The URL can be used to link to this page

Home My WebLink About100-235• Page 1 of 1 Maunder, Thomas E (DOA) From: Foerster, Catherine P (DOA) Sent: Wednesday, February 04, 2009 9:04 AM To: Maunder, Thomas E (DOA) Subject: RE: Status Change to P&A Recommended for Two Suspended Wells I agree. From: Maunder, Thomas E (DOA) Sent: Wednesday, February 04, 2009 8:14 AM To: Foerster, Catherine P (DOA) Cc: McMains, Stephen E (DOA); Davies, Stephen F (DOA); Roby, David S (DOA); Saltmarsh, Arthur C (DOA); Williamson, Mary J (DOA) Subject: Status Change to P&A Recommended for Two Suspended Wells Cathy, ,A `-~.~~i ~~~ ~ ~~ 7a~~. ----~ 100-235 OCS-Y-191 #1 ~----- 100-271 OCS-Y-191 #2 I have reviewed the subject well files and reports of final well and island abandonment dated early October, 1983. The final well and island abandonment document was received by the Commission April 14, 2008. I believe this document was obtained through the efforts of Dave Roby. Although the Commission does not have jurisdiction regarding these wells, it is not unusual for federal offshore information to be carried in the Commission files as part of the historic record of drilling on federal offshore acreage in the Alaska Region. These wells are carried in RDBMS as Suspended. That status was correct according the last information received by the Commission in April and May 1982. On the basis of my examination of the files and the most recent documents, it is my opinion that OCS- Y-191 #1 and OCS-Y-191 #2 are properly plugged and abandoned. It is my recommendation that the status be changed from Suspended to P&A. I further recommend that since the P&A work was accomplished in 1983 that the effective dates for P&A be September 20, 1983 for OCS-Y-191 #1 and September 23, 1983 for OCS-Y-191 #2. If you agree with this recommendation, please message back. I will place a copy of your response in each well file. Tom Maunder, PE Sr. Petroleum Engineer ~F~ ~1e0 ~- ~ 2009 2/4/2009 9-331 ~ . n Approved. 1973 oudget Burt=au No -~; UNITED STATES 5. LEASE ~' -; DEPARTMENT OF THE INTERIOR OCS-Y-1-9~. _ GEOLOGICAL SURVEY 6. IF INDIAN, AE~QTTE£ OR 7•RIBE NAME SUNDRY NOTICES AND REPORTS ON WELLS 7, UNIT AGREEMENT i~IAME., (Do not use this form far proposals to drill or to deepen or plug back to a different reservoir. Use Form 9-331-C for such proposals.) $. FAR•Ii.~~.Kp-~~~'',' 1. OII gas , `~{~~5~_~~~ well ^ well ^ other Exploratory 9. WELL N0. 2. NAME OF OPERATOR 1 ~ ~ ZO~8 way-a3 ~---~ Exxon Corporation 10. FIELD OR WiL[7~~T~VAMry~ - - 3. ADDRESS OF OPERATOR /~~~c (,~~Q~~~Q(1S ~0111(~1 Pouch 6601, Anchorage, AK 99502 11. SEC., T. R ~~QN 7JD5 ~2V~Y OR 4. LOCATION OF WELL (REPORT LOCATION CLEARLY. See space 17 •'AREA (5 ~ ~ C . ~ 2 Q , T. 10 N , below.) Well No. 1, 1777' SNL & 708' R ~;~-w~, U~ _ AT SURFACE: y~L Blk 6 54 12. COUNTY OR • ~ ~I 13~, STATE ~~~lp+~~:TxT~r~p~~'`~~p~~N2t~€~ Well No. 2, 1777' SN nff~l,c,r~~ ~~~ ~A~ask~. XXX~XXK~~X- & h 8-' W B 1 k h 5 4 14. API NO. F= ~ '~ "7 y 16 CHECK APPROPRIATE BOX ~ 5 ~==~~. - 0~ 0 ~ 1 a;~ld • TO INDICATE NATURE OF NOTICE, 5~~-'~~Q~1-0 002' REPORT, OR OTHER DATA 15. ELEVATIONS (Slfi~l/ DF`a"KQ6, AND WD) REQUEST FOR APPROVAL TO: SUBSEQUENT REPORT OF: y~ ~ ~ ~'~" ~-'~ '~ i -NiSL WD 1~ ~ _>.:= TEST WATER SHUT-OFF ^ ^ ~~ - ~ FRACTURE TREAT ^ ^ ,- ~, .~ SHOOT OR ACIDIZE ^ ^ - ~ ~-- ' :` ~ . ~ REPAIR WELL ^ ^ (NOTE: Report result's of naultiplexompleti~n~r zone PULL OR ALTER CASING ^ ^ change on Form 95 330). ~ MULTIPLE COMPLETE ^ ^ _. ~, ~ ~ CHANGE ZONES ^ ^ ~ ~ -~ ' rr C ABANDONS ^ ^ ~ ; ~' G ~ U ;D ~ ,~ ~"~ - , (other) ~b~ecrnc~nt rPrx7rf cif nPrmanent abandonment -of island ~oc~a°t~i~n _-- ~ ~~v~ 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details~~ a,rit~ give~peiae~t'~ates, including estimated date of starting any proposed work. If well is directionally drilled, giri8 subsurface loc~~~ and measured and true vertical depths for ali markers and zones pertinent to this work.)* ~; ~ ~ ~ ,' ~ ~ ,~ ~' - . ~~ r This island location was permanently abandoned on ~',~te»b~l~~, 1983. Attached is a report detailing the abandon~~rl oe~~.t.~ns. i~Vl:.l? ,~ .~ ~;_ r ~ ~ I~ ~I ~ ~~ ~ m ~; ~- ~; _, ~ ~~ m ~ iV : )~ - :~ .L ;Ail ~ ~ ~ t' ~;S ~„ ;~ r " ~~ 'J° ~ `3 ~ ~ ~ ° a {a {1' - ~ ~ ` S ~ ~ `' ` MANAGEMililT `~ MNa~I-1 ~, . ~Q!~ACE, I4LA~i6A ~ _ ~ J Subsurface Safety Valve: Manu. and Type ~ ae'# ~"~ J ~ ` Ft. 18. Ihereb yc t '~ #oregoingistrueandco~ecL.lOratl di C t~ -~ ° '~' '• '' On na oor . ~ / ~, SIGNED ~ Alaska l~ ~~lo ~83~ TITLE DATE ca ~ ~;.. it _ N _ ,TCInP c ~ ~ ~, a c~ ~ i/1 (This space for Federal or State office use) ? '' ~ ''• ''ROVED BY ~"Y °' /~~ of , a ~~~ 1 H ~.~~~ ( . T1r~Ff~HL1&E DIST SUFEf2~.~0,. DATE ' iDITIONS OF APPROVAL, IF ANY: °See Instructions on Reverse Side L?ISTRIG~°) ~. • E7~ON COMPANY, U.S.A. RE~E~VEQ ~~c~w~o POUCH 6607 • ANCHORAGE, ALASKA 99502 APR 1 4 2008 :acs A~S~"RicT o~~~c~ EXPLORATION DEPARTMENT plaslca Oil & Gas COnS. Comrr~-ssron ~~; 1 ~ =' ALASKA/PACIFIC DIVISION anchorage ~p p~Cpp p~ ~1 ~g~ _ _ D.H. JONES IY1~tdGtV'~L~ 11I1A11tAC7CiY9E~~~ a9~~~iViin+'ns EXPLORATION COORDINATOR - ALASKA ~ic1'i'Viv'~~~..9 ~~~~~ October ll, 1983 OCS Y-191 Island Drillsite Permanent Abandonment Mr. Brian Schoof Minerals Management Service Alaska OCS Region 411 West Fourth Avenue, Suite 2A Anchorage, AK 99501 Dear Mr. Schoof: As you requested in your August 25, 1983 letter, attached is a follow-up report of the abandonment operations conducted on the OCS Y-191 island drillsite. If you have-any questions concerning the report or the operations that were conducted, please contact me at 263-3714. Very truly yours, NB:sjm 40/25 Attachment A DIVISION OF EXXON CORPORATION R~CEII~EC~ APR 1 4 2008 g18~skat Oil & Gas Cans. Commissio ,,....... Anchorage Introduction • FOLLOW-UP REPORT OF ABANDONMENT n EXXON'S ISLAND DRILLSITE OCS Y-191, WELLS NO. l & 2 ~~~~d acs ~~s r ~~cr ~~~ec ~ilI~ERALS ~A1dAG~i~~i " S}~~r A~Nt~B~~~, ~~ This report is a follow-up to the abandonment plan submitted by Exxon on July 29, 1983 (see attached). This report details the actual operations conducted during the work. Pioneer Oilfield Services, Inc. was the general contractor for the project. Burrell/Heppner Construction Company, Inc. was the subcontractor for the wellhead removals. August 31 - September 1, 1983 During these two days, equipment was mobilized to the island by barge from Deadhorse. The equipment consisted of: two 966 loaders, 90T crane, 80T crane, D-8 cat, compressor, air drill, and a 40-man construction camp. .The cellar boxes were removed and sandbag removal started. September 2-12, 1983 The sandbags were removed using the two cranes working from the island surface along with the 966 loaders and cat. The cranes worked the underwater slopes of the island while the loaders and cat recovered the above water bags. Labor crews assisted in splitting open the bags, stacking empty bags and banding them together. The loaders and cat were also used to pull the filter fabric up onto the island for stacking by the labor crews. Two divers assisted the crane operators during the underwater bag and filter fabric recovery by establishing the outer limits of the bags and marking them with buoys. On September 12, 1983 the divers made a final inspection of the island perimeter and did not find any bags or residual bag material. Attachment II is a copy of the re ort Dr. Robert Lewellen, w o conducted the inspection dive for Exxon After the inspection, a portion of the cloth, one loader, and a water truck Deadhorse. September 13-24, 1983 camp, all of the filter were demobilized to The wellhead removal work began on September 13, 1983. The Well No. 2 9-5/8" casing was cut using a shaped charge and pulled at 17.5' below mudline (BML). On September 14, 1983, the Well No. 1 9-5/8" casing was cut at 19' BML. The air drill and compressor were then used to drill holes outside of the 42" conductor pipes. These holes were loaded with explosives and blasted to loosen the frozen backfill around the conductors. Explosives were also loaded inside the 13-3/8" casings and shot to shear through the casing and conductor pipes. Steam lines were placed outside the 42" conductors to a depth of approximately 40' to further loosen and thaw the material around the conductors. After the material was sufficiently thawed, a clam shell bucket was used to excavate around the conductors to a depth of 35'. The conductor and casing strings at Well No. 2 were pulled on September 20, 1983. They were cut at 17' BML. _The conductor and casing strings at _Well No. 1 were pulled on September 23, 1983 from a depth of i8'! --~. The D-8 cat and loader were then used to rac-kf;t1 the areas where the conductors had been removed and to place gravel in hummocks over the surface of the island. On September 24,.1983 the camp was rigged down, navigation lights were replaced on the North, South, East, and West sides of the island and a final cleanup was conducted. The grading work was completed and a small level area was left on the south side of the island for a helicopter landing. area. The camp and equipment were loaded onto barges and demobilized to Deadhorse. The attached photographs show the island surface after removal of the sandbags and the conductor and casing stricn~gs which were pulled. RO ~~~~°Scv~~S PCO•.>`tic`~rccJ ~~ ~j~-a~ To verify complete removal of the slope protection materials, Exxon will conduct a follow-up diver inspection during the 1984 open water season. During this time we will also install the waterfowl nesting boxes in coordination with the USF&W and the North Slope Borough. E~~ APR 1.4 2008 NB:sjm 40/27 Attachments Alaska (7i1 & Gas Cons, Commission -2- ~ ~ 1 ~~ • - d-131 ,.' . ''' 1973 • form Approved. duddK Bureau No. 42-R1424 . U D STATES ~ sE ~ :: _ _ ^ ~ DEPARTMENT OF THE INTERIOR e OCS Y-191_ _ ' ~sEOLOGICAL SURVEY 6. 1F INDIAN, AtiLQT'i'EE OR 7RIBE:NAME SUNDRY NOTICES AND REPORTS ON WELLS :. - 7. UNI7AGREEYENTi11AME c: =~ (Oo not use this form for pro ak to drill o- to deepen or plutt back to a difhnnt pos reservoir Use Form 9-33]-C for ivch propouls ) _ _ = _ _ _ e - !e . . $. FARM OR LE~SE RAME is c =- `- - - ~ - 1. oil ;as ^ ^ - £ _ ~- _. ~ - well wen other Exploratory ` c - s 9. WELL NO. - - 2 NAME OF OPERATOR _ 1 and 2, " _ ~_ v ~ = z bacon Corporation c 10. FIELD OR WIt.UCATNAME - 3. ADDRESS OF OPERATOR Wildcat - ~ - y s Pouch 6601, Anchorage, AK 99502 11. SEC., T., R., Y«OR~~BLK. ~1ND S'~iRVEY OR ~. LOCATION OF WELL (REPORT LOCATION CLEARLY. See space 17 ~~- 65k, :Sec. 2Q, LION, below.) 817E '. VM - `_ _ = f AT SURFACE: Well No. 1. 1777' SNL b 708' EWL, 12 COUNTY OR PAi2iSH 13. STATE ~-7 ~R-~a--+~~~ Blk 654 ~ Offshore lllaska ` ~. ~~77 • SNL b 683' ~7_IQ'iAl_QEPJl~: We~No • $1 6 14. API NO. s~ ~0~-00001. ana 16. CHECK APPROPRIATE 80X TO INDICATE NATURE OF NOTICE, 55-201-00002 ~ ~- ~ =- REPORT, OR OTHER DATA 1S. ELEVATIONS'~jSNOW DF,-iC08, ARID WD) To of islannd + 13.3 ~ ~ISL WD 18' REQUEST FOR APPROVAL TO: SUBSEQUENT REPORT OF: , - TEST WATER SHUT-oFF ^ ^ ~`~ G$i V~ j' fRACTURE TREAT ^ ^ SHOOT OR ACIDIZE ^ ^ ~~ ~ _ r _ REPAIR WELL ^ ^ _ (NOTE: Report resuMs of AfuRiple eoniplatipn or zone PULL OR ALTER CASING ^ ^ ehea+se~p~rm s,33 MULTIPLE COMPLETE ^ ^ .• r Y _ _ _ _ _ CHANGE ZONES ^ ^ ~ =` -' _„_ : - : c } - '- y (other) Dermanently abandon island location ~ -'' = - = ~ - - =• s ~. - 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Gearfy state alt pertinent details, dnd give peeiinent~lstes, including estimated date of starting sny proposed work. If well is directionally drilled, give subsurfsce bcat+ons and measured and true vertical depths for sll markers and zones pertinent to this work.)• - _ - v _ Approval is requested to permanently abandon this island ~.Ocetion fa accozdance with the attached plans. =_ <- ; ~_ - ~ . - .~ C' r. S. Abandonment details and drawings of wellbore No. 1 were proved on ti_;; ~~` March 29, 1982. - ~ S i ~: " `,: c - -:: -= Abandonment details and drawings of wellbore No. 2 were ~pros-ed on =. --= April 13, 1982. . ~ _ ~• = ` ` '" - ~ ? - - . - ,T _ 1 _ ^ ' ~ ~ - - _ ~ - . ` Subsurface Safety Valve: Manu. and Type _ ..` ; r - ~ ~ ` ` Ft. 18. 1 hereby certify the foregoing is true and correct ` L C ~ ' ~ _ ~• = ~ ~ ` ~ = - ._ _ ~ ~ r SIGNED TITLE _ ~. . ~ ID i. - _ OATf .~(il~/ ~9* ~$3 `- - (This span for Federal or State offiu use) _ •- ~ L -' :- = -~ ~ - S = ' ~ AUG 2 51983 SUPERVISOR ' FSHORE DIST ~ . ~ ~QF t APPROVED d~ T _ c PATE - %• •o c• T CONDiT10N5 Oi APPROVAL. IF ANY: - " - ~- ~' ~' n ~ 7 -. ` y j L ~ - C V ~~~ r t ~~ !rt"~ - 4C t =- . •:,..6,etrvetie~..n Reeene ad. App 1 4 2008 Alaska ail & Gas Cons. COmmissian Anchorage ''.AN OF ABANDONMENT 7 XON'S ISLAND DRILL SITE OCS-Y 0191, WELL NOS. 1 AND 2 Introduction- RECEIVED ois~icT OIL M10 (~qg Ogg , :a 4 '' 1983 ~INCHOf3AGt; j~„A8Kl--~-. This report has been prepared to provide information to the reviewing agencies on our proposed plans, methods and techniques for abandonment of the OCS-Y-191 island, including the scope of work involved, and our planned schedule. The abandonment plan consists of removing all artificial mate- rials (i.e. sandbags, filter fabric, and conductor and casing strings) from the island and allowing natural forces to erode and re-shape the island. Island Description emu. ~s-built drawing of the island is included as Figure 1. As shown on the drawing, the surface diameter of the island is approximately 450 feet. Figure 2 is a cross-sectional view of the island which details the slope protection materials. As shown on this drawing, the water depth at the island site is 18 feet. The island has 13.5 feet of freeboard for a total height above seafloor of 31.5 feet. Approximately 12,000 sandbags are currently in place on the island. The bags consist of woven polypropylene material. Each bag contains approximately 2 cubic yards of gravel fill. The majorityof the baggs have been placed in a single layer, however from +10' MSL to -10' MSL there is a double layer around 751 of the island,•refer to Figure 3. Under the sandbags is a layer of polypropylene filter fabric. The filter fabric was placed in 40' x 125' overlapping lengths (approximately 272,000 SF total was used). Twa wells were drilled. from the island and their cellar box ~iocations are shown on Figure 1. The cellar-boxes are 10' x 10' 'x 8' deep fabricated from 1/2" steel plate with 4" of insulation !.around the outside as shown in Figure 4. Wellbore sketches for 'each of the two wells are shown in Figures 5 and 6. These ,sketches show the casing and conductor strings along with the 'wellhead sections currently in place for each well. i As shown in Figure 5, Weli No. 1 has 9-S/8", 13-3/8", 20", a 28" x 32" x 36" refrigerated conductor, and 42" casings. The 9-5/8" x 13-3/8" annulus is filled-with calcium chloride water. All ,other casing annuluses are cemented to surface with permafrost .cement. Well No. 2 is shown in Figure 6. This well has 9-5/8", 13-3/8" 28" x 32" x 36" refrigerated conductor, and 42" casings. The 9-3/8" x 13-3/8" annulus is filled with calcium .chloride water, I RECEIVEC~- APR 1 4 200$ Alaska Oil & Gas Gons. Commission ._ ~ Anchorage ,. -c- AECEIVBD all other casing annuluses are cemented to surface with ped~ct frost cement. ~so~~ A t-2" diameter, approximately 40 .feet long velocity aurvey~~~pey jo83 is also located in the island as shown on Figure d. This pipe is not cemented, just backfilled with gravel. -~'~ _ __ • Sandbag and Filter Fabric Removal ~~~- '' All sand bags and fitter fabric will be re~v+ed fran the island, both above and belay the water level. A large crane will be used too conduct this operation either working fran the island surface or using a barge. The gravel from inside the sand bags will be used to fill in the areas mere the conductors are raroved. The reraining gravel fran the sand bags will be du~~ped in an irregular pattern on the island surface to provide a Wore natural ar-~earanoe to birds and ~im31s . An array Of -24 plywood water fowl "npstirig" boxes (Geo~~ge Dicky designs3) will be installed. This activity will be ooord.inated with USF and W. Diver inspecti.oazs will be conducted to e:LSUre that slope protection material are retrieved; confianatian dives are scheduled during the 1984 open water ~ seasoaz. The empty sandbags and filttr fabric will be hauled off the island and will be disposed of at an approved site such as the LU :cz.h Slope Borough's disposal-yard in Deadhorse. (,~ ~Tellheads, Cellar, and Casing and Conductor Removals ~ The wellhead sections and blind flange from the two wellheads will be removed and transported to the E~cxon pad in Deadhozse. Exxon will provide the recessazy inspection to insure that the wellheads are properly removed and it is .safe for the conductors and casings to be removed. The cellar boxes will be excavated and completely removed includ- ing the 4" of insulation and any wooden timber materials which may have been installed on the inside for support. These mate- rials will be hauled off the island and disposed of at an ap- proved dump site. The conductor and casingg strings from both wells will be removed to a depth of at least 5 meters below the ocean floor as required by Alaska OCS Order No. 3 - Plugging and Abandonmeat of-Wells. Subject to any permit restzictionc, explosives will be .used to cut off the casing and conductor strings. Air drills may be utilized to drill between the casing strings and outside the y2" conductor to loosen the cement and provide access for more explosives. After cutting the casings, they will be removed using a large crane and hauled off the island for disposal at an apgzoved dump site. Only qualified and experienced blasting contractors will be used. In addition, Exxon will review and approve the contractor's plan. pricy to blasting. The work will be carried out in accordance with all federal, state and local zegulations~peztaining to the transport, storage, and usage of any and all txplosives. 0 0 N '~ Q .~ ~~ as a ..a Project Schedule ~ - - .~ Subject to obtaining all of the required permit .approvals, we plan to stare work in early August 1983. The work is expected to take approximately 30 to 45 days to complete, depending on weather conditions.. Camp and subsistence facilities in Deadhorse will most likely be utilized during this project, due to the close proximity to the work area. All work will be supervised and approved by Exxon. Wei plan to maintain at least one representative on the project at all times. ~ ~. _. _. - - - Island Fate An artificial island with unprotected slopes will erode. in a similar fashion to the natural barrier islands. in general, with sufficient wave action, the slopes which front the waves will begin to erode first.- Sediment or gravel fines from the eroded area will be transported around the sides of the island .and may form 6ma11 spits which point in the direction of prevailing winds. This process will probably continue .until the gravel above the waterline has eroded to below wavebase. The length of time for this process to occur is dependent on many variables including the size of the island, water depth, type of fill material used to construct it, grain size of fill material, and the frequency, duration, and magnitude of storms. It is almost impossible to predict how rapidly a particular artificial island without slope protection will erode, but estimatts can range from a single storm event to many years. Figure 7 shows the fate of Exxon's Duck Island Pad 1 three years after construction. This was a 400' surface diameter island located in 4 feet of water approximately 4.5 miles southeast of the OCS-Y-191 island. This island did not have any slope pro- tection materials installed on it. ~n the southeast and north- west sides of the island the spits are clearly cvident and indicate that the island is eroding. ~~~~`~~ NB : rms 2008 40/34 4PR ~. ~ i't'{{~ yCii13~ ,:i~&GasCa-s.Com,.:.: , gE0EIV8D Anchorage ~~+~ OIL AND OAS OBE f~.'..; ~ 4 283 ...~. - I. ,,_.K -mss i~, fi- i~~~'~` ''=~ ~~ ~~1 >1 t : ~ ~~ L c ~a~l • ~ 1 ~'!' 1 ~.1 ~ , i_ ~_ _ ~ M ~ ~ j ~ i ~ ti ~ ~ Z s •~'; se i ~~ i 2 :. Y ' .~ is i ~~ 1 r +~prii E • i i) r ~ /~ ; = _ - ~r. f~ _ ! i;. SIT YI •~i ~- ~~ .. j / ~ f: / / ~ _ .~~ j !«: is I 1 i j S _• t ~ _~. ~ )I • Q t ~~~ ~ , 3F ~ ' ~ ~~ . .:. .,: :: -------- /% // i. ~ ~-' ~ !~ ;, ` d. ~ _' a :i ~«';. _~_ -_ Q Y O ~ N v ~ Q ~ X r p t7 ~ O W } r ~ ~ N N u p J ~ _J Op X x ~~ ~ \ ~` i ~` F~~~ , ~ APF~ ~ 4 ~i;~8 Alaska dii ~ Gas Cons. Commission Arxrhorage _ ___.___...,~ / , RECEIVED ptBTHlC7 / Olt AND OAS OFFlCE F.:;G 4163 AOt; -. ~ ~...__ Q A ~ turf ~~ ~ m 2~ ~L • . • - ,' ~, .. M ~ a .. a . ~, ~ . ~, o ~ ~ ~ -- o . N li 1 ~ ~ ~ ~ 0 0 _ ~ ~: ~~ 3 +~~~ + ~ ~~ F~ - c tc ~~ ~ 1 Q Q ~ , ^ v I ~. ~- O a z a ~ •• g ~ o m a a U W .r O tt! a X ~ c W m ~ e ~ i ~ ~ 2 O 3 !n c N o °' ~ ~' ~t ~ ~ o U C V ~ _ ~ o ~, ~ - a ~ m 0 1 0 } ~ °~ ~ " ' a n ''#i~~ ~ V ~ o ~w ~~, ~ ~ ~~R ~ 4 ~i~08 c Alaska Oil 8 Gas Cons. Comm' ' . Anchorage agCE1Y8D o~ ~ ~ ,u~ ~,1a~3 F, , . _.. _B~'6 ~. i ~, C :~ ~ ~~-=, - START Toe Line We ter sine ~` ~1 / ~ OEFLGYMENT ~ - . / /_ ~ - ~oP Line ` O Eerm . ! ~ .. 1 ~ I 240 r't. 1 EOFt _4ff // ~ ~` t05 Ft. ~ ~ I ~ ,~ . ~ - ~ / ,, ., $ C V8D ~ cis o~ ~ ~ - ~ / ,.~G 4 0 I„~~ --- _ ____ 0 ~ ---- FlG 3 f 20 yd3 Sondboq Couble Loser 320o eogs OC S Y O1 ° ~ DP~~!-S1Tc 2 20yd~ Sondbog Single coyer 770o eogs S~NDeAG SLOFE PPOTrCTiON LAY 3 20 Yd 3 Sondbog Berm OU 1 1000 Bogs ~~~~ FOR EXXON COMPANY U.S.A. aka C>il ~- Gay ~~r~~, wc~~ i~~~sio,C1 8Y Anchoru~e EESSE,, EPPS 8, PGA ~ S ~~~CNC4t~Gr. aLASKd 3a9-o4S~ r 1 GuQc ~ 4 (3 ~~-Z.~--~, P T. ~ i ~. ~ z - ~ ELF A /~ ' 4+c-7711 L ~CT~--~._ ~O' CSO~ARE I . ~ ~ - ' . .~_ • ~~ r . ~ _ ~J" 2NSvawnoa/ , •, - , ~ ~ 1.?- • ~ • ~ • . .. .. . :••~ -. r ~ ' ~ - • ~ Az :c ;~ • - ': ' ; . '~' Fu ~c; s ' • ~ • : ' ` ;'ti . =' ~ DISTRICT ol _ , ~•~~a aE 7~ sr . . t ~ c~AS oFFlt~ M~bM cz~+Ouvrf s• 1f1.~4T ~- +'~,- - a~ ~~ . o„~. :. ; ; : ~ AEG ~ laE3 Le. FLL #~ A FE/ av4/dI AOovE _` ' • ~• . . ~_ '~ .. ~ APR 1 4 200$ - 2t,S ~ Oil & Gas Cons. Commission ~ ~ 3b"slr" /ZEFR16. C~w ovc~Q -. ,~laska • • ~ - gncha~'age ~, ~. F-SEC ~' d- SEC. !-' I ~ • C- 1 ~ '• i I 3~ ~ ,, • i •, 1 " ' .l ~ __ i ~ ~..-_~ "' ~ I I . •~-ll -•~ • ~- ~ ' r • i .•~ i ICS CF ~_LANj~ --r--.i - • .1- -___ ~ ; I S.S~ t3 5 J ~: - h ~I •~q j - ~ ~~ "I' • ~ Oj ~ /'^ ~:b: { _ ; ~,., ti ..j.. Z° i • ~` Gum CtF MEQt: .~ ~ . ._~ . ~. .~ Li ~-- z(,' ~ 3Z~~ ~L9 ~ REF. GoND. Tp b0 BCt= - ail e. t:5" r+.t. ~ ~. - s« Dcf4;t q.iour ~j , c.~sa~~ .a.t. i~ :~~ .~ j i ~= fn ~ .~ r'•" ~ ,0\ :~ ~ ~. 5~~-vLY ~ ~wES t~. ~ ~ i ~ RETV~t~,l lt~J~S ~, . I ~, .o~ moo: `~,~ i -- . a :: ~.~ , o. ~ 14 ,...t. ~ S/6 , .~, Z - .o.i- BE C D ~ l11r~ dprg 0~ p;~u 41°83 RECEIVED ~=-~ - __--- ~. APR 1 4 2008 N~® Alaska Oil & Gas Cons. Commission ~ . o. z 5" Anchorage O.2$.. o•t~" 11oT -'~ ScaLE ~.. CEL`r~r~ r_ae~ ~ G ~:i I F~~. 6 fSLD F.4 ~ etc _. A 5« . ~I .Y 1 . . :~ ~ i az "Cs c i- ac ~ --~ . C.,40~.. ~.~.'L, ~ 1 ~. -' ~~ ~ 1 ~ ~ i s .# ~ . _; ~ :~ R ~ _ _~ , '~ i •.~ •I :JT OFr ' ~a~~ ~ ( 'L~'<.2~~~36 RED ce.~a. To b0 QC~ ~: 1 f~ TOP OF iSLA/J~ 5' ~ r ~.~. - f•_. 13.5 l i - _ + - - - I i ~f~' ~ MIL .1 i i =- : '~ 1 ~~ ~ ~B' ~ ~.. j ~ ~ - ~~ - =` I ~- t ~ 1 ~ j • c~~7 ~~ ?c' To :gyp. ~cr ,J ~~ ~~ '~ ~ ~ i ' ~ -sa L C =~~^ 3cF ~ -1 _ - 8 . i • ~ ." _~ ? ; i . i.i ~ ~j =i~ o. aTZ' ~,.t. f~ll'~ APR ~ 4 ti~~~ Alaska Oil 8 Gas Cans. Corttrrtisspn Anchorage ct<< 0•25~~ .a.t. ~ERE~i ~D ac'«tL Otil "F-4uRE b. aEC$iV$~ f~,~~ ..~•. SRN-~' ~T _C GALE ~•~..~: _,~ , y. ...' .. -,~_~`~ 0 ;~~..` ~ s ~r •~"~~-`- fir... .<.~ ; 1• 7~M s ~ 4 !: J __ ,~ ~;~ S '~ f ~~w _ r ~ ~ ~ +c,~ .r ~'.~o,` ~,.~~ ~~ `~ ~ • J ~ ~TT #~ Lewellen Arctic Research P.O. Box 2089 ~ Palmer, Alaska 99645 ,m ~ ~ 30 September 193 ~~~ - 9071745-3184/659-2403 i~Ir. R. L, 4estbrook Drilling Operations Superintendent EXXON Company, USA Pouch 6601 Anchorage, Alaska 99502 Dear N1r . Westbrook On 10 September I arrived Prudhoe and unpacked diving gear, picked up scuba tanks from airfreight, filled tanks, and readied equipment for diving on the morning of 11 Septem- ber. At x:4.5 P.M. the two back-up divers arrived on a delayed Alaska Airlines flight. One of the back-up divers acted as dive-master and equipment tender. The other diver and myself would carry out the inspection. On the 11th we traveled to BF-37 via the Evergreen helicopter. After landing we looked around the island at the bag recovery operation. I can candidly say that I was impress- ed at the operation. Somehow I figured it would be more diff- icult to scavenge the.slope-protection bags. We were suited- up and in the water about 9:30 to 11:30 A.M.. The waves were bad on the east side of the island and the visibility was less than one foot. at the very best. Nevertheless, we were able to see enough of the slope, from the waterline down to the toe, to verify the bag removal. We only found a few small fragments below the waterline. Above the waterline the clean- up crew was pulling filter cloth out of the gravels, but we found none below the waterline. While diving below the depths of any discernable wave action the entire unprotected gravel slope was slowly slump- ing and rolling toward the island toe. At this rate of gravel movement it will not take long for BF-37 to be reshaped by wave action. After the dive we returned to Deadhorse, cleaned and re- packed the dive gear, and sent the two support divers back to Anchorage. In our opinion the contractor has done an excellent job of bag removal. Si c r l~y, _ - ~ bf -. obert I. Lewellen, Ph.D. July 9, 198~ t.~r. Hugh Bushne I 1 Exxon Company U.S.A. P. O. Box 42?9 lious t on, Texas ? 70 01 Dear Mr. Bushnell: The .Alaska Oil and Oas Conservation Com2nission, through myself, has been in ecm~muntcatton with J'ohn Staffield of Exxon's Anchorage office, He has informed me that a request to you may help us gain som~ information. ~xxon has re'eently drilled the OCS Y-0191 #1 and #2 wells in the disputed area of the Beaufort Sea. Since the disputed .a~.ea, by agreen~ent, is regulated by fedei,.al agencies, .the Ecologic staff of the.'Commission has not been privy to the well data, The Commission has been informed that with certain applications and approvals one person could be designated by the Governor to inspect the data but could not remove or copy. We are continuing to study the Sa~ Delta - Duck Island area as a future produ.einc area and we' feel the need for any. and all data 'in' the vicinity. Exxon~s t~o wells may or may not be important data points but we do not. feel comfortable with a .structural interpretation'which lacks these data. Accordingly, the Commission would like to acquire a DIL 1o~, a mud log and the test results on each. of the two wells. It is understood that B~xon and its partners are under no obligation to supply us with this information, But in ease of an affirma- tive answer, the data would be held confidential until after it 'is released to th.e'publie by the Federal Goverm~ent. We thank you for your consideration of our request, Yours very truly, ., liar ry W, t~ug I e r C~mi ssioner hi,fi: b e F~rm 9-330 (l~ev. 5-63) U, .. :'ED STATES SUBMIT IN DUP &' (...',,e other In- [DEPARTMENT OF THE INTERIOR reverse side) GEOLOGICAL SUrVEY WELL COMPLETION OR RECOMPLETION REPORT AND LOG* Other Temporar i1¥ P & A la. TYPE OF WELL: uu, ~ (:As WELL b. TYPE OF COMPLETION: NE. II "'"'O %%' EI.L OVER ~ DA~K n~:sv~. Other 2. NAME OF OPERATO~ Exxon Corporation 3. ADDRg88 OF OPERATOR ~. O. ~ox 4279 ~2243, ~ousto~, Texas 77001 4. LOCATION OF WELL (Report location clearly and in accordance with any 8gate requirements)* At,,r~.~c~. 1777' F~L & 708' F~L, ~lock 6§4, Stefansson Sound &t top prod. lnt~r~al r~po~ted below At total depth 11,~. PERMIT No. { DATE ISSUED 55-201-00001 10/21/S1 Form aoproved. Budget Bureau No. 42-R355.5. 5. LEASE DESIGNATION AND ~4ERIAL NO. OCS Y-0191 6. IF INDIAN, ALLOTTEE OR TRIBE NAME 7. UNIT AGREEMENT NAME 8. FARM OR LEASE NAME -- 9. WELL ~o. 1. 