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Home My WebLink About100-271Page 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, 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 Aprii 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 plu~~ed and abandoned. It is my recommendation that the status be chap ed 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 .. ' ~'~ ~ ~ ~ 4 4 2009 2/4/2009 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 other Exploratory 2. NAME OF OPERATOR Exxon Corporation 3. ADDRESS OF OPERATOR Pouch 6601, Anchorage, AK 99502 4. LOCATION OF WELL (REPORT LOCATION CLEARLY. See space 17 below.) Well No. 1, 1777' SNL & 708' AT SURFACE: EWL Blk 654 ~~~~~~~~~~ Well No . 2 , 17 7 7 ' S N ~~~~~ &~ 8 .wL, B ik h 5 4 16. CHECK APPROPRIATE BOX TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA . n Approved. audget Burgau No 42.F 5. LEASE ~ `' , ,,. OCS Y=1.9,;1 6. IF INDIAN, Af~QTTEE OR ~RIBE,(VAIVj~I ;p _c. 7. UNIT AGREEI~IEN'f ~IAME:_; B. FAR ~', - ~' t® 9. WELL NO - ~' ~^ 10. FIELD OR WILD~A~-NAME; -- _- 11. SEC., T., R., ~` _. ~1ND S`~)F~~l~Y OR ~~1REA 654= (..i c ~ 2p, T . 10 N, R ~! 7- ~;;;~ jJ~ l; , 12. COUNTY OR Q/>rR~~~~ 13~ ST~~E 14. API N0. 55.~~a'~1._00001`,.a~d ~- -. N, 15. ELEVATIONS,~~(~F8>3~jf DF,=:1(DR;~I~ND WD) ~"` l REQUEST FOR APPROVAL TO: SUBSEQUENT REPORT OF: Tnn cif i sl`--t~r~' ~+ l~ _ ..,, ~ ~'` ESL WD if TEST WATER SHUT-OFF ^ ^ - , . -' . FRACTURE TREAT ^ ^ ~ , . SHOOT OR ACIDIZE ^ ^ ;~ ~ '- ~ .,, REPAIR WELL ^ ^ (NOTE: Report res}Ifs.e-f multiple omple'tiun~pr zone PULL OR ALTER CASING ^ ^ change ortForm~-330.)s '-* ~- MULTIPLE COMPLETE ^ ^ - s Q ~ w _ CHANGE ZONES ^ ^ ~ _. ~ _ ' ~ ~•1 ;~ ~~ ABANDONS ^ ^ `~` = `~' .~,.. °u ~=~ .7 3 3 v ,a. (other) SuIjGE,rr~ent rPnnrfi of permanent abandonment :of ~cs~~~d 1o~~t~i~n ;. 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent deta?I~ antl give3per~jae~C~iates, including estimated date of starting any proposed work. If well is directionally drilled, ~iv_E~e~surface to °trogs and - ~ measured and true vertical depths for all markers and zones pertinent to this work.) =- ? T' ~% ` " ~=% `-: 't, ~ Ff. T ~t _ i1. ~ ' ...: ~J _.d ..-. L 7 " ~~ .~ ~ ..l• This island location was permanently abandoned on ~~~ter~b~-1r' `~~, 1983. Attached is a report detailing the abanddn~e~ri~ o~e~~ ©ns. _ :a D ~ II ~,i /M~ j - d ~~,! i ~ 1Q~3 ~ ~ ~ ~ ry _ ~_ J .a. =+ ~ _ Y m T MINA M~NAGEME!+tT 5 ~ ~; ~; ~ `~ , wA~~ ~L ' `' `~ a lw D ~ + . 1 ~ ~ '7 SJ = v Subsurface Safety Valve: Manu. and Type , ~ 5eT ~ ~ "~' ~Y s~ v ~ ~^ . w:,~;;r 18. I hereby c t foregoing is true and co ~ `% „ ~ v loration Coordinat~~ ~ ~ ,; w ~, SIGNED ~~~'"~-- ...~ TITLE Alaska DATE l~ ~~1~~3c ~ ~, ~ a A ~ _ (Triis space for Federal or State office use) ' nj ; .~~ ~ ~ ~~ ~ ~ il~~ ~ $ ~~Z ~ 'ROVED SY n>E ATiT~y)-~aHGI~E i~IS~' ~~'lydlS~ DATE ~ ~OITIONS OF APPROVAL, IF ANY: ~ - g .~ :• ` t_' p 'See Instructions on Reverse Side ~ FJ f e~-! fit; ±L ~- ~ ~ ~~~` ~ f~ DI~TRlC • :~, EI~ON COMPANY U.S.A. ~ '~ `~ ~ `~~ RiCElV~D: POUCH 6601 • ANCHORAGE, ALASKA 99502 ,t ~ i '~ ~~' ~ Utis d!S ~ Rl~T O~F1Ci =;9 t`v ~..~~ ('+, ~ ~ n EXPLORATION DEPARTMENT -- ALASKA/PACIFIC DIVISION ~' ~ `;i' ,;~ ~~s i.-~~~_ D.H. JONES MINERALS ~A1~GEMFiESA~T S~r'tt~'~ EXPLORATION COORDINATOR - ALASKA /'1iCV11~~~.~ P1~c~~r, October 11, 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 ,~ ~~ ~' ;~~7 ~~ ~ ~ ~ w~ n r„c', ;~:; ", ,;~~ gC~'i~~~: j~ py Y. _".,..,. Introduction FOLLOW-UP REPORT OF ABANDONMENT ,~ EXXON'S ISLAND DRILLSITE OCS Y-191, WELLS NO. 1 & 2 ~~G~lVcD GC8 DsS i RiOT €~r=;"{t;~; ~~I~dEBALS{'~LL~~a:~yrp~~'G~i~!`r~ i S r~v`r ~31i'iai3 ~t~i,Y1'1.::'_y ~~LN ~:~ 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 report we received from Dr. Robert Lewellen, who conducted the inspection dive for Exxon. After the inspection, a portion of the camp, all of the filter cloth, one loader, and a water truck were demobilized to Deadhorse. September 13-24, 1983 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 18' BML. The D-8 cat and loader were then used to backfill 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 strings which were pulled. 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. ~~ ~~. ~~ ~~~ ~~ ~~ Zu~B NB:sjm 40/27 Attachments :.....w_..._. ~h0 -2- l-J31 t ~ - ~ ~ ~ J- ''' 3 - 193 UN~ STATES • DEPARTMENT OF THE INTERIOR ~aEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for propossk to drill or to dsepsn or plea pack to • difhrsnt nsarwir. Ucs Form 9`331-C for such proposals.) 1. oil =as well ^ well ~ outer ExplOrat 2 NAME OF OPERATOR Exxon Corporation Form Approved. _ Budget Bureau No. L2-R 142! S.L E ~"e ~ :~- OCS Y-191 = " 6. IF INDtAN, Al~LOTTI~ OR 7RIBE~IAME 7. UNiT AGREEMENT NAME. ~ .:.; a FARM OR LEASE RAME is c_-~ ~ ~. - ~a- 9. WELL NO. _'_ " `- t 1 and 2 ": ~ s ~ ?~ - _ ~ c 10. FIELD OR WILaCIiTNAME - - Wildcat = ' - y ~ - - s•~- Il. SEC., T., R., Y:.OR~LK. AND S'1,IRVEY OR AREA 654, :Sec. 2Q, LION, 12 COUNTY oR ?A_Rlsli1 1!: STATE Offshore =. I ilaske ` 14. API NO. 5~ ~2t?i-00001 and 55-20I-00002 r• ~= = =~ 15. ELEVATIONS'~(SH,01N DF~-~CDB,~ AND WD) Top of island + 13.3 ~ ~lSL, WD 18' 1~-LC$iV5$I~ - -_ D~~- (NOTE Repoli ~rprw~ltsrnof~ lO~w3kipN ~onipletien or zone tA~nas/'1 i~ lY _ _ ~i 3 C _ - - C 3. ADDRESS OF OPERATOR pouch 6601, Anchorage, AK 99502 ~. LOCATION OF WELL (REPORT LOCATION CLEARLY. See space 17 below.) AT SuRFACE:Well No. 1. 1777' SNL b 708' EWL, -+~~R-P~~~~~+~% B1k22654 .AT_IQ'CAt_.QEPJli: We~No81k' 6~~77' SNL ~ 683' 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 AC1012E ^ REPAIR WELL ^ PULL OR ALTER CASING ^ MULTIPLE COMPLETE ^ CHANGE ZONES ^ ABANDON' ^ SUBSEQUENT REPORT OF: cation 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, nda give~peId ~ent~stes. including estimated date of starting sny proposed work. if well es directionally drilled, give subsurfste bcat+ens and measured and true vertical depths for all markers and zones pertinent to this work.)- - _ _ ;~ _ . - Approval is requested to permanently abandon this island ;iacation fn ~ccozdance with the attached plans. `.:' ; ' _ r_ - . _ - _ _ F ~ . s Abandonment details and drawings of wellbore No. 1 were proved on ti ~_~~_ ~: - March 29, 1982. ~~` ' ~~ " ' `;: ~: _ . Abandonment details and drawings of wellbore No. 2 were a~proired oa =.r -= April 13 , 1982. ~ . ~ _ `' - 2 , ;: ~ - - . - ,T '. - :- -_ ~ ~.. Subsurface Safety Valve: Manu. end Type c = ~ ~i ~ ' a ` "` Ft. c - @c- _ _ 18. 1 hereby certify the foregoing is true and t:otTect ^. Y ~- - ~• ~• . ~ ~._ `= - „= SIGNED TITLE DATf .3ttl~/ ~~* 2983 ~ (This span Ier Fsdecsl or Stats effies use) •_„ _ ~ _ ~: ~ _. ~ c: APPROVED ar ! ~ ' ~ T~QFFSHORE DIST. SUPERVISOR 'c -`~ = ~ ~ -_ ~ T- ~ AU~ 2 5 ~~3 SoNDITIS)N5 rJF APPROyA!, !F ANr: DATE _ '' `' r• ,ia ~~~ ~ ~ ~~ _ ~_ _ -ass fnatnrctlens sw- Rewne aids : ~ ,~ '~ ~ ~r ~' ~'~ .1!.~a'>1 °~~~~~ t '.AN OF ABANDONMENT ~lCON'S ISLAND DRILL SITE • OCS-Y 0191, WELL NOS. 1 AND 2 RECEIVED D18TRtCT O!L AND OAS OfFiCE . - ~::.