or 200 psi above precharge) to accumulator operating pressure. Power for pumps - 1 source required - Electric or Air - 2 pumps required. Lines from operating unit to BOP units 4°000 psi Minimum Yield [] Seamless steel lines .70" minimum I.D. [] Seamless steel lines with Chiksan joints [] Hose per Sec. 3.20 Operating unit fluids: Hydraulic oil or soluble oil. All controls shall be clearly marked to show unit operated. Blind Ram control to have easily removed latch or guard. Sufficient bottled nitrogen or other back-up storage system to equal accumulator capacity, manifolded to by-pass accumulator and close BOP directly. Alarm or visual indicator to show when accumulator is shut off from preventers. SHELL MINIMUM MUD SYSTEM REQUIREMENTS Pump stroke counters each pump. OPTIONAL MUD SYSTEM EQUIPMENT Degasser Pit volume recorder with alarm. Flow line monitor. Trip tank (with 6th man) Flow line gas separator MISCELLANEOUS EQUIPMENT SPECIFICATIONS AND INSTALLATION INSTRUCTIONS 1. All connections shall be welded, studded, flanged or Cameron'~:lamp of comparable rating. 2. All flanges shall be Apl 6B or 6BX and ring gaskets shall be APl steel RX or BX. Do not re-use BX rings. Always use new rings below lower most preventer when flanges are parted. 3. Drilling spools shall be forged or forged and welded. Pipe spools not acceptable. 4. BOP stack shall be braced to subbase or suitable support by turnbuckled lines or rods. (No rigid connections.) 5. All gate valves shall be equipped with handwheels. Rams should have manually operated screw locking extensions (extended beyond Subbase) ready for use. 6. For land rigs, the master control station and operating unit shall be located at ground level, a minimum of 50' from the well. If used, the remote station should be located near the driller's position. For marine rigs, the master control station and operating unit may be on the rig floor with the remote station located so that it is protected from the well area and accessible from a logical evacuation route. Hydraulic lines may be high pressure hose provided they meet the requirements in Section 3.20. L in the Shell BOP Control Manual. Inoperative.condition of remote unit is not to interfere with operation of the master control unit. 7. Housing and heating should be provided for accumulator, blowout preventers, choke manifold where conditions warrant. 8. Contractor shall make no connection to casing head side outlets except by orders of Shell. 9. One spare set of ram blocks for the drill pipe in use shall be kel3t on rig. 10. Any misalignment of rig should be corrected to avoi~t undue wear of casing. 11. Four way valves shall be kept open or closed, not in neutral position. KILL A~ RECEIYED JUN 2 'Alaska 0il & Bas Cons. r~ommtssion Anchorage 72 SHELL OIL COMPANY DRAWING AND CHECK 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 Drilling Nipple - 4 Annular Preventer* _ 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 C~_~ing Spool 14 Gate Valves 1-13/16" ~ 5 Flanged control plug or valve 1-13/16" 16 Compound pressure guage ~7 Kill line to rig mud pump manifold 2" OPTIONAL 18 Rotating blowout Preventer** 19 Power operated valve gate 6" 20a Drilling spool with 3" outlet or 20b' 3" Outlet in ram preventer 21 Gate valves 3-1/8" 22 Auxiliary choke line 3" :23 Roadside connection to kill line 2" 24 Shear ram blocks for blind rams ,,f *NOTE: If design criteria indicate 7,000 psi or greater, a 10,000 psi w.p. annular preventer should be used, otherwise a 5,000 psi unit is satisfactory. *'3,000 psi rating ANNULAR PREVENTER BLIND RAMS O PIPE RAMS O (~) ~ PiPE RAMS ,,~ JUN2 119 Alaska 011 & Gas Cons. Commission Anchorage 73 SHELL MINIMUM AUXILIARY EQUIPMENT REQUIREMENTS Master control with Hydril pressure regulating valve 6 unit remote control