10. FIELD AND POOL. OR WILDCAT Wildcat Il. SEC., T., R., M., OR BLOCK ANP SURVEY O~ AREA Block 654 'Stefansson Sound, Beaufort Sea 12.COUNTY OR 13. STATE PARISH Offshore Alaska PRODUCING INTERVAL(S), OF THIS COMI'LETION~TOP, BOTTOM, NAME (MD AND TVD)* I 25. WA8 DIRECTIONAL I SURVEY MADE None I Yes 26. .. TYPE ELECTRIC AND OTHER LOGS RUN Dual induction, BHC & LS sonic, Formation Density-Compensated Neutron, Dipmeter, Caliper, RFT 27. WA8 WELL CORED Yes 2,% CASINO SIZE I WEIGHT, LB./FT. 28" IS[: u-Jr 20" II ~-~ 13-3/8" { ~ 9-5/8" 47 CASING RECORD (Report ali strings set in well) DEPTH SET (MD) 159' 812' 2,816' 9,868' SIZE 42" CEMENTING RECORD emented to surf w/permafx ~3300 sx permafrost ~1100 sx'permafrost. 26" 17-1/2" 12-1/4" AMOUNT PULLED ost None None ..' None None 29. LINER RECORD 30. TUBING RECORD- ' SIZE TOP (MD) BOTTOM (MD) SACKS CEMENt* SCREEN (MD) SIZE DEPTH SET (MD) PACKER BET (MD) 7" 9367' 11,637' 1000 ..... . , 31. PERFORATION RECORD (Interval, size and ffumber). 10,346'-10,4~2' (0 4" 4 spf)' 10,234'-10,256'. (0.4", 4 spf) 82. ACID. SHOT,I FRACTURE, CEMENT SQUEEZE, ETC. ~ ' r ? : D~,.~,.~5 INTERVAL (MD) AMOUNT. AND KIND OF' MATERIAL USED {10,34~;~;345' Squeeze w/150 sx Class G {~~[~]345[ Squeeze w/275 sx Class'G [[~; 412 [ Squeeze w/150' sx Class' G ~;256 [ Squeeze w/150 sx Class G 33.* --_~. PRODUCTION : DATE FIRST PRODUCTIONsee Attachment IPRODUCTION~w'~(FIO/~ng'pasllyt'pumpinp-sizeaffdtJIpe°lpu'~p),~..,._ IJWELLSTATUS(PrOdUCi~pO~shut'iff)' DATE 0F TEST HOURS TgSTED .~0~ I,~D'~.' ~0R OI~BBL ' ' %AS--MCP'. WATER--BaL. i ~AS-Ol~ ~TI0 ~ ~..~ ~{ TE~PERIOD. I I t ] ' ~" ~ ~ ..... :.,~,.. F~W. T~INO rrna CASING PRESSURE CAL~>ATED".,~ 01~,.~ GAS--MCF. WATER--~. JI OIL GRAVITY-APl (CORR.) 34. DISPOSITIO~ Or GAS (~Otd, None 35. LIST OF ATTACHMENT8 Formation Test Summar~ matlon is complete ~~~~~ecords *(See Instructions and Spaces for Additional Data on Reverse Side) i "' "'" '~ ' '~ ~' o o 0 ,.1 ~ 0 .~ (U ~ 0 .0 . ~ D.~ ..~ ~ ~ I~ r,.) ~ ~ ~ ., ~.. . .-~ .... 0 ~ .. ~ 0 · -~ .... 0 . . ~: ~.~ ' .. . .' ', ~ ~ 0 -~ ~ ~ -~ ~ .... m ~ 0 m 0 0 0.,.. ~ ~ ~ ~ ~ ~ . ~,. ~. .,. ,:..,, ,,. .. m~ 'm m 0 'm 0"0 '" ~.~~ ~ ,. ~.-~ ~ ~ ~ ~ m 0 0 m o~ 0 00~ ~ .. · 88 8 8 8 8 888 . . ~ '. Z 0 0 ~ ~ O' ~ t~ E~ ~ 0 0 0 ~ 0 .e4 ~ 0 m 0 ~4 Received OIL DISTRICT AND GA,9 OFFICE MAy 1 8 ',:982 Mine,.els a,~_'_ ' . EXXON OCS Y-0191 NO. 1 WELL HISTORY SUMMARY WORKOVER OPERATIONS Re-entered well on March 18, 1982. Drilled out surface plug from 145 to 275', displaced calcium chloride water in 9-5/8" casing from 3100' to surface with mud and drilled retainer at 9300' and cement to top of 7" liner at 9366'. Pressure tested liner top to 3500 psi and did not leak off. Tagged top of cement in liner at 10,760'. Squeezed through perforations 10,343' to 10,345' with 150 sacks cement below a retainer set at 10,330'. Drilled out retainer and a pressure test indicated no squeeze. Resqueezed with 275 sacks cement below a retainer set at 9756'. Drilled out retainer and cement and drill stem tested the following intervals: Test No. 1: 10,346' to 10,412' Test No. 2: 10,234' to 10,256' Test interval No. 1 was squeezed below a retainer set at 10,286' with 150 sacks cement. Test interval No. 2 was squeezed with 150 sacks cement below a retainer set at 10,160'. Mud in the 9-5/8" casing was displaced with 10 ppg calcium chloride w~ter from 3000' to surface. Set a 100 sack permafrost cement plug from 370' to 90'. Pumped 500 sacks permafrost cement down the 9-5/8" x 13-3/8" annulus. The'well was temporarily plugged and abandoned at 1200 hours March 31, 1982. RLL: et .. _ DI~T,.'fiOT . OIL AND ¢? ~ ~, "~ OP'FICE MAY .3 :,-,,, Mineral,, .. Ancho,'=,-.~'~'' .';' ", ~'arvice REA 9-331 1973 UNI¢~.~ STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use Form 9-331-C for such proposals.) 1. oil gas well [] well [] other Exploratory 2. NAME OF OPERATOR Exxon Corporation 3. ADDRESS OF OPERATOR Pourch 6601, Anchorage, Alaska 99502 4. LOCATION OF WELL (REPORT' LOCATION CLEARLY. See space 17 below.) AT SURFACE: 1777' SNL, 708' E~¢L, Blk 654 AT TOP PROD. INTERVAL: AT TOTAL DEPTH: Straight tlole 16. CHECK APPROPRIATE BOX TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA ' [ IE. ENTIAL PROPR I ETA R ,u,,.. ,...::. ,o. OCS-Y-01 '" ~ ' ~ "; ~ '" :i 2~ '-.. ";' ;'..;." 6. IF INDIAN, AELO3'~EE OR ,TRIBE'NAME · .,,_..-.: ~:~ c.. ~.~ 7. UNIT AGREEMENT NAME. 8. FARM OR LEAS~ ~A~E :' 9. WELL NO. ...-; .'3 ;"2-. !?: i ~; .~ ,:, 1 .'.- ['." "~ ~' i; "-' -'.- ~- 10. FIELD OR WILDCAT NAME· '"" [~, ' · ."; '~ ,: F ' Wildcat .';," .: .. --... :: 11. SEC., T., R., M.';;:OR BLK. AND SURVEY OR AREA 654,:'. ~'df, 20; ~,.~, 12. COUNTYOR ~ARISHI 13..'.:STATE,/' 14. APl NO. ~i' a''" · :,." .... 15. ELEVATIONS (SHOW DF,';KDB, A~D WD) R~S-43~ MS~.; :~D-18. REQUEST FOR APPROVAL TO: SUBSEQUENT REPORT OF: TEST WATER SHUT-OFF [] [] FRACTURE TREAT [] L-J SHOOT OR ACIDIZE [] BI REPAIR WELL [] , [] PULL OR ALTER CASING [] [] MULTIPLE COMPLETE Bi' ~ CHANGE ZONES r'-I [] ABANDON* [~ [--] (other) (NOTE: Report results of multiple completion or zone change on Form 9-330.). .: ;! ', , .. .- · ;.. :.' ! ~ ' · ':. :.~ .-,.~,, *;. ; .-._ ,'.% ;! . :, ~, .' _... 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates,' including estimated date of starting any proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths for all markers and zones pertinent to this work.)* ;. :. "· ..... Request appr;v~l to temporarily .abandon the captioned we~'l,." ..Well wi~"l,be:. abandoned in accordance with OCS order number 3 per the ~ttached description. The attached Figures 1 & 2 detail the wellbore as proposed· f.o? this abandonment. I1 E C, E'[ V .E D ;.'; ";) ?'. " .' ~: 3. Subsurface Safety Valve: Manu, and Type .......... D[?i'R!CT ¢,, :.,- :,.: ,., '.. ":: Z t. OIL A~:o c~,~.,s C,'-FIC~ ;. "i' ' '.- ' ; O " ; ' ':. ' _. ;' ,.,.. ~ .. ., · .. · , . ;"~'"',2 ~'" ' "' ~': ':; !'' ' ~'[ '.' · ..... ,5 ;'" ' " " .~' ';~ ... r: '" O:":;5 "' -. ;' .: ' :.' ,,) 2'.... ;'.. - ~ ¢~ ~ · · n~'-.'.: ; ::., .. ',,':-' _____..._._ANCHORAC',I~, ALASK~ ' ' .' '. .....,"" --~ · ' r'. .. ~ '-" " "- ' O ~'"' "''~ '::" ,. .:"' ".'. '" N/A ..... Se,.t @" '" ..-. '""" ., · 18. I hereby,~erl~fy tbat the.~oregeipg i~ true and correc~ . ,I . SIGNED ~.~ . -' ~...-,'~ ..~." _t~__,~:~ ........... TITL~ ......... DATE '' / j,,;(~his t APPROVED .BY-'~': ~ ~ -' ~.' ..... , · DATE COaD~T~OaS"O~ROVa[, i~¢"a.~~- · ......~... ....... ~ '. . 3'~. '2..9-8 2 *See Instructions on Reverse Side Ft. .-: .,. 4 '.. ? !.. C' : -- : ,'., .-; , · ., ® · · · · · ·' · · A cement retainer will be set at 10,160' DIL ± and 132 sacks of Class G cement will be squeezed through the retainer and 18 sacks dumped on top. Top and bottom of cement are 10,110' ± and 10,256' ± respectively. The plug will be tested to 1,000 psi for 15 minutes. Pressure can not decline by more than 100 psi. The top 3,000' of mud. will be displaced with 10 ppg CaC12 water. A balanced open hole plug will be set from 336'-110' MD with 100 sacks of permafrost cement. 500 sacks of permafrost cement will be injected down the 9-5/8" x 13-3/8" casing annulus followed by 76 Bbls of 10 ppg CaC12 water. Calculated top of cement is 1,308' MD ±. This plug will be tested to 1,000 psi for 15 minutes. The BOP stack will be nippled down and a blind flange will be installed as shown in Figure 2. The blind flange will have the following bead-welded identification. Exxon Company, U.S.A. OCS-Y-0191 Blk 654 Well 1. The wellhead cellar will be covered flush with .the top of the island. CMR: b sw 213/J-2 3/29/82 FIGURE 1 OCS-Y-191-1 Final Wellbores Sketch Blind Flange DA Spacer .Spool A Section ~10 ppg CaC1 Water 36" x 32" x 2~" Refrigerated Conductor ~ 159' Permafrost Cement Plug 110' to 336' Permafrost Cement 10 ppg CaC1 Water 94 lb/ft ~40 STC @ 812" TOC @ 1308'+ Permafrost Cement 13-3/8" 72 lb/ft LS0/NS0 BTC @ 2816' 3000' Mud/Water Interface ,' 9.8 ppg Mud TOC @ 7000" Class G Cement Top of Liner @ 9367' 9-5/8" 47 lb/ft L80 BTC @ 986.8' HOWCO EZSV Retainer @ 10,160' DIL · 150 sx Class G · TOC 10,110' Zone 2 10,234'-256' DIL HOWCO EZSZ Retainer @ 10,290' DIL · 150 sx Class G · TOC 10,280' Zone 1 10,346'-412' DIL 9.8 ppg Mud TOC Inside Liner 10,830'~ .Class G Cement 7" 32 lb/ft Pll0 LTC @ 11,637' TD @ 1.1,638' FIGURE 2 OCS-Y-191-1 WELLHEAD SKETCH for Temporary Abandonment 5'6" ~ Blind Flange Labelled "Exxon Company U.S.A. OCS-Y-O191-1 BLK 654 Well 1" B-Section I Wellhead A-Section , [113-3/8" Surface 20" Conductor I IRefrigerated 1 Conductor . _| _ Gravel Island 18' Thick ,/ )'.'al'cb 23, 1982 ?'..r. Brian Schoof Dcpart.ment of Thc l~lcrior :'~ir, erpls ,.','a~ffement Service Offshore ~'~ st ri ct ~ur~c,i"v~ sor P.O. Pox ?59 Dear ':r. Sc]',oof: !~ reference to your conver.q, ntinn with ?,"essrs. John Caldwcl] end ' .'. ~fe]d (: b this letter ,.,..,,n Sta: ur~:~!?. I c week of .~.~arch 15, 1982, . ?, ,.,),vt,,: to ,..r..,~f~].p~ ii'.. :"IS' i:,l(:rpretaiir, n of the phrase dov,'nhole ,'..lr:.'r..t{,:.v activ~iic=" to i~:c. ludc any ~.~nd oll activities in c i pcere lv ::c' J. A. St~,ffe]d ..) 9-331 1973 UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use Form 9-331-C for such proposals.) 1. oil gas well [~ well E] other E×ploratory 2. NAME OF OPERATOR Exxon Company, U.S.A. 3. ADDRESS OF OPERATOR Pouch 6601,- Anchorage, Alaska CO JE ]TIAL Form Approved. ........ ..Budget Bureau No. 42-R1424 ,' ' . ~,~ ,~ · 5. LEASE :~' ~ ~ OCS-Y-0191' ' .-': ,~: .- '.':.* :~ - 6. IF INDIAN, Al'LOT;FEE OR TRIBE'NAME .... .*i" ':~ "." ;q ,,': .~ -., .., 7. UNIT AGREE~ENT'NAME '-: .: :' .o - ·; -~-- ' :' ,.~- :; C.~ =.' . ,' ;.~ 8. FARM OR LEASE NAME ' ..... .,T; .. . .... 9. WELL NO. 3 ';'4'; ..... .... '~.-T .:- zo. F ELD OR W DCAriNAM :' " Wildcat ' '=' '"' ~' ':: :== = -": ...~ ..... 99502 [1. SEC., T., R., M.,..0R..BLK. AND sUI~VEY OR AREA Blk 65.4~, '~.'.'Sec ,.20, Stefansson' S'o~"~d, :!Be~'~0~:t Sea 12. COUNTY OR PARISHI 13:~ STATE.;; 55-201-00001r" ~- ::': :~ ' · .. 15. ELEVATIONS .(SHOW DF," KDB,' AND WD) WD = 18' ":RXB'= 43' "~*"'* : SUBSEQUENT REPORT OF: I~ ~' (', :'; 1 '" l'~ 'i.) .., ,';' '"" · · :. , .. ! .'J .;~ D!STR:OT .~ :n. ".' "' "' .~)11. A~:D GA:} OFFIOE -' ~.'-': '" ': ': ''~" . ,.,, (N.O~rE: Repo, res,Its o~ .~u,ti,,e' com,,e~io.' Or ,one ') ~ ..2. j_ change on F~rm 9-330.) · · . ~ .: · .: : .'.". .' ~ .:.' ::~.: ' :';::~- i.'" :': :: .'... ":' · :'.r ?-. :.:,.~. --. "'" .~"..': ,,' :' '-'..'... :...: /3' ,. ;.: .' " :':" ANCHORACE, ALASKA .' , ' 4. LOCATION OF WELL (REPORT LOCATION CLEARLY. See space 17 below.) Z-- 1530889 ¥ = 25620219 (U~f Zone 6) AT SURFACE: 1777' SN~. & 708' g[~, Blk 654 AT TOP PROD. INTERVAL: AT TOTAL DEPTH: SXotaAght_}Ioike___ 16. CHECK APPROPRIATE BOX TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA REQUEST FOR APPROVAL TO: TEST WATER SHUT-OFF [] [] FRACTURE TREAT [] [] SHOOT OR ACIDIZE [] [] REPAIR WELL [] PULL OR ALTER CASING MULTIPLE COMPLETE [] ~--] CHANGE ZONES ABANDON* E] [] (other) Reopen to Test 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details~ ~nd give'pert, inent'dates, including estimated date of starting any proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths for all markers and zones pertinent to this work.)* · ': '. :: ..~.i." _' ,.."., :'. :.. .,; ,. .'~ ... ~ :'... :~.. ", The wellbore will be reopened and production tests performed.'~'n ~he'~ifqil.'0.wi.ng intervals: ".: . :'!: .,.~ .., .- .: ':. !'~ .:.'.,, .:;: ., .'~ .~. ~", ~.. Zone #1 ' 10346-41.2' DTT, .;.,..::,,.,. :.'. .... : ..j .,. ;:.- ",..:,, ._... Zone It2 10234-256' DIL .,'; .., .. '., , .. · :..,'; ,.~ ..: '"~ 3 '*:~ " 0C$-¥-0191 #2. All work will be performed with the same equipment previously approved for the APD. :. ~"'. '""" . -. '.~ · · .~: '~: ... ' · : , .~ ...' "':::': :':' if '"* "' ' - . : .' .'.:; ...~ . , ,V'.':, .. ~'' ": ' ' ': " Subsurface Safety Valve: Manu. and Type ~/A ' : S~'~ @ * · ~, .'.' ,,, correct .... ·'. " 18. I h ify that t~re~?,}~ is true and .. :. ..... SIGNEO~/~L~~~_ __~7 .... TITLE --~L t ~DATE :'}3715/'82 ';.. . ': ,. . APPROVED BY CONDITIONS OF APPROVAL, IF ANY: *See Instructions on Reverse Side Ft. AREA D~,STR! '.OIE AND GAS OFFICE .xxo ocs WELL HISTORY REPORT SUMMARY 'JAN 2 6 1 52 Spudded well on November 1, 1981. Drilled a 17-1/2" hole to 840' with 9.2 ppg mud and ran open hole logs. Opened hole from cemented 20" casing at 812' with 3600 sacks of permafrost cement. Topped out 20" casing annulus' with 250 sacks of permafrost cement. At a drill depth of 850' a jug test equivalent to 11.2 ppg mud weight was performed. Drilled a 17-1/2" hole to 2825' with 9.6 ppg mud and ran open hole logs. Drilled 20' of new hole to 2845' and cemented 13-3/8" casing at 2816' with 3300 sacks of permafrost cement. A pressure integrity test below the 13-3/8" casing shoe leaked off at 13.0 ppg EMW. Drilled a 12-1/4" hole to 9904' with 9.8 ppg mud and ran open hole logs. Set 9-5/8" casing at 9868' and cemented with 1100 sacks of class G cement. Established annuluar injection down the 9-5/8" x 13-3/8" annulus with mud at a rate of 3-1/2 BPM with 925 psi pump pressure. Pressured up to 14.8 ppg EMW below the 9-5/8" casing shoe and did not reach leak off. Drilled an 8-1/2" hole to 10,242' with 9.9 ppg mud and cut the following cores: Core No. 1 - 10,242' to 10,302' Core No. 2 - 10,302' to 10,362' Core No. 3 - 10,362' to 10,432' Drilled an 8-1/2" hole to 10,871' with 9.9 ppg mud and cut the following cores: Core No. 4 - 10,871' to 10,912' 'Core No. 5 - 10,912' to 10,991' Core No. 6 - 10,991' to 11,027' Core No. 7 - 11,027' to 11,076' Core No. 8 - 11,076' to 11,166' Drilled an 8-1/2" hole to 11,613' with 9.9 ppg mud and cut Core No. 9 from 11,613' to 11,638'. A final total depth of 11,638' was reached on December 15, 1981. Ran open hole logs and cemented a 7" liner from 9367' to 11,637' with 750 sacks class G cement. The liner top was pressure tested and broke down at 1200 psi. A squeeze jOb was performed below a retainer set at 9300' with. 250 sacks of class G cement. A 50 sack cement plug was placed on top of the retainer and successfully pressure tested for 15 minutes at .1000 psi. Mud in the. 9-5/8" casing was displaced with calcium chloride water f~om 3000 fe~t to surface and a cement plug was placed from 90' to .. 280'. Calcium chloride water was circulated from 90' to surface. The well was plugged and suspended at 1200 hours December 25, 1981. Plans are to skid the rig 25' west and drill OCS Y-0191 No. 2. .n S-~.~O ..er. 5-68) U~I . ' TED STATES '~UBmT (See other in- DEPARTMENT OF THE INTERIOR reverse side) GEOLOGICAL SURVEY I I __ ..~ .. ~. "J %' ' i ~,' WELL COMPLETION OR RECOMPLETION REPORT~-A-~D-'~OG :':;?r'_IU la. TYPE OF WELL: B. TYPE OF COMPLETION: NEW ~-~ wontc [~ wF:r.L OVER O!I, E~ (;AS ,,'ELL WELL [~] DRY [~ Other r.N n.,cg n~:svn, t_~ Other 2. NAME OF OPERATOR Exxon Corporation ,~. AI)DRERS OF OPERATOR P. 0 Box 4279 #2243 Houston Texas 77001 ~ '~ ........ ~"-AL~'~KA · , , ' ! (,'~U.'t~-;, t. ~ .... ~ 4. LOCATION OF WELL (Report location clearly and i,& accord,thee with anF State requirements)' At surface 1777 ' FNL & 708' FWL, Block 654, Stefansson Sound At top prod. interval reported below At total depth 14. PERMIT NO. DATE ISSUED 55-201-0000'1 I 10/21/81 Form approved. · : Budget Bureau No.' 42-R355.5. 5. LEASE DESIGNATION AND S~RIAL NO. -. OCS Y-'0191 6. IF INDIAN, ALLOTTEE OR TRINE NAME -- . ?. UNIT AGREEMENT NAME -. -- f -. ~. FARM OR LEASE NAME -- 9. WELL NO. ! 10. FIELD ANn POOL, OR WILDCAT .. Wildcat ll. SEC., T., R., M.. OR nLOCK AND SURVEY OR AnEA . , · Block 654.Stefansson · Sound, Beaufort Sea 12. COUNTY OR I 13, STATE PARISH . ] ' Offshore ' Alaska 11-1-81J 12-15-81I 12-25-81 (Suspended)I ' 45 KB ." i.'I' ' "- ' ' 11,638 'I 90'I .0,v .,,Ax,._ 2~[. PRODUCING INTERVAL(S), OF THIS COMI'LETION~TOP, IIOTTOM. NAME (.%ID AND TVD)* None . . 23. INTERYAr,S DRILLED BY ROTARY TOOLS .. CABLE TOOLS All "'1 .. I 25. W~S 'DIRECTIONAI, '"T'PEELECTR'CANnOTHER"oGsnVNDual Induction, BHC & LS Sonic,;Formation Densi...tf~,'wAR wEL''¢°RED. .... ... Compensated Neutron, Dipmeter, Caliper, RFT ' ' ." "'".' · Yes 28. CASING RECORD (Report 111 strings set in well) ..' '~ CASINO SIZE 28" WEIGHT. LB./FT. Structural 20" 94 13-3/8" 72 9-5/8" :29. SiZE 11 t 47 TOP (MD) 9367' DEPTI! SET (MD) llOLESIZE 159 ' 42" 812' 26" 2,816' 17-1/2" 9t868' LINER RECORD 12-1/4,, BOTTOM (MD) 11~637' I CE.~IENTING nEC'6RD ---' ,.. ~emented to surf w/permafr~ '..~850 sx permafrostI ."r._ . ~300 sx permafrost · :. 1100 sx class G ' · ' SACKS CEMENTs 1000 SCREEN (MD) ' 30. TUBING RECORD SIZE DEPTh'SET (MD) AMOUNT PULLED )st' None None None None PACKER SET . 31. PERFORATION RECORD (Interval, size and number) FRACTURE, CEMENT SQUEEZE, ETC. 32. ACID, SHOT DEPTH I.~TERVAL (MD) AMOUNT AND KIND, OF MATERIAL USED .. · .. . .. '. . · . 33.* PItODUCTION .. DATe rlaST PRODUCTION [PRODUCTION METHOD (Flowing, gas l,$t, pumping--size and t~/pe o! pump) , WELL STATUS (Producing or I .,[ . shut-in) · . NO Tests I ' '' ' ' I '' '" FLOW. TUBING PRESS. CASI.NO PRESSI:RE CALCULATED OIl,---BBL. GAS--MCF. WATER--BBr-. . ' ] OIL GRAVITY-APl (CORR.) ..... r- ' :" ...... ':" '"' % : ..... '"' · 34. DISPO~JlTION OF GAS (~01d, used ]or ]l, el, ~cnted, etc.) . · : ·. I TEST WITNESSED. BT u. ":"'"'i ... ' i::'~.":: :.'-"'': 35. LIST OF ATTACHMENTS '. ]- :.~-:.'.' : ' ': '~ .. :'' .. , ; :' :.. . ': ,,., . [.., :.: - .... 36, I hereby certify t~at the foregoing and at. tach'ed information is complete and correct as determined from all available records-; ,.-, .... , .,...,...: .. ;; ;, ~ ..... , . SIGNED - TITLE Geological ;~sociate ;'."[' DiTE '" 1'./2'6/82' ' ~] · · / ~'&/ ,..: *(See Instructions and Spaces l~or Additional Data on Reverse Side) RECEIVED DISTRICT '.OIL AND GAS OFFICE JAN 2 0 i982 ~D CLY ABUNT CMT CONTAM 42 5200 56.6 SD I/4 I0 SOL 5 13 FC 3 GY,DISM THRU SMPL /SME SLT COMP MAS~ WOOD FRAGS~PL FOS' IMBD/ABNT SB RND CLR SD GRS MKY- WH, M- CRSE, SB ANG-S8 RN[ dNCONS,TR PYR,TR MINRL FLOR CLR,MKY, SB RND, F-M GR, W SRT UNCONS GY,V STKY, SFT, SL SOL, LIG INCL SL AREN NOTE: FREE SCI GRS,CLR-MKY, SB RND- SUB ANG,MOD W SRTD, F-MGR TR 'PYR iTE: DEPTH SYSTEMS BROKEN, DRILL RATES AVG INCLUDE JET DRILLING t- ,'ti"';';' , I .... ~ ;.f-.t .:- t ....... i+!i .... ~ Ii*t . , NOTE; SD PEAT --NOTE; ;ONG .IG TR LIG ~ LT GY-MKY WH,SB RNO-ANG, F-M (iR, MOD V; SRTD, QTZ FIB PL 8~ WOOD FOS TISSUES, LOC SNO LAMS, W PRESERVED DEPTH SYSTEM FE:PAIRED PRED DK GY CHT / OCC WH QTZ PEB, W RND, V PRLY SRTD,V PRLY IND, LOC PYR COATED DK BRN-V OK BRN, FIB PL 8~ WOC TISSUE, SFT, TR SND GR /LIG MTX GY-DK GY, V SFT,V STKY,SL ORG ODOR~ SLTY TR SS CLR-MKY WHtSB ANG,V HD,SIL CMT,V W IND, ASS/CONG SB RND-RND, GY-DK GY,OCC. MKY WH QTZ , PRLY IND , PRLY SRTD LIG DK BRN-V DK BRN~ FIB PL 8~ WOOC TISSUE,SFT,TR SD GR /LIG M'IX AT BRN- OK BRN, PL 8~ WOOD TISSUE,SF'I SPLTY, ASS / M-CRSE GR FRS'lO QTZ GR GY-OK GY, V SFT; V STKY,SLTY, SL ORG ODOR DIE AND GAS OFFICE L~I ~1111111111111illll I -- _~_.i..F LIIII'il I1111 II 11 III i il lJ ~ 'lB[I-Il I I I I Il I I 1 I I I I I |! I ,., ~ I'lllllll~l IIIIII 21 l';il.l, llllllllllllillill LT 'U[ 'IIc~ llkl- - :|lilllllllllll llllllll. !.1..11 I I I I I J I I I I I II I I I I I i '.Lllllll I IIIIIIII1111 ~l. lt II11 I11111 I III[111t il- ~,l:tilll I I Ii111 III I11 III ~._ ,1_.1] I II I I I I III i II I I I I II , i,~'~J~~'llJ[[':tllllllllllllllllll!ll .,L:.~L_.. ::1 I.I IIII I I1111 I II I I I I I1 I ;'llllllllilllll II111111 ] - '1111.111 IIIIII! III IIIII L__ · I ~IIRVE]YI IIRI I,f:~,'L~IOR I I I ] . ! Ilillllilllllllllllll[ . !1:11111 !111111 I11 IIIII I , ~['illlll Ii11111 Illtllll [-_ . ,,1=.!1 III I I I IIIi III I I I III |I-.Il !11 I I I I III III i I I i II~r . · :t111111 IIii111 III 11111 !.1 II I,Ill i I I II1.1 II I I I I II , .i I"1'11 I I I I III I ! il I I~ I I1 . ;!1.1.1 I Ii I I i I I1.1 I I I I I I I II ) . I!11 IIIIIIilllllll i.~i.':llllll Ilii111 III11111 :!'I:,11111 i111111 II!i111 ~"1.1'1 I I! I.I I ! III I I I I I I I I ! · ~ !qllllll III!111 IIIIIII [ , ~ ilil.llll Iillll] l! I Iii I 1 :'Id I iI.il 11 I III III I I I !1 i . ~1..1 I !'1 I I I I I I I I'1 I I I I I I I ,I i:.I I.ii Ilil III IIII II Ill I I ~,.'I-~~ ~;~r4j 1/12Pm~ II ltECEIVED DISTRICT 'OIL AND GAS OFFICE WI.. yp. ~ . · · 'M-DK BY, V '. JaaY, V ' .... IND ~ PRED W, ENO ..... ...... .... . ~- DK GY,V..~rV , ~. . .: .,'.~ .. ~.~, .~.:'~...',~ ' DK GY, SRTD, PReY ~ND, ~ ..~].~~ a-" , . ' ,?.~,~,' . ,, ' .~ .. . ~.~, . . , . . '.. ....~ ~.F, . ...., 1,982 :JAN 2 ....... ......-., ......,,..'...'.' F" :.:':1 ~.':,': ..... ,.., ,., ,...,..:. ....... , . . . . ... ~ ,' :'..:.;' i':".'..",..'"r... :~.. ~, _:.; ,. j, ;:...,. .,.,-.' ,,/f · ":; ~ '.: ,;, '~. '. , , "/ i,. :- ' · ...... . .......... -)1i ,.'l y ... ~,~C~Q~GE, ALASKA /'ti/6 / ~ ,, ,..:,, i~ ~¼ I · .~ .... ~: '~. ,..~, ......... .... ] ,, j . .~ ,.~_~,..,,..,~ [ .,.~ I ] I I I I I i I I I i I I I I I ~i__ lll{lll :~', L. I L' ',*l /{I I111 II1111111 , ;I / !~., !Ell [llll!IllIlIllIliill i1 l!i rT1T~TTT~] Jill ii ,-I l/I; r 1 T .I~TI ITtTtTTTI--1 iiiiii ~" ~'fT ''l'''['''iU ~'[] lTlillllllill{{{l{ , ....~i~LL~.J.J{.~_' u_u_u_u_m , , ' ii 2[xo ii ii Pi:IU I ii I-i-' :{ ,,'C ITI]~.I 1111 11 .......... :_ kLJ. J 'Fi" _ .... lllll ...... - ,--: :: ::: ::;..:... :; ~'T[TI~I] [! IIIII_ .., ..... .2_ I!11111111111111' Illlllllllllllll H/IIIIIIilIIll I!qi . ' ' ~I/ll~l~r 1'1 I',1 1 1. l ! _'1 [j 13 q i .......... ;. AT ~:1i II IIHT~ MXI~,al I [I I I1 · I l .'Ill,R°! I 2BDl~l II I II ] II ilRP~llllllllll ~ ii ILLLI~.LL I I I I~ 3~E 11 !111"11111111111 ! I1 III1o11111111111 1 I1 CLY ,NG WL PV --yp GY- OK GY, V SFT,V SI'KY~V ,. ABNT MICRO MiCA ,. , CLR,GY, ANG-S8 ANG, V PRLY ~ " ,. V F-CRSE, VHD,LOC PYR,TR PEA SIZE GVL,GTZ ,em , . . GY- ~ GY ~ V SFT, V STKY'~' V ' .:~.~ SLTY, A~ ~C~ MICA ., GY,~ WH, RNO-SB RND,~ ~A SIZE / SME GVL, UNCONS,MOO- SRTO ~ PRED C~, SEC QTZ ~ ASS/~O '::~ .. .. '.... '.~ 2.q ANG- PRED SB RNO, UNCO~,PRED. GTZ~ CHT '*.'.. ."5 '. .' ~.~ ~H 8.$ ~:','.. g oc". :, ' 9 S~ 6 .. .'.: ., 12 FC ':... '~.~ ,,.~. ~ ,, !~ECEIVED DISTRICT 'OIL AND ~A~..~ ....... ~ ........... .':, :'.', r,.'":"., .""~ [~v;. 'm-v;'~';%~l'r-.lLj{~;' "" .... '. .... : '~... , ., '. "' . ~ . . .· ,. ~. ~ .. · . ., , ;. ,,' . ~;., ,...,~; ,, ~ ~ · '.."w'~; ~,.",L".~ 'v.'" ~ 1~ ' :.,["..' '.; :;..'~' :'; {.,,~'. ", .... ;RNCHORAGE, ALASKA SS SS IND ~ PRED 'TRA'NSLQTZ~ ANG-SB SEC CHT~ASS/CONG~SIL CMT · OY-DK OY~VSFT~V STKY~V SLTY~' ' - LT ~Y QTZ,GY CHT~ SB RND-RI~ PRLY-MOO SRTD,GVL$ HD-V HD~ . UNCONS~ LOC PYR~ ASS/SS · . ,.., LT GY-GY~ F-CRSE GR~W IND~HO~ "~ TRANSP- TRNSL, SEC CHT~ANG- 3B ANG, SIL CMT~ ASS/CONG, GY-DK GY~ V SFT~ V STKY~V SOL ~ V SLTY LT GY QTZ,GY CHT~GN &GY LITH FRAGS~ SI) RND--RND,PRLY SRTD~UNCONS, GVLS HD-, V LOC PYR LT GY-- GY, HO, F- CRSE,W IND, ' SD GR TRNSP- TRNSL,SEC CHT, ANG- SB ANG, SIL CMT iRECEIVED D~STRICT 'OIL AND GAS -" :_Jj.,..JJ..j..1 ~" ~'!~ 'i- ~]m~ ~m I i _11 II2~IDOJ I i I 18001 Ii I I I I~ I ~J JJ JJl jJrll~ __.L.L , -LJ.%'LLLLI ?l~ ~/ITT--' )-' · I ~ I IIL.LI .... ;*..,,;. m "1: :J,.~ ' II l tl'J-J-J'JJ - '~" LII"IIII1 [ III IIIII -)' ,__T~. tll.'l"" . IIII IIIII J_]]i'-,'~- ,,,:,,,,,,,,,,-,,, ,,,-,,,,,,,,, Ili"lllll IIIlllll ~_jL IIII111! · iJllllll J HRSI I I I 7 I/~l !1 I I1 " I FtTI~I 11 11~1~3 [11 IIIII ! II1-11111 IIIllJll-) LLIldR NI~ I BilIIIIIII i IHH II I-~i~ ~ II I II I I.t' ]~T ~' I ~iF~ I I I1-~ r~ III IIl, lilll ~ Illl I:~J I I IU [ll. llll I I11 IIIII ~'/.j II1.11111 I1.111111 (1¢ i/ lll.lllll IIIIIII1 j r~.,]~ i i Ill III II II. llll I .llllljJl ~.~ ~aJRV~Y! 4 ~ '.I ISlSH£1 I I ~ ( [. ~' !/,, / VIS PV YP )NG --SS ''i ~.§ pH 10.2 . S! 51 Cl- 2?oo .., I.':i 9.6 SD ~2~/4 "1; '~ 17 SOL 8 FC . . : . ..i~ · '" LT GY CHT, SB RND-RND,PEA SI '.~ PRLY SRTD, LOC PYR LT GY, F-CRSE,SB RND-RND, FRI MULTI-COL LITH FRAOS~OTZ,CHT LT 6Y- 6~', HO, F - cRsE ,~16 -se"xJi8 MOD W-WIIND,PRED QTZ, SEC CH1 .' $11,. CMT, OCC FE STN ORNG-BRN '. - .- · GY - DK GY, V ~FT~ V STKY~ V AR G, IMPURE ~ HCL DISSOLVES .EASY p, EC= ~., ~V DISTRICT 'OIL AND GAS O?FIC. MULTI COt- ~ V F-V CRSE GR~ANG- SUB ANG, SME PYR~TR AMT PYR REPL PL FRAGS LS NOTE: NOTE; TAN/AREN QTZ INCLUS,SLOW REACT, MOO SIL ,TR CARB INCLUS GY.,, V SFT, MOD STKY, V AREN/SD GRS AS ABOVE~ LAG 4.4 MINS I IOSPM 2_2 UNITS 4840 STKS GY- LT TAN~V SFT ~ SL SOL,MOO STKY V ARENa, SOUPY .. ,. TR SD IN CLY,CLR MKY~BLK~$B ANG-SB RND~ F-M ~UNCONS~QTZ TR . LS~ TAN ~AREN~ SFT~DIRTY RECEIVED' DISTRICT OIL AND GAS OFFICE ~,, ?.-',:. p,. ~ ,"t ~,'f"~['"~:.,.~.. .~.-:~..'.r'~ t:'...'.:'" ~=:,"";i.i ..~?,r l:!-; ;".. :: : :~,: ;!: .:'. ~'-',L t]' ¢"t v.. ' :.,-.: '.f ;.t i! ;~ i.; .... ' ........ ' ' :"'"; "'" ,,..~¢,~.:~:.:,-~,.,'. ', '..,.,, .., :. ",. ,...i, : '.,,~',~\', t, ~ ~',[:...".L':;, JAN 2' ,'" ............ " ..... ' ~..) [~,.~_~il.~ ,,.'..-..,:"':...:..... :/:~.: 'L-., ';, ,,..:::.~,' u '~-..,;. ~..~" u:: ",- -, d, p I~ ',': :'!. 1'i t!, ~' ~: ," "t H ANCHOi::b~GE, ALASKA ~LY LT GY-TAN~ V SFT~ STKY~V SLTY SL AREN, PRE[ QTZ & CHT FRAGS~ MULTICOL i'd .. .,i ~.,~ , :... '[.~ .. '... '"." . . ~ .., ..~//' ' :'.:,, ~.~., ~ V SFT~V SL~ I"' . ', . .:~ ':'-" ~ANCHORAGE~ ALASKA --CARBIDE CLY CLY .. ' ......... DIS'TRICT OIL AND GAS OFFICE .. LAG 52 MIN$ 109 SPM ?.6 UNITS 5690 :S?KS GY-DK GY~ V ~FT~ V STK~.V' ... SLTY~ SL AREN~ SL ORG OI30R~ ':':' '''~ . · . .~. ~ ..', .. · .,~. TR SD~ CLR-TRNSL QTZ,F · , · '.~' , i '.., ;..~' ,. .t:. ~' , . . . , OY-OY 8~N~ ¥ SFT~¥ STK¥, .... ' $L AREN, MOD MAT, CHUNKY SLTY, TR CARB .~"' ~.: · , · ,,. ': '~.~ ~.. 'TR SD~ CLR }MKY~BLK- OR, SB ANG- ANG, PRLY SRTD~ '.."'~'.,.. '~.. UNCONS, OTZ ~ CHT "" ~ . . ... GY~ V SFT~STKY. SL AREN, WTR SAT~ ANCHORAGE, ALASK/~ ~OTE: VIS WL PV YP REC "" :~ .......... .:_., '., .... :" '-'.;" '"' ~'~ .. ...! ~.:. ,.. . . .... [~ ::~' ~.~. -.,.~,.~..:~ ND ~.~,,:~' i".' ..... · ANCHORAGE, LT-NI GY-TAN, V SFT, STK¥, . ~ .:! SL SOL, V AREN ,V SL CALC'' TR LIS ~ FLAT BLK , BRIT LT- M GY, V SFT, STKY, MOD V AREN, SL SLTY 9.4 pH 10.7 42 C I ' 2700 8. 8 SD TR II SOL 7 5 FC 2 LAG 62 MINS I00 SPM, 42 UNITS 6150 STKS LT - M GY, V SFT,STKY, V ~ SL SLT¥~ SL CALC NOTE: ~"l E C .};,' ~ *?' ];;; i3 Di 'GTF:.'iCri' 'OIL AND GA3 OFFICE . 'JAN 2 O ., o2 LT-M GY-BRN, SFT, V SOL,V :~*"- '] AREN, V SLTY, SL CALC '.'. '..';'~"l'J~, · . ~'~,! , :, .~,.;. · .. TR SO CLR~MKY, BLK, F 'GR~ .. ' UNCONS~SB ANG-SB RND~ MOD " W SRTO~ QTZ,CHT '" :"';' ., , ', . ~ ,. ,'..L~" · '.,..... · ::, ],:'? .:, , ..,. LT - M GY-BR,, '~FT,v SOL.",¥: ' V SLTY, SL CALC .' ::- !'~" : '. .2: .,, · .. .., TR CONG,TAN,BLK, WH~CLR"~ RND, M- CRSE OR, PRLY SR'rO~- ... PEA SIZE GVL, UNCONS, CHT~QT2~.'~':' ,.. CLR - OP~, OCC PALE GY~ LT GY~:' V F- M GR, ANG-SB RND, F~ED'., QTZ ~ CHT ': ANCHORAGE, ALASKA CARBIDE LAG 68 MINS I00 SPM " 44 UNITS 6808 STKS . . .;~;. . .-'... ~.~ LT BRN- GY,TAN-ORNG~WH~ V F.: GR~SB RND--SB ANG~W IND~QTZ CALC CMT :,.' ,, .:-:.. · .. .... TR L S ~ FLESH COL-TAN~V HD,,' ANG~BRi'T~ TR CONG~,WH~BL.K RND-ANG ~CRSE GR~ QTZ · . LT- M .GY, V SFT, V SOt. ;"MOO' STKY~ V AREN ~V ' SLTY} SL ,,-,,.~,.,:. -=,-*".' ::" .,, . ,'. · . - . ~-i'~ '.'.., ~I.'. ~~ ,' ~ ~di~lTH-,, ~tF~~I'T" ''~' '~ ~ t ~ ~t, ..... 1-1 .T,. . ..... ,.._ .... lllll lllllllllll llllllllllll ..... C~Y TR SS~ LT GY - GY:, LOC FE STN,ORG-BRN,V F GR, ANG~MOD W SRTD~FRM-HD~PRED QTZ, CALC CMT GY- DK GY, V SFT, V SLTY, V STKY, SL AREN TR SS, LT ~Y, LOC FE SI'N, ORNG-BRN, V F 6R,W-MOOW SRTD:, ANG, FRM-HD, PRED CLR QTZ, CALC CMT GY-DK GY, V SFT, V SLTY, V STf SL AREN ~WTR SAT GY'--DK GY:V SFT~ SL SOL,.. V STKY~ SL AREN, .SL CALC ;Y tlEC'EIVED DI '3TRIC'~' OIL AND GA3 JAN 2,} :~,o~ ",' '.ANCHORAGE, ALASKA ~ECEZVED DIS'rRICT AND GAS OFFICE JAN 2 i982 ANCHORAGF., ^L~'~SK^ ' CLY SD NOTE: M-DK GY, V SFT,V STKY~MOO SLTY, SL AREN ~, MOD SOL LAG NO RETURNS DK GY-DK GY BRN, M-CRSE SB ANG- SB RND, PRED. CHT,~ OCC CLR QTZ,MO0 W SRTO M- DK GY tV SFT, STKY~ V AREI~ MOO SLTY~,MOD SOL TR SD,,CLR ~ F- CRSE GR, ANG~ SB ANG~QTZ~SEC DK GY CHT,. PRLY SRTD~ UNCONS , ABNT PYR, NODS RECEIVED 'OIL AND GAS O',""FiOE JAN 2 3 12S2 ANCHORAGE, A~.SKA ~S WT VIS --PV YP GY-DK GY, V SI:T, V STKY~ V SLTYt SL AREN~ V SOL TR SD, V F-M GR, ANG-$B ANG MOD W SRTD~PRED CLR QTZ. · SEC DK GY CHT~ HD~UNCONS GY-DK GY, V SFT~ STKY~V SLTYI SL AREN ~ SOL GY-GN GY, V F GR, W SRTD~ANG PREO GY QTZ,SL ARG,FRM,CALC CMT IO.3 PcHi' 10.5 55 6.2 SD TR 26 SOL I I 8 FC 2 'OIL AND G'AS OFFiCe- CRSE GR GVL · .. GN-GY-M OK GY,FRM~V F GR, , ANG- SB ANG, MOD .W SRTD, QTZ, CALC CMT, TR STRM .YEL CUT FLOR, STRW VIS CUT, GLD *'DRY ... CUT FLOR .. · ,. LT 'SRN- T'AN, SFT-FRM~PLTY~ .. ,:, TO SH,SIL .:. ... . '~." ~,..