~ 4 1983 Introduction This re ort has been ~~ '~- p 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 wank 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 ~~. ~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 majority of the baggs have been placed in a single layer, however from +10' MSL to -]0' MSL there is a double layer around 75x 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). ;Two wells were drilled from the island and their cellar box locations 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 peach 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. As shown in Figure 5, Well No. 1 has 9-5/8", 13-3/8", 20", a 28" x 32" x 36" refrigerated conductor, and 42" casings. The 9-S/8" x 13-3/8" annulus is filled with calcium chloride water. All .other casing annuluses are cemented to surface with permafrost .cement. i Well No. 2 is shown in Figure 6. This well has 9-S/8"; 13-3/8". 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; P ;~~~ • ~~~~~r ~ ~ ~ ~ all other casing annuluses are cemented to surface frost cement. A 42" diameter. approximately 40 feet long velocity is also located in the island as shown on Figure 1. not cemented. just backfilled with gravel. Sandbag and Filter Fabric Removal aECEIVgD with peg ~ ~~CE survey~~~pe~ jo~3 ?his pipe is -- - -- ~k~- ___. All sand bags and filter fabric will be removed frar- the island, both above and belay the water Level. A Large czanye will be used t0 conduct this operation either working iron the island surface or using a barge. The gravel from inside the sand bags will be used to fi21 in the areas mere the conductors are zeroved. The renaming gravel fz~n the sand bags will be damped in an irregular pattern on the island surface to provide a more natural appearance to binds and animals. An array Of -24 plywaood water fowl "nesting" boxes (George Dicky designed) will be installed. This activity will be coordinated with USF and W. Diver inspections will be aoa~ducted to ensure that slope protection mater' are retrieved; canfianati:on dives are sc3~eduled during the 1884 open water seasons. The empty sandbags and filter fabric will be hauled off the island and will be disposed of at an approved site such as the ::~~Lh Slope Borough's disposal yard in Deadhorse. Wellheads, Cellar, and Casing and Conductor Removals The wellhead sections and blind flange from the too wellheads will be removed and transported to the Exxon pad in Deadhozse. Exxon will provide the necessary 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 casing strings from both wells will be removed to a depth of at least 5 meters below the ocean floor as required by Alaska OCS Crdez No. 3 - Plugging and Abandonment of.i~ells. Subject to any permit restrictions explosives will be used to cut off the casing and conductor strings. Air drills may be utilized to drill between the casing atzings and outside the 42" conductor to loosen the cement and provide access for more explosives. After cutting the casings. they will be removed using • large crane and hauled aff the island for disposal at an approved dump site. Only qualified and exgerisnced 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 regulations pertaining to the transpozt~ storage, and usage of any and all sxplosives. ~~ _.~ \ ~ Project Schedule - - Subject to obtaining all of the required permit approvals, we plan to start work in early August 2983. 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. We; plan to maintain at least one representative on the pzojiect at all times. ~ " Island Fate _ - _- _._ - . . An artificial island with unprotected slopes will erode in a similar fashion to the natural barrier islands. ~in general, ~+ith 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 small spits which point in the direction of prevailing wirds. This process will probably continue tmtil 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 estimates can range from a single storm event to many pears. Figure 7 shows the fate of Exxon's Duck Island Yad 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. On the southeast and north- west sides of the island the spits are clearly evident and indicate that the island is eroding. ~.~ NB:rms t~~ ~~~~ 40/34 -• ,~ s~$1~~~~ ~ AHa ~ pFFtQE ~.~ ~~ 41°83 ,~~, ..~.-- ._--~ . I~'. ~ ..v,.K N`'cS~' .. ~ ~ . ~ ~L_ ~~.V ~. .~ -7 - ~ ~~/~~-- ti,:r ~ ~ ~t' .fit I ~ G _ i ~ .~ . ' ~ ~ ' . • '~• ~'~~. 1 iy~ . 1 ~ ~~ ~~~~~ 7a /~ ~ /~ ~ j i i ~ i~ !~ ' ii / ~ 't ... / t i ~~' .-- ---~ 4 j~~:. • ~ ! i ~~~tsn t ' it i I I ' 1 4 I ~ f f .'. .~ ~~~ ~ ~ i ~~~ , ~ Y~ , ~, ~i ~ _ .:. i~---- --- i. ,~ ~ ~d: ~~ _ ~;~ ~ ~ }_~ ---- ` i ~G 4 1°83 . ~ofuOef ~u~uc - _ "s i ` = ~ ~_ i ~ ~ sS ~ Z . ~ • i ~~ ' i` i , z~ :. I i i 1 ~ ~ s w W E ~ _ ' ++ •i ~l w • L a ! Ec ,_~ t ~~: i '" f t 2 !!i W~ w ~ i t~ w.. 0 W > ~ ~ N N u p ~ `_J` 0 .7 X x W =_ 0 ~ Y i r C~~ i ai Yw V v y ~ N A 2 a ~ , ,;-. ~; .I =f _ I i :' =~ .i •~ i , t RECEIVED ptBTRICT OtL ANO OAS OFFlCE Q Y O „~ N v ~ Q LL a' X ~, a ?< 2.0 YI).3 Sondbops ti Filter Fabric ----.. ~---~ 10 Ft. MWL 10 F T. ~/ ~-!~t~--,..~ 1.3 ~10 F7 \ •' -~". ~ . ' ~ ~ ' __ ~ ' FIGURE ~ 2 OCS Y-0191 Drillsife ,Seaward Sandbag Slope Protection Cross Section ~ ~ ~ ~.~r 1, ~ ~ ~ ~=; ~ ~ :, w d ~' j..: c__, ~°~, 3~,~~r: ' ~~ N `../ U ~oR .EXXON COMPANY U.S.A. BY BESSE, EPPS ~ POTTS AGE, ALASKA _ 3i ~3 F 135 FI ~~ 4.64~r ~: - . - ~ ~•} -- ~ _~_ • Toe Line START - ' Water Line ~EF1•DYUIFNT / ` - - +oA Line ` 2O ~- / Berm - • O ! - 1 240 r't. EOFt ~4Ft / 0 ~` 105 F!. + ~ l ~ -' ~ / ~ ,~ ~, - / $ ~ y&n ~ ~ c ~ 83 z ~. __ o ~~ F1G 3 i 2C yd3 Sandbog Coubte toyer 32 0o Eags I OC S Y 0191 DPlLLS 1Tc 2 2-~yd Sandbag 5-ngte L.oyer S~`hDE^G SLOFE FFSOTCC-ION ~YCUT 3 Z~ yd 3 Sondbo 7 70o Pogs ~' 9 berm 1000 Bogs ' - ~" ~ ~ ~ FOR - EXXON COMPANY U.S.A. ;~<~~~~ BESS`, Et FS ~ P0--~ S ~;~~NCQaG~, dlgSKd - 3a9•oaS~ c r r l GuQc 4- c'~Zl+a-Y P T. ~ ~ f. ~ Z C ELL /I /t • j~C-~ ~ L -RCTvs~ L I /o ~SauARE! 1 r ' _~ 'h •_ .• .• .. ~. . :... .: i ; .. ~' ;: ~- `• . . FLA.~4E S d•vs0 6E ' ?v ~r ~,• . Ii~~iN c.uO+r6K S• 1f~,AT . T1+s t ~~Y' Q~fht4. ovTl.EIT• :' ... i~ $E #~ A FE/ ..r4/dI Aa.vE .~ T7+E ~E~.,.~uT. ~. _ ~ = R ~ ' ;;;ss,,7yyy a ~~' °~ ~~I 7 M L1 IN s~awno.r Z-Z ., ~ r • - ... ;• ~A :~ .; .' i• ., t ~: .; -' ;: RECEIVED `' ~ DISTRICT -ti .- . Ott NVD CiA.S OFFlCt: ;: ~ A:G. ~ 1a83 .• -' .. ~--- .. w ~ 7 ~ _. .: ~ 4 ~ICtl~t, "~+.~vf 3v"* i r" IL EFRIG. C ~.+ove.ya . . F «~. s FOLD FAG ir' si:c ___c~r r't.ocic _ ~~}J d- SEQ. ., j o ~ .~ , -~.~ .,t w '~, ( - .~,I_ li~ 1 ~ ~ '' ~a c t~ ~ r .;, .300' . ' ! I " . ; - ' ~ • ~ `' ~. r2`~. ~'~~~. ~~ :AFL ~' ~~ 1~ ;~ o ~~ ~/ .~~~j o; ", i '- =a Imo- = ~ --+i ;.~ J` , i } i _ .. fps CF IAN -r---•i •`-- - 1 I i ~ ~ f 5.~~ I ~ ~ g.5~ ~ = .r ., ~. '- __ .. i p~ ~ /~. ~: b 2~ ''~ ~ ~` ' Gum' CGF NERE t d ~ . . I i .# L~ i I : ~ z6' t 32•~ ~ GB~~ REt. GoyD. Tp 60 $C~ - Qtl e. z5" ..,.i. ~ •. - s« Def.:t q.iou.r ,_ '~~~ O.Sl4 sr.t. ': BBC D ,~~ ~~RPLY L~~lE3 ALa 4 1°83 ,~.