Hydraulic BOP operatin9 unit. See below for detail. Kelly cocks [] Upper [] Lower Pressure Ratin~] 5,000 psi Kelly Saver sub with protector rubber. Inside BOP, surface type, for each size drill pipe. Pressure Rating 10,000 psi Full opening ball valve for each size drill pipe in use. Pressure Rating 5,000 psi Labelled crossover subs for each different connection in drill string. Circulating head for each size drill pipe in use with steel pipe and Chiksan joints to reach standpipe connection. OPTIONAL AUXILIARY EQUIPMENT Inside BOP - Drop or downhole type. Cup or plug type BOP tester with spare seals. SHELL MINIMUM HYDRAULIC OPERATING UNIT SPECIFICATIONS Accumulator volume - sufficient to make one position change on all hydraulically operated units and retain 1,200 psi (but not less than 200 psi above precharge) without pumps. Pump capacity to recharge in 10 minutes from 1,200 psi (or 200 psi above precharge) to accumulator operating pressure. Power for pumps - 2 sources required - Air-Electric or All Air (rig air plus separate air tank) - 2 pumps requi red. Lines from operating unit to BOP units 5,000 psi Minimum Yield [] Seamless steel lines .90" minimum I.D. [] Seamless steel lines with Chiksan joints [] Hose per Section 3.20 Operating unit fluids: Hydraulic oil or soluble oil. All controls shall be clearly marked to show unit operated. Blind Ram control to have easily removed latch or guard. Sufficient bottled nitrogen or other back-up storage system to equal accumulator capacity, manifolded to by-pass accumulator and close BOP directly. Alarm, or visual indicator to show when accumulator is shut off from preventers. SHELL MINIMUM MUD SYSTEM REQUIREMENTS Pump stroke counters each pump. Degasser Pit volume recorder with alarm. Flow line monitor. OPTIONAL MUD SYSTEM EQUIPMENT Flow line gas sel~arator Trip tank (with 6th man) MISCELLANEOUS EQUIPMENT SPECIFICATIONS AND INSTALLATION INSTRUCTIONS 1. All connections shall be welded, studded, flanged or Cameron clamp of comparable rating. 2. All flanges shall be APl 6BX and ring gaskets $h011 be APl steel BX. Do not re-use BX rings. 3. Drilling spools shall be forged or forged and welded. Pipe spools not acceptable. 4. BOP stack shall be braced to subbase or suitable support by turnbuckled lines or rods. (No rigid connections.) 5. All gate valves shall be equipped with handwheels. Rams should have manually operated screw locking extensions (extended beyond subbase) ready for use. 6. For land rigs the master control station and operating unit shall be located at ground level a minimum of 50' from the well. The remote station is to be located near the driller's position. Inoperative condition of the remote unit is not to interfere with operation of the master control unit. For platform and barge rigs the master control station and operating unit may be on the rig floor with the remote station located so that it is protected from the well area and accessible from a logical evacuation route. Hydraulic lines may be high pressure hose provided they meet the requirements in Section 3.20. L in the Shell BOP Manual. 7. Housing and heating should be provided for accumulator, blowout preventers, and choke manifold where conditions warrant. 8. Contractor shall make no connection to casing head side outlets except by orders of Shell. 9. One spare set of ram blocks for the drill pipe in use shall be kept on rigs. 10. Any misalicnment of rig should be corrected to avoid undue wear of casing. 11. Four way valves shall be kept open or closed, not in neutral position. CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee ~-'~'---~, 5b./ '~ : . (2) Loc (~.~-._~... '? - / 3 -?~'~'? ,~("'2 thru ~7 ":" YES NO REMARKS ., 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 ................... 