~ GY - 0~ GY- ~N. VF- F' ~,, MOD I.O ~'~ · ~ SB RND-RND,W SRTD~GTZ~ CALC '. . ~ CMT, SLOW MKY YEL STRM CUT 3. · FLOR,DK STRW VIS CUT,LT STR~ '"-'i DRY RING CUT, DULL GLO DRY RING :'.~ CUT FLOR '. ' MULTI-COL, ANe- Sa RNO,M: CRS£." "' GR~ UNCO~CHT, GTZ~OCC CONC ' .. FRAC~TR MINRL FLOR , ........, ..~ BLK~ BRIT, ANG, V HD · "'~' .... '. .::" :~.": · . . ..,,.::-.,.',.~!:....'~'. , ,: . ., ":~':,1'~ CLR, MKY, GY, S~ CHT,QTZ,UNCONS,TRNSL ~RNSP .., . :.~ WL PV YP LT GY, V SFT, SOL, V AREN. SLTY 10.3 pH 10.3 53 CI- 2800 6.4 SD TR 2 6 SOL I I 7 FC 2 BLK, FRM,BRIT, CONC FRAC,TR GAS BUBBLES IN FRAGS,GRDG TO LIG ~TE' ABUNT PYR NODS LT GY-GY, V F-CRSE, OCC PEA GVL,V PRLY SRTD, SB ANG-SB PRLY- MOD IND, PRED MKY GY QTZ SEC GY- DK CHT~ CALC. CMT. TR FNT YEL SAMP FLOR,LT YEL STRM CUT FLOR,STRW VIS CUT,$LD DRY CU,T FLOR CLY LT GY,V SFT, SL STKY, SOL,WTR SAT, V AREN, SLTY . , ~NOHORAGE, ALASK/~ LT CoY,V SFT,SL STKY, SOL~V AREN ~ SLTY, WTR SAT I0.1 pH I0.0 VIS 44 el- 2200 WL 6.2 SD TR PV 18 SOL I0 Y P 9 FC 2 ;ARBIDE LAG NO RETURNS GN-GY, SB ANG-ANG,F-M SRTD, FRI, QTZ , PYR,CALC CMT TR FREE TAR, DULL YEL STRM CUT FLOR.~DK AMBER VIS CUT e" ANCHORAGE, ALASKA SS LT 6Y-GY, FRM-HD, V F-V CRSE, V PRLY SRTD,MOD-W IND, ANG- SB ANG,QTZ,CHT, LITH FRAGS, CALC CMT NOTE; ;ARBIDE l SLTST ABNT CAV IN SMPL GY-DK GY, V SFT, V STKY,V SLTY, SL AREN~ SOL LAG 75 MINS 106 SPM 65 UNITS 7920 STKS GY, V SF'I', SMOOTH TEX, V SLT¥, AREN~ SL CALC~GRDG TO SLTST CLR ~ BRN ~BLK ~ SB ANG-SB RND~ F-M GR~ MOD W SRTD~UNCON~ :' QTZ~ SME PYR NODS~ LIG ~CHT BRN-GY BRN ~ V SFT ~V ARG ~ .MIC- MICA ~OCC CARB LAMS~ GRDG BETWEEN CLY 8~ F GR SS~ SIL ;ANCHORAGE, ALASKA SKS, MICRO XLN, NO ViS FOS .. .,. CLR, OFF WH XLS, PRED QTZ;' PRED FN, MOD FRM-FRI, CALC" CMT THRU .. ..-~ LT-M GY, SFT-SL FRM, SL OCC GRDG TO V ARG SLTST, ... CARB I~ CALC INCL SCAT THRU ' POS TR KAOL "~ · ABNT SLOUGH THRU SMPL SLTST BUFF-BRN/GY, SFT-OCC SL. FRI~' ' ' SOL ARG MTX, OCC. VF RND ..': QTZ GRS '~'~ .-,, · .: COAL CARB LAMN APP~ POS SL;.OU61~I' 4 .. .. " LEFT IN .HOLE DURING TRiP ..:., SS GY-GN, SA-SR, VF-F, IND~ P ."...,; SRTD, CALC, QTZ, TR PYR .,,.., .,.:j GY- DK. GY, V SFT', SOL ;' SLT':'":".', '~: DESIM THRU ...,.~.".:. -.,, .~, .... '.. ,1 ;ANCHOP.~.GE, ^LASKA ~S LEFT IN HOLE DURING TRIP GN-GY: SA-SR: VF-F: FRM- MOD IND~ SL-V CALC~ SME FREE CALC CLR BRN MLKY, SA-SR: M-C~ UNCONS :ARBIDE LAG - 9443,' 28 MIN 105 SPM 105 WT 9.9 DH 10.2 ViS 42 ~,1- 1900 20 WL 5.9 eLY GY-DK GY BY/BRN,: V SFT, SOL: SLT DESIM THRU SLTST SD GY/BRN: SFT- V SFT: V ARG~ SL CALC LT GY-',GY, VF-F: SA-SR: MOD' W SRTD, PRED UNCONS: PRED l CLR-LT GY QTZ, CHT . ': ~ ~ i iI I ANCHOFb~GE, ALASKA 't-?:-*'i ,' +.4 ~.-t.-r t t.i-.i , . ' .; ~ t. ~--o GY, VF F, SA · ,,:~ ,~ ~ ,, ,''~ · ',- ..': -' u.co.s, c.T, .... ,.1.; i ~ *.)r-t + .... MOD - W SRTD ' t' :',.~ ~ ~ ' ' ~ Tt t't ~ ~.~.i-~ L ~.~ · , . . ' . ~ ' ,,L..~:,t ~.~ . ~.~_~.~.,.~; SLTST GY/BRN - BRN~ SFTj V ARG~ SL ; ......... ;=~ ~ CALC . J, r~ j~ :~.,.~;~.~ SD PRED i ~ = . , , - I i.~.~-t'j ; ~-~t t'*1 . '.I~ t.-~.~ · "~ t" ,.~.=~, J..iL_~ :LY LT BRN-GY, V SFTj STKY, V ',., '.] [,~ ,4-.~, ~ '' SOL~ S~ TEXj V SLTY~ OCC ,,.,_.[,,,, ,,'~f SD ORS SCAT THRU ;ARBIDE LAG - 9856' U 7'2 MIN 98 SPM 108 WT 10.1 pH 10.2 ViS 48 C'- 1700 YP 6 FC 2 SLTST BRN-TAN BUFF, V SFT, V ARG. SL CALC, OCC SL AREN 'T CLY LT TAN-BUFF~ LT BRN, PRED SFT-V SFT OCC FRM, MOD-SL ARG~ SL AREN, OCC GRDG TO VF SS · TAN-LT GY, SLT DESIM THRU, OCC SD 6RS .: SLTST LT TAN-BUFF, SFT-FRM~ ARG, MIC MICA, SL AREN~ SL CALC CLY TAN-LT GY, GY, V SFT, SOL~ SLT DESIM THRU, OCC SD GRS SLTST PRED A/A, SL-MOD DEC IN CALC CMT r. ~NOHOP,-.~GE, A~I-/"~SKA CoY- CoY BRN, V SFT, V STK¥, V S/TY.~ SOL ,OCC SL AREN LT BRN-TAN, SFT-SL FRM, V ARG , MIC-MICA, SL AREN ,OCC SL CALC GY-LT BRN~ V SFT,V STKY, V SLTY, SM TEX ~GRDG TO SLTST 9.9 pH I0.1 VIS 4:5 Cl- 1600 W L 6. Z SD I/4' PV 17 SOL I0 YP 7 FC 2 --CARBIDE LAG- 10~621° U 38 MIN 108 SPM 117 SLTST LT GY-$Y~ LT ARG~ MIC MICA, CARB, SL CALC BRN, SFT FRM~ . SL AREN~ SL .,, D,o ~ R,G ~ ,',' GAG OFFICE O!L A,,D ~T VIS PV U 30 SLTST GY- GY BRN, V SFT, V STKY, V SLTY, SL AREN BRN-GY, SFT~ V SL AREN~V ARG , MIC- MICA~SL CARB 'TR SD~ LT GY-TRNSL~ DK (~Y BR F-CRSE~ SB ANG-SB RND~PRLY SRTD,UNCONS, PRED QTZ ~ CHT I0.0 p H 103 49 Cl- 1400 5.6 SD I/4 24 SOL I0 II FC 2 LAG - t0,959 MIN 117 SPM 118 GY-GY BRN~SFT-FRM, V ARG, V MIC-MICA~TR V F SD GRS TR PYR~ OCC IN. CTC /SI-TST GY-DK GY, V SFT, V STKY~V SLTY iIE C"E i'VE iD. DiSTi:",tO'7 OiL AND GAS J,-,,l',] 2 :oo2 ANCHORAGE, ALASKA WL PV YP ;T U 87 )TE; NOT E GY- DK GY, SFT- FRM, ARG,MIC- MICA , V SL AREN LT GY-BRN, V SFT, V SLTY, STKY SOL I0 pH I0.~ 44 CI- 1200 - SD I/4 18 SOL I0 8 FC 2 GY- GY BRN, SFT,ARG,TR VF SD, ABNT MIC- MICA LAG- 11~16' MIN 114 SPM ' 107 TR ASPH, BLK,SFT, STKY, FNT YEL STRM CUT FLOR,STRW VIS CUT, FNT YEL DRY CUT FLOR TR NUT PLUG RE C ;",; iV E ',,.0 D;STRICT 'OIL AND CAS JAN20 , I ~ANCHOFL~GE, ALASKA ANCHORAGE, ALASKA FRSTD, CLR, M- F O(:X~ CRSE, SB SB RND, PRED QTZ, UNCONS SH FRSTO ,CLR, F - V F. OCt M, SB S8 RND,SME ANG, FRI-MOO HO QTZ, BLOT, DK MAFIC MNRLS, SME , ABNT CARB LAM,TR FNT YEL STRM CUT FLOR ,. LT- DE GY, SFT- FRM, SL- MOl) ARG GRDG TO SH,OCC SL AREN GRDG '. TO V F GR SS MULTI-COL ~PRED CLR- FROS QTZ,C, W SRTD, SB ANG-ANG UNCONS, : YR ASSOC /SD ..: DK GY- GY, FRM,PLTY, ARG,GRDG SLTST, WXY TEX,POSS BENT ' ,o.,:, ,,, ViS 44 ~1- 800 ., WL 6~ SD tr ., PV 20 SOL II -- YP I0 FC 2 SLTST LAG -- NO RETURN LT-DK GY, SFT-FRM,MO0 ARG~ '." GRDG TO VF OR SS, PLTY, GRDG TO SH, SL MIC- MIC~ ' , '.''~' ABNT NUT PLUG~.MINIMAL'i'R INOc '; CARBIDE LAG- 11678 U 47 MIN 127 SPM III · . '"' , , · 9.9 pH 10.7 '; .%5 CI- 800 ' 7. 6 S D T R ' PV 12 SOL . . I0 ' ' ..' YP 4 FC 2~ CLY GY-LT GY, V SFT,V SOL,SM TEX .. ;LTST TR ASPH,BLK BRIT, YEL STRb CUT FLOR ~NO VIS CUT, TR SS, GY- GN,V F GR,SB I SB ANG, W SRTD, FRI-MO0 IND. CMT,QTZ , PYR ~ POSS GLAUC DK GY-GY,BRN,SFT-FRM, V BLKY- PLTY, GRDG TO VF GR TR FREE CALC XTALS GY-LT GY~ V SFT~V SOL~V .~ SM TEX WL PV YP I0.0 pH 10~5 50 Cl- 1~400 ?.~ SD 21 SOL I0 II FC 2 BLK, BRIT, ANG,HD TUFF wH- LT 6Y- BL, SFT- MOD FRM OCC GRAN,WXY, FIS,BRI YEL- ( MINRL FLOR~ DK GY -- GY, SFT, PLTY, FISS, TO SLTST FREE CALC XLS ABNT INOC TR LT BRN, V BRIT ABN LCM/NUT PLUG THRU SH 6Y-DK 6Y, SFT-FRM~FIS~ A CARB LAMN THRU, 6RDG TO SLTST I/P~ CARB FLKS FLO, TR ASPHALT-LIKE TAR TUFF ;H WH-GY, SFT WXY TEX, GL SHRDS APP, BRI MNRL FL~ GY $ BRN INTLAMN, SFT-FR! FIS~ CARB LAMN, SLTY I/P CARB FLAKES THRU ll llil'l ]1 I]lll]lllllll Il _ Illllllilllll EFIIil i FFH-H-FH~H-H-.. :~,~ H-~ ~..~: I-lllllllllllll i~ illil i II111111111111 ! II11.~ I l[llllllllll[l J-I.H_ i llllllllllil~ ILl i I111111 ,I I!1 I, 11! II11111111111 Ililllllllil 11111 illlllllll[ "'~t~'/'~' I~el I I I I I l~rl I ~M I Ill Il I~:t'1 I ~ ii llllllllll IIIIllllllii "+~"~' "_ llllllllilll - -"-~ ..... I111111111111 I|11 ......... [lllll|ll ' . _~ I IIIIllllllll ~ IIlllllllllll II!11 I1~i!11111111 JJllillllllll lillJ liilllillll Illli Illllllllllll Illlll illlllillllil Illi, 190 THRu, CA'B, SLT¥ I/P, yR. .. LT BRN E R ER .S L ALT~ .., G¥~ BRN GY, 'C~UT 'LEAF APPR ~ SL POILKER CHIP'. FLKY. MICRO MICA GD ROUGH CLEAV WHEN WET. HIGH PL FOS IMPRESS. FLOAT IN. .. ;-.~ ::;, ' · ...-:,/~,; ".. - .,:.:... ,;";.;',i-~,,'."' -' ., ', ,. .'-. .. ~.. .:..i' :L-.:....:'.;.". :.':,-' , :,'...-'.'.. - , ...-.'.:~. · . ;, ':'; .. TR OTZ PEB$ .': . . . :,,-~,:~.:.. · . ,,, ~.;: '.',.,- TR AMT SH 'CTGS DECR IN GRN SZ , , . . .. TR LMST,'DK,.GY M VIS BLENDS/'SH'IN SMPL. LAG of 12:~51'. ' .... DK BRN- DK GY, OCC FRM, MOD FI$~SL INCH . .. .; . -.._ MOT, BR"- WH-TAN, "D, I.. I. YEL CUT,, FNT. BRN' . i-1- T-i- I - --+|--14- _-~_.l_J.l.! i. i11111~111111 IIIII!11111111111/111111111/11111111111111111!111t1" --ill '1,+- .'.J_-.- :.[IIIIIIIIIlHIIIFll !11 fill I I I I111111IIIII!1I!11111!111!111111!11111111.: i!I -F-I -- .. :-;;'[i I I I I i I I I k.I ! I I I I ! I 11 I I I I I I I I 11 I I I 1 i I l illllllllllll[llllllllllillllll' !1Ir ~r' [ ~ ~ "lllllillllflllilll i I ! I I ! I I I i I I I I I ! I ! i I ililllllllllllllll;lilllllllllI,, '" -"g, - g:~.~ fl 1 II I I I ! I 1 ITl 1 I I ITI-I rI1'~LLLJJJJJ_U_IZI lllllll~lllllitllil, i ~ . ~""'-'"'"~"~ -HHt-H~IIi',III;' '" - " ,l'iillllt,lllllll ' illllllllllllllllllllillllIlllllIl, l! i'llill Ii --j-]-I.. -~-l-}-Igl~[llll~.lllllllll I!111 llllllllllllllllllll!lllllllllllll~i !!1 ! I -I-I -i-l-i-VIIMllll'lilllrr~l ~.~[c IlIIl , lIIllllllllllllil!llilllllllliilllll Ill ! I .!-I-I-, 4-14- l~-l-~l I 11 I I t.~ I I NialTl~ I~r= :III irl~l ~r~l t~l~l'~,111~t~l~ll~l~i~l~Wttll~l~lliiilltl I I i. i -I-i-I-- +l-.i-II/klillL~,-illll Iii ~I;~III4~HII~EIbhW~I-CI.~ ' J_ ill Il, _ -t- I--I-.rl'T'~ 1~ I 1 I I I I I IT-Icj I il::'i:l --i~'~r'~~rJIll~llll!]~lllllt. lll11~lllllli,]-- ~.HN~ ¢1=, ' '-l-F-l-illlilIJ_llllllllll ~ill~.H!!!!!!!!!!!!!i![!t'~l~l''i'~ :"!!!.~_ --'*i ",I lil,'.--t-I-t-IlIltLIFl'dlIllmel ,,7~ Illili-rli,'li.LIllllllIlllnlll~li!lIllllllll!ZlliI~l,,! llil: , i1,1 I/--I-I-I-I I I ITl-1 I.i-I_ I II ~,nlU I ' 4mlal t I I Ir~T-Ffl Ill r-,bIlllll~i~llllll~l~l!llli!/lu,,~ ill I . ,Il, I/.-. ' -1~- P-FltOH-H~,Ji~-H -H-t-~-~~I · - ; .t, ilill,, · 1 ii i L - -, ' + · 'ri', i :t&l'~~-.., . . .,, ~.,., , , ;Il I-I- ~l~¥-I-]qqqll~llllllllllll ,;I,I I 111 i 'I ...... ' - I il [ITTN-FT~III~iI~IJIIPJ]]]I]I]]]]]I~]~!]i ill ~ I~1 I, , l,II ,,E,: .... ' ·" .:--,+,-,,,,,,,',,,,,,,,,,, ..::..- I ! 1 I I ! I I I 1-F'FFt-F[Ti'I I111 Iii1111!11111111111111111!I1111, I .. Iil- l '7~rl~J~I] I III1'1'111111111 " '.LI..LLLLLI Iil IIIIIIlllllllllllllllllillllllllllllllill, 1 1Ii ,,~ -I,-I-1,4 I I I I 1 I 1.1 ! I I I I ! I I I 111111 I I 1 ! 1 ! I11 II Iil I lllllllllllllilllllilillillll!i,! I Il.. l 7 ~1,-I-t-I I I I I I I I-..I I I i I I I I I I I I 11 ! I I I I I II I I I I I I I Illllllllllllllllllllllilllll!l,I I'//] ............. ,' !~1 '~ ' ' Illlll ' II1 ~11 , [, ], - IIllll~ll~rJr'.,I : - Illllllil~ll~lf~lllllllllJllJ,mllll~U~lll~lIl, l i-'ill ~ ,l 1,1 ,LH-I-.Hll I i llll I lIllll] J_LLIJJJI~IIIIULULDIIL[LILUIIIIIIIIIIIII, I Ill ,, I,I I, /.I-I-IJ_LJ_.L_L[I Il II II111 II ....T I Ii ,l i,I ~ ~lllllFllIlllllllll l' Ill ,,, i · · · ,, ' ' ' ~ .... ., I-I-..F II I' "' -F-I-I-FTITFFTf[I_IlE[-Ill-IIIIIIIIllUIllllIIllUIIIIIIIII, I ~ll ,[.?.~.-. ,~,l.I..~tl2UtlI~-l. FI Ii ~.m{t ~[i ~i liIIIIIIilIIIIIIIIIIIIIiIlUIIIIIH Iii r%RL.: '.-H~ · ., ~ .:..Ht_H~H_HHt+H+H~I,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,rt ,,, Illlllllllllllllllllllilllllll Il I 1 .i+l-iZiNir~.ltHjjj~mal ~' -i-FFFFi-iTFFFiIIIiiiIiiiIiiB][ii,,[IiiIiIii]iii][[iiii, i I ! l I I I I I I 1 I ! I I 11 ! LLI I lliillllllltlllllllIlllllllllll,,I I I I Illlill I I I I illilllllillllUliillllUI!!lIlllllIIllll'l ! I I [ -SE E, IIIII I 1 I_LLI ! Ii I II Il I I IlllllllllllilllllIlllllllllJlll+ I I I 1 Il i I I ! I-LII I.IL[JiII.LIllL.I, rIIIllUlIIIIIIlllIIIIIIIII-I I I I ~ j. _ - 1 -I- i .l I ! I.I..LJ_L.L~_t' I l l I I l 11 I I l I I I I/l.] I 111JJJJ.ILtL[ULIUU~I~J I.I l ~ I "- .+.,.:~.~,,,,,,,=+.,,~~..~,~,,,, ,u=,,,,,,,,.,~um~m~m~,,,,,,,,,,,,,,,,., ,,, .... -.F-I I iril I ! 1 i i ! il ilN I I I I I IIII'NllllIIIIIIIllIIIIIIIIIIIIi.I Ill ;H ~H ~,. ,MST · 4' , 'F-M GR',.' CLR" SBANG, PRED SL 'ORNG FLOR, iNST' P STRMG CUT,', YEL*' FI.( AMBER. STN . PREDOM CUT FR STW DK GY, GRGO. TO SMOOTH STRAT TO VVF P¥ LMST'. *~- 5 MLK WH. AT GO.LIME; ,CUT,.N.O ,, CL~ LT AMT TO RED AT BRN Vl~ I '' WH- BRK RD,~ 'Fi IMBD IN .BRK, ] LMST) CLN BRK RD c,.,.U"co, s~,~' GR 'SZ IO00u~ ' ~ ~,. ;. ~ NOTE: RECEIVED DISTRIOT OIL AND GAS OFFICE FEB 1 8 1982 ABNT 'SLOUGH' iN CORING INTERVAL.. "SEE.' CORE DESCRIPTION:!...FOI ATIVE LITHOLOGY'. '".,. ,,., ~ ..,,.,. ',,,~:~ .,.~-',.' '~ t .ANCHORAGE, '!.:ILl I I · ~,'~l:f I . "I Y[ t '~- '~ , ;-~--- ~:LI I I L i- / ~.rll [ I ~'. -L[ i [ i L · ~tf_i,[ I I ~1 . ~'~1_] t't, -:1 · - [ .... '"] ~LI. ] ! ]~:L.i .i t · i ~_~].]. ~[1~1 I. I , · :' i~I~ I i · · ~ : l'"'l. ,- '~i,:[ · l.. i~: i . ~[~: ,, .' ii, .... ~'i,~'IT::~l~S d ~::_~,,.~ i! · ......~-'-1'-~' ~.?[.I -r F~:~ . ;I- l.'t'.'] i}i?'l;, t"l ~-1 [,t. · ~t t..l 4 · [ [;[;:}.[.j · ~ILI':I-:1 ~"t.;i ~l.l. Fll. };~ . t~l:ll [~llq' : ~T': F t}ll'l --:1 ~''tl['till ' ~'. Illl~I. [~l~'[l''i L DISTRICT OIL AND GAS OFFICE FEB 1 8 1982 ANCHORAGE, ALAd',~ NOTE: NOTE~ iii ' BIT 6~O,M.~ ~,$me l':~j ~ ~m m I ~ I ]; ~ m ; )l~ il ~m llll]~l ~ VISIBLY SAND, FR SRT6, NO I I I .. i ~ i I ' I l' ~I ~];ll~~ :oo- eoo.',l mo -[5 °/o ~ST CHT ...... .,. .... HIGH TORQUE, SH~T TRip;I:INTO';I CASING ~ I~OIO' DRILL ~'!)014'/ P.O.H. m ,:~'" CLR SBAN~ QTZ X~,SlLcMT,~E INTR GRAN T~ ,T[CTGS CMTD TO . ,.;. '.' ~. '..: ..... m '"~'m ;Z::': :.:~;~'m' LTGY, M HO,MOD FIS',$1~lCI~t BRN, FR SORT QTZ XL~ ' :l ' m PYR, GROG- SLTST CLR-MLKY~ VF GRN,V HD, FR W SRTD M-OK GY,SLHD-HD,CALCCMT,GRDG- :',.i SLTST~ ABNT COAL SLOUGH '~' ABNT SLOUGH THRU SMPL BITGRD,M HO ~TR PYRt SHE CTGS ;LTS T RD BRN ~ ARG, SFT'FRM 9.8 pH 46 CI- 18 WL ! 450 Z$ ~0~ .. RD BRN, ARG, SFT-FRM,PROB SLOUGH SLOUGH POOR RETURNS ~H : .J: .! GY- OK GY, BLK, HDTVHD, BRIT I/P V CARB,SHNY, SME PITY TALC = ~ CRM-LT TN/BRN SLCKSD V SFT- FRM~ WXY LSTR, NO MNRL FLOR GY-DK GY~ HD~VCARB,OCC.PLTY~:: ~.~ LO-MED GRADE META, PHYLLITE , .,~ IlECEIVED DISTRICT OIL AND GAS OFFICE FEB 1 8 1.982 ANCHORAGE, ALAS[A 9-331 1973 UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use Form 9-331-C for such proposals.) 1. oil gas well []] well [-1 other Exploratory 2. NAME OF OPERATOR Exxon Corporation 3. ADDRESS OF OPERATOR P.O. Box 4279 #2243, Houston, TX 77001 4. LOCATION OF WELL (REPORT LOCATION CLEARLY. See space 17 below.) AT SURFACE: 708' EWL, 1777' SNL, Beechey m~eP-m~<~.-~T~RV~L: Poi nt B1 ock 654 AT TOTAL DEFTH: Straight Hole 16. CHECK APPROPRIATE BOX TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA REQUEST FOR APPROVAL TO: TEST WATER SHUT-OFF [] FRACTU RE TREAT 'El SHOOT OR ACIDIZE [] REPAIR WELL [] PULL OR ALTER CASING [] MULTIPLE COMPLETE [] Form Approved. . .. Budget Bureau No.. .42-R1424 · 5. LEASE .,. :~ ~ .~ -' ~ *: :: 0CS-Y-01911' ~-' -: :'*,' .~., '* 6. IF INDIAN, ALLOTTEE OR TRIBE NAME . 7. UNIT AGREEMENT'NAME ' · . ..;. ~ .' . .: --m ., 8. FARM OR LEASE NAME. " '.-~." ._?, · . · . . 9. WELL NO. : .'. '. "* -. · . .. . ': ~. : ,-- ,; · ,.~ -- ,., 10. FIELD OR WILDCAT NAME: .. ' ' Wildcat · :. :.. .T.:: : 11. SEC., T., R., M:, OR BLK. AND SURVEY OR AREA Block: 654 Stefansson Sound, B6au'f(~rt Sea'..*'~- 12. COUNTY OR,PARISH 0ffshore:";-;i ii.i~-I !.Alask~; · , . 14. APl NO. :.."... '.:...: 55-201-00001 ": ,.- 15. ELEVATIONS. (SHOW DF; KDB,"'AND WD) RKB' 43'.:MS[' WD: ","18' ' SUBSEQUENT REPORT OF: ,., , ~ ",/ [!] .'t) ' :' " '"' ......: [] -..: ,.._"..,.. '.!,., .... - ... ,...: .... [] ;' '- ,,,,....~.~,,c':~.~. .. -. ,~.,. :.~i. ?: ' ..... . . , o':F~CE ]; ;~ '"'; ':" '" '~ '" [] OtL A~''~'D (': :"': ...... .r',. ,,,~, ~.. .~,., ~'::...; .':' .,." :,: ,", [] (NOT~:~ ~eport results 0'f ~ultiple completion or zone [] .~,, ~.~ ... [~i~:J~ange on'Form 9-330.):~- :: ;/. ,:~ ', [] [~'~.~, 2 .' ": .:~ .-~'": , :~ ,~: ..... .'. :.:' " CHANGE ZONES [] [] '., .i ~.~:.- ABANDON* [] [] ..... ~t,I OiV1510~1..'.: .:,,.!i,i!iI il ,:. ~: .... (other) Suspend co,'..:~ s"':~'.~ S,~,'~ i~ su,~v~ ~ ~_ ,---r~; ..:n'~, - ,,.,~ -..~ :,. "' "'~ .*.~ :'.... U.=. ~:":'~...'..;;, ,-..,: i',,LAur'~" ~'. ,:.- .,~('t.h :,', '",' ~'-~ ~' " 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearl~"'~t'~{e all pertinent details; ;ha give pertinent/dates, including estimated date of starting any proposed work.. If well is directionally drilled, giv. e'subsurfa.ce locations and measured and true vertical depths for all markers and zones pertinent to this work.)* ".'-; ;2 ~';. ~.': ii · '!.; '.;. Suspend 0CS-Y-0lgl #l leaving 9-5/8" x ]3-3/8" annulus op~:n~".~o su~fa(~e'.' for waste disposal when drilling 0CS-¥-0191 #2 Suspen ont.'procedure'~':'''' is attached ' ' "~ '3~ . ('> ~,, .. ~'....,-. ~, ~,~. _. ;q' · ,'.~ Operations to commence on December 23, 1981 ~ .~.'~? ..:.'.,.,:~.~i ~':. This notice also corrects the surface location which was"in error!':on*i .2 '' the original Application for Permit to Drill. The corre~ct,'..*::]'6c'ati0n .ls:'...'? '"~ ;: ~ '. .-.. ;.- .. . .~ ...~ ..... 708' EWL, 1777' SNL, Beechey_Pt. Block 654; . ,,. :'~:'.' :...'.-'..:~ :~,* -.-. :::;.? ..... O I I, O I I, c. ' Lat. 70 23 11.79 ,'Long. 147 53 27.98 ..... ~ ...... '..~'- ,~,,-' X = 1530889, Y = 25620219 '~.,.',~:~:.':.."~..~- ,: 5. ~ ,~- ~ = '.~ :.f..;4',.'~ a~/~: "-"' Subsurface Safety V Manu. and Type ........ ,' '.'~ '-:* :,, ..':. ~:' i,: i ~,": c" :~ Ft. g is trueq~n [~'" :'~ '''~ "' ,2 c.. ':~ .::. r.. .: ..., ..? :, / :": '. '~. ............. ---~ /"~A~r //~/ A~l'his space for Federal or St,te offic~e) ~.: '~,' . · t' ' ' · APPROVED ..... DATEcoNDiTiO~S ~ ~I~A.i.;,~'~ANY: -.<:::2 A . ;.. ~. :.,- .:.~ ~ : ;': ',-' .x, ,,~ ' r :, .'~ ;'F .-, ".":'. *See Instructions on Reverse Side ~"~ocedure for Temporary Abandonment of OCS-Y-0191 #1 · · · · · · After dumping cement on top of retainer pull up 5 stands and circulate out any excess cement. Pressure test' plug to 1000 psi. Good test constitutes of no more than 10% pressure drop during a 15 minute period· · P~OOH t_o 3000' laying down DP. Concurrently, in'e f9 mu aown the 9-5/8" x 13-3/8" annulus _,~3~ ~ d system _c~=ea,n,,tanks. and then mix 500 bbls. of 10 plq~q~,~ae-~ 'w~t~ '"~ ~uu.~z~ gallons of Corexit 7720 ~corros~0~'~:~:~'~k~ ~~'~ - - · ~,, ~~u~; an~ bO gallons of Corexit 7675 (bactericide) ~t~O ~ ~:' Reverse circulate 300 t b~ls of the 10 ppg q~ to the casing until clean returns are obtaine~O~j6~c~ ~=~ resh wa er pre ush. ec proca e pt e 10 ppg CaC1 water has a freezing point of approximately _20OF. 2 _ Shut down the circulation as required to inject mud returns down the 9-5/8" x 13-3/8" annulus. POOH to ~_~,O laying down DP. Set a ~O sack ~/~bbls) surface plug from _~7o,' to //O', as follows: A· Mix and pump 7~ sacks of Permafrost cement Do not displace. ' B· POOH to .~ and circulate out excess cement and treat returns with sugar.to prevent cement from setting. C. Mix the slurry as follows: DENSITY YIELD MIX WATER TOTAL MIX WATER 15.0 ppg 0.93 cf/sack 3.5 gal/sack 7.5 bbls. POOH and inject any remaining waste fluids down 9-5/8" x 13-3/8" annulus. APPROVALS: Engineering - . ~/' Oper/tions JRG: rms 25/J · . · · · . · · · 10. OCS-Y-0191 ~1 7" Line. r Squeeze 12-22-81 o~U ~ ' ... Wireline set a Halliburton 9-5/8" 47~ cem~n~etainer at 9300 '. · RIH with a retainer stinger and. 5" DP Close the annular preventer and put 5000 psi on the drill pipe annulus and monitor pressure. Establish injection at 3-4 BPM. Do not exceed 4500 psi. Release the pressure on the annulus; open the annular, and pick-up out of retainer. Mix and pump 300 sx of Class 'G' - .45% Hr-7 + 1.0% CFR-2. WEIGHT = WATER = _ YIELD = THICKENING TIME = 15.8 ppg '5.0 gps (36 bbls water) 1.15 cf/sack (61 bbls total slurry) ~.:35 Hrs at 175° BHCT Displace with 84 bbls of mud. This will put the cement slurry 1200' above the stinger. Sting-in to the retainer, close the annular, and place 500 psi on the drill pipe annulus and monitor pressure. Continue displacement with 76 bbls of mud. This will place 51 bbls (250 sx) of cement below the retainer. Do not exceed 4500 psi. Release the annulus pressure, open the annular, and dump the remaining 10 bbls of cement slurry on top of the retainer. This will leave a 140' plug on top of the retainer. Go to procedure for .temporary abandonment· APPROVALS: Engineering- / Date Date KSO / rms 219A/A 12/22/81 Form 9-331C ( SUBMIT IN TRI:"~ .FE* (May 1963) (Other instructi~ on UNI ]'ED STATES reverse s,de) DEPARTMENT OF' THE INTERIOR GEOLOGICAL SURVEY Form approved. Budget Bureau No. 42-R1425. APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK 1S. TYPE OF WORK DRILL [] DEEPEN I--I PLUG BACK [-I b. TYPE OF WELL O11. ~] GAR SINGLEO MUI.TIPLE El WELL ~¥,:L-.I--! OTIIER Exploratory zoNE zeN. 2. NAME OF OPERATOR Exxon Corporation 3. ADDRE88 OF OPERATOR P. O. Box q279 (122q3, Houston, Texas 77001 4. LOCATION OF WELL (Report location clearly and in fleeordance with any State requirements.*) At surt'nee 1842 ' FNL & 667' FWL, ,Beechy Pt. BI ock 654 Lat 70°23'11.15'N; Long lq7O53t29.15.W X=l,530,St*8'; Y=25,620,150' 14. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE0 Approximately 7 miles NNE of Point Heald LEASE DESIGNATION AND SERIAL NO. OCS-Y 0191 6. IF INDIAN, ALLOTTEE OR TRIBE NAME 7. UNIT AGREEMENT NAME 8. FARM OR LEASE NAME 9. WELL NO. 1 10. FIELD AND POOL, OR WILDCAT Wi I dcat 1L BEC., T., R., M., OR BLK. AND BURVRY OR AREA · Block 65#'Stefansson Sound~ Beaufort Sea 12. COUNTY oR PARISH] 13. STATE I Offshore I Alaska l~. DISTANCE FROM PROPOSEDe 16. NO. OF ACRES IN LEASE 17. NO. O{' ACRES ASSIGNED LOCATION TO NEAREST TO THIS WELL PROPERTY OR LEASE LINE, FT. (Also to nearest drig. unit line, if amy) 667 l #3#. q3 - IS. DISTANCE rltOM PR01'OSED LOCATIONe l~). l'ltOl'OREI)DEPTll 20. ROTARY OR CABLE ~OL8 TO. NEAREgT WEL~, DltlLLIN(~, COMPI, ETED, o,~,,~,~,o,.o~,,,~,.,. First Well 12,500 Arctic AlaSka Rig 0 21. ~VAT~ONa (Show whe~er DF, ET, GR. e~.) . ] 22. APPROX. DAT~ WOa~ W~ START* Water Depth=lS'l '~B=+~0'; Pad Level=+ll' "~lFe~r'~' ~0, 19S0 ~a. ' .......... .... ~ ~ ~ ~. X ROI OSED CASIN~ AND CEMENTING 1 ROGRAM ~ ~ ----,~! tl,~, _ : ' ~ '~ ~- ', . ~ ~ f '..' ,. Please se eattachmentsfor:Wellbore& Casing Design Sketch, Prop( Pro§ram, Casing Desi§n Criteria and Safety Factors, Mud Pro§ram ah'd~.MIRiJl~h~' (~antities~ Blow- out Prevention and Stack Test Program, Operational Procedure and Schematic Diagrams for a Four-BOP Stack and Diverter System, and Certification' of Consistency with Alaska State Coastal Management Pro§ram. The following additional documents are referenced for this well and were submitted separately.~ Exploration Plan with Contingency Plans and the Environmental Report for Leases OCS-Y 0189, 0190, 0192, and 0193. Not~ that a list of two (2) departures are requested relative to the proposed Arctic OCS Orders Nos. I & 2 concerning marking'of equipment and diverter system control valves. , ~ IN AnovK 8PACE I)I,:RCRIIIE Plt01'nsEo PRf)0RAM: If pr.p.sal is to deepen or plug back, give data Oll present Productive zone and proposed new productive Zolle. If I)rolmsnl is to drill or (le(,lwn ¢llr4~(:llonally, giv(, I.,rllnt,nt data on sul)surfaee loelttions .lid measured add true vertical depths. (live blowout preYenfer proffram, if any. 24. Exploration Supervisor DATE 12-19-80 (This space for Federal or State office use) APPROVED BY CONDITIONS OP API*ROVAI,, IP ANY: APPROVAL DATE [RC.TIN~. D!~TRIOT SUPERVI$ORDATE TITLE ,0C[ 2 11981 _~..~gO.V_Ah S. UDJECT TO AITACiI]~D IU~.QUIIIEMENTS - ,, USGS CONFIDENTIAL ti./ .o -5 · I i I II VICINITY OCS- YOI91 BEAUFORT ENOR SECTION &PPROVED PLAT BLOCK 654 ~SEA, A_I..ASKA _ · EXXON COMPANY, U $.A. PRODUCTION DEPARTMENT WESTERN DIVISION GRAPHIC 12- 19- 80 JOB NO FILE NO WA-548 A Y: 7,809,600 meters ( Y: 25,621,996' } 667' ELL N-~ I X= 1,530,848' Y -' 25,620,154' Lat. = 70°23'1,1'' 15" Long. = 147°55 ?_9. EXXON APPLICATION FOR WELL N° 1 OCS -YOI91 ( Y= 25,606,248') Y= 7,804,800 meters NOTE: Lease lines are in accordance with the Bureau of Land Mgmt. Outer Continental Shelf Official Protraction DiagramN-° NR06-O$ dated October 19,1979. Boundaries are defined in X and Y Coordinates of the Universal Transverse Mercator Grid System, Zone 6. I000 ! . LEASE PLAT of OCS Y-OI91 BLOCK 654 BEECHY PT. BEAUFORT SEA, ALASKA DRAWN BYJ.K. ICHECKED BY IOATE 'z"9'sO GRID · 0 I000 I METERS EXXON COMPANY, U.S.A. (DIVISION OF EXXON CORPORATION) PRODUCTION DEPARTMENT WESTERN DIVISION IREVISED.____I SHEET OF, 2O0O I , IFILE No. WA' 548 Certification of Consistency with the Alaska Coastal Management Program I certify that, to the best of my knowledge and belief, the proposed activity described in this U. S. Geological Survey Application for Permit to Drill complies with the approved Alaska Coastal Management Program and,will be conducted in a manner consistent with such programs. Signature of Applicant December 19 ~ 19.80 Date REQUEST FOR APPROVAL OF DEPARTURES FROM ARCTIC OCS ORDERS NO. I AND 2 BEAUFORT SEA, BEECHEY POINT AREA OCS-Y No. O191 Wel 1 No. 1 Order I I. Section 5, Marking .of Equipment, requires in part'that "whenever prac- ticable, all materials, equipment, tools, containers, and items used on the OCS are to be properly color-coded, stamped, or labeled with the owner's identification prior to actual use..." Exxon requests a departure from this requirement for marking of equipment inasmuch as activities for this proposed well will be conducted in shallow water or over ice roads after freezeup. Transportation in the relatively calm open water season is highly unlikely to result in the loss of equipment overboard, and anY lost material could easily be recovered. Further, there is no known commercial fishing in these waters. Transportation during freezeup will be by conventional land transportation methods. Order 2 II. Section 5.4.1, Drilling Operations from Bottom-Supported Rigs, states in part, "The diverter system shall be equipped with remote-control valves in the main and diverter flow lines that can be operated from the control panel prior to shutting in the well~" Exxon requests a departure from the above to provide for a remote- control valve in the main diverter line, but with two manually operated valves in the branch lines that control the direction of flow depending on wind direction. A diverter sketch and operating procedure are included with the permit request showing the desired arrangement. HLD/TLP :cf ' 12/17/80 BEAUFORT SEA, BEECHEY POINT AREA OCS-Y O191 WELL NO. 1 WELLBORE & CASING DESIGN SKETCH 30" l" Wt Gr B @ +_158' RKB (98' BML) Est. permafrost depth 980' RKB (920' BML) 20" 106.5#/ft K-55 Butt Conductor @ +-1000' RKB- (940' BML) 13-3/8" 72#/ft L-80 Butt Surface Casing @ -+2800' RKB (2740' BML) Waste fluids, drilling mud, and hydrocarbon injection zone. TOC @ approximately 7000' RKB Note: Prior to well abandonment, the injection annulus will be plugged with cement and the casing filled with a non-freezing fluid. Top of liner -+10,000' RKB (9940' BML) 9-5/8" 47#/ft Soo-95 LTC @ -+10,500' RKB (lO,4~d' BML) 7" 32#/ft N-80 LTC @ +-12,500' RKB (12,440' BML) LIJ ~ el'"' el.. el..