~ _ RCT~~k~l l~elES ,,,- ___- .~;~ .z o. zs.. =v .. o.I~ ~~ IyO7 ~? SCl-LE • ~ . ~~ ~ ` FAG. 6 ~ ~ ! ~~ CSLD FLCa TOP OF lSLAMD g Src 5.51 - a 5~_ ! 1 i ;! ~ ~ ~ ~ ~ . o , ~ ' ~' . , ~' # ` ~ 1 ~ :o 1 ~~ ~ : i 1 _~ i ~ 1 j 1 • ' 1 ~ ~~ .; I ,.. - I _.~ : ~ _ , ' ~ - f MuDi~Ni` cz "mss .c~- cc F -~ . ~ 1 ,° i 7 ~. ~ _' 1 ! ~ ~ ~ 7Q .) ~ i .:.IT Oar ~ 1 ` ~ ~GC~Z .~. ~7 ~CF ~ ~ 1 _ 1 ~ ' i ~ ~ ~ .. _ ~ ; i L~-Lr'<:z"-3e REF ce.~n. =o bo >r ~~. _ , ac ., ntt c.rs" ..,.t. ~ i ~EREr~ so acz.ai` aw I ~' } :^ 8~ C .D • , 1 • ~ ~ " O. a72~ .~.t. .,~~ ~ 11 1~G3 ~ ~ -- a ~.. ~ .-- _ tSdT -C ~ G 1- L E ~ c IC ZS~ c- r~,p --,~ toad i . .; ~,; ~~;~ ~~~ ~<< ;,.. 4 • ?.~ J Y~ ~;~ ~ ~•t r~ ~ .. J Lewe!!en Arctic Research P.O. Box 2089 ` Palmer, Alaska 99645 >Cr ~~ . ~~~~ .-_. - 9071745-31841659-2403 • 30 September 19$3 NIr. R. L. ~lestbrook 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 $:1a.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 ly , _ ~ tom` ` obert I. Lewelien, Ph.D. , (NOTE: Report results Ô' multiple completion or zone change on Form 9-330,)' -, ~ :- -: ;-' ',- '-;- :. ,"- ~ ,- ~::' ~ 7,:':= - - .. ' . .. "'".- ~~<l- ; " :';-' ~ :-.~ L- abandonment of island locatiþn ;.: - '-. 9-331 1973 :/~(' -, - Ron Hd J (}O -~7J UNITro rrAT~ - ot 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-<: for such proposals,) - 1. oil 0 gas! 0 well well other Explor a tory 2. NAME OF OPERATOR. Exxon Corporation 3. ADDRESS OF OPERATOR - Pouch 6601, Anchoraqe, AK 99502 4. LOCATION OF WELL (REPORT LOCATION CLEARLY. See space 17 below.) Well No.1, F177' SNL & 708' AT SURFACE: EWL. --Elk 654 ~X~R~X~~*~: Well No. 2,1777' SN ifx~~~~'& 683' EWL, Blk 654 16. CHECK APPROPRIATE BOX TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA , i REQUEST FOR APPROVAL TO: TEST WATER SHUT.OFF 0 FRACTURE TREAT 0 SHOOT OR ACIDIZE 0 REPAIR WELL 0 PULL OR ALTER CASING 0 MULTIPLE COMPLETE 0 CHANGE ZONES 0 ABANDON. 0 (other) sl1b~Pt'Jl1pnt- rppnrt- SUBSEQUENT REPORT OF: 0 0 0, 0 0 0 0 0 nf pprmanent ~r \ Form Approved, Budget Bureau NO, "2-R1424 5. lEASE '.. ~' r OCS-Ÿ~l'91 :: S : ~ 6. IF INDIAN, A~OTTEE OR TRIBE NAME - _.:-- :-: RE:CEivED 7. UNIT AGR:.r~~r;;;:o~iFIEu5 ÓPERATtÕ"NS 8. FARM OR LEASE NAME;' :. .:- , 'OC~ 24'~ 9. WELL NO. -. ~ 1 and: 2 ¡: 10. FIELD OR WllOCAT'NAME-- =-;~- - \"1 i Idcå t~MCKOBAGØ.'ALASM 11. SEC" T., R., M.;- QR BLK. j.ND SURVEY OR AREA 654; ~ec.'¡2Qi ~- 10 N, R i 7. :E', TIM =:>:' 12. COUNTY OR tA~S~113:, STfTE;' :, ()ff~hnr~ c. r- : ~ Alaska 14. API NO. 55-::=201-00001 ',and 55-2'01-00002' :. 15. ELEVATIONS.JSHOW DF.'.-KDB. AND WD) ." ;+ ~ 'ì""L WD , .. . ,.- F-~ ;: Î '. -- ., ,- ,." - ". ' ~ - ~ '- ~ . , " :. ~~ - " - -, :: :: ,. ,'0- . 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, ~nd give' pertinent ,dates. including estimated date of starting any proposed work. If well is directionally drilled, 1:ive subsurface I9cations and measured and true vertical depths for all markers and zones pertinent to this work;). ~ ~ ~: f '~ = .~, ~ REC:;IVED OCS DISTRICT OFFICE Subsurface Safety Valve: Manu. and Type 18. I hereby crfy t th~fOr_egOing- is true and co~l or at iön SIGNED J.~~. r;cc"<;' -- - TITLE Al aska n H .ìnnp~ - / / /' ,fT is "pace for Federal or State office use) APPROVED By-N~~'- - TITLEOFFS~ORE DIST. S~SORDATE CONDITIONS Ot~PPROVAl. IF ANY, , - PUBLIC FILE . COpy - " . ~- - ",- ,- oc-; 1 3 1993 MINERALS MANAGEMENT SERVICE '., ANCHOo..I\GE. ,.J,ASKA , Set @ ~-~_o- Ft. Coordinatòr- ~ DATE 10-:-11--83 .See In"tructlo"" on Reverse Side , "\ - 'OCT 1 8 1002 - ...0-' - '¡";i.,;.<io,- - ,..-,,--_. - -,,- - j ! . . t. WE1.L NO. :::: ~ 0; ~ - i 1 and 2, ~. ;: i' r: ~ ~ .. , - .. C,. :- ~ 10. FIELD ~ WI~ NÞ.ME ; ~ i I Wildcat " - : : ... i :: :. 11. SEe.. To, ".. ..~ ~'.L{.I.NO SS;Ih'tY OR AlttA 6S4~ :Se~. 20, ¡~OI~ n7! ~ ms ~ ~ ~ ; I 12. coUtm' OR !~J$H¡ 11. ST~Tt. ~ Off.b~e .' !, Al..k.a - lCo ÞI't NO, SS~()l-o0001~ and 5S-201'"!'ÓOOO2 ; ~: ~ ~ ~. 15. tLEVAnoHS:'{IÞ4OW DF,:-KCI. AND WD) , To of û Im4 + 13.1 t t.!SL, WI> 11' REQUEST FOR .tJÞPAOVAL TO: 1U8S£QUtHT ItEPORT OF: wi." '- - . T£ST WATER SHUT-oFF 0 8 ?CaIV.~.,; ~ f"IItACT\JRE nEAT B : '*'~ i.,,: SHOOT OR ACIDIZ£ 0 0It~ BI.S (J . -tt: j ". "EPAIR WELL 0 0 (Þ8ØT'I: ~~. ;'-.fti...i-~.......'..- IÞUU OR A£.TER CASING 0 0 .....~~~' .', ~ . MUl TIPU COMPLETE 0 0 ~ MipU: ~ ~~:- ': : -t CHANGE ZONES 0 8 : l.r¡:__.~ ~:. ~ : ~ ABANDON 8 0 ~ '; ::.:.:-. ~ -_!:. '! ~ -£.- ~ (ather) per=anentlv abandon :hland .loc.aUøa ~~~: ~ t 17. D[SCRIBE PROPOSED OR COMPLETED OPERATIOfofS (ONrty r...ta all pi8>1'tin.nt ~fI&. and ¡!'t'8 ~rtil\.nt :cS.tn. - -... :c..'~.~~~~~ ~~~"C:h ~~ ~ ~~_~~~~n~. -~ .~~~~ ~~ and IfooU 1 lt1J \ ~þ STATES DEPART. ,'. Of THE INTERtOR GEOlOGfCAl SURVEY SUNDRY HOnCrS AND REPORTS ON WELLS (Do - .,.. "'I' ..""" fill. ~poula tD frill ., to "'p8f\ .. ~wc 1o8ck.. . ,I"'"", ~r. UN '0""" ~-C for ~ p~-",) I. ofl 0 ' ... 0 ..11 ..11 J. NAME OF OPERATOR !Z2on Corporation J. ADDRESS Of OPERATOR Pou~h 6601, Anchorase, AX 99502 . .. LOCATION Of WELL (REPORT LOCATION CLEARLY. s.. Sþ8C8 17 Mlow.) AT SUR,..AC[:WeU 180. 1. 1777' SNL , 708' EWL, .u-%OR.~.tw:tta.l./.ALö. !lk 654 .u_1Q.'tALQ~ We No . 77' SNL , 683' II. CMECK APPROPRIATE BOX TO INDICATE NATURE OF tfOT1CE. REPORT. OR CTM~R DATA Dtker Exploratory l tte-- ~, - ~ ..,..... ~, '2-"- /41. r- - - . ~ oq i ( ;=r _S-T-191 ~ ~ ~ ,~ : ... IF JHDL4N, ~ OR ptllt~A"'E - \"ï-~- .. .'. ~'. : .. - - 0 7. UNrT AGR£E.WENT "AM£. ro. : - ,-,' '. . .' -.:' , '. -':, L fARM ~ ~ ~~E ~ t~ ~. .. . :.~ ~:fÞ / (JO - (). 7 / Subsurl'CI s.fwfy v,rYe: Manu. al'd Type tl'le foraaoil'll is trvt and COIT'8Ct DA 1'1: . , '". "'- . . .. :. ~, ~:~!~ - ~:."::~' i,:-, i:-r~f .:.:. - -- .. '"' "'. - r, ~ :: ~ G~':-. :"."",- ~i(': ~i t~~ ~ ...,' - .. sa;~- ]III~ .'9 t9B3 ,'-:. . or- . Ft. TrT'LI IIGHED (T'It.. ~ .., ""'" .r ~tI .fPica -) t ~SHORE CIST. SUPERVISOR DATI ¡VvI/ ¡:/1~" ~O"'[D ." CONDITIONS 0' "~IIO\tAL. Ir ANY: .... '...4 .......... .. ....... ... :-: ~ ;;:' ~:.. £. ~ ' ;.;. . ~ ~ ' - .- " ::.~~~:" ~" ".:.\"-:. -~ È"~'= ~t ~~~- ~ .::': i" , I. :' r: e :. AU6 25 t9f ~ ,. 7 :.. ... ... ::I : " :- : ¡, ~, a : . c: r :. t. 7 ¡. r i~:. . F~rra 9-330 (I~v. 5-63) UN. ,. ED STATES SUBmT iN DUPE, ~* · (See other DEPARTMENT OF THE INTERIOR structionson reverse side) GEOLOGICAL SURVEY ..... :',UaI-tUEi II IAL '; '. "'. .... ':"'' ' Form approved. Budget Bureau No. 42-R355.6. 5. LEASE DESlGNATIO~ A~D SERIAL OCS Y-0191 WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: b. TYPE OF COMPLETION: WEI. L OVER OIL [] (;AS WELL [--~ DRY .. , WELI, r-'l Other Pluqqed & Suspends DE,:~-Q Pi.u.[2 D,FF.r--1 EN BACK RESVR. Other 2. NAME OF OPERATOR Exxon Corporation 3. ADDRESS OF OPERATOR P. O. Box 4279 %2243, Houston, Texas 77001 4. LOCATION OF WELL (Report location clearlM and ~& accordance with aRM State requirements)* Atsu~aee 1777' SNL, 683' EWL, Blk 654 Stefansson Sound At top prod. interval ~eported below 5053' SNL, 5050' EWL, Blk 654 Stefansson Sound At total depth 5817' SNL, 5473' EWL, Blk ! 