5. Is sufficient undedicated acreage available in this pool ............ ..'~ . 7. Is operator the on y p y ............. . ~~ 7-/7'~q s. Can'permit be approved before ten-day wait .......................... ~,. '(8).. (3) Admin ~-~. ?-~/~'.~,~ 9. Does operator have a bond in force ................................. [<~-~.__ {' '.~ . ~(~ thru 1.1) ' . 10. · Is. a conservation order needed ...................................... ~%~. . .... ' .... . . . ~J~ :: 7",./7~ffq'' . 11,' Is administrative approVal needed .... . ................................ ' ~.. . · . ..' ' ." ii: i:iiiiii: iiiiii!i:i!i i!!i!ii! i i :!iiiil .. ~ : !: ':~1~ ~i:~..~.:~..:::~:~:~..~:...:..:.:/:..~../.~:.?.~:.~.:i:~..~!..;......:..Ar....~.:..:p.&e~:ssa~y, a.~:~:~...:::...:~af..:.~:...:a~e~;t~/.~.....:..ana....)::~.~..:ieq.u..~ea%~.?:~a:ehed''' "' :~ ::::.~:. · ..' ~ ~ .~:,:?:.',':.:' "."'.::":': ~.:.:.:: ./.i:.'.. :::: :~.~:'!2'$:2 ':::.:"".~:0:~.~" ]~'O~'.E:' '~ave:...s~/::£ :~ ..: ~ .".. ,.' ..... "',.":.:.,:,:'?.,.':,:.'::,.,: ...... ," ,v .' · v .,.., ..... "~ 'i .i ..' ': · : - .i :. '~~!.:.",'.'i ." :"'i:... .::."':.".':.'.'.? i":'..'...'?..i.'J2:.4 ?..."..Do.e's''ehe'.'.dh6ke['. ma'ffi'f ~ld. ." .. co, mply' ..:?(?~.:.' GeologY,: ' · 'Engi.n~, ~. i._n'g: ':'i,?: .' :,.'.'. ~"i... ':':?"."'"....ii:":': :..,.'.i'/:.:.~.'': :'..,.:. :..'.':..' :.,'/:"/?:..:."i'"';.....:'.'.'~':" .'.. :"'..'.':.':'.:".::"..i"."...'.': · ,',~.( . "~ . , · 2.. ~----.--~...~..' .' t. ~ ~!.~,,.....,.,,...:-..' .:.'.:....... '.i.": ';" " ' :: . .' ~ .'.: .'"'. ...'.... ".. '.. ..... ......". ":-:.~ ' '."/i"".."".' '?':"..'""':' ."' ", ' ".' :" .. ..': '. ~ '. '. '." . . ." ' :'." . ' ..': . ' .... .' ' '"" '.' ..".:..4".' .' '" '.. "' ~. ..' ' · ' : ' ... : . . ' .' '.: . .....' ' ' .' [.' "" "'.. ': ".' ' ':.. · ' . "'. . ' ' ' ."'. "!'.. : ' ' ' ..', ".' ':':':'.'," ..%`~.~...``........:v~..:::..~..:.;...:t....?:/:.:.~.~!:.~:...:.......~....v.~.......~..~.. ' .. ".'.".".'.' f". :"' '. '..".. " .' . :',,' .'.,.'. , :' ' '"' 'i"" . .'... , .:'i ..... : ": '..". '}:' " :'. : ... '..' .': '..' .... ' .." ...." . .'"'.". ".'... .' ......: .:~ .~... '..' . ...... .. "' ...'. :'."'...:::.:.':'.::.':'.':'.i':. iI ............ CHECK LIST FOP. NEW WELL PERMITS ITEM APPROVE DATE Lease & Well No. YES NO REMARKS , ,, (2 thru 8) ' 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 .................... ~ 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 ......... !ii ~]]~i~!'*/~d >~gE~V~O ~-~A-~q'#O'~ 8. Can per. it be approved before ten-day wait ..lllllllli . i'll ....... ' ~ ~o~"/e~ _~. '~;~'~s~. (8) (3) A min (9. thru 11) (.lp. aha 1,I') ' . · ·..'...' _. ;- ::: -~:2'- . - ' ~- ~: --c-~ -..'.~- .: _ ~ - . e 10. 11. Does operator have a bond in force ............................ . ...... Is a conservation order needed ' ' ..,...,..~.....®~$$...$....~....~..®.. Is administrative approval needed 12. I.s conductor string, provided ........... ' 13.. Is euough 'cement used'to circulate';; ;';;~;;;';; a;~..;;;ia;; ;:[;[[:::" 14'. Will cement, tie in surface and intermediate o.r production strings .¢ 1'5'.' .Will..cem.ent.'c°Ve.r'.'a.'l:l'.known pr0d.uC.t.iVe"horizons .... ,'. ........... . . . ... . . . . . ,., .. .' , . 16 'Will,'. rfa cas ng prot ' fre ' ' ' ' ' ' ...'. Su ce.. :i .. e.ct ,s.h. wa.ter zones.. ...... . ..... , ........... " .. 1.7'.,....".' ..Wi:.!.l' all:'" Casing.. give. adequate. S. afety..~..i-m, c.Ol'i..ap, se..,..t..enSion, and b.u~s.t'...i,. ~ .... · :: INI'TIAL:~: .'." ~GJEO,- : UNliT "/ON/OFF 'P-00L.' : CLASSL. STATUS kREA - NO.. .: SHORE" 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 APPENDIXl No special'effort has been made to chronologically organize this category of information. ,'. ,... · :?~.i'.. 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