- N ee BEAUFORT SEA, BEECHEY POINT AREA OCS-Y 0191 Well No. 1 CASING DESIGN CRITERIA AND SAFETY FACTORS (See Attached Wellbore Sketch) SURFACE - 13-3/8" @ 2800' · Burst - Considers gas gradient to the surface causing lost ret'urns at the shoe assuming maximum expected leakoff gradient. External fluid weight 9.3 ppg. Maximum Surface Pressure (MSP) MSP = (Max. shoe leakoff gradient - gas gradient) casing depth = (13.9 x .052 - 0.10) 2800' = 1,744 psi · Permafrost Freezeback - Considers maximum external collapse gradient of' 1.44 psi/ft and minimum internal fluid weight of 9.0 ppg. Maximum Collapse Pressure (MCP) MCP : (Max. external gradient -min. fluid gradient)max, permafrost depth = {1.44 - 9.0 x .052} 1000' = 972 psi · Permafrost Thaw Subsidence - 13-3/8" 72#/ft L-80 Butt post yield strain performance exceeds the requirements based on worst case well spacing. · 'Safety Factors Burst 1.312 Collapse 1.00 Tension 1.50 PROTECTIVE/PRODUCTION 9-5/8 @ 10,500' TD · Burst-Protective - Considers gas kick of sufficient intensity ana volume to cause lost returns assuming maximum expected leakoff gradient and casing filled with water. External fluid weight 9.0 ppg. Maximum Surface Pressure (MSP) MSP = (max. shoe leakoff gradient -water gradient) casing TD -- (15.1 x .052 - 8.33 x .052) 10,500' : 3,696 psi · Burst-Production - Considers shut-in gas well .surface pressure on kill weight packer fluid and external fluid weight of 9.0 ppg. Maximum Surface Pressure (MSP) MSP -- (max. est. pore pressure gradient - gas gradient) well TD : (9.6 x .052 - 0.18) 12,500' : 3,990 psi CASING DESIGN CRITERIA AND SAFETY FACTORS (Continued) · Collapse - Production - Considers surface pressure = 0 psi, internal fluid weight 0 ppg, and external fluid weight 10.0 ppg. Maximum Collapse Pressure (MCP) MCP = (External fluid gradient - internal fluid gradient) casing depth - surface pressure : (10.0 x .052 - O) 10,500' - 0 : 5460 psi · Safety Factors - Protective and Production Burst 1.312 Collapse 1.125 Tension 1.50 PRODUCTION LINER 7" @ 10,000 - 12,500' TD · Burst - Same as for protective/production casing. · Collapse - Considers surface pressure = 0 psi, internal fluid weight = 0 ppg, and external fluid weight : 10.0 ppg. Maximum Collapse Pressure (MCP) MCP = (External fluid gradient - internal fluid gradient) casing TVD - . surface, pressure = (10.0 x .052 - O) 12,500 - 0 : 6,500 psi · Safety Factors Burst 1.312 Col 1 apse 1.125 Tension 1.50 0 u Z MUD PROGRAM PERMAFROST DRILLING OCS-Y 0191 Well No. i Permafrost is expected to be encountered to approximately 980 feet RKB in the subject well. The Shallow Hazards Survey conducted at the location does not indicate the presence of any shallow hazards, including any indications of gas hydrates. The well does not fall within the area of shallow biogenic gas described in the USGS Open-file report 80-809. Also, none of the wells near this area are known to have encountered gas hydrates. Exxon's Alaska State Duck Island Unit Well No. 1 located just outside this area to the south had permafrost to approximately 1500 feet RKB but did not encounter gas hydrates. It is planned to carefully monitor mud temperatures and gas content while drilling surface hole. Amud logging unit will be in operation from the mudline to TD, and a flow diverter will be installed on both the 30-inch and 20-inch casing. If indi- cations of gas hydrates are detected, mud temperatures will be controlled by cold water additions to reduce melting and penetration rate will be limited to reduce gas concentrations in the mud. The planned surface casing depth of 2800 feet is expected to cover all potential gas hydrate zones. HLD:cf 12/17/80 Figure 3 ,.~ ~ el,.. N I I I o o _J 0 o ¢+,. . $. o o _ . 3)~0H3 ARRANGEMENT OF A FOUR-BOP STACK BUTTERFLY VALVE ~ FLOW LINE TRIP TANK --~ $" LINE OR ~ J ~. BUTTERFLY VALVE LARGER ' rAN NULA [ mOP J TRIP TANK CHOKE MANIFOLD I COMPONENT SPECIFICATIONS Flanged plug or gate valve - 2" size - same working pressure as 'A' section. Screwed tapped bullplug with needle valve and pressure gauge. Flanged plug or gate valve - 2" size - same working pressure as top of 'B' section. Flanged tee v. ith pressure gauge and/or connect/on to casing pressure gauge on hydraulic choke control panel. Flanged plug valve - 2" m/ntmu~ size - ~OWCO "Lo Tort" or equivalent. Flanged hydraulically controlled gate valve,' 7. Flanged plug valve - 4" minimu= size - BOWCO "Lo Tort" or equivalent. Flowline from spool to choke manifold - 4" mintmu~ size - all connections must be flanged or velded. Co-nection at top of annular preventer amst be equipped.~[h an ~I rims groove, EI rims gasket, and ~I companion flange on bell nipple. All flange studs mus~ be installed. 10. ~e ID of the bell nipple and companion flange must not be less than the ID of the BOP s~ack. Il. Spool-24" height with 2 flanged side outlets - 4" ~d 2" ~nta~ ID. BEAUFORT SEA, BEECHEY POINT AREA OCS-Y 0191 Well No. I Figure 2 ,. t, DIVERTER SYSTEM For Use on 30" Structural and 20" Conductor Casin~) SHAKER TRIP ----), TANK BUTTERFLY VALVE TRIP TANK 20" HYDRIL MSP 2000 0" HYDRAULIC VALVE 20" 2000 PSI SPOOL (~) lO" 20" WELLHEAD OR ~/ 20" CASING (30" not shown) VENT OPERATING PROCEDURE VENT / MANUAL VALVE Diverter system has one-lO" hydraulically operated main valve and two-lO" manually operated branch valves. Diverter and main valve controls are interlocked. The main valve is normally closed and the' diverter and branch valves are normally open while drilling. In a Well Control Situation' 1. Close Hydril diverter which automatically opens main valve 2. Close upwind branch valve BEAUFORT SEA, BEECHEY POINT AREA OCS-Y 0191 Well No. 1 Figure 1 POUCH 6601 · ANCHORAGE, ALASKA 99502 I~ECEIVED PRODUCTION DEPARTMENT OFFSHORE FIELD OPERATIONs ALASKA OPERATIONS ~P~Y CONSERVATION MGR. t,!. ~, November 10, 1981 OCS Order Departure OCS-Y-0191 81 Mr. Rodney A. Smith Deputy Conservation Manager Offshore Operations United States Geological Survey P. O. Box 259 Anchorage, AK 99501 Dear Mr. Smith: OCS Order 2 Section 4, Directional Surveys, states in part, "On both vertical and directional wells, directional surveys giving both inclination and azimuth shall be obtained at intervals not exceeding 150 meters (492 feet) prior to, or upon, setting surface or intermediate casing, liners, and at total depth. Composite directional surveys shall be filed with the District Supervisor." We believe that directional surveys at intermediate casing point and at total depth are sufficient, and therefore request a departure from the above requirement to delete the directional survey at surface casing point. Since this is a vertical well, .we plan to run drift surveys every 490' to total depth, but will run a gyro survey at 9-5/8" casing point, before drilling into any productive zones, and at total depth. We are currently at surface casing point on this well and have taken the following drift surveys: 479' 0° 817' 1/4° 1306' 1/2° 1786' 0° 2260' 1/4° 2735' 1/2° A DIVISION OF EXXON CORPORATION Mr. Rodney A. Smith November 10, 1981 Page Two These surveys represent a maximum horizontal deviation of 13' from vertical, and indicate that we have essentially drilled a vertical wellbore. We believe that confirmation of this data through a directional survey is not necessary due to the shallow depth and low angle. If you have any questions regarding our request, call John Willis at 263-3741. KSO:sjm cc: O. C. Rath R. K. Riddle Very truly yours, ~nn v COMPANY. U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 PRODUCTION DEPARTMENT ALASKA OPERATIONS July 29, 1981 Alaska Department of Environmental Conserva Cion R O. Box 1601 Fairbanks, Alaska 99701 Attention:. Mr. Doug Lowery Gentlemen: An oil spill occurred on Exxon's. Beechey Point, OCS-Y-0191, drill pad at 1000 ADT on ~July 22, 1.981. This report is being made for your information since this lease is in the area included in litigation between the State of Alaska and the United States currently before the United States Supreme Court. Pursuant to 18 AAC 75. 100 under authority of AS 46.03. 020 (10) (A) . and AS 46.03. 755, this letter constitutes written confirmation of the telephone report made by Ms. J. R. Hinn to Ms. Dorothy Miles of the Alaska Department of Environmental Conservation at 1305 ADT on July 22, 1981. The information required by 18 AAC 75.110 follows: 1. Date and time'of discharge: July 22, 1981, at 1000 ADT. · Location of the discharge: Exxon's B~echey Point, OCS-Y-0191, Well ~1 location. 'Beechey Point is located Lat. 70° 23'11.15", Lon~. 147° 53'29.15". · Persons causing or responsible for discharge: Fuel truck driver with Alaska International Construction. . · Type and amount of discharge: Approximately ~o~_ne pint o_~f_ diesel· ' Cause of discharge: Diesel which had accumulated on the floor of a truck/tanker pump room drained onto the drill pad when the truck climbed a 40° slope. .A DIVISION OF EXXON CORPORATION RECEIVED AUG- ~ 1981 Alaska Oil & Gas Cons. Commission .Anchorage Alaska Department of Environmental Conservation page 2 · · . · Please you may require. Environmental damage: None. Diesel remained on the drill pad. ' . Absorbent was used to clean Clea. n. uP__~ Contammn~_ ?_ _ ~ _~allOn u~ · contaminanu= date of disposal of discharge and transported to LocatiOn, meth°d .and"~ntaminantS .were the North Slope cleanup mater~al' ,.,-~house and given to Exxon'S Deadhorse "==~ Absorbent has been Borough for incineration/disposal. to prevent recurrence: ActiOn taken floor of the pump room on the truck/tanker' placed on the ,. additional information contact me at 907/276-4552 for any Yer~iruly yours, jRll:emb 240-910 2£8/DD/3 Hamilton cc: ~Hoyle oil & Gas Conservation commission 3001 Porcupine Drive Anchorage, AK 99504 R. K. Riddle AUG'- 3 1981 Alasga Oil & GaS Cons. Commission Anchorage NOTIFICAT£ON TO O&GCC Date & Time of Notification: ~..:~. _c./-<'_: / Person Notified: .J/;~..?~ ...... [-.~. Informati,}n required by 18 AAC 75.110 · 2~ · · · · , Date and time of discharge: Z- Location of Discharge: / Pers',}n or Persons'causing or responsible for the discharge: ~~//'~ ~'~' ~-;/.~"','"::¢ ;~.'/g .'".:'ZtcZ Type (s) and amount (s) of hazardous substance (s) discharged: . . Cause of Discharge: Environmental damage cause by tl~e discharge to the extent ascer- tainable: /~~ '. Cleaning act ions undertaken: .. · Location and methbd of ultimate disposal of the. hazardot~.s :;ubst:ance and ,contaminated clean-up materials including data of disposal: · Actions taken to prevent ,recurrence of tl~e discharge: · of ALASKA TO: F NOTIFICAT£ON TO O&GCC ~ ' ' ~ FILF: Date & Time of NotiFication: Z,,~p~,,/V 7-~--~? ~ y~/~/ Person Notified: ~ ,/~ _~</~~ .. ~f~c / /~ Information re~~ 18 AAC 75.110 4, i. Date and time of discharge: 2. Location of Discharge: 3. Per.~',>n or Persons causing or responsible for the di~<':harge: 5. Cause of Discharge: 6. Environmental damage cause by the d{~cha~ge ~o ~l~e extent 7. C~ean~ng act~on~ unde~taken~ " .. e Location and method of ultimate disposal of' the haz;~rdo~m !*ub:;I::tnce and contaminated clean-up materials including data of ciisposal. Actions taken to prevent recurrence of tlie discharge: ..... ~4~.z~4 l_~_.//o COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 907/276-4552 Alaska Department of Environmental Conservation P. O. Box 1601 Fairbanks, AK 99701 Attention: Mr. Doug Lowery March 20, 1981 Gentlemen: An oil spill occurred on the ice rgad adjacent to Exxon's Beechey PoTty, O.CS_~T~!91~. Well 91 location at 1530 AST On March 11, 1981· Pursuant to 18 AAC 75.100 under authority of AS 46~03.020 (10) (A) and AS 46.03.755, this letter constitutes written Confirma- tion of the telephone report made by Ms. J. R. Hinn to Ms. Lorraine - Rohloff of the Alaska Department of Environmental Conservation at 0940 AST on March' 12, 1981. The information required by 18 AAC 75.110 follows: l· · Date and time of discharge: March 11, 1981 at 1530 AST. . Location of the discharge: On the ice road adjacent to Exxon's Beechey Point, OCS-Y-0191, Well 91 location. Beechey Point is located Lat 70°23'11 15" Long · · · · 147°53'29.15''. · Persons causing or responsible for discharge: None. Discharge was due to equipment failure. · Type and amount of discharge: Approximately three .gallons of hydraulic fluid. · Cause of discharge: Broken hydraulic line on a dump truck owned by Alaska International Construction, Inc. · Environmental damage: None. on the ice road.' Discharged fluid re~ained 'RECEIVED A DIVISION OF EXXON CORPORATION MAR 2 5 1981 Alaska 0ii & Gas Cons. Commission Alaska Department of Environmental Conservation March 20, 1981 Page Two . · Cleanup actions undertaken: Hydraulic fluid was cleaned up with absorbent and contaminated ice chipped up. All contaminants were placed in plastic bags. · Location, method and date of disposal of discharge and cleanup material: Contaminants were taken to the North Slope Borough disposal site on March 11, 1981. · Action taken to prevent recurrence: Broken hydraulic line has been repaired. All hydraulic systems will be periodically checked to minimize future line breaks. Please contact me at (907) 276-4552 for any additional information you may require. Very truly yours, · JRH:sjm 240-910 cc: Mr. Hoyle Hamilton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 R. K. Riddle .( E OH COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, AL/~,SKA 99502 March 17, 1981 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION NPACO-RF-P Beaufort Sea 101 Re: 071-0YD-2-800193 Construction Gravel Island Beaufort Sea North Slope Borough Colonel Lee R. Nunn District Engineer U. S. Army Corps of Engineers P. O. Box 7002 Anchorage, Alaska 99510 Dear Co.lonel Nunn: ' Drilling operations at the subject 'site are progressingiin accordance with 'the plan described in our letter to you of 'Decembe~ 23, 1980, and we anticipate that downhole drilling operations will have been completed for the current winter seaso~ prior to March ~1, the cut-off date provided for in Special Condition a. of th9 subject. permit. We anticipate at that.time we.will have reached a measured depth of 10,.500',. although the true vertical depth will.be slightly less than 10,000'. At this depth, as we have previousl~ advised, 9-5/8" diameter casing will be set and further drilling :will be suspended until it is'resumed on o.r after November 1, .1~'81. Although downhole drilling operations should thus not e~tend beyo. nd the critical date of.March 31, further downhole operations'Will be required to complete the logging of the well and the running and cementing of the aforesaid 9-5/8" diameter casing. Accordingly, we are at this time requesting that a two week extension beyOnd .the'March 31 date be granted us so that this additional 'downhole work may be completed prior to shutting down operations for the.current winter season. Yours very truly, RKR:et ~aska Oil & Gas Cons. Comrr;Jssior~ Anchorage cc: Shehla Anjum, NSB; Hoyle Hamilton, AOGCC; Glenn Har'rison, DMEM; William Copeland, FLWM; Douglas Lowery, ADEC, J. Scott. Grundy, ADFG; Ron Morris, NMFS; .Jerry. Stroebele, 'USFWS , ' A DIVISION OF EXXON CORPORATION Ii,'" ALASKA OIL AND GAS CONSERVATION COMMISSION Dave }!as s State Clearing House January 26, 1981 Blair E. Wondze~ Petroleum Engineer Exxon OCS-Y 0191 Island State I.D. No. 81011641 COE No. 800441. We appreciate this opportunity to comment on Exxon's proposed gravel island for Drill Site OCS-Y 0191. We have reviewed portions of the proposal, especially those concerning the drilling program. The program appears to be adequate, based on our knowledge of the area. In general, we believe that the Joint Beaufort Sea lease sale took place after it was determined that the resulting actions would probably be "consistant" with the approved Alaska Coastal Management Program. Since this type of action was contemplated prior to the sale, and the necessary surveys (geotechnical and cultural) have been made, we believe this particular action is "cons is tant". Please send us a copy of the State's reply to the COE. Thank you for this opportunity to comment. BBW~mm -. I IIII I I II I I I I I I I I I I I I I II REPLY TO ... ATTENTION OF: NPACO-RF-P Beaufort Sea 167 DEPARTMENT Of THE ARMY P.O. BOX 700~ .~. 'k,, L '" ANCHORAGE. ALASKA 99510 JAN 1 .~.~ 1981 R. K. Riddle, District Landman Exxon Company, U.S.A. Rouch 6~01 Anchorage, Alaska 99~02 Dear Mr. Riddle: Reference:. 071-OYD-1-800441 Gravel Island OCS-Y O191; Well No. 1 Beaufort Sea, Alaska Your application dated 2 December 1980 for a Department of the. A~my permit for the referenced work has been received. It has been assigned No. 071-OYD-1-800441, which should be referred to in all future correspondence with this office. We have received your signed. Certification of Consistency and will soon issue a 30-day public notice .to solicit comments in regard to your proposed work. Objections received in response to the notice will be forwarded to you for resolution or rebuttal. The Corps of Enqineers is authorized to issue permits at the District level in those cas~s in which all objections have been resolved to the satisfaction of the District Engineer. Since unresolved objections to your proposed work could resUlt in delay or denial of the requested permit, it is to your advantage to devote every effort toward resolving any objections received. For your information, a processing fee is required should a Department of the Army permit be issued. Since the planned or ultimate purpose of your proposed project is commercial/industrial in nature, the fee will be $100. You will be notified as to the time for submittal of the fee. If you have questions, please contact this Branch at (907) 279-4123 and ask for CRT Mahoney. Sincerely, ... ~e~,E~e~uA~RaU~oHry Functions Branch " DEPARTMENT OF TH RMY ALASKA DISTRICT. CORPS OF ENGINEERS R Er E i v: ..-,'--. " ' ""/ ANCHORAGE. ALASKA 99510 REGULATORY FUNCTIONS BRANCH '~ ., :~.~ (907) 279-4123 ATTENTION OF: -RF-P R E C E .,J^. PUBliC NOTICE' NPAC0 No. 071-0YD-1-800441 Operations Manager An appl$cat~on has been ~eceSved in this office f~om Exxon ~mpany, U.S.A., Pouch f~l, Anchorage, Alaska 99502, ~o~ a Department of the Azmy pemit un~ Section 10 of the R~ve~ and ~bo~ ~t of 1899 (30 Stat. 1151; 3~ U.S.C. 40~) to construct a 480-foot-d~amete~ g~avel island d~11 sLte ~o~ Exxon's 0C~Y 0191, Well No. i on the ~te~ Continental ~elf in the Beaufort Sea app~oxLmately 15 tulles northeast of P~udhoe Bay~ Alaska, as shown on the plan attached to this not,ce. · . The applicant proposes to place 301,000 cubic yards of gravel to construct ... '' . the island in water 18' deep. The island would stand 11' above mean . .....,: ,.. ...higher high water, and a 5-foot-high berm around the perimeter of the ....~..":'.. island would give added protection against wave action and storm surges. :'I' I :' ';' The sides of the island would be sloped 3H:iV, and sandbags would be "'.:.... '.::'::~.,',: . :.' ..... placed as erosion' protection. Gravel for the island would be hauled in ",.. trucks over ice roads from an onshore mine located in Section 1' & 12, ,..:.ix:...:...,..'"..':' TiON, R15E, U.H. · ~'.:.:'.:?!'.:,..;;..... .... .,...., The island would be used to conduct exploratory drilling in Beechey Point :;. Block No. 654, an area under U.S. Oil and Gas Lease. Drilling will not ';"~'';;'.~'' ''I ': · 'begin unitl an Environmental Assessment is prepared and the drilling plan .,.?..:.,... ...... approved by the Alaska Region, Conservation Division, U.S. Geological .';"..' Survey, Department of the Interior (DOI) Section 4(f) [Renumbered to Section 4(e) in the 1978 Amendments] of the Outer Continental Shelf Lands Act of 1953 (67 Stat. 463; 43 U.S.C'. 1333(f)) extended the authority .of the Secretary of the Army to issue permits under. Section 10 of the River and Harbor Act of 1899 fo..artificial islands and fixed structures located on the Outer Continental Shelf. Where the islands or structures are to be constructed on'lands which are under mineral lease from the Bureau of rand Hanagement, DOI, that agency, in cooperation with other Federal agencies, fully evaluates the potential effect of the leasing program on the total environment. Accordingly, 'the decision whether to issue a permit to Exxon for the work described in this PUblic Notice will be limited to an evaluation of the impact of the proposed work on navigation and national security. The Division of Policy Development and Planning, State of Alaska, is reviewing this Work for consistency with the approved Alaska Coastal.. Manangement Program. NPACO-RF-P Beaufort Sea 167 Preliminary determinations indicate the issuance of this permit is a major federal action not significantly affecting the human environment, and an environmental impact statement is not required. The National Register of Historic Places and the latest published version of the Federal Register have been consulted in regard to the proposed activity. Consultation of the National Register constitutes the extent of cultural resource investigations by the District Engineer, and he is otherwise unaware of the presence of such resources. Preliminary determinations indicate that the proposed activity will not affect an endangered species or their critical habitat designated as endangered or threatened pursuant to the Endangered Species Act of 1973 (87 Stat. 884). Formal consultation pursuant to Section 7 of the Act with the Department of Interior or Commerce is not required for this proposed activity. Written statements received in this office on or before 2 February 1981 will become a part of the record and will be considered in the determina- tion. ~ny response to this notice should be mailed to the Alaska District~ Corps of Engineers, ATTN: Regulatory Functions Branch, R.O. Box .7002, Anchorage, Alaska 99510. If further information is desired concerning this notice, contact CPT Mahoney at (907) 752-4942 or (907) 279-4123. FOR THE DISTRICT ENGINEER: '3 Incl 1. Plan 2. ACMP Notice .3. 401 Notice DAVID L. ROBBINS Chief, Construction/Operations Division ~.' PROTECTION _ P ,L____A, ~ I00~ 200';: SCA'LE IN.FEET" "--'-----I. APPRO~ ~;O1',0OO~ CU.-' YDSt 0F; GRAVEL: REOI~I'RED~ FOFP FIE. b,.. . , ~ - ._Ii LAY..':'0.e~ ~)' .. ,..~TB£AUFORT_.. SEA .. . ~ :~I NEAR MOUTH ~ ' EOC~I~ · ~ ~AVANIRKTOK . . . .., ~ j.. . · ~.'.~ . . : ..%-.' -.. 2.: .. . · . . ,,'.'~. . · .,~ :.~- . · ' .[~ .. . ~2-~.. ~ICI~t'TY MAP .. . ~ __P__ ~ ' ~ ~ . , ... ~ ...... .... ',. 9CAEE IMM~LES ~RO~ US~ Q~D $~ET ' -. '. . . ',. '. ~- . .i · . '' . ' ._,.', '~ ~.. .. , ., . . . . . ~eO~ __.~ .,, .,... , : :,~ _,, ....... ,, , ~ . ~ - t · / ~..'..'.. . ,~, .. ,~,. . . , ., SECTilOH '"A-A · . , · .. PROPOSED GRAVEL ISLAND .. IN BEAUFORT SEA NEAR M'~Oum' I~i~ . , SAGAVANIRI<TO{( RIVER; ".. ' '' . ~..:.ECHEY POI.NT BLOCK 6.5.4 '"'. ' .,, APPLICATION BY: EX3~ON CO.,U.S.A. · SHEET I OF I' DATE :.'I I-21"80 '. · ,. '..PURPOSE= PROVIDE DRILL SITE FOB , ; EXPLORATORY WELL ..' .~..... EXXON OCS--Y 0191 -. WELL NO. I · · .. . . i' · · '.DATUM; MEAN SEA LEVEL . :~... .... . ,.;. .. . .' NORIZOHTAI. O VERTICAl. 0 6' 12' 18' ~CALE IN ~'EET REPLY TO ATTENTION OF: NRACO-RF-R ~aufort Sea 167 DEPARTMENT OF TI( 'ArmY ALASKA DISTRICT. CORPS OF ENGINEERS P.O. BOX 7002 ANCHORAGE, ALASKA 99510 P,.Eb'-~L~TORY :FUNCTIONS B~,NCH (907) 279-4123 20anuary 1981 PUBliC NOTICE NPAC0 No. 071-0YD-1-800441 An application has been received in this office from Exxon Company, U.S.A., Pouch 6601, Anchorage, Alaska 99502, for a Department of the Army permit under Section l0 of the River and Harbor Act of 1899 (30 Stat. llS1; 33 U.S.C. 403) to construct a 480-foot-diameter gravel island drill site for Exxon's OCS-Y O191, Well No. i on the Outer Continental Shelf in the Beaufort Sea approximately 15 miles northeast of Rrudhoe Bay, Alaska, as shown on the plan attached to this notice. The applicant proposes to place 301,000 cubic yards of gravel to construct the island in water 18' deep. The island would stand ll' above mean higher high water, and a 5-foot-high berm around the perimeter of the island would give added protection against wave action and storm surges. The sides of the island would be sloped 3H:iV, and sandbags would be placed as erosion protection. Gravel for the island would be hauled in trucks over ice roads from an onshore'mine located in Section i & 12, TION, R15E, U.M. The island would be used to conduct exploratory drilling in Beechey Point Block No. 6~, an area under U.S. Oil and Gas Lease. Drilling will not begin unitl an Environmental Assessment is prepared and the drilling plan approved by the Alaska Region, Conservation Division, U.S. Geological Survey, Department of the Interior (DOI). ., Section 4(f) [Renumbered to Section 4(e) in the 1978. Amendments] of the Outer Continental Shelf Lands Act of 1953 (67 Stat. 463; 43 U.S.C. 1333(f)) extended the authority of the Secretary of the Army to issue permits under Section 10 of the River and Harbor Act of 1899 to artificial islands and fixed structures located on the Outer 'Continental Shelf. Where the islands or structures are to be constructed on lands which are under mineral lease from the Bureau of Land Management, DOI, that agency, in cooperation with other. Federal agencies, fully evaluates the potential effect of the leasing program on the total environment. Accordingly, the decision whether to issue a 'permit to Exxon for the .work described, in" this PUblic Notice will be limited to an evaluation of the impact' of the proposed work on navigation and national security. The Division of Policy Development and Planning, State of Alaska, is reviewing this work for consistency with the approved Alaska Coastal ~anangement Program. I EC 'IVED JAN 1 4 1981 Alaska Oil & Gas Cons. Commission ' Anchorage NPACO-RF-P Beaufort Sea 167 Preliminary determinations indicate the issuance of this permit is a major federal action not significantly affecting the human environment, and an environmental impact statement is not required. The National Register of Historic Rlaces and the latest published version of the Federal Register have been consulted in regard to the proposed activity. Consultation of the National Register constitutes the extent of cultural resource investigations by the District Engineer, and he is otherwise unaware of the presence of such resources. Preliminary determinations indicate that the proposed activity will not affect an endangered species or their critical habitat designated as endangered or threatened pursuant to the Endangered Species Act of 1973 (87 Stat. 884). Formal consultation pursuant to Section 7 of the Act with the Department of Interior or Commerce is .not required for this proposed activity. Written statements received in this office on or before 2 February 1981 will become a part of the record and will be considered in the determina- tion. Any response to this notice should be mailed to the Alaska District, CorPs'of Engineers, ATTN: Regulatory Functions Branch, P.O. Box 7002, Anchorage, Alaska ¢¢510. If further 'information is' desired concerning this notice, contact CRT Mahoney at (907) 752-4942 or (907) 279-4123. 'FOR THE DISTRICT ENGINEER:~ 3 Incl 1. Plan 2. ACMP Notice 3. 401 Notice . DAVID L'. ROBBINS Chief, Construction/Operations Division LO C,~'T I ON. SEA MOUTH OF' RKTOK R. IPE/~N~ C~ I00~ 200" ' ~ ' I. ,&PPi!IO~ :~O1',OOO{ CU: YDS'. OF' GRAVEl-' REOU. I'RED~ FOR~ FI.kL. ' 'I~IEECHE~ POINT · 3 o, ~ o,o, o, ..~.;.'~ o .'~,'~'~.o o. ~ :3 '" - 'i, ~. ~., -..-..~' :;'IL 0. ~., ~./I~. :,' ~. "' - .~.~.~..~ " . · = . · PUR~SE~ PROVIDE DRILL SITE fOR ' . · t~ORIZOHTAL '' '' , ... t · ' EXPLORATORY ~EI.L [,.~~~ .'. .~,~ ...... ~ ....... ' "." J.'. Exxo~ oCS-~ 0~ ' ~ ' ~' ~0,' ~~..~~~~. VERTICAL , :'." . WELL uo ~, ' ~,.~ ~' PROPOSED GRAVEL ISLAND .!..... ··. .' ._,~,~..~ ~ · . . . . " ' ' 1~ G' 12 1~ Z4~ : · '. . i I"'"'" .' ' ' '. l',~av.~.~o~ ~v~m ' ': ~ '. ' .'..;.' . .' -..~ ' · / ~,=~ ,,~,' ~,~.,,-~,~,o ...