1~. PERMIT NO. DATE ISSUED 654 Stefansson Sound I 55-201-00002'00!1 12-24-81 (~. IF INDIAN, ALLOTTEE OR TRIBE NAME 2]7.UNIT AGREEMENT NAME $. FARM OR LEASE NAME -- 9. WELL NO, .; 2 10. FIELD AND POOL, OR WILDCAT Wildcat ' 11. SEC., T., R., M., OR BLOCK AND SURVEY OR AREA · Block 654 StefanSs0n Sound, Beaufort Sea 12.COUNTY Ok 13. STATE PARISH Offshore Alaska 15. DATE SPUDDED12_27_81. I16' DATE T'D' REACHED2-11-82 17'DATECOMPL'(ReadNtoprod'){18'ELEVATIONS(DF'RgB'RT'GR'ETC')'[19.ELEv'CASINGHEAD3-15-82 (Suspended) 45' KB - 20' TOTAL DEPTH' MD & TVD 91' PLUG' BACK r'o" MD & TVD { 22' IF MULTIPLE COMPL" I 23' INTERVALS ROTARY T00LS { CASLE TOOLS13,441'MD (1i131' TVD)80 ' HOW MANY'_ D~ILLED~ n~ ~All ' ' - 24. PRODUCING INTERVAL(S), OF THIS COMPLETION--TOP, BOTTOM, NAME (MD AND TVD)* 25. WAS DIRECTIONAL SURVEY MADE 11,438'~11,500' MD (9341'-9393' T~) Upper Cretaceous Yes 26. ~x~ ~L~CTR~C *N~ OTZAR LO~S ~US Dual Induction, LS Sonic, Formation Density - t 27. w,s w~ co,mo Compensated Neutron, Dipmeter, NGT Log ~ 'Yes CASING RECORD (~ort all string~ set in ~eIl) CASINO SIZE WEIGHT, LB./FT. DEPTH SET (MD) HOLE SIZE 30" Structural 128' 4 2" 13-3/8" '72 2,389' 17-1/2" 9-5/8" 47 12, i20' 12-1/4" · Femented to surf w/permaf~o~ ~e '13_000 SX permafrOst / ~--o'~'e 29. SIZE 7" LINER RECORD TOP (MD) iii. BOTTOM (MD) 11, 589' 13, 440' 460 sx Clabs G / 30. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 31. PERFORATION RECORD (Interval, size and number) 12,764'-12,774' , 12,835'-12, g44' 12,700'-12,716' (0.4", 4 spf) 12,470'-12,576' (0.4", 4 spf) 11,438'-11,458' (0.4",i 4 spf) 11,438'-11,458' 11 470'-11 478' ~ ~, ,~ ~.,, ~ =~)_ ' 33.%'~ ' ~"" ~ ..... ?E ACID. SHOT (0.4",4 s PTH INTERVAL (MD) ........ , 11,483' ' FRACTURE, CEMENT SQUEEZE, ETC. AMOUNT AND KIND or MATERIAL USED Squeeze w/150 sx Class G Squeeze w/150 sx Class G Squeeze w/175 sx Class G PRODUCTION DATE FIRST PRODUCTION 3-12-82 IPRODUCTIgN METHOD (F!0wing, gas lift, PumPing--size and type o! pump) Flowing IWELL gTATUS (Producing or '. shut-in) . ' · SusPended · " DATE OF TEST I HOURS TESTED 3-12-82 ' I. WATER--BBL. ' ] GAS-OIL RATIO '0 I 287 FLOW. TUBINO F~fl. I CASING PRESSURE 140 psi t - I CALCULATED I OIL--BBL'. 24-HOUR. .~-RATE 224 IGAs-McF'64 WATER--BBL. OIL GRAVITY-APl (CORR.) .. 21~3 @ 60°F· 34; DISPOSITION OF OAS (Sold, used for fuel, ye, ted, etc.) Flared TEST WITNESSED BY .: John Rigg ins 35. LIST OF ATTACHMENTS Formation Test Summary 36. I hereby eertifwthat tlle for. egolng ~ud jttach~l] information is complete and correct as determined from all available records TITLE Geolo(~ic Advisor DATE 4-14-82 " *(See Instructions and Spaces ~or Additional Data on Reverse Side) ., ARE/~ .. , , . i INSTRUCTIONS · . General: This form is designed for submitting a complete 'and e0rreet Well completion report and log on all types of lands and leases to either a Federal agency or a state agencY, oc both, pursuant to applicable Federal and/or State laws and regulations. Any necessary special instructions concerning the use of this form and the number of copies to be submitted, particularly with regard to local, area, or regional procedures and practices, either are shown below or will be issued by, or may be obtained from, the local Federal and/or State office. See instructions on items 22 and 24, and 33, below regarding separate reports for separate completions. If not filed prior to the time this summary record is submitted, cope. es of ali currently available logs (drillers, geologists, sample and core analysis, all types electric, etc.), forma-': tion and pressure tests, and directional surveys, should be attached hereto, to the extent required by applicable Federal and/or State laws and regulations. All attachments'· should be listed on this form, see item 35. · . i#em 4: If there are no applicable State requirements, locations on Federal or Indian land should be described in accordance with F~deral ·requirements. Consult ·local State' or F~leral office for specific instructions. I~em 18: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments... Ifem~ 22 and 24: If this we!l is completed for separate production from more than one interval zone (multiple completion), so state in item 22, and in item 24 show the producing interval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 33. Submit a separate report (page) on thi~ form, adequately identified, for each additional interval to be separately produced, showing the additioual data pertinent to such interval. ' I~em 2~: "Sacks Cement": Attached suI)plemental records for this well should show the details of any multiple stage cementing and the location of the cementing teol. ' ' I~m 33: Submit a separate completion report on this fo~m for each interval to be separately produced. (See instruction for items 22 and 24 above.) ,. ~ 'i' ~ 37. SUMMARY OF POROUS ZONES: .. ~qlll)~' Al, l, IMI'OIITANT ZONES OF POROSITY AND CONTENTS THEREOF; CORED INTIJRVALS; AND ALL: DRILL-JITEM TESTS, INCLUDING 38. GEOLOGIC MARKERS DEPTH INTERVAL TESTED, CUSItlON USED, TIME TOOL OPEN, FLOWING AND SHUT-IN PRESSURES, ~ND RECOVERIES .. FORMATION TOP BOTTOM · .. ~. . DESCRIPTION, CONTENTS, ETC.. TOP ' J . NAME "' ~ 12',522" 12,551' Cote #1:. Mudstone & talc sandstone ~EAS. D~.PTH ~ .... ~' . . " ' W/patchy oil stain. Bower ?ertiary 4,.520' .4,338' i ~ 12,:551' . :!2,:57t:' Cor'e #2'.'. Mudstone &. silty sandstone' tipper Paleocene 7,120'" "' 6,196' ~ : ~ . ; .~ w/patchy oil stain. · ... tipper Cretaceou~ 9,299' 7,727'. : 12,736:' ' 12,776' Core i#2 ' Shale & sandstone w/spotty Lower Cretaceou~ 11,900' ."9,732'. ~ .. . 12,764' 1'2,774' DS~ #1: See Attachment. · ~ ' : :'11,438" 11,458" DST #4A: · See' Attachment . ~ ' U.S. GOVERNMENT PRINTING OFFICE: 1963--O--683636 871 - 2 33 ' FORMATION TESTS EXXON OCS Y-0191 NO. 2 TEST NUMBER DATE TYPE TEST INTERVAL CUSHION HOURS TESTED --PROD ' N FOR ..TEST PERIOD CHOKE SIZE FLOW RATE FLOWING TBG PRESS TBG SIZE IFP ISIP FFP FSIP 1 2/21/82 DST Through Perfs 12,764'-12,774' (4 spf) 12,835'-12,844' (4 spf) Nitrogen 62 hours 57 minutes Fluid Did Not Surface ,~. 6/64" Reversed out 76 bbls Oil (14.6©API Gty) 0 3-1/2" 4617 psi 5082 psi 3727 psi 4634 psi 2 3 3/2/82 DST Through Perfs 3/5/82 'DST Through Perfs 12,700'-12,716' (4 spf) 12,470'-12,576' (4 spf) Nitrogen 10 hours 11 minutes Nitrogen 12 hours 16 minutes 125 BW 19/64" (1)152 BWPD 110 psi 3-1/2" 4586 psi 5057 psi 4801 psi 5105 psi 5'luid Did Not Surface 48/64" Reversed out 6 BW 0 3-1/2" 4107 psi 4725 psi 354 psi 148 psi (1)Based on 3 hour stabilized test TEST NUMBER 4A 4B DATE 3/9/82 3/11/82 TYPE TEST INTERVAL CUSHION HOURS TESTED PROD'N FOR t TEST PERIOD CHOKE SIZE FLOW RATE FLOWING TBG PRESS TBG SIZE IFP ISIP FFP FSIP Production Through Perfs Potential Through Perfs 11,438'-11,458' (4 spf) 11,438'-11,458' (4 spf) 11,470'-11,478' (4 spf) 11,483'-11,500' (4 spf) Diesel Crude Oil 15 hours 12 hours 9 minutes 148 BO 18/64" (1)186 ~O/D & 67 MCFG/D (21.3©API Gty) 62 psi 3-1/2" 5007 psi 4408 psi 3476 psi 4395 psi 112 BO 32/64" 224 BO/D & 64 MCFG/D (21.3©API Gty) 140 psi 3-1/2" 4422 psi 3492 psi 4376 psi Page two CONFIDENTIAL (1)Based on 6 hour stabilized test (1)Based on 6 hour stabilized test Mr. John Caldwell Exxon Company, U.S.A. Pouch 6601 Anchoraqe, Alaska 99502 March 4, 1982 DISTRIC'F OIL AND GAS OFFIGE Re: Our Boss Gyroscopic Survey Job No. Boss-16974 Well: OCS Y-0191 ~2 (SEC20 T12N R17E) Wildcat Field North Slope, Alaska Survey Date: February 21, 1982 Operator: Marvin Milam Dear Mr. Caldwell: Please find enclosed the "Original" and nine (9) copies of our Boss Gyroscopic Multishot Directional Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Kirk Afflerbach ' District Supervisor KA/pr Enclosures EXXON COMPANY, USA OCS Y-0191 #2 ........................................... WILDCAT ALASKA VERTICAL SECTION CALCULATED ALONG~AZ 'WELL SURVEYING 'COMPANY ................................................................... PAGE 1 ....... ANCHORAGE ALASKA ' ' DATE OF SURVEY FEBRUARY'21, 1982 FAT'ION'DATE ..................... BOSS GYROSCOPIC"SLIRVEY ........................................... MARCH 3, 1982 dOB NUMBER BOSS-I6974 KELLY BUSHING ELEV. = 36.88 FT. .............................. OF'ERATOR-MILAM ............................................ OF 125.62 DEGREES ..................... TRUE ...... ...... Ol._, JB-._,EA o :z; ! ,- MEA._ L RED VERT I CAL VERT I C:AL DEF'TH DEPTH DEPTH --COURSE ........... COURSE .......... DOG-LEG INC:LINATION DIREC:TION SEVERITY DEG MIN [EbREE.=. DEG/I00 TOTAb RECTANGLILAR COORD I NATES NORTH/SOLITH EAST/WEST VERT I CAL. _) SEC:T 101¢~ 0 O. O0 -36.88 100 100. O0 63.12 ....... 200 ......... 199 .-99 ............ 163, 11 :300 299.99 26:-_-:. 11 400 399.99 :---:63.1 i 500 499. ~8 - 463. 10 ~ ~:,00 599.97 56:_::. 0':-; · --~.~=-:0o ........... 799. ~ 9s_~.~. :~ - . _... ~,-.'.¢].~-0 (') 0 '-?'-?'? 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E ...... .t ,.'.~ :i3 .-, :1 -/:'::, 6, 0 "::" ...... :, 4;27 :-':-: Y'i--:.' 41 :£; 40, :::'~ E 1 1/-, ,:,'-' ~:'-'I 6, 'F':3 ,.c; ,q.:2,1. 6 , ,:,'"'""; [:.': .... ~:',._-,'-"-',:, .--,"' 7' :':!: ..:,'-. ,_,'::' :'::.. 9.. ~, ?.;' E-'0· ':-/1 ..::"-,:~"" c,' ".J ..... 00 .$ ~., .....":; !5:3 . q. i ~:.'-' D ~ :--: 7 . ~:, ::'""' ..... 4- ......._,':' ":":'~"._, ..., ?;,h_. -F'-_ ............ 1'-, 'i~:q ..... ........ -."q!q~-i:.:; :~_ 62 '-L:';,-1. :3 E:: 8 , ~,,S ~. ~-' ...... t;'~'~¢i-: ':::/%... ...... F"t:--- ~ ."% 2::.:' ._,'::' :3':;', !:5('~_. E ~').. 7(:) :3344 , :3:::._,':' ,1.,.:1.:2:::.:', ,0% E ."-,._,-:]..:, . :2:--: 1 S: 3'.".;'. 0 E 0 44 ":":"='~q F~'=' . ...... ~::,=,-,a 6,:~, ............... ,., F; q .q. '::; ;';-, 7:.'5 [;:: ....... ;, ~. · ..... · . _ -' SPERRY::SUN WELL SURVEYING C'OMPANY'~ USA~' ii i ' DATE OF .:.LRVEY FEBRL~'4RY 21, , ..... ... I ' I- :--':--° _~.lI 'i ............................................... MARL. H <,, l'~:=.z ,.lOB NLIMBER BOSS-16.;74 KELLY Ed ..... ;:::H I NG ELEV = o6 '-"-':,,:, FT. .............. CIPERA TOR-M I LAM 1'-.~ ~'~ DEGREES ~ .... TRUE .................. SUB-SEA ............ oOkllRSE ............. c:c_. _IUR cE"- ...... ........... DOC-LEA_ ............................ TOTAL' ..... , .............................. ~ ...... l: :l~]C ..... ~~'l VERTICAL VERTICAL' INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTIUAL2 DEPTH DEF'TH ' DEG MIN [~EUREE.:.-' ' -'-' DEG/100 i~ORTH/SOLITH EAST/WEST SECTIO~ 46 '-' ~ '-' '-' ;~._, E' ~ ~''''* 66 E ' : : - ~ ~ ~ ~ ~I~ ,:,~ ..... ~ .:,o6. c, ~:~ ........ ' ..... 0~ 86 ........... .:,o,.~':'.}°o ."'~:~o ..... .:,- ........ ~.~,._,~.~ ....... ,:,.~,~'~ ........... ~ :~ 7~ ......:,~'"' · _7;1 A4 96 '"'=' ~i:~'-. 34 m,_, ~61 S ._,c" <'._, . 60. E i . 16 :<:~i:=:F: ~0 S 46(.}9.. .9Z. E ._007. '" ~ cy c,.-, O~ ;/ (') l: ~,: ~~ 26,: ~;16: ' ' S ~6,. 10 E 2 45 3/-,A'~,. 04 S 4/-,~/-,. 4:3 E · ...... ._ ;. ~.. - 60 ':':.~., ~ . .. .' o/. 22 S 26. 19 E 0 11 3708.~,°=o ~,o 4675.97 E ': 5':~61 60 '--~5'---4 ...... S:'"'20;'-3'F,'- E ................. =~ '66 .......:,7~o.~ '~'- .... 7:,~ .... ~.=, .... 4:,o4.~ '~ '-'o7 = .......... E ._,;~':'7~/;7I 00 24 45 S 1'2, 6'F/ E 0.88 3748.54 .S; 4.691.80 E 55,97.11 10 .~,.:,~ - o .-,- ,.-. ._0 19 60 E 0.91 o7o7.29 S 4705./-':' E 6030 92 .:,1=,~.11 04 S 4719. 48 E 6064; 1'7 ..... 70 22 30 S 19. .89 E 1.13 '3861.75 S 47:33.07 E 6096.~'-' '.. ~';~ ' 20 2.2 6 '=' ltV. Z-E/E 0.40 :38~7 46 S 4745 93 E 6127.84 ~0 ............ 2~ ~ ......... S -~'~ :::9' ~ ............ 0; c,~ ........ ~,,:r-..-, ..... .-~ ........ ~-,-. - .... ~, ~ ._, ~ o ~. ~ ~ o ~ Y._,o. ~.~ E ......... 6 ~ oo. ~'' .... ~-'~- "--- · -(.) H ~ (')8 :~:gAA (~ c~ 4769 co ~ 6~87.~b " i i ..... i . ~ i 50 19 42 :3 16 .... ~C) E 1.87 3982.47 S 4774.92 E 620C).91 70 ..... 18'-5¢]. " ~':; 1=._,.:39 E ............. 1.89 ...... 3~98.34-'S ........ 4779.46' E .......... 621d.84- " 8C) 17 /-, S 1"" . _ o.50 E 1.84 4028.20 S '4787.18 E 6237.51 10 .16 13' ._,¢: 1°~.50 E , _s'.23 4N:::9... .66'S 478'~.83 E A';'46__ .34' 6~6::,. '"'~ co FEET AT SOUTH 4'Fy DEG. 51 MIN. EAST AT MD = 13441 EXXON COMPANY, OCS Y-0191#2 ....................................... ~ILDCAT ALASKA VERTICAL SECTION CALCULATED ALONG AZIMUTH OF · . MEASURED DEPTH 11800 9646,, 34 9609, 11900 ';'7::: 1.70 'P6'F;4. 12000 '' I 9817.70 ...... ·.~ 7,_-.0'-? '-' '. 121 O0 :-.-;9(:)4 · 42 986,7. 12200 'F;'~ :-? I. ,:,4 9954. 12:300 10079. o - ,_,0 10042. 12400 101 ' -' ob. 80 101 '-'I 1250('} 10'~'.=,':' 40 10221 . 'el el~ '-- ';l · · ....... 1 -',- .-,v "I (:):-":(:)3 · =('. _ _ ._, .) .......... 1 (')2A/',, 12600 I C.)..,4 o'-' '-' · '-',_-,(:)' ! 0312. 1270(:) 10440.00 1 (:)4(.'):--:. 12 F:(')(.} 1 (.} = '-" · : · .. 4 ...... ,._-,1..5(:) ' 1()4' . 12'~ C) 0 1062:3.60 1(.)' ._~"",_-, 6. .--$ - . . 1 ._-,(.)0(.) 10716, · 10 1067:-?. 13100 ........ 10809,00 ....... 10772. 13200 10902.40 1086.5. 13250 10949.30 10912. 13400 11071.70 11054· 13441 11130.~0 110~4. HORIZONTAL DISPLACEMENT = ---THE CALCULATION IpROCEDLIRES- ARE--BASED--ON--THE-USE- OF-THREE DIMENSIONAL RADIUS IC|F L. JRVA1LiRE METHuD . . : 'x ~) ~,',~z~,--.~>, oPERRY-.:,UN WELL .:.URVEY I Nb F. OPIPANY . · F AAE ', '"x~ ~ ~],F~'~ ANCHORAGE ALASKA :.' .~ . EXXON COMPANY, LiSA . ~,~ ~ ~ '4'~.. ~_ .. []AT~: i'1~. '::;! Ic'U~L'V C~::~C'I IAc'v '":~ ":' ""~;'] -' ~ 4 N~RUH ::~, 1w82 dOB NUMBER BOSS-1697~ ALASKA ~~ KELLY BUSHING ELEV. = :36.88 FT. ............ %- ................................................ OPERA]'OR-M I LAM INTERPOLATED VALLE.:, FLR EVEN 1000 FEET OF MEA:,'-;URED DEPTH TRUE .:._IB-oEA TOTAL MEA:-';URED VERT I CAL VERT I CAL RECTANGULAR COORD I NA'TES MD-'I-VL] VERT I CAL ~ DEPTH DEPTH - DEPTH NORTH/SOLITH EAST/NES]' D I FFERENCE ............. CORRECT I ON .................................................................... 0 ............ 1000 ....... ...c 3000 4000 5000 6000 ...... 7000 8000 $~000 "· 100~]0 · 11000 · .- U 0 U ............ 