~ GI-A3LH O .. ~7~[Z~ AY S. HAM/~,C)HD, Governor DIVISION O1: POLICY DEVELOPMENT AND PLANNING / ~ouch AD- Juneau 99811 STATE. OF ALASKA DIVISION OF POLICY DEVELOPMENT AND PLANNING Notice of Application for Certificat~.or. of Consistency with the Alaska Coastal Management Program Notice is hereby given that a request is being filed with the Division' of Policy Development and Planning for concurrence, as provided in Section 307 (c)(3) of the Coastal Zone Management Act of 1972, as amended [P.L. 94-370; 90 Stat. 1013; 16 U.S.C. 1456 (c)(3)], that the project described in the Corps of Engineers PublJ. c Notice No. 071-0YD-1-8004gl will comply w~th the Alaska Coastal Management Program and that the ' project will be'conducted in a manner consistent with that program. Any person desiring to present views on cons~derations pertaining to the project's complJ, ance or consistency with the Alaska Coastal Management Program may do so by providing his views in writing to the State Clear- inghouse, Division of Policy Development and Planning, Office. of the Governor, Pouch AD, Juneau, Alaska 99811, within 20 days of publication of this notice. incl 2 :4 465-2601 / POUCH 0 - JUitt~All ~$~11 NOTICE OF APPLICATION FOR STATE WATER QUALITY CERTIFICATION Any applican't for a Federal license or permit to conduct any activity which may result in any discharge into the navigable waters must first .. apply for and obtain certification from the Alaska Depar'~ment of 'Envirol~ental Conservation that any such discharge will comply with the Clean Water Act of 1977 (PL 95-217), the Alaska Water Quality Standards and other applicable State laws. By Agreement between the U.S. Army Corps of Engineers and the Alaska Department of Environmental Conservation application for a Department of the Army Permit may also serve as applica- tion for State Water Quality Certification when such certification is necessary. Notice .is hereby given that the application for a Department of the Army Permit described in the Corps of Engineers Public Notice No. 071-0¥D-1-800~41 also serves as application for State Water Quality Certification from .the Alaska Department of Environmental Conservation, as provided in Section 401 of the Clean Water Act of 1977 (PL 95-217).. The Department will review the proposed activity to insure that any dis-. charge to waters of the United States resulting from the referenced pro- ject will comply with the Clean Water Act of 1977 (PL 95-217) the Alaska Water Quality Standards.and other applicable State laws. · Any person desiring to comment on the water quality impacts of the pro- posed project may do so by.writing to: .. Alaska Depar'~nent of Environmental Conservation Northern Regional office P.0...BOx 1601 Fairbanks, Alaska 99701 Telephone: 452-1714 within 30 days of publication of this notice. 'Incl ~ -.- COMPANY, U.S.A. POST OFFICE BOX 4279 - HOUSTON, TEXAS 77001 EXPLORATION DE~PARTM ENT GULF/ATLANTIC DIVISION ALASKA/PACIFIC DIVISION tl.R. WARNAC:K PERMJTTING December 19, Expl oratory OCS-Y 0189~'0190, 0191, 0192, .0193 0191 Well No. 1 Beaufort Sea, Alaska ~ ,,,, .';. !....., .q · '"'*'::":'!!~::":~;~'~"'";':'~' Mr. Rodney A. Smith Deputy Conservation Manager "Offshore Operations ].'United States Geological Survey 'Post Office Box 259 ge, Alaska 99501 "'? S:,' :', :.'. Dear Mr. Smith: ,~,~ · "'ched are duplicate copies of the Exploratory Plan including the Contingency an for the subject lease areas. This Plan is submitted for. your review for eteness, by and for Exxon as Operator and its joint lessees, Union and .:'Also attached are confidential and public information copies of an appli- tion for Permit to Drill with certification of consistency with the Alaska management program for the initial well proposed in this Plan. The Upporting Environmental Report (Drlaft) was submitted to you December' 4, 1980. hould you have.any questions, please call Mr. Otto C. Rath, (713) 999-9154. ~., I "'' ' Sincerely, '. - Worthy R. Warnack A DtVISION OF EXXON CORPORATION ,../- ,0 L'"AWN_ J' K. V.ICINIT¥ PLAT OCS-.YOI91 BLOCK 654. BEAUFORT .SEA, ALASKA j ENGR SECTION REVISEO ~ APPROVED Ilia I r i iiii i ~-- i i EXXON COMPANY, PRODUCTION D£P~RTM£NT WESTERN DIVISION SCALE GRAPHIC JOB'~0 ;IL'r NC~ ,~,E. 12-19- 80 WA-'548 A' · Y= 7,809,600 meters ' ' r '"'"i (Y=25,621,996') I I. x= ~,,.~O,B4B i I I ~ot. = 70°2~1~j'' ' '~ I ~/'~ / Long.--147055'29.'5" APPLICATION FOR WELL N° t OCS -YOI91 ', ( Y= 25,606,248') Y= 7,804,800 meters BLOCK 654 GRID NOTE: Lease lines are in accordance with the Bureau of Land Mgmt. Outer Continental Shelf Official Protraction DiagramN-° NR06-03 dated October 19,1979. Bou. ndaries are defined in X and Y Coordinates of the Universal Transverse Mercator Grid System, Zone ~. I000 0 I000 2000 METERS : EXXON COMPANY, U.S.A. LEASE PLAT of OCS Y-OIgl (D~V~s~oNOF EXXON CORPORATION) BLOCK 654 BEECHY PT I ' BEAUFORT SEA, ALASKA I PRODUCTIONw.ESTERN DEPARTMENTDiviSiON ' Form 9-:~1 c SUBMIT II~ CATE* (May 1963) (Other instructions on · UN ITED STATES reverse s,de) DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Form approved. Budget Bureau No. 42-111425. LEASE DESIGNATION AND SERIAL NO. OCS-Y 0191 APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK ~fl. TYPE OF WORK DRILL J'~ DEEPEN [-'] PLUG BACK [-I b. T~PE OF WELL SINGLE [~ MULTIPLED O'LwE,.L I-'1 WE'-LGAR I--I OTHER Exploratory -.ONE ~ONE NAME OF OPERATOR Exxon Corporat ion ADDRESS OF OPERATOR P. O. Box #279 #22#3, HouSton, Texas 77001 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.*) Atsuri'aee ~.~_~_2,.1 FNL &_6_67.' .... FWL Beechy Pt Bol,;ock 654 :... ,,=;_;==: ~ . __ Lat 70x"~n-i'i":~f~'"N; Long 1;7.,3'29.15"W X=l,530,g4g'; Y=25,620,154! DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* Approximately 7 mil~s NNE of Point Heald 6. IF INDIAN, ALLO'FTRE OR TRIBE NAME -- 7. UNIT AGREEMENT HAME -- S. F~RM OR LEASE NAME -- 9. WELL NO. 1 10. FIELD AND POOL, OR WLLDCAT Wildcat 11. SEC., T., R., M., OR BLK. AND SURVEY OR AREA Block 654 Stefansson Sound~ Beaufort Sea 12. COUNTY OR I'ARI-qHI 13. STATE OffshoreJ Alaska 18. 21. DISTANCE FROM PROPOSED* LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. 6 6 7 (Also to nearest drlg. unit line. if any) DISTANCE FROM I'ROPOSED LOCATION* TO NEAREST WELL, DRILI,ING. COMPLETED, OR .PUED PO.. O~ TH,S =asE... F i r s t We I I 16. NO. OF ACRES IN LEASE ~9. PROPOSED DE~H 12,500 ELEVATIONS (Show whether DF, RT, GR, etc.) Water Depth=IR'; RKB=+40';'Pad Level=+ll' 17.NO. OF ACRES ASSIGNED TO THIS WELL 20. ROTARY OR CABLE TOOLS Arctic Alaska Rig 4 22. &PPROT. DATE . 23. PROPOSED CASING AND CEMENTING PROGRAM SIZEOF HOLE SIRSOF CASINO WEIGHT PER FOOT . SETTING DEPTH , QUANTITY OF CEMENT .. · . 'Please see attachments for: Wellbore & Casing Design Sketch, Proposed Casing & Cementing Program, Casing Design Criteria and Safety Factors, Mud. Program and Minimum Quantities, Blow- Out Prevention and Stack Test Program, Operational Procedure and Schematic Diagrams for a Four-BOP Stack and Diverter System, and Certification of .Consistency with Alaska State Coastal .Management Program. The following additional documents are referenced for this Well and were submitted separately.~ Exploration Plan with Contingency' Plans and the Environmental Report for Leases OCS-Y 0189, 0190, 0192, and 0193. Note that a list of two (2) departures are .requested relative to the proposed Arctic OCS Orders Nos. I & 2 concerning marking of equipment and diverter system, control valves. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen or plug back, give data on present productive zone and proposed new productive zone. If proposal is to drill or deepeu directionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowou: preventer program, if any. ....... 2.4. Exploration Supervisor DATE 12-19-g0 (This space for Federal or State office use) PER.MIT NO. APPROVED BY CONDITIONS OF APPROVAL, IF ANY : APPROVAL DATE. TITLE DATE USGS CONFIDENTIAL e: Certification of Consistency with the Alaska Coastal Management Program I certify that, to the best of my knowledge and belief, the proposed activity described in this U. S. Geological Survey Application for Permit to Drill complies with the approved' Alaska Coastal Management Program and will be conducted in a manner consistent with such programs. Signature of Applicant DecemSer 19, 1~t80 Date REQUEST FOR APPROVAL OF DEPARTURES FROM ARCTIC OCS ORDERS NO. 1 AND 2 BEAUFORT SEA, BEECHEY POINT AREA OCS-Y No. O1 91 Wel 1 No. 1 Order i I. Section 5, Marking of Equipment, requires in part that "whenever prac- ticable, all materials, equipment, tools, containers, and items used on the OCS are to be properly color-coded, stamped, or labeled with the owner's identification prior to actual use..." Exxon requests a departure from this requirement for marking of equipment inasmuch as activities for this proposed well will be conducted in shallow water or over ice roads after freezeup. Transportation in the relatively calm open water season is highly unlikely to result in the loss of equipment overboard, and any lost material could easily be recovered. Further, there is no known commercial fishing in these waters. Transportation during freezeup will be by conventional land transportation methods. order 2 II. Section 5.4.1, Drilling Operations from Bottom-Supported Rigs, states in part, "The diverter system shall be equipped with remote-control valves in the main and diverter flow lines that can be operated from the control panel prior to shutting in the well." Exxon requests a departure from the above to provide for a remote- control valve in the main diverter line, but with two manually operated valves in the branch lines that control the direCtion of flow depending on wind direction. A diverter sketch and operating procedure are included with the permit request showing the desired arrangement. HLD/TLP 'cf 12/17/80 BEAUFORT SEA, BEECHEY POINT AREA OCS-Y O191 WELL NO. 1 WELLBORE & CASING DESIGN SKETCH 30" 1" Wt Gr B @ _+158' RKB (98' BML) Est. permafrost depth 980' RKB (920' BML) 20" 106.5#/ft K-55 Butt Conductor @ +-lO00' RKB (940' BML) 13-3/8" 72#/ft L-80 Butt Surface Casing @ +-2800' RKB (2740' BML) Waste fluids, drilling mud, and hydrocarbon injection zone. TOC @ approximately 7000' RKB Note' Prior to well abandonment, the injection annulus will be plugged with cement and the casing filled with a non-freezing fluid. Top of liner +-lO,O00' RKB (9940' BML). 9-5/8" 47#/ft Soo-95 LTC @ +-10,500' RKB (10,440' BML) 7" 32#/ft N-80 LTC @ _+12,500' RKB (12,440' BML) " 0 (3.) I-- ~0 0 ~ ~ ~ 0'~ 0 ~ 0 0 0 ~ 0 ~ ~ ~ ~ 0 ~ 0 ~ 0 0 0 .., ~ i I 0 I . , ~ ,. ~m,~ ., . , ,, el .1~ ~,...0 c.. o (Y~,.C~ I.L') i--..~ i.-- i.... ~.. I I I C) e. BEAUFORT SEA, BEECHEY POINT AREA OCS-Y 0191 Well No. 1 CASING DESIGN CRITERIA AND SAFETY FACTORS (See Attached Wellbore Sketch) SURFACE - 13-3/8" @ 2800' · Burst - Considers gas gradient to the surface causing lost returns at the shoe assuming maximum expected leakoff gradient. External fluid weight 9.3 ppg. Maximum Surface Pressure (MSP) MSP = (Max. shoe leakoff gradient -gas gradient) casing depth = (13.9 x .052 - 0.10) 2800' : 1,744 psi · Permafrost Freezeback - ConSiders maximum external collapse gradient of 1.44 psi/ft and minimum internal fluid weight of 9.0 ppg. Maximum Collapse Pressure (MCP) MCP = (Max. external gradient -min. fluid gradient) max. permafrost depth : (1.44 - 9.0 x .052) 1000' : 972 psi · Permafrost Thaw Subsidence - 13-3/8" 72#½ft L-80 Butt post yield strain performance exceeds.the requirements based on worst case well spacing. · Safety Facto'rs Burst 1.312 Collapse 1.00 Tension 1.50 ,,, ,' PROTECTIVE/PRODUCTION 9-5/8 @ 10,500' TD · Burst-Protective. - Considers gas kick of sufficient intensity and volume to cause lost returns assuming maximum expected, leakoff gradient and casing filled with water. External fluid weight 9.0 ppg. Maximum Surface Pressure (MSP) MSP = (max. shoe leakoff gradient -water gradient) casing TD' = (15.1 x .052 - 8.33 x .052) 10,500' = 3,696 psi · Burst-Production - Considers shut-in gas well surface pressure on kill weight packer fluid and external fluid weight of 9.0 ppg. Maximum Surface Pressure (MSP) MSP = (max. est. pore pressure gradient - gas gradient) well-TD = (9.6 x .052 - 0.18) 12,500' = 3,990 psi CASING DESIGN CRITERIA AND SAFETY FACTORS (Continued) · Collapse - Production - Considers surface pressure = 0 psi, internal fluid weight 0 ppg, and external fluid weight 10.0 ppg. Maximum Collapse Pressure (MCP) MCP = (External fluid gradient - internal fluid gradient) casing depth - surface pressure : (10.0 x .052 - O) 10,500' - 0 = 5460 psi · Safety Factors - Protective and Production Burst 1.312 Collapse 1.125 Tension 1.50 PRODUCTION LINER 7" @ 10,000 - 12,500' TD · Burst.- Same as for protective/production casing. , · Collapse - Considers surface pressure : 0 psi, internal fluid weight : 0 ppg, and external fluid weight = 10.0 ppg. Maximum Collapse Pressure (MCP) MCP = (External fluid gradient - ~nternal~ fluid gradient) casing TVD - surface pressure ~ : (10.0 x .052 - O) 12,500 - 0 : 6,500 'psi · Safety Factors Burst 1.3i2 Collapse 1.125 Tension 1.50 r LAJ MUD PROGRAM PERMAFROST DRILLING OCS-Y 0191 Well No. i Permafrost is expected to be encountered to approximately 980 feet RKB in the subject well. The Shallow Hazards Survey conducted at the location does not indicate the presence of any shallow hazards, including any indications of gas hydrates. The well does not fall within the area of shallow bio§enic gas described in the USGS Open-file report 80-809. Also, none of the wells near this area are known to have encountered gas hydrates. Exxon's Alaska State Duck Island Unit Well No. 1 located just outside this area to the south had permafrost to approximately. 1500 feet RKB but did not encounter §as hydrates. It is planned to carefully monitor mud temperatures and gas content while drilling surface hole. Amud logging unit will be in operation from the mudlineto TD, and a flow diverter will be installed on both the 30-inch and 20-inch casing. If indi- cations of gas hydrates are detected, mud temperatures will be controlled by cold water additions to reduce melting and penetration rate will be limited to reduce gas concentrations. in the mud. The planned surface casing d~pth of 2800 feet is expected to cover all potential gas hydrate zones. HLD:cf 12/17/80 er,., · · r'-- ~ ~ ~0 ~ E ~ E ~ ~ E ~ ~ ~ ~'~ ~ 0 E -- ~ ~ ~ ~ ~ ~ ,'~* ~ E ~ o O O CD O Fi gure 3 ARRANGEMENT OF A FOUR-BOP STACK BUTTERFLY VALVE TRIP TANK --~ $'* LINE OR (~) i I LARGER ' f-ANNULAR 1 L mop j ~ ! 1 I TRIP TANK KILL ~ [RAM BOP ,I LINE. ~ ~ ~ - ! ,J .~ _ FLOW LINE BUTTERFLY VALVE CHOKE MANIFOLD .COHPO~ SPECIFICATIONS 1.' Flamged plug or, gate valve - 2" size - same working pressure as 'A' section. 2. Screwed tapped bullplug with needle valve and pressure gauge. 3. Flanged plug or gate valve - 2" size - same working pressure as top of 'B' section. &. Flamged tee with pressure gauge amd/or commection to casing pressure gauge on hydraulic choke control panel. 5. Flanged plug valve - 2" minimum size - MOWCO "Lo Torc" or equivalent. 6. Fla~ged hydraulically c~ntrolled gate valve. 7. Flanged plug valve - 4" minimum size - HOWCO "Lo Torc" or equivalent. Flowline from spool to choke manifold - 4" minimum size - all connections must be' flanged or welded. 9. Connection at top of annular preventer must be equipped with an API ring groove, API ring gasket, and API companion flange on bell mipple. Ail flange studs must be installed. 10. The ID of the bell nipple and companion flange must mot be less than the ID of the BOP stack. 11. Spool-24" height with 2 flanged side outlets - 4" and 2" minimum ID. BEAUFORT SEA, BEECHEY POINT AREA OCS-Y 0191 Well No. 1 Figure 2 __ . mi i . m i ii ii i i i i i i i i_i !1 m ii ii o. %RIP TANK ~ DIVERTER SYSTEM For Use on 30" Structural and 20" Conductor Casin9 ,= ' ~ SHAKER BUTTERFLY VALVE TRIP TANK 20" HYDRIL MSP 2000 0" HYDRAULIC VALVE 20" 2000 PSI SPOOL ~(~ lO" lO" VENT 20I' MANUAL VALVE. WELLHEAD OR ~/ 20" CASING (30" not shown) VENT OPERATING PROCEDURE Diverter system has one-lO" hydraulically operated main valve and two-lO" manually operated branch valves. Diverter and main valve controls are interlocked. The main v. alve is normally closed and the diverter and branch valves are normally open while drilling. In a Well Control Situation. 1. Close Hydril diverter which automatically opens main valve 2. Close upwind branch valve BEAUFORT SEA, BEECHEY POINT AREA OCS-Y 0191 Well No. i · Figure 1 · COMPANY, UiS. A. POUCH 6601 · ANCHORAGE. ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION Re: December 9, 1980 U. S. Army Corps of Engineers Permit to Construct Gravel Fill Drill Site OCS-Y 0191, Well No. 1 Lat. 70° 23' 11.15" Long. 147° 53' 29.15" Beaufort Sea, Alaska . : Colonel Lee R. Nunn District Engineer U. S. Army Corps of Engineers ....' P.O. Box 7002 ..':.... Anchorage, Alaska 99510 · , ..,',.,.... , .."' Dear Colonel Nunn: . ., .,.. .,, .,, "...' :".'.i'..;i...:'~i'..Exxon Company, U.S.A., A Division of Exxon Corporation, herein ..".'".!ii~.?':.'..'submits an application for a Department of the Army permit under "i".!..'.':'..".:'..}i:..'.':: Section 10 of the River and Harbor' Act o~ 1899 and Section 4 F . ..'.".....:.7'" of the Outer Continental Shelf Lands AcC of 1953 (Renumbered to ..'"".":':i:::!i:!?'!i.'.;.'i'?'".'.'!""'Section 4 E in the 1978 Amendments to said act), to construct a ...i?.ii'.:'.%.'i.'~...::i.'.'..gravel fill artificial island in the Beaufort Sea, for the conduct .'i:'::i"'"~'":'.L.:'i'."~:' of drilling operations upon the subject U.S Oil and Gas Lease. .......~..:........=..:...;:.... ..... .In due course we shall also be filing ali necessary applications' · ~:~i:~;:i.~..~.: ...... .~'~':"~:'.to conduct Such drilling operations with the Alaska Region, Conservation DiVision, U. S. Geological Survey. .. Should there be any 'remaining questions or need for additional information, please telephone the undersigned at 263-3714 or Mr. O. C. Rath in Houston at 713-999r9154. RECEIVED JAN 2 0 1981 ~.laska Oil & Gas Cons. Commission Anchorage .RKR: et ." enclosures c w/encl.: Very truly yours, EPA, Region Ten - Attn: Mr. Danford G. Bodien, P. E. Chief Water Permits Section bc w/encl.: A. L. Hermann, A. V. Lockett, O. C. Rath, M. F. Smith, W. M. Selvidge, W. J. Whaley A DIVISION OF EXXON CORPORATION · . . .... I I ii iii - · iiiii iii i .... i, i 10. Date activity is proposed to ~e~ce. Following freezeup in the winter of 1980-81. Date activity is expected to be completed Within thr~e months after commencement. 11. Is any portion of the activity for which authorization is sought now complete? ~ YES ['~ NO If answer is "Yes" give reasons in the remark section. Month and year the activity was completed · Indicate the existing work on the drawings. 12, List all approvals or certifications required by other federal· interstate, state or local agencies for any structures· construc- tion, discharges, deposits or other activities described in this application, Issuing Agency Type Approval Identi ficatio~ No, Date of Application Date of Approval USGS Permit to - To Be Submitted Drill USGS Exploratory Plan - To Be Submitted ~ with Environmental Report 1:3, Has any agency denied approval for the activity described herein or for any activity directly related to the activity 'descri bed herein? Yes ~'1 No' (If "Yes" explain in remarks) 14. Remarks or a~itional information. Certification of Consistency with the Alaska Coastal Management Program I certify that, to the best of my knowledge and belief, the proposed activity described in 'the subject Department of the' Army application for permit complies with the approved Alaska Coastal Management Program and will be conducted in a manner consistent w~-th-Tsuch programs. ' · Signature -/~'' -- '"'- Date 15. Application. is hereby made for a permit or permits to authorize the activities described herein, I certify that I am familiar with the information contained in this application, and that to the-be~}"'of'~ny knowledge and belief such information is true, complete, and accurate. I further certify that I possess the authority to. undertake thF'l~Op(is~I activities, Signature of Applicant ~r .A~th0rized Agent The application must be signed I~y the applicant; however, it may be signed by a duly authorized agent (named in Item 5) if this form is accompanied by a statement by the applicant designating the agent and agreeing to furnish upon request, supplemental information in support of the application. 18 U. S. C. Section 1001 provides that: Whoever, in any manner within the jurisdiction of any department or agency of 11~e United States knowingly and willfully falsifies, conceals, or covers up by any trick, scheme, or device a material fact or makes any false, fictitious or fraudulent statements or representations o..' makes or uses any false writing or document knowing same to contain any false fictitious or fraudulent 'statement or entW, shall be fined not more than $10,000 or imprisioned not more than five years, or both%' "'Do not send a permit processing fee with this application, The appropriate fee will be assessed when a permit is..issued... 10. Date activity is proposed to c,o~e~ce. Following freezeup in the winter of 1980-81. Date activity is expected to be completed Within thrAe months after commencement. 11. Is any' portion of the activity for which authorization is sought now compl'ete? I---I YES I~ NO If answer is "Yes" give reasons in the remark section, Month and year the activity was completed · Indicate the existing work on the drawings. 12. List all approvals or certifications required by other federal, interstate, state or local agencies for any structures, construc- tion, discharges, deposits or other activities described in this application, Issuing Agency Type Approval Identification No, Date of Application Date of Approval USGS Permit to - Drill USGS Exploratory Plan - ~ with Environmental Report To Be Submitted To Be Submitted 13. Has any agency denied approval for the activity described herein or for any activity directly related to the activity 'described herein? Yes I-X-] No (If "Yes" explain in remarks) 14, Remarks or a~itional information, 'Certification of Consistency with the Alaska Coastal Management Program I certify that, 6o the best of my knowle~ge and belief, the proposed activity described in the subject Department of the' Army application for permit complies with the approved Alaska Coastal Management Program and will be conducted in a manner consistent w~i.-th-~such programs· ' · · Signature -'///F ....... Date 15. Application is hereby made for a permit or permits to authorize the activities described herein, I certify that I am familiar with the information contained in this application, and that to the-bes'~""~f';ny knowledge and belief such information is true, complete, and accurate. I further certify that I possess the authority _to undertake th.e/l~fopq, s~l activities, Signature of Applicant or.A~thorized Agent The application must be signed t~/ the applicant; however, it may be signed by a duly authorized agent (named in Item 5) if this form is accompanied by a statement by the applicant designating the .agent and agreeing to furnish upon request, supplemental information in support of the application. 18 U. S. C. Section 100.1 provides that: Whoever, in any manner within the jurisdictio~t of any department or agency of The United States knowingly and willfully falsifies, conceals, or covers up by any trick, scheme, or device a material fact or makes any false, fictitious or fraudulent statements or representations o..' makes or uses any false writing or document knowing same to contain any false fictitious or fraudulent statement or entry, shall be fined not more than $10,000 or imprisioned not more than five years, or both', 'Do not send a permit processing fee with this application, The appropriate fee will be assessed whert a permit is.issued, . i LAT. 70~ 2~' 11.15"'~ BEAUFORT SEA LOCATION NEAR MOUTH OF SAGAVANIRKTOK R. VICINITY MAP 0 I ::' :3 4 · I ! I ! I i, SCALE IN MILES FROM: USGS, QUAD SHEET BEECHEY POINT (B-2) NOTES: .pLAN 0 I00' 200' SCALE IN FEET ~ .I. APPROX. :301,000 CU. YDS. OF GRAVEL REQUIRED FOR FILL. I_ 'I SLOPE PROTECTION 5' BERM i. 480' I I j C) 0 0° o o oo0o o o°joOo -'-I~ _o o°oo ooo o- c'o o°o°o,~ c) o o OlO o o_ o_ O°o. ooooo ~ O O q" O O 0-4) ' -- O O ~' O "' -- --t.,~O O O~) O O O -- O L'~ c~ Oo° o o ~) oo 0 o o c, '~_o o ~I' C) o ., o '1'o 00 _°o o o '"_ o %oo°oO_°0 o OoOo. oO_'-o~oLOo80-o 01oo o° °o°°oo ~,.,%" _~_ . .~ u 0 0 0 M 0 K..d ~ O ~ 0 0 0 o o-o0o°o o" o o oo o ou° '"o''' or-' o° .- ..1o..o ~ c:)Oc) oo o _ _o O O o o _o_ c)o o _ o _ o o _'" o o o o'-' o _ o o C ~ ~ · oo o o O G O OO O O O O O O ~ O O O OO O O GoO O '~ ~. SEA PURPOSE.' PROVIDE DRILL SITE FOR EXPLORATORY WELL EXXON OCS-Y 0191 WELL NO. I .. DATUM '. MEAN SEA LEVEL SECTION "A-A"' HORIZONTAL O' 50' I O' VERTICAL ' ' t ' ~ ~ I 6' 12' 18' 24' SCALE IN FEET PROPOSED GRAVEL ISLAND IN BEAUFORT SEA NEAR MOUTH OF SAGAVANIRKTOK RIVER. BEECHEY POINT BLOCK 654 APPLICATION BY: EXXON CO.~ U,S.A. SHEET IOFI DATE: il-21-80 I I i . . ii1_ II i i i _ · _ ii _ ,, ,,DC Oi ?Og" F...~ t.. /?77 1li3/ 5",r'- -' 2. ~ I - O (~ (~ O ~ /0 2, O j. EXPLORATORY PLAN BEAUFORT SEA, BEECHEY POINT AREA OCS-Y 0189,.0190, 0191, 0192 AND 01'93 EXXON (A DIVISION OF P.O. HOUSTON, TEXAS CO.,U.S.A. EXXON CORPORATION) BOX 4279 77001 OPERATOR FOR UNION AND ARCO J ' DECEMBER 1980 VOLUME I RECEIVED '~' JAN20 l!~Sl Alaska 011 & (]as Cons. Commlsalon Anchorage EXPLORATION AND CONTINGENCY PLANS BEAUFORT SEA, BEECHY POINT USGS MAP DESIGNATION BEECHY POINT, UTM ZONE 6 OCS-Y 0189, 0190, 0191, 0192, & 0193 Exxon Company., U.S.A., et al. (a division of Exxon Corporation) P. O. Box 4279 Houston, Texas 77001 December 1980 TABLE OF CONTENTS Ie II. Exploration Plan - Introduction A. Schedule for Prompt and Efficient Exploration B. Description of the Drilling Operations 1. Drill Site 2. Drilling Equipment 3. Fire Fighting and First Aid Equipment C. Geophysical Operations Proprietary Data E. Safety Meetings, Training Procedures, and Drills F. Proposed Mud Program G. Proposed Sampling Program H. Geological and Environmental Information I. Environmental and Sociocultural Training Program Contingency Plans *D. (1) (2) (3) (4) (5) (6) (7) Scope and Objective of Plan Pollution Control Plan Critical Operations and Curtailment Plan Oil Spill Containment and Cleanup Plan Uncontrolled Blowout (Relief Well) Plan Emergency Islan~ Evacuation Plan H2S Contingency Plan *Includes Proprietary Information Page 1 5 10 25 26 30 31 33 41 43 46 49 EXPLORATION PLAN BEAUFORT SEA, BEECHY POINT USGS MAP DESIGNATION BEECHY POINT, UTM ZONE 6 OCS-Y 0189, 0190, 0191, 0192, & 0193 Exxon Company., U.S.A., et al. (a division of Exxon Corporation) P. O. Box 4279 Houston, Texas 77001 December 1980 Ie EXPLORATION PLAN Pursuant to 30 CFR 250.34 "The Lessee shall submit Exploration Plans to the Supervisor for approval." Exxon Corporation, as Operator for Union and ARCo, is submitting this Exploration Plan for leases in the Beechy Point por- tion of the Joint Federal State Beaufort Sea Sale area. Within the designated area, Exxon Corporation currently holds joint oil and gas leases with Union and ARCo on Federal leases OCS-Y 189, 190, 191, 192, and 193 (in Beechy Point, UTM Zone 6, Blocks 654, 656, 608-610, 652-56, 698, 699, and 743). Extensive geological and geophysical surveys and a rock habitats investigation have been conducted on this lease area. These, along with subsurface geologic data obtained from the wells drilled in the Duck Island area to the south, provide evidence that these leases may be sites 'of potential hydrocarbon accumulations. We propose to explore and evaluate this possibility according to the procedures outlined in this Plan.. It is to be understood that the type and sequence of explor- ation activities outlined herein must, of necessity, have considerable latitude and flexibility as work progresses and new data is acquired. For example, the subsurface geologic information .acquired, as each well is drilled and evaluated, is'the most salient data, dictating any future specific proposals of well and gravel drilling island locations. Exploratory prospect evaluation and ultimate reservoir description is always a dynamic, iterative process. -1- Lease No. OCS-Y 0191 Schedule for the prompt and efficient exploration of potential accumulations of hydrocarbons. 1. Exxon, as Operator, now plans to construct one gravel island and drill one exploratory well. Well Est/mated Projected Projected Drilling/ Surface BH Measured Proposed Testimg Location Location Depth TVD Time 1842'FNL & 667' FWL Beechy Point, Block 654 Lat 70° 23 ' 11.15"N Long 147°53' 29.15"W X = 1,530,848' Y = 25,620,154' UTM Zone 6 Same 12,500 Water Depth 12,500 150 days 18 ft. 0 It is Exxon's intention to implace the first gravel island immediately after approval of this Exploration Plan, and begin the drilling of the first well identified above within 10 months thereafter. Decisions of whether or not, and when, to drill subsequent well(s) will be made within a reasonable period of time follow- ing the evaluation of geologic data provided by this well. Such future operations will be further conditioned upon the availability of appropriate drilling equipment and drilling season limitations (Federal Lease Stipulation No. 8). -2- e e So 6. Subsequent to the first well, other wells may be directionally drilled from the same surface location. It is projected that up to eight 12,900'+ wells and surface locations may possibly be necessary to evaluate the commercial hydro- carbon potential of the subject leases. Conceiv- ably, a maximum of ten gravel islands with over 100 wells might be needed to facilitate complete geological evaluation and description - such a maximum is highly unlikely. Other information, which may bear upon our decision to drill additional wells, will be be obtained from wells drilled in adjacent areas by Exxon or other operators (See listing in Environmental report, Appendix IV) and the additional planned seismic control programs. The drilling rig(s), to be used to explOre the area covered by this plan, will be typical of those currently in use in the Beaufort Sea area currently under contract. Arctic Alaska's Rig No. 4 is. under contract and is presently planned for use for OCS-Y 0191 Well No. 1. The expiration date of the leases covered by this Plan is July 1, 1990. The stated schedule is deemed sufficient to efficiently evaluate the commercial hydrocarbon potential of these leases .prior to the stated expiration date. -3- · The contents of this section will be updated every six months or within 30 days after comple- tion of each well drilled. If there is no change within the six-month period, an update would simply state "No Change". -4- DESCRIPTION OF DRILLING OPERATIONS 1. Drill Site A. Artificial Island Drilling operations for the proposed plan will be conducted from a gravel island constructed in approximately 18 feet of water during the winter of 1980-81. Gravel will be obtained from an approved gravel mine near Prudhoe/ Deadhorse and trucked over ice roads to the proposed site. The island will be designed as a two-well location and will have a diameter of 4.80 feet at 11 feet above mean hi h~.D_ter. Approximately 301,000 cubic yards of gravel will be required which will provide a side-wall slope of 1:3. The slope will be suitably protected from waves and ice motion. See attached drawing (Figure 1) which is from Exxon's Department of the Army, Corps of Engineers permit application. The island design and construction will be certi- fied in accordance with the requirements of USGS No. 8. b. Isl'and Fa'cili'ti'es Figure 2 shows the layout of equipment and facili- ties for the proposed two-well island. A self-contained camp facility for housing 70 people will be provided together with utilities including a potable water supply, a sewage treat' ment plant, and incinerator unit. -5- Ce A fuel area will be constructed with an impermeable lining and a gravel berm which will contain any possible loss of fuel from the double walled steel fuel tanks. In addition to the fuel area, there will be a lined reserve mud pit which will be used for emergency discharge of fluids. This pit will normally be kept dry to maximize storage capacity. Pollution Prevention and Control Equipment and Procedures Pollution prevention receives priority second only to safety of personnel and is assured through awareness and training of personnel, good housekeeping, maintaining adequate prevention and clean-up equipment at the site and at the supply base, and reliable communication and supply facilities. Equipment and procedures are detailed in the Contingency Plan which is a part of the Exploration Plan. Exxon will maintain on the island a state approved sewage treatment plant at the drill site. Gray water and treated sewage effluent water will be used for rig wash and water for drilling mud. Presently under consideration is a plan to use a desalination plant to provide as much as 1100 bpd of fresh water. In the event such a unit is installed, an EPA National Pollutant Discharge Elimination Permit will be obtained for the sliqht~_ concentrated seawater effluent which would be discharged to the ocean. -6- There will be no discharge of any other liquid from the site since sewage and sanitary waste effluent and waste mud will be retained as necessary in a steel storage tank and injected into a subsurface disposal zone provided in the drilling and casing program for the well. Burnable waste will be incin- erated at the site with a state of Alaska approved oil fired incinerator and solid waste and junk material will be transported ashore to an approved site for disposal. Minor equipment spills will be cleaned up on the site and materials burned or transported ashore. -7- [ I.B.1. · I NOTES: PLAN -- Il · 0 I00' tOO' SCALE IN FEET ~ '1. APPROX. $01,000 CU. YDS. OF 6RAVEL REQUIRED FOR FILL. SLOPE PROTECTION IL. AT. ?0° ts' II.[s'.~. ~. ' 'B-EAUFORT SEA ! ,~.^~,n~, ~'"'-. NEAR MOUTH OF .......... =" SAGAVANIRKTOK R. I '1 . SCALE IN MILES ] FROM: USGS, QUAD SHEET BEECHEY POINT (B-Z) PURPOSE: PROVIDE DRILL SITE FOR EXPLORATORY WELL EXXON OCS-Y 019[ WELL NO. I 5' BERM 480' I I o, I ! C) '"O 0 0 0 0 O, 0 ~ ' ~ ~ ,. 0_0. z ~,,e~'_,_ $E~I~ "~-~"' HORIZONTAL , ~0' ~[RTIO~ I [ I Il ~ 6' 12' 18' 24' SCALE iN FEET DATUM: MEAN SEA LEVEL PROPOSED GRAVEL ISLAND IN BEAUFORT SEA NEAR MOUTH OF SAGAVANIRKTOK RIVER. BEECHEY POINT BLOCK 654 APPLICATION BY: EXXON CO., U.S.A. Figure 1 --8-- SHEET I OFI DATE: 11-21-80 ... iI.B.1 i . 42' EXAMPLE II~ 40' /I FIGURE 2 ::::::::::::::::::::::::: I:""'"":'"'""""1- .':':-:':'.':':':':':':'.'.'.'.'.'.'.'.'.'-'.:-'1 I.:.:.:.:.:.:.:.:-:-:.:.:.:.:-:-:.:.:':':-:':':' ,:,.:.:.:.:.:.:.:.:.:.:.?.:.:.:.:.:.:.:.:.:.:.:1 :i:i:i:i:!:i:i:i:i:i:i:l!:i:i:i:i:i:i:i:i:i:i:i ::::::::::::::::::::::: ::::::::::::::::::::::: i:!:i:i:i:i:i:i:i:i:i:i :i:i:i:i:i:i:i:i:i:i:ii · :.:.:.:.:.:.:.:.:.:.:. :.:.:.:.:.:.:.:.:.:-:.j ::::::::::::::::::::::: ._'.?.?._'.:.:.:._'.': ::::::::::::::::::::::::::::::::::::::::::::::: · .........................-...-.-.....-........ I::::::~ ::::::::::::::::::::::::::::::::::::::::::::::: ~:i~J l Ileeelelal',~ellllllleele'emeellele"'eeelelee®e ee i1111111111111111111111111111111111111111111 iiii i:i:i:i:i:i:!:i:i:i:i:i:i:i:!::"]."i:i:i:i:i PIPE RACK 130' I.B.2 Drilling Equipment The drilling rig to be used for this proposed exploration is not known at this time, but it is anticipated that Arctic Alaska Drilling Company Rig No. 4 will be used depending upon when the drilling can be initiated. Any substitute rig will be similarly equipped. AADCO Rig No. 4 is an arctic drilling rig capable of drilling to 20,000 feet. All outside walls of the rig enclosure (including the pipe rack house, walk and ramp) are insulated from ground level to 10' above the derrick floor. Windwalls extend on up to 50' high around the derrick floor. The piperack house is equipped with an automatic hydraulic pick- up and lay-down machine powered by a 75 HP motor and can handle up to 50' lengths of 10" drill collars and 20" casing. 12,000' of 9-5/8" casing can be racked in this house and the 5" drill string either laid down or left standing in the derrick. Included with the rig is an insulated heated shop building with separate mechanic, electrician, and welder areas. Overall size is 36' wide x 48' long x 17' high with four personnel doors and a 16' wide x 16' high vehicle door. The shop is equipped with work benches, a drill press, anvils, vises, grinders, welding equipment, and a 5 ton overhead electric crane. Following is a listing of major rig and drilling equipment. a. Specifications and Capacities · Prime Movers - Five Caterpillar D-398, 900 HP diesel engines driving five 700 KW AC generators, a total Of 3375 KW or 4500 brake HP. -10- One Caterpillar diesel 3304 "cold start" and stand-by generator with residental spark arresting mufflers. Rigdrive - General Electric; AC/DC SCR system and motor control distribution center, all pressurized with controlled atmosphere. Six GE 752 DC motors are controlled from the drillers console position. .~ Drawworks - Oilwell E2000, 2000 HP with V-200 Parkers- burg brake powered by two 1000 HP electric motors. Motors and brake cooling systems used for heating substructure area. Derrick and Substructure - Dreco; M14225-1330; "Slingshot"; 1,300,000 9 GNC; 900,0009 casing capacity; 500,0009 set back; 25' wide legs x 142' under crown working space. Crown Block - Oilwell 500 ton, seven 60" x 1-3/8" sheave. Traveling Block - Oilwell; B-500, 500 ton, six 60" x 1-3/8" sheaves. Hook - BJ, 5500, 500 ton, dynaplex, automatic positioner hook. Swivel - Oilwell; PC-500, 500 ton, goose neck tapped for 2" free point access. Bails - BJ, 350 ton. Rotary Table - Oilwell; B-375, 37-1/2" opening, driven from drawworks. -11- · Drill Pipe - 5" 19.5#/ft. U.S.S. IEU grade G-105 and S- 135 tubes, with HTCO 5" extra hole tool joints, 6- 1/2" OD with smooth hard-facing and AMF TK-34 internal plastic coat. 10,750' is G-105 rated 554,000 lb tensile and 10,750 is S-135 rated 712,000 lb tensile. · Pipe Handling Equipment - VARCO iron roughneck Power slips Hand slips Kelly spinner Drilco easy torque · Accessories - Mathey 20,000' hydraulic wireline unit 10,000 lb. air winch 2'5,000 lb. derrick booms 2-personnel elevators Geronimo derrickman escape device Geronimo derrick climber S & S, Crown-O-Matic protection device b. Driller's Control Center · Totco Driller's Console with gauges and indicators for: String weight Rotary torque Rotary torque Rotary RPM Tong torque Easy torque Iron Roughneck -12- Flow-show Tank volume totalizer Hole-fill indicator Pump strokes per minute Tank gain/loss Totco eight-pen recorder for: String weight Trip time Penetration Rotary torque Pump pressure Pump strokes per minute PVT Totco circular record for trip tank Koomey BOP control console Cameron automatic choke control console Diverter Controls Communications equipment as follows: 16 AD open all station intercom 3 RCA closed circuit TV cameras (shale shaker room, mud mixing room, pump room, and derrick floor areas covered). 3 Tv screens (driller's dog house, tool pusher's office, company man's office). -13- Main BOP Stack; 10,000# WP: 1 - Hydril GK 13-5/8" - 5000 psi WP annular BOP with studded top and hub-clamp bottom connections, fast change locking bonnet. 3 - Hydril 13-5/8" - 10,000 psi WP single gate BOP's with top and bottom hub-clamp connections, each with one 3" flanged side outlet. All gates equipped with automatic-ram-locks. 1 - Shaffer drilling spool, 13-5/8" - 10,000 psi WP top and bottom hub-clamp connections with one 3" flanged side outlet equipped with two 3" 10,000 psi WP flanged valves (one hydraulic) for kill line and one 4" flanged side outlet with two 4" - 10,000 psi WP valves (one hydraulic) for line to choke assembly. See attached Figure 2 for BOP schematic and Figure 3 for a typical test program. (OCS-Y 0191 Well No. 1) Control and test equipment 1 - NL Koomey seven station, 3000 psi WP BOP accumulator control system, with 20-11 gallon accumulator bottles (220 gal, capacity), 280 gallon fluid reservoir, 20 HP electric triplex pump at 8.7 GPM at 3000 psi, two air pumps 3.5 GPM each at 3000 psi as first back-up, 6-275 CF nitrogen bottles as second back-up with remote electric control console behind driller on derrick floor. -14- d. Mud. Treating · Mud Pumps - Two Oilwell A-1700, 1700 HP, triplex single acting pumps, each driven by two 900 brake HP traction motors. Pumps are equipped with 5000 psi WP discharge manifold to kill line and stand pipe system, Demco shear relief valves, TOTCO mud gauges, Hydril pulsation dampeners. Pump suctions are super charged. · Shale Shaker - Brandt Engineering Co. double shale shaker with dual decks and screens. · Mud Degasser - SWACO vacuum type degasser · Mud Cleaners - Two Brandt Engineering Co. "combination" 400 gpm cleaners and/or desilters · Centrifug~ - Pioneer Mark I, 100 gpm with four feed pumps. · Mud Blender - Two Pioneer sidewinder cyclonic · Mud agitators and mud guns · Mud Tanks - 1000 bbl active tanks 350 bbl storage 80 bbl trip tank e. Blowout Prevention Equipment · Diverter - One 20" Hydril MSP - 2000 psi WP annular BOP with flanged bottom and studded top with 10-3/4" diverter system, diverter opens to one of two diverter lines when 20" annular is closed. See attached Figure 1 for schematic and operating procedure. f, g, 1 - National 10,000 psi WP single acting triplex test pump driven by 50 HP AC motor complete with tank, gauges, by-pass valves, manifold, hoses and controls. Accessory equipment Hydril 10,000 psi upper Kelly cock. Hydril 10,00D psi 3-1/2" & 5" lower Kelly cock. Hydril 10,000 psi 3-1/2" & 5" floor valves. Flocon 10,000 psi 3-1/2" & 5" inside BOP. Baker floats for DC float subs. Substructure 50 ton overhead BOP handling system. Choke system Unitized 10,000 psi WP choke assembly consisting of a 4" straight through, one 3" Swaco hydraulic adjustable' choke, two Thornhill-Craver 3" API manual adjustable chokes with two 10,000 psi WP valves up stream of each above function. Drillers remote console on rig floor. · .. and proper gauges and sensors both on rig floor and at the manifold. An Exxon designed mud/gas separator will be installed. See attached Figure 4 schematic. .. Kill line system - 10,000 psi WP kill assembly consisting of two 10,000 psi valves (one manually operated and one remotely operated) off of the drill spool to a cross with a connection for the muds pumps and a connection for a high pressure pump. See attached Figure 5 schematic. -16- he i® j · Water and Fuel Storage: . 1000 bbl total water storage · 7400 bbl total diesel storage in double wall tanks. · 1000 gallon gasoline tank for pickups · 250 gallon forklift-portable diesel fuel tank for fueling up machinery/trucks on rig moves. Air Compressors and Heating · Two Sullair series 12-5AO single stage rotary screw air compressors driven by 50 HP AC motors, rated 200 cfm at 125 psi WP. · Two Keewanee 100 HP boilers, automatic diesel fired and water level control. · 30 Stardozik Ruffneck steam heaters driven by 1/2 HP AC motors · Two Tioga 3,500,000 BTU indirect automatic fired diesel space heaters. · All heat will be salvaged from the D-398 prime mover cooling system (creating 1,500,000 BTU each under 75 percent load) and force distributed into the rig housing with additional fans to distribute heat turbulance in large areas such as the substructure and rack house complex. Safety Systems and Alarms · Drilling safe~y~ alarms include: Pit level indicator alarm Mud return indicator alarm -17- H2S detector and alarm (Mud logger) system Combustible gas detector and alarm system Camp safety alarms include: Heat and smoke detector and alarms Manual general fire alarm -18- I !.B.2 · TRIP TANK I, I . I.. DIVERTER SYSTEM For Use on 30" Structural and 20" Conductor Casing SHAKER BUTTERFLY VALVE TRIP TANK 20" HYDRIL MSP 2000 10" HYDRAULIC VALVE 20" 2000 PSI SPOOL ~ 10" lO" VENT 20" MANUAL VALVE WELLHEAD OR ~/ 20" CASING (30" not shown) VENT OPERATING PROCEDURE Diverter system has one-lO" hydraulically operated main valve and two-lO" manually operated branch valves. Diverter and main valve controls are interlocked. The main valve is normally closed and the diverter and branch valves are normally open while drilling. In a Well Control Situation: 1. Close Hydril diverter which automatically opens main valve 2. Close upwind branch valve Figure 1 -19- I .B.2 ' · ,ARRANGEMENT OF A FOUR-BOP STACK 10. 11. BUTTERFLY VALVE ' ~- FLOW LINE TRIP TANK ~ $" LINE OR (~ J m BUTTERFLY VALVE mop j ~ILL ~ ~ '1 I ~ . M~NIFOLD I RAM BOP] COI~ONENT SPECIFICATIONS 1. Flanged plug or gate valve - 2" size - same working pressure as 'A' section. 2. Screwed tapped bullplug with needle valve and pressure gauge. 3. Flanged plug or gate valve - 2" size - same working pressure as top of 'B' section. 4. Flanged tee with pressure gauge and/or connection to casing pressure gauge on hydraulic choke control panel. 5. Flanged plug valve - 2" minimum size - HOWCO "Lo Torc" or equivalent. 6. Flanged hydraulically controlled gate valve. 7. Flanged plug valve - 4" minimum size - HOWCO "Lo Torc" or equivalent. 8. Flowline from spool to choke manifold - 4" minimum size - all connections must be flanged or welded. 9. Connection at top of annular preventer must be equipped urlth an APl ring groove, AP1 ring gasket, and APl companion flange on bell nipple. All flange studs must be installed. The ID of the bell nipple and companion flange must not be less than the ID of the BOP stack. Spool-24" height with 2 flanged side outlets - 4" and 2" minimum ID. Fi gure 2 -20- F~gure 3 -21- ~ f..m opm qm ~ =o-~ I I o o _1 0 0 3)10H3 -- lml I ARRANGEMENT OF IOO00 PSi $ CHOKE MANIFOLD i ,~ ~ (~)Q FRO~ STANDPIPE COMPONENT DESCRIPTION 1. Accurate Pressure Gauge (.%artin Decker or equal) for measuring standpipe pressure. This gauge must be installed on a flexible Martin Decker or equal sealed line with a working pressure rating equal to that of the BOP stack. 2. Diaphram type Pressure Gauge and gate or plug valve - 2" minimum size - flanged to 5 way cross or to tee and valve installed between cross and first valve. 3. Flanged or Studded Cross - &" x &" x 2" x 2" x 2". &. Flanged or Studded Cross - &" x &" x 2" x 2". 5. Flanged Plug or Gate Valve - 2" minimum size. 6. Blind Flange. ?. Flanged Spacer S~ool - 2" minimum size and 18" minimum length. 8. Flanged Hydraulic Choke - 2" minimum size. 9. Flanged Manually-adjustable Choke equipped with tungsten carbide stems and seats. Seats to be l"size. 10. Flanged Plug or Gate Valve - 4" minimum size. 11. Flanged or Studded Cross - 2" x 2" x 2" x 2". 12. Companion Flange with. Screwed Nipple - 2" minimum size. 13. Companion Flange with Screwed Nipple - 4" minimum size. 14. Screwed Plug or Gate Valve - 2" minimum size. 15. Screwed Plug or Gate Valve - 4" minimum size. 16. Screwed Swage - 2" x 4". 17. Screwed Unions - 4" minimum size, flat face, hamaer type. 18. Screwed Bullplug with Screwed 1/2" Needle Valve for obtaining a flowing fluid sample. 19. Screwed Union with Nipple - 2" minimum size, flat face, hafner type. Fi gure 4 -22- ARRANGEMENT OF I0000 PSI BOP I(ILL LINE FROM MUD PUMP TO DRILLING SPOOL CONNECTION FOR PRESSURE PUMP .1. 1. Kill i/ne should be attached to drilling spool 2. All lines, valves and fittings shall be nominal 2" steel and have a rated working pressure at least equal to the worldng pressure of the BOP stack. 3. All lines shall be tested to rated working pressure of stack. 4. Kill lines should be welded or flanged $. An outle~ 'outboard of the check valve may be provided to tie in an auxiliary pump. Figure 5 -23- Ce ~ud Loqging An Analysts unit (Schlumberger, Inc.) will be installed on OCS-Y 0191 No. 1. Similar units will be used on subsequent wells. o Gas Detection and Alarm System - The hydrocarbon gas detection and alarm system is a catalytic hot .wire/thermal conductor system installed on the rig floor with gas trap located in the shale- shaker. The system provides automatic calibration at drill pipe connections, records data either in units of gas (30 units ~ 1%) or in percentage and has preselected alarm levels. Additionally, it provides a standby 'hot wire, a standby sample pump, alarm for equipment failures, and four alarms (one on the drilling floor, one in the mud logging unit and two in supervisors quarters.) o H2S Detection and Alarm System - The H2S (Hydrogen Sulfide) monitoring system is dual with fully adjustable warning and alarm levels. Modules are located in the mud logging unit and are continuous reading with indicating meters graduated from 0 to 100 parts per million H2S, Four.locations are continuously monitored for H2S, 1) a "mud duck" system checks pH and H2S levels as an early indi- cator in the mudline, at the shaleshaker, and the mud mixer, 2) a lead-acetate system records levels under the bell nipple. When preselected levels are detected, alarms are displayed in the mud logging unit, the drillers panel, and two- supervisors qUarters. -24- I.B.3 Fire Fighting and First Aid Equipment Camp - Automatic extinguisher over kitchen stove 10 - Ansul LT 30# hand extinguishers 1 - Ansul LT 1509 wheel mounted extinguisher hose and reel. Rig - 40 - Ansul LT 309 hand extinguisher 1 - Ansul LT 1509 wheel mounted extinguisher and hose. First Aid - MSA First Aid Kit MSA evacuation basket litters with blankets 6 - MSA gas masks wi,th oxygen, tanks -9.5 - Io Co l, Geophysical Operations The types of geophysical operations contributing to and a part of this Plan are: a. CDP (Common Depth Point) seismic surveys, b. velocity surveys, and c. high resolution shallow hazard surveys. a. CDP Seismic Surveys - It is probable that further seismic surveys will be conducted in the area concurrent with island construction and then later concurrent with exploratory drilling. A conventional ice crew seismic survey conducted with an appropriate geophone cable and non-dynamite energy source would be employed. A description of a typical ice crew geophysical field data acquisition opera- tion is included in Sections I.C.2-4, following. b. Velocity'surveys - Velocity surveys are antici- pated.for each exploratory well. They are obtained in the following manner: a specially designed geophone is lowered into the borehole at various predetermined depths; it receives acoustical signals from an air gun energy source that is either suspended within a fluid filed tank or in a shallow hole adjacent to the wellbore and transmits these signals back to recording equipment at the surface via a conductor cable. In the case of directionally drilled bore holes, primacord laid on a steel plate would be the energy source. -26- le ® Geophysical Operations, Cont'd. c. Shallow hazard surveys - High resolution geophysical surveys were conducted during the summer of 1980 to investigate potential shallow geologic hazards to planned opera- tions as well as to contribute to an inves- tigation of sea floor rock habitats. No additional geophysical surveys of this nature are anticipated. Equipment for Typical Ice Crew 1 Texas Instruments DFS V, 96 channel record- ing instruments complete with all necessary accessories such as ERC-10 camera, RLS 240-M . roll-along switch, TI-SRS shooting control system, radios, and test equipment 1 Texas Instruments FT-1, field computer for final diversity stack and final zero or mini- mum phase correlation 5 Texas Instruments TR-3 Vibrators 350 Strings of geophones each with 12 GSC-20D, 10 Hz geophones to be used 2 strings per trace 30 Seismic cables, 75 conductor pairs each, with 12-110 foot interval geophone connectors each, useable for any group interval that is a multiple of 110 feet 1 TT 200 6X6 wheeled recording vehicle 1 ARDCO 6X6 wheeled vibrator tender 4 TT 100 4X4 wheeled or tracked cable and geophone carriers 1 TT 100 4X4 wheeled survey vehicle 1 M-114 tracked survey vehicle 1 TT 100 4X4 crane equipped camp vehicle 1 M-115 tracked ice check vehicle with auger drill e e Equipment for Typical Ice Crew, Cont'd. 1 GN-110 tracked ice check vehicle with Mayhew top drive drill 5 Texas Instruments High Frequency, Force-2, TR-3 wheeled vibrators 1 45 person camp complete with all bedding, tools, utensils, generators, and spare parts (fiberglass houses - skid mounted) 6 D-7 Caterpillar tractors or equivalent 13,000 gallon fuel storage capacity 2 Motorola Mini-Ranger Survey Systems 4 Self erecting 60 foot survey towers 1 Wilde T-2 Theodolite with rods, chains, and marking devices Food service supplies Spare parts Safety equipment to include two-way radios Fuel, lubricants, field magnetic tapes, and other expendable supplies Air and ground support for line scouting and crew supply Instrument and.survey field service support Personnel in a Typical Geophysical Ice Crew 1 Operations Supervisor (may suPervise more than one crew) 1 Party Manager 1 Instrument Engineer 1 Instrument Engineer Assistant 12 Recording helpers and line truck drivers 1 Surveyor 2 Mini-Ranger operators 1 Survey helper -28- Ie Ce 3. Personnel in a Typical Geophysical Ice Crew, cont'd. 2 Mechanics 1 Mechanics helper 1 Vibrator mechanic 5 Vibrator operators 1 Administrator 1 Camp attendant 1 Cook 1 Cook's helper Tractor operators 39 Total 4. Data Acquisition Parameters Number of groups, cable/geophone Group Interval Number of geophone locations per. group Number of geophone elements per location Distance between vibration points Fold of CDP coverage Number of sweeps per shotpoint Recording sample period low cut recording filter High'cut recording filter Shotpoint offset from near group Shotpoint offset from far group 96 220 feet 24 1 440 feet/220 feet 24/48 Variable 4 milliseconds 12 hz at 36 db per octave 85 hz Variable 'Variable -9.9- De Proprietary Data This Section is composed of information considered proprietary by the lessee. These data include structural and stratigraphic interpretations based on available geophysical and geologic data, a description of potentially productive intervals, interpreted seismic sections, RMS velocity scans, and other information pertinent to the evaluation of the petroleum potential of the area. This information has been bound separately, as "Volume 2", and marked: "Exxon Proprietary for U.S.G.S. Use Only". - 30 - I. E. Safety Meetings, Training Procedures and Drills 1. Safety Meetings Weekly safety meetings will be conducted for the crews to discuss accidents, their causes, and corrective action. 2. Fire Drills Fire drills will be conducted weekly for all crew members. The duty assignments and fire stations for assigned personnel will be.posted in conspicuous places about the rig. 3. Pollution Prevention and Control Drills and Training The oil spill response operating team will participate in at least one drill each year as set forth in the contingency plan and as required in OCS Order No. 7. The oil spill response operating team will receive training with pollution control equipment and in procedures as set forth in the contingency plan and as required in OCS Order No. 7. Records of such training will be maintained on the rig. -31- · Training For Rig Personnel The training requirements referenced in Ocs Order 2 (GSS-OCS-T1) require that Company and contractor supervisory drilling personnel (including drillers) be trained in well control methods and procedures and in adnormal pressure detection. Personnel will be trained as required above in either approved Company or industry schools when drilling is commenced. BOP drills will be conducted as outlined in GSS OCS T-1. A list of personnel and their completed training will be maintained on the rig and will be available upon request. - 32 - f , Io Fo Proposed Mud Program The attached Table I shows an example mud program for the Beaufort Sea wells. Included in the table is a list of (a) the basic mud components, (b) additives normally utilized, and (c) special purpose additives rarely used. a. Basic Mud Components The basic mud components are those which are used almost daily and comprise by far the major portion Of the mud composition. Safety and environmental technical bulletins for the basic mud components are available but are not included since, as described later there will be no drilling mud discharges from the site. Table III lists basic mud types and component ranges for mud programs that will likely be used during the Explo- ration Program in the area. Planned minimum quantities of basic mud materials maintained at the drill site will meet or exceed the requirements of USGS Order 2. Table 2, attached, reflects the minimum and planned requirements for an example 12,500-foot well shown in Figure 1. Each rig has a.~-a`~.r~]f~..a-~]~-~l]~g~U].-~..--m-u~.~.~sy..~t-e-~-~.~c~p-acity, but will generally be 1000-1500 barrels. -22- b. Mud Additives The additives listed under item (b) on Table I are all common chemicals. They are used to adjust the pH of the mud system or to precipitate out carbonate ion or cement contamination. When added to the mud they have essentially no influence on toxicity. c. Special Purpose Additives Those special purpose additives listed on Table I are used in very small amounts and are either inert (mica, nut hulls, copolymer beads) or non-toxic in the concentrations used ( aluminum stearate, and zinc carbonate, etc.) _T..h_.q?e wi].!,,, be.