1 :_::000 1:3441 p. ... 0 O0 '~' · oo 0 ;"00 .. O. O0 0. ...... '-~¢~'-~........o7.. ............ :?/-,3...:')9. - - · ................. : .... - .... .':'--' ..... · .-,,-,:":"-'.~;.- ................. ~"-7':?-E-.-, · .............. 0. 1999.95 1963.07 2993.~9 2957.11 3~39.97 3903.09 4670.79 4633.~1 5387.79 5350.~1 6110;46 ....... 6073.58 6828.06 6791.18 7511.00 7474.12 ......... 10716~-10 ........ ~ 11130.~0 I 3.85 S 5.81E O. 8.97 S 78.24 E 6. .................... 141;27'-S .......... 364,32 E "' 60. : 542.83 S ~06.23 E 329. 982.13 S 1447.40 E 612. 1-395':-70-'-S ........ 2000':"74-E ........... 889:- 1775.24 S 2208.13 S -8229~-'73'. ......81~2.85 ................ 2651-;'~2-S 8984.83 8947.95 3087.31S 9817.70 ~780.82 3508.45 S 067~.20 ........... 88~7.46--8 10~4.10 403~.66 S 2584.65 E 1171. 3172.34 E 1489. ..... 3707.08 E 1770. 41~6.20 E 2015. 4552.83 E 2182. 0:3' O';-Cx3 ...... 05 0.01 01 5. '.~7 .__0 ............. · :, 54 · ¢)2 ................................................. 21 '--.'/- .:'~ · .: ..... 17 .,:. I L..'::~:-:. 00 54 .......... 277;-3:3 94 2:--:2.40 00 317.07 27 .................. ~,.-.,o,_, 1 ' 27 ............................ 17 ' 244 '~"-? · ": :' : . ,-~; · . .. · i. ' ~:] .'...' :] .~._. :30 · 1,5,7· 14 ..... I~' .-- *'". ................ ,--s ."~ s"'s 4.74._.. ~,:. E ~.-',:..:.: 97: 10 i';-6E,~ 478'F~. 8:3 E 2:310· (:)7 26.14 THE CALCULATION PROCEDURESARE--BASED-ON'THE L~,E OF THREE-DIMENSIONAL-RAKIU:, uF L._IRVATLIRE METHuD. '-- Ii~I~IAil IkhAl~hlP~lhl~ : "::: :::: :: :::':: : : :' ':::' : ................ -'"<~ "~': ;~',~ ........... E;PERRY-:=~! IN WELL-.· :=;I IRVEY I NG F:~']MPANY .............. ~l_)(~;l:'~ ~;'il~J~'~:, '-'E;~ NX'"',x~'~~T~ ' "i:: '"' .':"'.: RNI H' iRRI,E.~LA t ~ . - ' I!F''TE .FIF' SURVEY.. FEBi:;qj~l:;~.y~;i::21..~... ;i.,~i32 ..... --:-" - .= ' ~ ................... :--~x ........ ~'2':i,'ili' : ..... "-.''F.'.nMPilTATI~]N--DATE-- .... ..... ' - ....... _ ] '",. 5= ,~,~,,__,~.__ t ~ ::H :--:, 15 E'2 ..lOB NUMBER BOBS- 16'?74 ALAL-;KA ".,c-e X LL¥ ELEV. : FT. iNTERPCILATEI~' VALUES FOR EVEN 100 FEET OF SLIB-SEA DEPTH .......................................................................................................... ..... TRUE '-'-"~ :, JB-.:,EA TOTAL MEASLIRED VERT I CAL VERT I CAL RECTANGULAR F:OORD ! N~TEL=; Mi-v-TVD VE.'R T I CAL DEPTH DEPTH- DEPTH ..... NOF~TH/SOU1-H.. -.- EA._" ':;T/NEST - DIFFERENCE. .......... CORREC'I"Z ON 0 O. O0 -36.88 ~ S:6 ............. 3/_-,. 88 ........... 0.00 136 136.88 1 O0. O0 236 236 ':"-' . ,-,,:, 2~'~ 0. 338 :3:36.88 :300. 436 436.88 400. O0 536 536.88 500. O0 6.'_::6 ....... 636,- 88 ........... 600. O0 7:=-: 6 7:36. ,_,':":',_, 700 .00 836 :=::-=:6.88 800. O0 936 '- ' 936.88 ..... .':?00. O0 0.00 0.00 0,-00 0-,-00 - 0.17 N 0.71 E 0.00 0.00 00 0. '..."- '~- N 1 . F,._ 4 E 0 .01 0.00 O0 ............................... O. 4~'; N ............... '-' 34- E ........................... 0. O1 .,0.00 .................... O, 09. S 3.14 E: .:.. . O. 02 .. =========================== ... O. 57 L:; : 4, 12 E O. 02 ::':'::':': :: - 1--~--1'6--E; -- 5';-'09---E '0'~' 0:3 ...... 0;0t 1.64 S 5.89 E 0.0:2: 0.00 2.14 S 5.88 E 0.03 0.00 .................... 2~"28' S ..................... 5.7'.:~ "E .... . ............... O, 03 ............ ~ ..... O. O0 ..................................................... .'[ ]'-' C'-' c .:,6 I .~,6.,::: ::", 1000.00 1136 11 '-'~- · :,=,. ~.o 1100. O0 ........... 1236 .......... 1~.") ':' /-._, _, ..... ,-,':'-':,-:, .......... .~ 200 - O0 1336 1 :_--::_=: 6. ,-,o,:,,=, 1.:,c'-' ') (.)'. O0 , 14:36 1436.8::: 1400.00 ..... 1536 1~36 '-":' .... . o._. · · 1500,00 · -,/. ,:,,:, 16.3 t-,_ 16c, :,. ,_,,_, 1600.00 1736 1736. '-"" ,:,,-.-, 1700. O0 · 2. '~- . :': ':: 0:3 .::i: . ~.. · ": ..: S 76 E :. 0: :::::::':::::: :.:: O. O0 . -1. :::2---~::-': .... -5:64--' E 0-~04- :::::: ::"::': 0 ;-00 ~'~-' 1.:3:3 E; 5.27 E 0.04 0.00 I 2/:. S 5.0'-' . · o E 0 04 0.00 .................... 1.84 '$ ..................... 5.1:9- E ................... O; 04 .......................... O~ 00 ............................................................. . . 2.45 S 4.94 E 0.04 : 0.00' · :':3.01 S --. 4.95 El 0.04 0.00 : . ................. : ...... ~ ~ ............ SPERRY-SUN WELL' SURVEYING COMF'ANY ............ Y" ................... ~ ..... "'":"]":';-']'i'~' ...... F'"i~GE ..... '8":: EXXON COMPANy' LISA :~::~%:~ :' ~'~: DATE CiF SLIRVEY FEBRLl~Ry~21': l'Fx82 : OCS Y-Oi'~i -: '~,' ~. '?~ MAR3H 3, 1S82 dCE NLIMBER BOSS-16~774 · ~ I ' "'.' ..... I NTERF'OLATED_ ......................... :~ ........................................................................................................................................ ....................... ~ ............... SUB-SEA TOTAL VERT I C:AL RECTANGULAR COORD I PLATES DEPTH' ' ~' 7 "NORTH/SOLrI"FI .... EAST/WEST · ?: 42 '" =' E · ._i ................ ~. _..,, . ~._, ~ .... ~.~ ......... _L ....... ~ . :_'-:. R4 S 5. E MD-TVD VERT I C:AL D I FFERENCE C _IRREL. T I ON ............................. . · .: 0.04 0.00 : O. O~ 0 ~00 ................................. '- ....................... 0.05 0.00 E 0. E 0. E O. E 0. E ............... O, -- ¢). --' 2. - 7. -- ................... 11 ' - 15. - 18. - ' ' '22. _: 26. 05 O. O0 05 ................... 0 · O0 ............................... C .J 0.00 05 0. O0 07 ......................... 0;' Ol ............... .' ...................................... TRUE PLEA.:, _IRED VERT I CAL DEPTH DEPTH 37 O. 30 15 O. 7:--: 58 ...... 1 ' 42 5.2: 1. ?5 31. 2.78 20 '-" - :--,"~ .................... · "m. -- o ¢),~ :--:. :_::'P 76 :_--:. 67 62 .......... 3' 86 - ................. 'PO 4-. '-'-'..-' c: 1:3 5.2:2: 1736' .... 1936..88 .........1900 00 51' 2(:):_--:6, 2¢'):::,/-, ""'-' . .. ..... :, ,:, 20 0 0.0 0 9'--~ .-, .-,/. ,-,,:, 2136 ..' 1.:,'_',. '-"-' 2100.00 3.57 '.E; 6.46, .-~ .-., .-:,/..-,.-., ..:,/. ,-,,-, . ....... ,'. ..... .~.- ..... :,,:, 2200.00 ............. o.'6,2 S 6.43 2 "D '":, . - ..., ._, ,/:, .-,.",.-, . · .' .-',.:,/:,.,_,':":',-, 2:::00 .00 . 3 . .=;,.'F-:_ _ :--; 6. ,--m o. 24:36 243/.-,. -"-' . ... ::,,:, .'2400 00:::.: :. ::. ':: 6.4 :E; 7.:2:7 ........ --, r_~- .-~ , '-"~':'/' ..'._,.:,6,:,,:,'-"-" ......... ':..'P";O0 00 ~' '91' '= ................. ~': 69- .l:..-- ._i · .i-- . . I ,,..i I ._i 2/_-,37 2~3X_-,. ,:,'-"-',:, 2600 .00 5.20 ~5: 16.09.. 27:_--,'8 2736.,:,,:'-"-' ..... 2700 O0 5.80 '--.; 28.57 '-"':"-"--~ 2836 ,:,,= .... 4._,. '-'-'= · ' .... :,: '-'"~ 2 :~: (') 0 00 ................... 7 .' 60 . .--, 2'P41 29:::A. _ _. 88 2'.-.9¢)0 .00 8. :_::4 ~,':' /-_,..?]. 16 '-") ' '-"R 7':? · :,L 44 :--:0:--:6. ,.-,o 3000 00 10 01 '~ '-' '-' · · 0 ,";,- . .......... :_:: 14:_--: ..... 3136';'~'',:,,:, ............. 3100' O0 ................16, .25-S .......... 11~-_, · ..'o 1 '-"-'~ ,:,,=: '-' 142.01 · :,.--._ 1 3236. '"'- 3200.00 27.46 .:, · o.:.._,._, ._,._,._, _,. ,_,,_, 3:300 . O0 :::g~._. .:,._,'-'~ ._,'--' 166 .62 o--. I~' ................. · :,4.,'.,~ 3436. :--:8 3400. O0 '51..4: S' 171 . '?0 '--'~-'-' o._,.:.6. :--:8 :2:500 O0 6:--:. '-'~ · o,.. :E: 218. 