~no.dl,i.schar, ge, of,,.e i,.ther,.d~ .r..i. l i1 lng, m.ud.,,or..,, dr.i l.l,,,,.c u~,t.i ngs from the site. Cuttings will be stored .on..l~cati, on,and, ltransported ashore for disposal at an approved site. Maximum use will be made of mud solids control equipment to keep the volume of excess mud to a minimum. Prior to setting 9-5/8" casing, any excess mud will be stored on location or will be transported ashore and disposed of at an approved site. Following setting 9-5/8" casing, injectivity will be established down the 13-3/8" x 9-5/8" annulus and all excess mud will be disposed of in this manner. This is the same procedure as used on Exxon's Alaska St. Duck Island Unit Wells No. i and No. 2 which proved to be effective. In Exxon's Environmental Report it is stated that an estimated 2.5...00 bbl.,s ...... of .,,C.U~t,t.~ n.gs...a,.nd. 2.~.~.,.,,b~.!.,..s.,....~.of..,, drill i ng 'a typical well. Mud tests will be performed as described in the Arctic OCS Order No. 2 or more frequently, as dictated by conditions. Procedures will be as outlined in the API Recommended Practices for Standard Procedure for Testin9 Drillin9 Fluids (API RP 13B). Permafrost is expected to be encountered to approximately 1,000 feet RKB in the Exploration wells to be drilled in this area. None of the wells nearby this area are known to have encountered gas hydrates. Exxon's Duck Island No. 1 located just outside this area to the south had permafrost to approximate)y 1500 feet RKB but did not encounter gas hydrates. It is planned to carefully monitor mud temperatures and gas content while drilling surface hole. A mud log unit will be in operation from the mud line to TD and a flow diverter will be installed on both the 30-inch and 20-inch casing. If indications of gas hydrates are detected, mud temperatures will be controlled by cold water additions to reduce melting and penetration rate will be limited to reduce gas concentration in the mud. The planned surface casing depth of 2,800 feet is expected to cover all potential gas hydrate zones. A shallow hazards analysis will be conducted at each~ll location to determine the presence or absence of all shallow hazards, includ- ing any indications of hydrates. - :)5 - - 36 - c 4.1 C OI C C I~ 0 C E 0 - 37 - C:) CD) C:) e® o 0 c~ ~J .c: I-- Table 3 PROPOSED MUD SYSTEMS 1. Seawater Polymer Mud Component Attapulgite or Bentonite Clay Caustic XC Polymer Drilled Solids Barite Soda Ash/Sodium Bicarb Lime SAPP Seawater 2. Lightly Treated Lignosulfonate Freshwater/Seawater Mud Component Ben ton ite Barite Caustic Lignosulfonate Lignite Cellulose Polymer Drilled Solids Soda Ash/Sodium Bicarbonate Lime Seawater/Freshwater 3. Lignosulfonate Freshwater Mud Component Bentonite Barite Caustic Lignosulfonate Lignite Drilled Sol ids Cellulose Polymer Soda Ash/Sodium Bicarbonate Lime Freshwater 4. Lime Mud Component Lime Bentonite Lignosul fonate Lignite Barite Caustic Drilled Solids Soda Ash/Sodium Bicarbonate Freshwater #/BBL 10 - 50 0.5- 3 O- 2 20- 100 O- 50 O- 2 O- 2 0- 1/4 As Needed #/BBL 10'- 5O 0 - 180 1- 3 2- 6 O- 4 O- 2 20 - 100 O- 2 O- 2 41:1 ratio #/BBL 10 - 50 0 - 450 2 - 5 4 - 15 2 - 10 20 - 100 O- 2 O- 2 O- 2 As Needed #/BBL 2 - 20 10 - 50 2 - 15 0 - 10 25 - 180 i - 5 20 - 100 0 - 2 As Needed 5. Nondispersed Mud Component Bentonite Acrylic Polymer Barite Drilled Solids Freshwater 6. Spud Mud (slugged intermittently with seawater) Component Attapulgite or Bentonite Lime Soda Ash/Sodium Bicarbonate Caustic Barite Seawater #/BBL 5- 15 0.5- 2 25- 180 20 - 70 As Needed #/BBL 10 - 50 0.5- 1 0 - 2 0 - 2 0 - 50 As Needed I, - 29 - Mud Line BEAUFORT SEA, BEECHEY POINT AREA Typical Well Bore Sketch Showing Casing Depths and Hole Sizes 30" Structural Casing set at 98' below mud line 26" Hole; 20" Conductor Casing set at +-1000 RKB 17-1/2" Hole; 13-3/8" Surface Casing set at +2800' RKB Injection zone 12-1/4" Hole Top of Cement + 7000' RKB 9-5/8" Intermediate Casing set at +10,500' RKB 8-1/2" Hole e~, Total Depth 12,500' RKB I, Go Proposed Sampling Program 1. The mud loggers will be responsible for the following for drill cuttings from surface to total depth: a. Four sets of washed and dried cuttings will be caught and packaged at 30' intervals until drilling slows down to where 10' intervals can be collected. (Two sets for Exxon, one set for the USGS.) b. Four sets of unwashed cuttings will be caught at 30' intervals and placed in cloth bags then packaged in plastic bags. (Three sets for Exxon, one set for 'the USGS.) c. Two sets of canned cuttings, for geochemical analysis, caught at 10' intervals and canned at 100' intervals. Complete canning procedures are in instructions to mud loggers. (One set for Exxon, one set for USGS.) 2. Sample distributiOn will be as follows: a. One set of washed and dried cuttings, one set of unwashed cuttings, one set of canned samples will be sent to Exxon in Houston. b. One set of washed and dried cuttings, one set of unwashed cuttings, one set of canned samples will be sent to the USGS. e 4, Sidewall Cores It is anticipated that a number of sidewall cores will be taken in selected potential reservoir intervals for purposes of determining porosity and permeability, verifying lithologies in specific intervals, and detecting hydrocarbons. In addition, some sidewall cores may be taken from shale intervals for paleon- tological analysis. Conventional Cores Where considered necessary, conventional diamond cores may be taken to provide reservoir engineering as well as petrographic and petrolo'gic data. Approximately 300' of conventional coring is anticipated while drill- ing OCS-Y 0191 No. 1. -49. - I. He Geological and Environmental Information 1. Harding-Lawson Associates conducted a multi-sensor high resolution survey in June 1980, for Exxon Company, U.S.A., as Operator of offshore leases OCS-Y 0189 through 0193 and selected adjacent Alaska state leases. The report and data for this survey were submitted to the USGS as a part of the Environmental Report supporting this Plan. The survey's multiple objectives were to provide geologic information to supplement a foundation coring program for. shallow hazard and engineering assessment of the area and to investigate rock habitats on the sea floor as such habitats relate to local biological communities. Field acquisition was performed utiliz- ing concurrently the Klein Associates kHtz sea floor mapping side scan sonar system, a high resolution Raythion RTT-1000 depth recorder and 7.0 kHz subbottom profiler and a Van Reenan Mono-Pulser subbottom pro- filing system. The sea floor of the proposed location for the gravel island for OCS-Y 0189 No. 1 (H-L shot- point No. 2777) is smooth and free of any obstructions and slope instabilities; near-surface conditions are assessed from both geophysical and core data as favor- able. If, and as additional specific gravel islands and well locations are made, planned specific sites will be reviewed for such features as the presence of strudel scour, ice go~ge, sand waves, permafrost, and acoustic anomalies that may reflect biogenic or petr0genic gas. -43- . Regional maximum environmental conditions. a. Waves - Surface waves occur in the subject area only during the the summer open water period. Because of the barrier islands and remaining sea ice, the fetch is limited; therefore, the heights are usually less than 50 cm. Rarely, swells reach 2.1 meters with storm wave heights of 3 meters (USDI, 1979, p.44). b. Wind - Maximum surface wind 81 mph (seasonal variations in winds at Barter Island, Alaska, USCOE, 1980, p.-364). c. Current - Current velocities are about 3.5% of wind speeds, typically 15 to 20 cm/sec. In winter, under ice velocities are always lower than 5 cm/sec. (USACOE, 1980, p. 3-34). d. Ice - Ice forms in late September to early October, increases to a thickness of 2 meters in November-December, river flooded in late May with breakup usually in late June. e. Permafrost - Relict permafrost underlies the entire area of the subject leases. At the site of 0CS~Y..,01.91.,~.Well.~..No. 1, the top of the. permafrost is 9 meters below the ... ~.ea floor. - 44- 2. Regional maximum environmental conditions, Cont'd. f. Seismic motion - Seismic activity in the subject area is very low. Gravel island technology has been in the past, and is presently, considered adequate to preclude such ground acceleration in the Plan area as a major potential hazard to exploratory operations. g. Severe Weather -.Severe weather should present no significant hazard to explora- tory operations on gravel islands. It may cause temporary interruptions of transporta- tion and suspensions for personnel safety. Io I · Environmental Training Program An environmental training program will be given to all personnel directly envolved with the exploratory activities of the Plan. The program is designed to inform each such person, including Exxon supervisors, managers, agents, contractors and subcontractors of environmental, socio- logical, and cultural concerns that they might impact in the Plan area as well as training in arctic survival. As reviewed and found satisfactory by the Joint Federal/ State Biological Task Force, the program includes video tape presentations prepared under the direction of Mobil, SOHIO, and Exxon. The tapes are introduced and expanded by discussion given by a qualified instructor. Broadly, the purpose of such training is to mitigate possible impacts from Plan activities by stimulation of personnel sensitivity and understanding of local values, customs, and lifestyles as well as to facilitate recognizition of and to inculcate the need for protection of archeological, geological, and biological resources. Subjects included in this program are: 1. Physical environment with examples of potential negative impacts for avoidance: o Description and explanation of coastal plain geomorphol0gy, its topography and formation processes, o permafrost and significance of tundra protection, - 46 - 2, . o Arctic coastal processes of wind, wave, current, ice, and thermal erosion and their effect on natural and man made features, o sea ice cycles, distribution, movement, and potential impacts on transportation and structures, o climate with significance of daylight seasonality, wind chill factor, blowing snow, temperature inver- sions, and surficial freezeup/breakup effects. Biological environment and concerns for marine and onshore flora and fauna including identification and discussion of: o major common biologic forms including lemmings, caribou, fox, bears, seal, whale, water fowl, and raptors, their seasonal habits and habitat, o potential impacts such as noise, motion, destruct- ion of food/cover, siltation and disposal of wastes and potential effects of each, o interactions of the producer/consumer web. The Inupiat people and their traditions, work habits, and values: o the close interrelationship between the Inupiats, the harsh arctic environment, and their vital subsistance resources, o potential impacts to conservation of the "old ways", to food/clothing supply and to archeolog- ical resources such as grave sites, middens, or historic structures. - 47- 4. Arctic Survival: o clothing and supplies, trip itineraries, basic first aid, cold weather physiological hazards, shelter preparations, water supply, heat conser- vation, fire building, carnivores and insects, direction guides and distress signals. Although the program as presently constituted is satisfactory, an edited revision, prepared under the auspises of the Alaska 0il and Gas Association .is planned for Industry-wide application. - 48- CONTINGENCY PLAN BEAUFORT SEA, BEECHY POINT USGS MAP DESIGNATION BEECHY POINT, UTM ZONE 6 OCS-Y 0189, 0190, 0191, 0192, & 0193 Exxon Company., U.S.A., et al. (a division of Exxon Corporation) P. O. Box 4279 Houston, Texas 77001 December 1980 -49- CONTINGENCY PLAN BEAUFORT SEA, BEECHEY POINT OCS-Y 0189, 0190, 0191, 0192, and 0193 UTM Zone 6 I, Contents (1) Scope and Objective of Plan ........ 1 (2) Pollution Control Plan ........... 4 (3) Critical Operations and Curtailment Plan.. 10 (4) Oil Spill Containment and Cleanup Plan... 13 (5) Uncontrolled Blowout (Relief Well) Plan . . 17 (6) Emergency Island Evacuation Plan ...... 19 (7) H2S Contingency Plan ............ 20 i, Section (1) SCOPE AND OBJECTIVE OF PLAN BEAUFORT SEA, BEECHEY POINT OCS-Y 0189, 0190, 0191, 0192, and 0193 I. Scope. The scope of this Contingency Plan is outlined below and is intended to cover the OCS leases listed above: A. To define normal operating procedures to be followed during move, drilling, testing, and related operations undertaken in the areas listed. B. To detail all necessary special procedures and precautions to be followed during critical operations such as fuel transfer, well testing, etc. C. To outline preliminary plans for containment of pollutants should an oil spill occur. D. To describe action to be taken in the event of an uncontrolled oil spill, either major or minor, including: 1. Governmental agency notification and requirements. 2. Designation of authority. 3. Immediate spill control response actions. 4. Location cleanup plans. 5. Mobilization procedure for ABSORB personnel and equipment. 6. Disposal of recovered fluids and materials. E. To outline remedial actions to be taken in the event of uncontrolled well flow, including preliminary plans for construction of an additional relief well location. F. To outline the procedure for securing the wellbore and evacuating personnel from the location in the event ice forces cause lateral displacement, of the gravel island. G. To outline H2S detection and monitoring equipment requirements and personnel and well safety procedures. H2S is not expected to be present in any of the formations to be penetrated at this location, but monitoring and safety equipment will be available on location to provide personnel safety and to permit safe control of the well in the event H2S is detected. II. Objectives. The objectives of the attached plans are: I, A. Ensure the safety of all personnel involved in operations in the area. B. Minimize the environmental impact of operations. C. Comply with all current federal, state, and local regulations in effect, including local regulations and stipulations in effect. D. Protect the integrity of the rig, location, and ancillary equipment. The rules and procedures set out in this document are to be followed by all operations personnel, support personnel, and visitors on-site at the well locations in the area. It will be the Exxon Drilling Superintendent's responsibility to see that environmentally sound practices are followed on this well. The procedures outlined in this document are to be considered minimum standards for operation. It is up to all personnel involved to conduct their work in a manner minimizing environmental impact. In compliance with federal regulations, a copy of this document shall be available for inspection at all times at the .drill site. In addition to this plan, an ~x~,D .... N.o.~th ........ S~.pe.....~,Em~.gency Manual is currentl~,.bl~..~,n~ ~e~ar~d b~ An~r~ Drilling. This man~'~""~i"'ll contain ~f~"m~2 { ai led ~'~E2~r6~'""'a~'~'l'~ 6~m~'{-~"~F deal i ng wi th a,~]_l 1,,,,..ii~..p~ of em_~,~y~er_~,~i~3 that may be encountered during exploration 'drilling ac- tivities on the North Slope. This manual also will serve to avoid placing. repetitious material such as phone lists, equipment brochures, etc.,,- each individual Drilling Well Program. When completed, this manual will be submitted to the USGS, if requested. III, Personnel and Organization. A. Normal Operations. During normal operations (i.e., drilling, testing, abandonment, and move operations) the primary goal of all personnel shall be to prevent system upsets and pollutant discharges. Specific responsibilities are · 1. Exxon Anchorage Engineering - Responsible for review and dis- semination of information regarding applicable government regu- lations and development of procedures necessary to ensure regu- latory compliance. Engineering is also responsible for de- veloping technology for clean operations. 2. Exxon Drilling Superintendent - Responsible for daily activities including sup))ort operations for rig supply, construction, etc The Exxon Superintendent is also responsible for ensuring tha~ all personnel are aware of regulations and procedures pertinent to their activities. 3. Contract Superintendent - Responsible for the maintenance of the rig. and training of crews to ensure sound operations. 4. Ancillary Contractors - Responsible for knowing and following procedures applicable to their individual operations. -2- B. Emergency Operations. During emergency operations (i.e., uncontrolled well flow, oil spill, etc.) the main effort should be toward minimizing the effect of pollutant discharges. Major areas of responsibility are: 1. Headquarters Drillin§ - Responsible for overall management of ~rilling efforts, including well control and relief well opera- tions. Will advise Anchorage Drilling regarding action required to comply with federal, state, and local statutes. 2. Anchorage Operations Manager - Has overall responsibility for emergency response team. Transmits pertinent data to Western Division management. 3. Anchorage Public Relations - Will act as the single point media contact. 4. Anchorage Drilling - Advises management of the extent of the emergency. Additionally, will be responsible for filing all reports required for regulatory compliance. Plan and carry out well control and relief well operations. 5. Exxon Drilling Superintendent - Advises Anchorage Drilling of situation and coordinates on-site efforts. 6. Contract Superintendent - Responsible for safety of contractor personnel and r'ig. IV. Person in Charge of Overall Drilling Operations. Anchorage Exxon Drilling Manager -Mr. A. L. Hermann Office telephone: Residence telephone: 907/263-3752 907/276-4562 -3- I. II. III. Section (2) POLLUTION CONTROL PLAN BEAUFORT SEA, BEECHEY POINT OCS-Y 0189, 0190, 0191, 0192, and 0193 Objective. The following plan outlines actions and procedures considered essential to conduct operations while minimizing exposure to pollution. These plans should be supplemented by the experience and knowledge of those involved in the operation. Location. Gravel island locations will be designed and built to accommodate the drilling rig, camp, and necessary supplies for a winter drilling operation. The locations will have a freeboard of 12 feet which is designed to resist ice override and lateral movement and is above the maximum indicated tide based on observations along the surrounding coast. Figure 1 shows the island proposed for the first well, OCS-Y 0191 We 11 No. 1. I s ~d~d~i~am~`~e~e~-~i~"s~-~48~-~f~ee~.t~.~w~h.i~c~i~s~.~l~g~.u.~h-~.ta`permi t dril!!9.Q..,......t,.~,Q,,~..e~p.].o.,r,,a~,t,,!,~..n,, wells if necessary. If it is desired to later use this island for pro~'O-~l~"ib-fi' p-o-r~i6§-6~; ~n be enlarged to meet this need. Note that in addition to the 11-foot freeboard, a 5-foot berm is,.,~,~,~" planned for the perimeter of the island. ~protection is also~an~n_e,,d_.~ to control slope erosion. The rig and associa~-d-~q-O~ent a~d su~'~lies will either be trucked over ice roads to the location or will be barged durin~ the summer open water period. - .... --., General Site Details. Figure 2 shows an approximate rig layout. The location and operating plan will be designed to provide containment of all drilling operation effluents that could be considered as pollutants. An im.p.e~.m..ea.b.].e......_s...,h....e.,et wi..)..!.._be p.laced~`u~d~`~r~`i~h~`~d~r~i~l~`~i~g~.r`~.i~g`~t~..c~.~]]e`ct and divert any liquid waste for proper disposal. In addition to this, drip pans and other containment measures will be provided under the ~-~{"~i'6-{ ...... A'h'd rig ma- chinery. Good housekeeping will be stressed on all parts of the location, with emphasis on minimizing contamination of the peripheral drainage from the i s 1 and. Fue-q~-~-~.i~1]~-b-e-~s~t`~`~.r~``~i~n~d~u~.b.]~``e~-w~a~]]~ed- ,steel......ta~ks..],c~t~ed on waa, A_t_6~_n impermeably.., lined ..a..r~..a,.. inside a.g~,avel berm; Sewage and kitchen waste ~"TT""6'6 ........ ~..F.16.E6..~.~ed .... ;~h"~'c~gh '~'"'l~{'~"{~J"~"~'~roved biological treating system with excess sludge being incinerated and the disinfected liquid contained in a steel holding tank. Treated effluent may be used as drill water, if needed, with excess being injected as described below. A lined reserve pit will provide space for emergency discharge of fluids, if required, and will normally be kept dry to maximize storage capacity. Additional precautions will be taken to prevent drainage of hydrocarbons to the sea. After freezeup, the surface of the island will be sprayed with water to form an impervious ice seal. This should prevent liquids spilled -4- on the surface from draining downward into the gravel fill. Also, any spills will be cleaned up as soon as possible. Snow contaminated by toxic substances will be incinerated on site or hauled to a disposal site on shore. The island surface will be thoroughly cleaned after clearing the island of all drilling equipment. Since there are no natural containment traps at this offshore location, mechanical devices including spill booms and skimming equipment outlined in the Oil Spill Containment and Cleanup Plan will be used to contain an open water spill. After freezeup, the natural snow surrounding the location will be used to stop the spread of any potential pollutants. IV. On-Site Spill Response Team. Selected members of the drilling and roustabout crew, under supervision of the Exxon Drilling Superintendent, will be designated as the On-Site Spill Response Team. This team, along with on-site Exxon and contract drilling supervisors, will be given periodic instruction in all phases of pollution control including the following: A. Pollution prevention and good rig and location housekeeping prac- tices. B. Pollution detection methods under different climatic conditions. C. Control and containment methods for toxic spills under different climatic conditions including drills in using the various items of containment and cleanup equipment listed below. D. Cleanup and proper disposal procedures. The ABSORB Manual will serve as a good training manual for this instruction along with the Exxon North Sl.o...~e Emergency' .M~a...n..~...a] ~.~.b~ich is under preparation. The la-t-i~-'"'~'~-n-Li~'l ......'W"~l"ll ......... '~6'h'~'~l'ih ...... ~ more complete description of the On-Site Spill Response Team's assignment, duties, and~ training. ~i The On-Site Team will be responsible for investigating and handling all minor spills, both on location and between Deadhorse and the location. This team will be able to handle most minor operational spills of oil, which will be collected with sorbent material and disposed of by incineration. At the discretion of the Exxon Drilling Superintendent, additional labor crews and material can be mobilized from Deadhorse to assist the Spill Team in cleanup. For spills beyond the capability .of the On-Site Team to contain or to clean up, the Exxon North Slope Oil Spill Response Team, as outlined in the previously mentioned Exxon North Slope Emergency Manual, will be activated to the degree required by the severity of the spill up through complete loss of control and blowout of a well. V. Available Equipment and Materials. To allow for deployment of pollution control equipment and construction of dikes, berms, and other structures, the following equipment wilt be maintained on location and at Deadhorse: -5- On-Site At Deadhorse** I Caterpillar 966 Front Loader 1 Caterpillar D-7 Bulldozer I Spill Containment Boom* (1,000 feet long) 1 Oil Skimmer* *Summer dr i 11 i ng only. Front End Loaders Rolligons Belly Dumps Boats, Barges, and Tugs Labor Crews Graders, Bulldozers, Trucks Ditching Machines ABSORB Co-op Equipment **Equipment available at Deadhorse is expected to require 6 to 12 hours to mobilize to the location, dependent upon weather conditions. In addition to the equipment shown above, the following construction and absorbent materials will be maintained on location to combat oil spills: Polyethylene Sheeting and Plastic Bags 10 Rolls - 5/8" x 3' x 150' Absorbent Sheeting Barite Bentonite Lost Circulation Materials (Walnut hulls, cellulose, etc.) Centrifugal Pumps and Hoses Additional spill cleanup equipment including oil mops and sorbent materials can be mobilized from Anchorage to Deadhorse within 4 to 6 hours. Also, additional personnel and equipment can be rapidly mobilized from the Alaskan Beaufort Sea Oil Spill Response Body (ABSORB) Organization, of which Exxon is a member. VI. General Operations ProcedUres. A. Site Surveillance. Under normal drilling operations the Exxon Drilling Superintendent will be responsible for conducting frequent reviews of the drill site to ensure that equipment maintenance is kept up to standards and that proper on-site procedures are followed. The items to be checked during site surveillance include, but are not limited to: 1. Mechanical condition of tankage, lines, and pumps. 2. Correct positioning of flowline valves. 3. Operation of relief valves. 4. Fluid levels in drip pans, containment pits, etc. 5. Condition of drains (ensure clean and unfrozen). 6. General condition and cleanliness of rig. 7. Condition of spill removal equipment and material. -6- 8. Proper operation of sewage treatment facilities. 9. Snow removal status. 10. Check outer edges of location to be sure no seepage from pad. In addition, the following procedure will be followed while operating on these locations: 1. The Exxon Drilling Superintendent will designate "Briefing Areas" where all personnel will meet in case of emergency and where emergency equipment will be kept. 2. The site will be equipped with an Exxon operated radio system. 3. A list of current emergency telephone numbers and a map of the local area will be maintained by the Drilling Superintendent. B. Inject ion Procedures. A primary feature of the drilling plan will be to provide 13-3/8" x 9-5/8" annular injection capability. The well casing program is designed to set 13-3/8" surface casing through the major gravel sections and below any possible freshwater zones. The 9-5/8" protective casing will be cemented to isolate the saltwater sand sections from below the surface casing shoe to approximately 7,000 feet for injection of lube oil, excess mud, melt water in the case of summer operations, waste waters, and well test liquids. The following procedures will be followed: 1. After the 9-5/8" casing string is set, injectivity tests will be conducted down this annulus using drilling mud and make-up water, limiting injection pressure to below the casing collapse and/or below surface line pipe and pump burst ratings. The injection pump will be used to inject all fluids. 2. Use the supplied forms to record daily the fluid injected into the well. 3. Prior to injecting any fluid down the annulus, notify the Dri 11 ing Superintendent. -7- ! RIG I! LAT. 70° ~,3' It.lS".,L ,~'.T BEAUFORT SEA ........ NEAR MOUTH OF T ~.uu~.,u- gl SAGAVANIRKTOK R. I,O ~1 I I 0 I ~ 3 4 '~ I I ~ t ~ ~ t I ' SGA~[ I~ ~1~[~t FROM: USGS~ QUAD SHEET BEECHEY POINT (B-2) PLAN I00' 200' 480' SLOPE I , ~ //o-: .o_. o .o_o-o:o .. - o -.oo:o oi_o_--o"0-,,° o:o_O ,, o ~,--~. r I ,r--./,/c, .° o- o - o ° u.. o ., o ° ,.,- o i-,~ o _ - .. "' "'o o... &\II - I I ,i .,~/_o:..Oo-OOO o o ;..O_oo o_ .o oc,-.°toC, lOoo"to-'ooO_o..?..::../~A ' . =i I · //_° "°;0 oo . .. ,_--'_oO~)o.GO - - o,° _° "o0Oo °_M~I'tWT"q'~;~ I II /~,.,.o0,, o oO o oo'o°o_o -..oo'' °,:,o"-° o,°0 °_"_°o .... Iro'oO°_ o o o o o -- o _ o o._ .1-o0 oo _o _ ~ .