78 :_--:669 :3636. 88 :_--:600. 00 78. ':18 $ 24E:. 2(') EXXON COMPANY, 0C8 Y-0191 WILDCAT ALASKA ~ ~!~i? .:,F ERRY-,..,_IN WELL' SURVEYING L. OMF ANY PAGE ........ ~' ' ' <::'1 -' , ................................................................. ~ ~ ~'~% '. ANCHORAGE ALASKA "~. j,,7..A __....%~~;,~ D~TE OF SURVEY FEBRUARY 21, 1982 ~2 ...................... % ~~*~ CONF'U TAT ~ ON -' D~ TE ~~ MARCH b:, 1'P82 JOB NUMBER BOSS-16974 g&~ ....... KELLY BUSHING ELEV. = 36.88 FT. ................. ~ %~ - I ' - "~ ................. ~ ' ~... . . LI-ERAIUR-MILAM , , N-~ .: · INTER~OL~TE[~LLIE'.~ FF~R EVEN 100 FEET OF ,--I · :,L B-.:,EA DEPTH .................. TRUE SLIB-SE~ TOTAL VERT I CAL VERT I CAL RE' F'_.TANbULAR" -' COORD I hIATES IdD-TVD VERT I CAL DEPTH '~' DEPTH ' NJRTH/c, UUtH 'EAST/WEST - DIFFERENCE CORRECTION 00 '25.~'=' '" 281 ~/. E '="~ ..... =, 00 6. · .. 86 . 00 .................... 1-i 6-'" .... ' o4 S ..........319~-38- E ....................... 477~2 c 00 140 47 c. .:,6~. '-"- ..-, ,=, y E 59.63 11 . 71 MEASLIRED DEPTH 3775 3736.88 3700· 3884 ....3836.88 .......... 3800. 3996 3936.88 3900, 4112 402:6.88 4000. 4235 4136.88 4100. 4372 4236.88 4200. 4518 4336.88 4300. 4663 · "4436.88 ....... 4400. 4807 4536.88 4500. 4951 4636.88 4600. 5092 4736.88 -' 4700. 5232 4836~88 4800. 5373 4936.88 4900. 5513 ....5036.88 ......... 5000. 5652 5136.88 5100. 5791 5236.88 5200· 5929 '5336.88 6067 6205 0 ¢] ....... 169. o 6 S 41 c:. ~ 1 E 75 ~':' 15. ':70 00 '-- 207 '-':~ ~ ~' . . . . . :, .-, - ' .... 474 'F,,'7 E ":.?'~ 02 ............... 2:3,; 49 O0 261 '-"-' · .'.:, :E: ~('~ '='/- E 1 ...... . .:,._,. 46 36 · 45 00 .'~,.z,~ - - ,:,~..-,. 0:-': '-' "'~' - · ::, 6.:,._,. :~:?': E 1L-:I · 15 ~5.69 00 ............... 390 ...... · 4o '= ............. '"' · -, 7 ! ,:, · 0 t ...... E .................. 226'~' 41- 4.._ ;- 26 (30 4._,._, 7:_--: :--; 799 '""- '-' F. ....~.'-: E 44 46 · ..-7 .~ 87 · O, 0 ._F, ..'-, 1 · 40 ._, '=' 879 '-"-' · ,=,,=, E ..-,'-'.t .~._ · 12 4.4. .,..._ O0 ............ ~'="":' 66 'S ' "'_9~/-, 73 E ":'.'=;:' 78 40.66 · ,., i_i ._l ' · ': ............. · . -- -- · .~l._ ,_1 · 0 0 644 E:"-: ~'' :~ 1¢x::2 49 E '-"-~-- · *~.,* · _', Y.-,, :_--:6 2'2 F,,z, -- -- · _ . · ,_ I_i 00 707· 28 .--,'-' 1 lO~."- 94 E 436'. 42 ": 41.06 00 7: .... 71 Il:--:6 12'E .......... : ..... 476-34 .............. /.o S ......... O0 829·77 8 1261.04 E 515·41 37·07 00 890 · 84- S 1 .~,._-,._, ..... 40 E ,-~. 19. .=. c, .'-"-'-' 78 5300. .00 ...........':.)~1. ~ .~.'E:. '='._, ' 1409. · 59 E 5436. :BE: 5400· O0 1011.38':--; 14,.:-]._-,.'-' 74 E 5536 · :=:8 5500 · O0 1070.31 S 1557. :-':6 E · ................................................................. 592.71 ................. 38.52 ....................... 630.84 3L=: · 14 668.2'2 37 · 45 ......................... ~ ........ SF'ERRY-SUN WELL SLIRVEYING-COMPANY .............................. ~~ "~'~iL')~ ANCHORAGE ALASKA EXXON COMPANy, LIE: OCS Y-0~9~ ~2 ................. ~'~ x ........ ~"~ .... COMPUTATION' DATE .... WILDCAT ~-~ ~ ~" MARCH :3~ ~982 ALASKA ..... ) ....... 5 ................ INTERPOLATED V~ FOR EVEN 100 FEET IDF SUB-SEA DEPTH ...................................... PAGE .... 10 .... DATE OF c, URVEV FEBRLIAR-..-i,':'' ".l':C"::-'Y,~.~ JOB NUMBER BOSS-16974 KELLY BLISHING ELEV. = ..:,6 '"'---' . ,:,,:, FT. ...... OPERATOR-M I LAM ......................... VERT I CAL TRUE SUB-SEA TOTAL MEASLIRED VERT I CAL VERT I CAL RECTANGLILAR COORD I NATES MD-TVD DEF'TH DEPTH DEPTH ....... NORTH/SOUTH EAST/WEST--. D I FFERENCE ........... CnRRE C:T I ON .............................................................. 6342 5636.88 6479 ........5736.88 6617 5836.88 6756 5936.88 6896 6036.88 5600 00 11.~,.,. :2-::3 1 - ""*-",v. :. 57AF).-0A 1't'85~-i-'1--:-:; ..... i ,': 1705~'44- 5800.00 1242.38 S 1781.99 5900.00 1299.01 S 1859.17 6000.00 .............. 1355.10 S ......... 19.)3'.~. 82. 7037 7177 7317 7456 7595 7734 7872 8012 8153 8297 8447 8597 8748 8894 ::::. :1462.77 S .'. :2105.00: · : · . .: ~ ~ ~.--. ~. · : . .--, 1' ~,'1 ~,-'~'-,., ~'-'- o ........ ~ 187', '42- 6436.88 6400.00 1568.34 S 2268.71 6536.88 6500.00 1621.17 S 234~.75 6636.88 ....... 6600.00 ............. I673.61S ..... 2430.95 6736.88 6700.00 1726.20 S 2511.06 6836.88 6800.00 177~.~7 S 25~1.72 6936..88 .......:--6900 00 ............. lo~A.'"" _--- . _ ,:,~-S'-'-' ...... 2674-.0A 7('~:3/-, o,:, 7000 00 1'-"-?' - '-,-.=,,-, o; c,. 9: .'_-< ..- 7..o. 12 7136 8:--: 7100 00 1 '262. '-"-' · . ..-o S 2L--:4Y. 93 72:_--:6 A'- Y200 O0 2029. Y3 :--: 293:--:.0Y 7:_-':36 88 7300 O0 '-'""--'~ · ..',., ;-._,. 03 :_:: 3027. E"" 7436.88 7400.00.' 2162.8:_::. S :-': 112.64 · . ............................................ E 37.04 E -- 742.--35 .87.~.02 E 780.70 38.35 E 819.13 38.42: E :., 859.32 .................. 40..1~ E 9(')0 ':":' ': :..!':..' 41 01 E 940 1:3 "'.::::::::::::::::::::::: .: :::';', '-'~ · · · · ~ _ . ~ o~ ~1 E- ll -- ......... 980;'1~ l:l: :l:'::''=; ~--': · .,; .~. ,/%l E 10 ~ 9. :37 :39.25 E 1058.51 39.14 E ......... 1097.._, E 11:36.10" : -- · : .51 E : 117._,. 37 . : :3'2.27 E' 1~1 _,~87 -- E 1260.66 E 1310.13 E ....... 1360.71 E 1411.26 E : 1457.73 41 -, 50' - · 43.79 / ' 4.9.4-7 ......... 50.' 58 ............................ 46.47 ..... ' ' SPERRY-:=:LIN WELL SLIRVEYING COMPANY ....................................................................... PAGE"-'11 ANCHORAf~E ALA.:,KA EXXON COMPANY, l,-' J.=,A DATE OF :=:URVEY FEBRUARY 21, "1"'-"": I}LTM Y-O 1 .'.? 1:1:i:2 .......................................................... COMPLITAT I ON" DATE- WILDCAT MARCH 2:, 19::,'?. -... ,_lOB NUMBER E LI.z,.z,-169741-'-"-' ALASKA KELLY BUSHINO ELEV. = 36.'-"~ ,: .... FT. ...................................................... OF'ERATTJR-M ILAM .................... INTERPOLATED VALUES FOR EVEN 100 FEET OF"".:,LB-oEA! '-' DEPTH TRUE :=;UB-SEA TOTAL A MEASURED VERT I CAL VERT I C:AL REC:TANGI_ILAR COORD I NATES MD-TVD VERT I CAL DEF'TH DEPTH DEPTH NORTH/.=,'-'FjLi]" H - ..... EAST/WEST D I FFER ENCE .......... "-CORRECT I ON ' .................. ......................... 9036 7536.88 7500.00 2223.47 S 9174 .......... 7636,88 .............. 7600~00 .............. 2280~67---$ 9311 7736.88 7700.00 2339.43 S 9452 7836.88 7800.00 2402.87 S 9593 7936.88 7900.00 ....... 2467.47 S ..... 3268 ,,- 27-E ............ 1537-;,-23 -- -37z'79 -- 3342.57 E 1575.00 37.77 3417.10 E 1616.00 41.00 3494.42 E ' - 1656.89 ....................... 40.88 ............................................................... .-" 9733 9871 0009 10146 10282 10417 10550 10682 8036.88 8000.00 2530.80 S 3568.94 8136.88 8100.00 2593.11 S 3640.98 '8236-~'88 ........8200.00 ....... ' 265d,'~48"-'S .......3712;'03' 8336.88 8300.00 2718.26 S 3782.36 8436.88 8400.00 2778.25 S 3851.59 8536.88 ........ 8500.00 .......... 