- oZ'G--.d~'l- qL I /Y~..-o- _°..o o _0 oo.o- o .' onoo /'_ ° o" oo .,,~, --_ , , · /;~' -oo o °-o · -_ o ,.e ' ° ° '-- =-o ~-,... o o _o o o~_%~'"_o o ~_~ -mi I · A'o-O'.oo°°o~°oo"o °°-- ooO°~'°-°-~]--°-°-°o'-' ~.°-"_oo&% -~1 -mi I //_ooo'o0°'ro_o°*--_°oO .Oo°. o ..o., o o o o oo_o~ ooy..-o~_l -I I //b~ .o°.°o.°_-..o_-ooo o, oOoO,-,o .o., o. °0:o~','Oo~ 1 & t /~' ooo*,oo°.o_-"o_ o-o - ° .~,0o0 o oo o-o ,,o.--~ o o OOo o ~ -0~..- :~-% I · ! //' ,,. d~-- -- - ,,, .._ m A -. - - -- -- · ' · :~/.---,/.--',/~/....~/"",/...~,-'-.~,- '~,.~, -, . , ',- ~ .' ~ ' ~- ' '~ '-'/ %/. ~/- ~//<//<//</-/,,//~/./,,//t/-/~/ · PURPOSE: PROVIDE DRILL SITE FOR . . HORIZONTAL EXPLORATORY WELL ', t ~ EXXON OCS-Y 0191 4~ 50~ ' VERTICAL PROPOSED GRAVEL ISLAND WELL NO. I t ! I ' "1 ~ 6' 12' 18' 24' SCALE IN FEET IN BEAUFORT SEA NEAR MOUTH OF SAGAVANIRKTOK RIVER. DATUM: MEAN SEA LEVEL BEECHEY POINT BLOCK 654. APPLICATION BY: EXXON CO., U.S.A. SHEET I OF I DATE: l i-El-BO II. FIGURE 1 ,Pa ge 8 . .. 42' EXAMPLE RIG LAYOUT tl/ 40' ::::::::::::::::::::::::: eeeeelleeeeee.leeeeelelellleeleleeleeeelilllll Ill,lllileeeeelleeellelellellllleee®llelelleel PIPE RACK 130' // FIGURE 2 Page 9 Ii:i:!:! l::::::J i~::~ Section (3) CRITICAL OPERATIONS AND CURTAILMENT PLAN BEAUFORT SEA, BEECHEY POINT OCS-Y 0189, 0190, 0191, 0192, and 0193 Certain operations performed in drilling are more critical than others with respect to well control and for the prevention of fire, explosion, oil spills, and other discharges or emissions. The following list details those operations and the conditions under which they are to be terminated. I. Fuel Transfer Procedures. Operations involving fuel transfer are critical in that mistakes occur- ring at this time will likely lead to an oil spill. It is the Drilling Superintendent's responsibility to ensure that proper procedures are implemented during each fuel transfer. A detailed procedure checklist will be provided and is to be followed before fueling operations commence. General guidelines for these operations are: A. Ensure by testing or inspection that all equipment and lines are in proper working order before each transfer begins. Lines are to be pressure tested to 1.5 times the maximum anticipated transfer pressures. B. Review procedures with all personnel involved to ensure that everyone knows his job. C. Double check that all valves are positioned correctly before transfer begins. D. Make a visual inspection of equipment once transfer begins. Keep track of volumes and pressures during pumping. Shut down operations immediately at the first sign of pressure loss or leakage. II. Well Testing. Well testing operations require careful planning and safe procedures to keep the risk of an oil spill at an acceptably low level. No open-hole--~ drill stem testing will be performed in exploratory wells. Any necessary test work will be accomplished utilizing a production-type test through casing. It is the Drilling .Superintendent's responsibility to ensure that the following special procedures are carried out during well testing: A. Ensure that all test vessels are inspected prior to testing. In addition, flowlines should be tested to 5,000 psi to assure pressure integrity. B. Review test procedures and equipment operations with all involved personnel just prior to start of the test. Ensure that everyone knows his job assignment. C. Double check positions of flowline valves prior to commencing testing. -10- I . I , D. Check equipment for leaks after testing is initiated. Monitor pressures and flow rates during the test. Shut down operation immediately at any indication of leakage. III. Drillin9 in Close Proximity to Another Well. Not anticipated unless a second well is drilled at the location. In that event, the first wellbore will be plugged and abandoned in accordance with OCS Arctic Order 3 prior to spud. Also, the necessary surveys and precautions will be taken to avoid hitting the existing wellbore. IV. Running and Cementing Casing. The following guidelines shall apply: A. Careful monitoring for well flow should be taken during the last trip in the hole with drill pipe. B. The mud weight shall be greater than, or at least equal to, that with which the last drilling took place. C. Check for normal hole fill-up and mud displacement on trip out of hole and while going in hole with casing. D. Monitor flow line returns while displacing or cementing. E. Good care of hole conditions shall prevail. Running casing will not be started if the well is not static. V. Cutting and Recovering Casing. A. Prior to cutting any casing, the absence of annulus pressure will be verified. B. After cutting, the well will be carefully monitored for well flow. The well will be static prior' to pulling the casing out of the hole. C. The mud weight shall be equal to or greater than the mud weight used to drill the interval at the depth of the cut. D. Casing will be pulled at a slow enough speed to prevent swabbing and to ensure normal hole fill-up. VI. Logging or Wireline Operations. The drilling mud shall be adequate to contain any exposed formations. The well will be monitored and kept full at all times. Logging shall not be initiated until the hole is stable (no lost circulation) and mud is not being gas cut. VII. Well Completion Operations. The Exploratory Drilling Plan for these offshore wildcats covers only the drilling and evaluation phase. If well completion is anticipated at a -11- later date, the well will be plugged and temporarily abandoned in accordance with OCS Arctic Order No. 3. VIII. Drilling Into Abnormal Pressure Zones. Abnormal pressure is not anticipated while drilling to the planned total depth in this well; however, a mud logging unit will be on location and the usual abnormal pressure indicators will be monitored at all times below structural casing. IX. Determining Formation Pressure Integrity. Formation pressure integrity tests will be run after setting conductor, surface, and protective casing strings to ensure that formations are competent for the planned mud weight program. No problems are anticipated with lost returns in this area. X. Drilling Below Conductor Pipe. Well control contingency plans will be in effect while drilling below the conductor pipe. Drilling will be discontinued if: A. Minimum quantities of mud material on 'board are less than those reserved for emergency use as shown in the Mud Program section of the Application for Permit to Drill. B. Blowout prevention equipment as outlined in OCS Arctic Order No. 2 fails the testing requirements of said Order. XI. Plugging and Abandonment. Plans are to plug and abandon wells in accordance with OCS Arctic Order No. 3. Plugging will not commence if the well is not under control. Blowout prevention equipment will not be removed before placing surface plug. XII. Encountering H2S. H2S is not expected in the planned area of operations, but if it is encountered, drilling will be stopped and measures taken as described in the H2S Contingency Plan contained in Section (7). XIII. Drilling Structural and Conductor Casing Holes. The possibility of encountering shallow biogenic gas-bearing zones in the depth range of 60-115 feet BML over portions of the planned explOration area is recognized, and appropriate safety measures will be provided. The mud logging unit with gas and H2S detectors will be in operation from spud at the mud line to total depth, and the mud vacuum degasser will be available for use, if needed. In the event gas is detected, drilling will be stopped and flow checks will be conducted. If necessary, mud weight will be increased to control the well. -12- Section (4) OIL SPILL CONTAINMENT AND CLEANUP PLAN BEAUFORT SEA, BEECHEY POINT OCS-Y 0189, 0190, 0191, 0192, and 0193 I. Objectives. The purpose of this section is to outline action to be taken in the event of an oil spill on the locations included in this Exploration Plan. A. Notification and compliance with .all regulatory agencies. B. Spill cleanup procedures. C. Recovered fluids disposal procedures. D. Coastline Sensitivity Atlas. II. Notification Requirements. In the event of an oil .spill, the Exxon Drilling Superintendent shall immediately contact the Anchorage Drilling office and issue a report including the following information' A. Date and time spill occurred or was first observed. B. Where spill occurred and present location. C. Estimate of amount and type of material spilled. D. Environmental conditions (temperature, wind, etc.). E. Description of area likely to be affected. F. Cause of spill. G. Action taken to combat spill. Anchorage Drilling will be responsible for making contact with Head- quarters Drilling, Law, and all required governmental agencies. General procedures for Anchorage Drilling to follow in this regard are: A. Contact U.S. Coast Guard by telephone and notify that spill has occurred and is being investigated, only if the spill threatens to enter any navigable waters (lakes, streams, ocean and/or ice). B. Contact USGS by telephone for spills reaching navigable waters, if the well is outside the three-mile limit. C. Notify Headquarters Drilling of the spill providing available de- tails. D. Notify Alaska Department of Environmental Conservation by telephone for spills within three-mile limit. -13- III. Oil Containment Plan. A. Before Freezeup. (Summer Operations) In the event that an oil spill occurring before freezeup at the location cannot be contained on the drill site or in the contingency pit and pollutants reach open water, the following steps will be taken to contain the oil spill' 1. Stop the spill at its source unless it is the result of an uncontrolled blowout, in which case see Uncontrolled Blowout Plan. 2. Mobilize all equipment required to contain the spill fluid. 3. Ascertain the direction of current (general direction in which the spill is moving). 4. Using boats, deploy the spill containment boom to surround the spilled fluids, block the fluid flow, and collect the spilled fluids. As the 1,000 feet of boom will not surround the entire perimeter of the island, it will be necessary to place the boom to block the expected path of spill migration. Atypical deployment diagram is shown in the attached Figure 3. 5. Once the spill containment boom is in place, deploy the oil skimmer directing it into the location of the highest oil concentration. 6. Make a sweep periodically of the outside perimeter of the containment boom to assess whether any oil has escaped to open water. 7. Mop up any residual fluids with absorbent materials and recover all contaminated ice, snow, and gravel, placing contaminated materials in containers for disposal. B. During Freezeup. During freezeup limited operations may be possible to contain and mop up spilled fluids depending upon the extent of the ice cover and ice conditions. 1. If. sufficient ice leads exist to allow navigation of small boats in and through open ice, the following procedures may be initiated- a. Deployment 'of the spill containment boom may be feasible if open water exists around the drill site area. b. The oil skimmer may be deployed in large ice leads to mop up isolated spills. c. Sorbent materials should be used where applicable to clean up oil spilled in small ice leads. -14- d. An oil mop can be used in conjunction with a small boat to recover floating oil slicks in ice leads. 2. If sufficient ice leads do not exist and/or only a thin continuous ice layer exists, the general perimeter of the spill should be staked and movement of the spill area closely monitored. In this case, the procedure will be to allow the ice pack to freeze sufficiently so that equipment and personnel can be mobilized for cleanup procedures identified in the after freezeup section. NOTE: SAFETY OF PERSONNEL IS A MAJOR CONSIDERATION WHILE CONDUCTING CLEANUP OPERATIONS DURING THE PERIOD OF FREEZEUP. PERSONNEL SHOULD NOT OPERATE ON ICE PACKS HAVING QUESTIONABLE INTEGRITY OR ON FREE-FLOATING ICEBERGS. C. After Freezeup. (Consolidated ice pack existing.) After freezeup the primary defense outside the island perimeter will be the naturally occurring snow on top of the ice. Recent information indicates this is preferable to building a snow berm around the location for limiting the spread of a spill and for preventing the spill from getting under the ice. Cleanup operations after freezeup should be aided by the increased viscosity of fluids at low temperatures. Recovered fluids and contaminated cleanup materials (snow, ice, absorbents, etc,) should be placed in steel containers for disposal. D. Spill Cleanup Procedures. The spill cleanup efforts at the locations will be directed toward returning the affected area to as near natural state as possible. Minor spillage of'fluid will be cleaned by use of absorbent materials and recovery of contaminated materials such as gravel, etc. These soaked materials will be placed in containers for future disposal. Major oil spillage will be handled by use of conventional skimming equipment. Snow, absorbent materials, and other contaminated ma- terials will be recovered and processed by incineration. IV. Coastline Sensitivity Atlas. The ABSORB Organization is currently Preparing a Coastline Sensitivity Atlas which will show locations and rankings of sensitive areas, along with specific methods to protect each area from an oil spill. Two types of areas are to be considered as follows: biologically sensitive areas such as fish spawning and bird nesting areas, etc., and socially and economically sensitive areas such as settlements, subsistence hunting, and commercial or sport hunting and fishing areas. Target date for completion of this atlas is mid-1981, which is prior to anticipated spud date of any wells in the exploration area. Oil spill contingency plans for each well location will contain a description of any sensitive areas that will be affected by the exploration operations and will include appropriate countermeasures to minimize the environmental impact of a spill. -15- 0 0 H 0 H I, Section (5) UNCONTROLLED BLOWOUT (RELIEF WELL) PLAN BEAUFORT SEA, BEECHEY POINT OCS-Y 0189, 0190, 0191, 0192, and 0193 I. Scope. This section of the Contingency Plan covers action to be taken to initiate relief well operations in the event of an uncontrolled blowout in the area of operations. The possibility of this occurring is considered extremely low because of the extensive precaution to be taken to prevent loss of well control. This section does not deal with control of pollution resulting from the blowout'. This is dealt with in Section (2) of the plan and in the Exxon North Slope Emergency Manual and the ABSORB Manual. II. Well Ignition. The blowout well will be ignited at the discretion of the on-site Exxon Drilling Superintendent if there is immediate danger to personnel. Otherwise, the well will be ignited for safety and to limit the potential for environmental impact only after discussion with Exxon management and the proper governmental agencies. III. Equipment and Supply Mobilization. In the event of a blowout, all equipment necessary for constructing the relief well pad would be immediately mobilized from Prudhoe to the location. The equipment used and transportation method will depend upon the time of the year and availability. The ABSORB Manual contains comprehensive lists of construction companies located at Prudhoe. A drilling rig will also be located at this time and planned for mobili- zation as soon as the pad is available. With the high level of drilling activity at Prudhoe and anticipated industry cooperation, it is antici- pated that a suitable rig can be obtained without undue difficulty. If necessary, a rig under contract to Exxon could be transported from the Pt. Thomson area, or, as a last resort, a Herc transportable rig could be flown into Deadhorse from another area. Depending on the time of year the blowout occurred, it may be necessary to obtain a helicopter transportable rig. Supplies and equipment required for drilling the relief well would be obtained and located at a staging area at Deadhorse to permit rapid transportation to the location as soon as the relief well pad was completed. Relief well tubulars and wellheads will be kept at the Exxon Deadhorse warehouse facility. Gravel for the relief well pad will also be available at a nearby location. It is anticipated that most rig and supply movement will take place over existing ice roads or by tug and barge during the summer season. During the periods of breakup and freezeup, all transportation will be by airplane, helicopter, or possibly air cushion vehicles. -17- IV. Relief Well Location. The optimum location for a relief well pad is dependent upon several factors existing at the time of the blowout, including blowout well depth and both current and projected wind and current conditions at the location. In this nearshore area, currents are strongly influenced by wind direction. Wind patterns have been recorded on a monthly basis at the Prudhoe airport. An attempt would be made to place the location in minimum water depth at a distance from the blowout well to provide optimum directional drilling parameters for the relief well. In case the blowout well was directional, an attempt would be made to locate the relief well pad such that the relief well could be drilled as a straight hole to intercept the blowout wellbore. In all cases, the relief well pad will be placed a sufficient distance from the blowout well to ensure personnel and equipment safety for the duration of the anticipated drilling program. It is anticipated that in most cases the relief well pads would be located in water depth similar to the original pad. V. Pad Construction. After freezeup a gravel location large enough to accommodate the drilling rig and kill equipment would be constructed using construction techniques similar to those used for the original pad. All available equipment that could be used efficiently would be utilized. As soon as pad size is large enough to support the drilling rig and associated drilling support equipment, the rig and equipment may be mobilized to the pad over ice roads, ice conditions permitting. Pad size could then be expanded as necessary to accommodate the kill equipment and fluids which will not be required until the relief well is drilled to TD. Another possibility, depending on timing, is that the kill equipment could be brought to the location on barges after breakup. During open water periods, a relief well gravel location would be constructed utilizing the proven technique of using barges and tugs to transport the gravel from the Prudhoe Bay West Dock to the location. During periods of breakup and freezeup, pad construction would not be attempted until such time as conditions were safe for personnel and equipment to operate. In this case, all supplies, equipment, and material necessary for construction would be assembled at the nearest staging point such that construction could begin immediately when safe to do so. -18- i, Section (6) EMERGENCY ISLAND EVACUATION PLAN BEAUFORT SEA, BEECHEY POINT OCS-Y 0189, 0190, 0191, 0192, and 0193 I. Scope. The gravel island locations planned for the subject area are designed in accordance with industry experience in the Canadian and Alaskan Beaufort Sea and will be certified as required by OCS Arctic Order No. 8. With ice loading expected under normal conditions, these islands are not expected to be displaced laterally at any time. Despite this, an ice pressure and ice movement monitoring program will be conducted on at least the first and possibly additional locations. Ice monitors will be installed as soon as ice conditions are safe for personnel to operate. II. Emergency Plan. The potential for island movement or shearing exists primarily during the period preceding freezeup. During this period, high winds could direct the sea ice pack against the location, causing the island to be displaced laterally. In this situation the integrity of the well would be in question due to shearing above the mud line level. It is anticipated that sufficient time would be available to complete actions to seal the well and evacuate the location, ensuring prevention of pollution to the environment and safety of personnel. In the event of this emergency, the following steps will be followed in the priority listed: A. Pull pipe to the lowermost casing shoe and set a storm packer with back pressure valve at 100 feet BML. Hang pipe on storm packer. (Note: Storm packers shall be maintained on location for the 13-3/8" and 9-5/8" casing strings throughout the period before and during freezeup. ) B. Pull out of the hole and lay down the drill string and packer running tools. Close and manually lock the blind ram preventer and drain the BOP stack and lines. C. Demobilize and secure the camp and evacuate all personnel with the exception of a skeleton crew to complete operations listed below. D. With sufficient time available and annulus injection capability established, all fuel (with the exception of a minimal supply) shall be injected subsurface to restrict the quantity which could be spilled to the environment. Contents of the sewer plant and other miscellaneous liquids should be injected and all unnecessary fuel lines should be drained. Upon completion of injection, displace annulus with drilling fluid. Secure the rig and evacuate all remaining personnel. -19- J, Section (7) H2S CONTINGENCY PLAN BEAUFORT SEA, BEECHEY POINT OCS-Y 0189, 0190, 0191, 0192, and 0193 I. Scope. Although an examination of well records within a lO-mile perimeter of the subject area has shown an absence of H2S in the formations to be penetrated by the wells drilled under this plan, certain precautionary measures are to be taken for personnel and well safety in case H2S is unexpectedly encountered. This plan describes the precautions and actions to be taken for this possibility. II. General Requirements. A. Briefing Areas. Two briefing areas will be designated at each location. The Exxon Drilling Superintendent on location will designate which briefing area is to be used depending on wind direction. B. Wind Indicators. Windsocks, 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. C. H2S Detectors. Continuous recording/monitoring-type H2S detectors complete with visual and audio alarms will be monitored at all times by mudlogging personnel from the mud line to total depth. Detectors will be located at the bell nipple, shale shaker, and in the living quarters. Alarms. will be set to go off when detectors sense an H2S concentration in excess of 5 ppm. D. Mud Treatment and Checks. In the event the mud becomes contaminated with sulfides, a supply of "Milgard" (100% zinc carbonate) or an equivalent scavenger will be available in Deadhorse in sufficient quantity to treat the entire mud system with 2 lbs. per barrel. Below protective casing, daily mud checks will be made to determine the presence of sulfides in the mud using a Garrett Gas Train or equivalent. E. Well Site Communication. Portable two-way radios will be provided on location in order to permit rapid communication between supervisory personnel in case of an emergency. -20- F. Safety Equipment. The following minimum safety equipment will be provided at the location: 1. Personnel air breathing equipment sufficient for the on-duty rig crew, all supervisory personnel on location, and the Mud En- gineer. Spare bottles will be provided. 2. Hand-held H2S detectors with refill tubes for both H2S and S02. 3. Vapor tester (explosimeter). 4. H2S lead acetate ampoule detectors. 5. Resuscitator with spare oxygen bottles. 6. Rope and harness sets for going into H2S areas. 7. Stokes litter or equivalent. III. Training Requirements. I , Periodic on-site instruction and training will be given to rig crews in the following areas: A. Toxic effects of H2S and SO2 gas and the need for the "buddy system" when dealing with H2S. B. Proper use of breathing apparatus and safety equipment and location of such equipment. C. Emergency well procedures and drills. D. First aid with particular emphasis on the physiological effects of H2S. IV. H2S Emergency Procedures. A. If at any time as much as 10 ppm of H2S is detected, the following steps will be taken: 1. The person detecting the H2S must immediately notify the Driller. He must then notify 'the Exxon Drilling Superintendent and contract Toolpusher. The Exxon Superintendent and contract Toolpusher will bring portable gas detectors to the rig floor in order to find the source of H2S. 2. 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 gas masks. All other personnel will immediately leave the'area and go to the upwind briefing or other safe area. -21- 4. The contract Toolpusher will alert all personnel that an H2S emergency exists. He should be prepared to shut off the Forced Air Circulation System in the living quarters. 5. The Mud Engineer will run a sulfide determination on the flowline mud. 6. A maximum effort must be made by supervising personnel to resolve the cause of the H2S and to suppress the H2S as quickly as possible. Drilling must not proceed until the cause of the H2S is determined and the ~ is circulated. 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, mudlogger unit, mud storage room, etc. All persons who remain in the potential danger areas must utilize the "buddy system." 8. The Exxon Drilling Superintendent in charge will notify the Exxon Operations Superintendent of current conditions and actions taken. 9. The on-duty Exxon Drilling Superintendent 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 Exxon Drilling Superintendent in charge will notify all approaching vehicles and helicopters to stay upwind and to be prepared to evacuate nonessential personnel. 11. The Exxon Drilling Superintendent in charge will alert the Deadhorse dispatcher to assure continuous radio watch. The U.S. Geological Survey and U.S. Coast Guard must also be notified. B. If the H2S concentration exceeds 20 ppm (from an increase in gas cut mud) and the well is not attempting to flow, the following steps will be taken: 1. The person detecting the H2S must immediately notify the Driller. He must then notify the Exxon Drilling Superintendent and contract Toolpusher. 2. Driller will shut down mud pumps and continue to rotate drill pipe. 3. 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. 4. Once air breathing equipment is on, the Driller should: -22- a. Stop rotary. b. Pick up kelly above rotary table. c. Be ready to hang off and close the BOP's if necessary. d. If well control problems develop, shut in the well. 5. The contract Toolpusher will alert all personnel that an H2s emergency exists. He must shut off the forced Air Circulation System in the living quarters. 6. All personnel not listed above must report to the upwind safe briefing area for 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. 7. Always put on a portable air breathing mask before proceedng to assist one affected by the gas and utilize the "buddy system." If the affected person is stricken in a high concentrated 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 contaminated areas. 8. The Exxon Drilling Superintendent in charge will notify all approaching vehicles and helicopters to stay upwind and to be prepared to evacuate nonessential personnel. 9. Notify dispatcher to alert heliport and establish 24-hour watch. Notify appropriate state agencies in addition to USGS and USCG. 10. DO NOT PANIC. C. The Exxon Supervisor and contract Toolpusher will assess the situ- ation and assign duties to each person to bring the situation under control. When the severity of the situation has been determined, all persons will be advised. The Exxon Supervisor and contract Tool- pusher will: 1. Direct corrective action. 2. Notify the Exxon Operations Superintendent in Anchorage on action being taken. -23-