2838.03 S 3919.51 8636'.88 8600.00 28?6.29 S 3985.75 8736.88 8700.00 2953.03 S 4049.64 ,-,,..,. ......... --, ..... (. 0.00 ..... .:, J U,:,; 00-' S c~,:7~ :--:,-_--~ ..... 8'.-.93/-,_.::'= ,=-: :=:,-.-~0o ...... O0 3061. ~(j' S 1065 :~036.88 90C)0.00 3115.34 S 1189 9136.88 ...... 9100. O0 .............. 3169.12 S 1312 ?'-W::A. ...- _ _. 88 ".~20A.. O0 ...,~..- .,;.":'":"--'":". 16 S 1433 9336· ,_,'.:"=',_,'~3,F),O. ... O0 3274.3",'2 S .......... 4110,'66-- 4:[69.40 4224.53 4274.81 4321.40 4365.29 E 1696.75 E 1734.86 E 1'772;94 E 1809.93 E 1845.55 E '' 1880.40 E 1913.76 E 1945.30 E ........ 1974~70 E 2002.43 E 2028.68 E ............. 2052'87 E 2075.29 E 2096.32 3'9.87 ,:,,::,. 11 ~,, -~1 i-i--. ..:, ,r',. '~) ,_.-, :_::6.99 o5 62 · _,! 0_ . ........... 34.85 .... :36 · :., ..:,. 31.54 '29,-40 -- 27.73 2/:, '-'= . ..................... 24.' 19 ';'2.42 · .7,1.0:3 · ANCHORAGE ALASKA EXXON COMPANY LoA DATE OF SURVEY FEBRUARY 21, 1'.-.-~82 ......... 0 C ;~; Y-OI'PI #2 ........................................................................... COMF'LITATION DATE W I LDCAT MARCH 3 1 '--,'-"-' _ , .. ,-,.- ,_lOB NUMBER BOF;S- 16.,'.-.-~74 ALASKA KELLY BU'::;HING I--LEV. - o6.,.o,-,'-"" FT. C F ERATOR-M I LAM MEASURED DEPTH II. INTERPOLATED VALLE.=, FOR EVEN 100 FEET OF '-'l · =,L B-.=,EA DEPTH TRUE SLIB-SEA TOTAL VERT I CAL VERT I CAL RECTANGLILAR COORD I NATES MD-TVD VERT I CAL DEPTH - DEPTH NC~RTH/SOLITH EAST/WEST ' D I F.'F:ERENCE .... C:ORRECT I FiN 11552 'P436. 116..71 ........9 5 ]~: ~, . 117o,=, ,--;A:_z:/-, 11906 :~'~73/_-,. 1.- L) .-..- <' ' '-"<' S;836 . 12137 ?936. 12251 10036. · .' ..:, =,4 101 ..... 12475 10236., · 1 '" F,'-' · -'.- ,=,6., 10336., · 1 '.-'. '6'.~6 10436. 12805 10536. 12914 10636. .......... 13022 10736 ~ 13129 10836. 13236 10'.-.-/36.,. · 13342 11036. 13441 11130. 88 88 88 88' 88 ?0 1 90 1 ~'0 1 90 1 ?0'-- 1 ?0 1 90 1 :~0 1 '.-.-~ 0 1 *- ' ' '-"-~'-* 2 {.J *400.00 ..:,._-,..' 4 · 74 S 4406. c; ' ':.'-~500.00 .................... --' '=' o -- . ..... 7 .... /_'.4. S ............. 4447~'08 '~'~ ......./-, ~'~ ¢). 00 "-" 4 .._...r, 2 33 S,~ a,-,/..~ -~ ,=, '-, · ~.]-='.z, ?.' 700.00 :'::_ 47 ¢~.. 42 ._,o ..'4 ._~] ~.":' .,':'. 6., 9 9:g;¢)¢). 00 .-:,~z..-:, 37 .=' n~c;..-, .95 00¢:)0. ¢)0 360'P. 11 :=; 462::. 41 0100.00 ............... .=, =,._,4'/- = .... · ,r. ................ 7 o 4 :,47~"48/- -- 0200.00 ::: A 9'-} '.~"/- ::-': 4671 '-" = 0300.00 374.3.35 :_=; 4.68?. 94 04¢x). 00 ....... 3786.,. 00 :--: 4705· 17 0~0(]. 00 3827 '-"-' ...... .-._-, S 4720.31 060¢]. 00 ' '-"-'.. ._, '-' '- = . o066 'P4 '=' 47o4. y._, 0700.00 .............. :_--:705' 42' S ......... 4748;'78 "' 08¢x]. 00 3742.40 ._, ¢' 4762.12 09¢~0.00 3978.18 S 4-773:. 64 1000.00 ' 4011.57 S 4783;0:.~ 10'.-.-¢4.10 403S~. 66 S 4789.:;=:S:c E '.-..' 115.7'~ 19.47 El .............. 21:34;,-'14 lo.._-,._ ,__~ ._i 17 1.=. ................... 16.20 ................................................... · 14 .' 99 "-"": :::'.: ............. I4,11 1'3~ 04 11 . ~--'- 10.91 '9.78 ........................... S 2268. :-.-~5 .. .: ::::::i..:.'. ::~. 22 :..: ..:..::::......-. ..' .............. ' . ...... ,,-,=- ' r.-;O ......... - ...........~' ;- ¢:! 4" -'": '-:- ..... ' - " ' · " ." ~Z, .~ · ._, o. ,-, - '-"-"-"¢'-' 04 7 46., _ ..' ~.. $ .", · · - 22'P9.87 6., · 83 -- .............. '.'.. '305.73 ........... 5;86 ............................. Z 2:i:10.07 4.34 ............. THE CALCULATION-PROCEDL~RES THE NEAREST 20 FOOT MD .......................... ..... ........ ..... . ' USE-A- bi NEAR"'I NTERPOLAT I ON"'BE~WEEN ................................................... (FROM RADIUS OF CURVATURE) POINTS : . . ! -1000.00 TAUE NORTH --1000.00 --2000.00 --3000.00 --4000.00 '-5000.00 Exxon Company, U.S.A. Our Boss Gyroscopic Survey Job No. Boss-16q74 Well: OCS Y-OlOl (.~EC20 T].2N Wiidcat Fie]_d North Slooe. AlasWa Survey Date: Pebruarv 2l, ~oerator: ~arvin Mi!am Scale: !" = ~_n00' ~oob. oo ~oob. oo 3oob. oo lo82 13441 HOBIZONT~L PBOJECTION k O. O0 Exxon Company, U.S.A. ©ur Boss Gyroscopic Survey Job No. Boss-16974 Well: OCS Y-019] ~2 (SEC2Q T12N ~wF) Wildcat Wield North Slome, Alaska Survey Date: February 21, ©oerator: Marvin Milam · Scale: 1" = 2000' 2000. O0 4.000. O0 6000.00 8000. O0 i0000.00 12000.00, 6265.89' ~ S4~° 51 'g I 2000.00 4000.00 6000.00 8000.00 V'ER. TICflL PROJECTION 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 [] other Exploratory 2. NAME OF OPERATOR Exxon Corporation 3. ADDRESS OF OPERATOR Pouch 6601, Anchorage, Alaska 99502 4. LOCATION OF WELL (REPORT LOCATION. CLEARLY. See space 17 below.) AT SURFACE: 1777' SNL, 683' EWL, Blk 654 AT TOP PROD. INTERVAL: AT TOTAL DEPTH: 5880' FNL, 6390' F~,~TL, Blk 654 16. CHECK APPROPRIATE BOX TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA REQUEST FOR APPROVAL TO: TEST WATER SHUT-OFF [] FRACTURE TREAT 'E~] SHOOT OR ACIDIZE [] REPAIR WELL [] PULL OR ALTER CASING .FI MULTIPLE COMPLETE [] CHANGE ZONES [] ABANDON* E~ (other) Form Approved. . .B~dget Bureau No..4,2.-_R1424 5. LEASE '" .... ::.. :i ':; :' '~ ~' -' 0CS-¥-0191 - :'- ~ ~ " :'~ ~ 6. If INDIAN, AL~O_ .TTEE OR TRIBE N~'ME .,'~. ~ ~- ~ ,~: ., ~;- ~j · .: % '3 0 7. UNIT AGREEMENt. I~IAME.,, ~ ~, 8. FARM OR LEASE i~I'~,ME · .-. ,= .. -~ .- ~ ,., .~ :~; 9. WELL NO. ' .~,: 10. FIELD OR WILDCAt, NAME "'; '~' .~. ;~- Wildcat ; i~ 'L~ ':! 11. SEC., T., R., M.~-OR?LK. AND S..UR. VEY OR AREA 654'~ ..S~. 20, R17E, UM .? =.':; :,' Offshore 15. ELEVATIONS ·(SHOW DF,. KDB,';ANb WD) 1~B-43' MSL; .,WD-18' ';' ':::g 5' SUBSEQUENT REPORT OF: .... .~. .:; ~ .~,~, ~. ] :' '" ~ ~2, ~2 '.;~ ~ -. , ,. ~.) :~ ",) ... ,~ .., " :~ 3. ~ ~- ~ (NOTE; Repo~ results of ~ultipl~ compl~lonf~r zone ~ change on Form g-330.); ': ~ r- [~ . . _ .~_"; b- '..~ ..... '"" '~ '-'.; :-- .L: 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 IdCatiops and measured and true vertical depths for all markers and zones pertinent to this work.)* 'V :.' ,.':. f'- ":- :.. ' % ; '._ .'. -. ~";i :::~, ~: Well has been temporarily abandoned in accordance with O~~er'.:number. 3Ti:p~r the attached description. The attached Figures l~?~__~,~e.t~il.lthe~wellbore ,. as temporarily abandoned, oIL AND GA . ,-. :, ~ 'i{~ j. :~ ':';. i!i i~ Subsurface Safety Valve: Manu. and Type N/A 18. I hereby c~rti~~) that/~h~e-f~rl~going,~t~ue and correct ~~ t /~) , ~ (This space for Federal or State office use) CONDITIONS 9~ ~Q~L, ~N~' / ~ :~"!~I~ *See Instructions on Reverse Side z'~,,/- ,. ../ . . / .. mR=A OCS-Y-0191 #2 Temporary Abandonment NFIDENTIAL 1. A cement retainer has been set at 11,365' DIL ± and 150 sacks of Class G cement were squeezed through the retainer and 25 sacks dumped on top. Calculated top and bottom of cement are 11,295' ± and 11,987' ± respectively. · · · · · · · The plug was tested to 1,000 psi for 15 minutes. Pressure- did not decline by more than 100 psi. The top 3,000' of mud was displaced with 10 ppg CaC12 water. A balanced open hole plug was set from 336'-110' MD with 100 sacks of permafrost cement. 500 sacks of permafrost cement was injected down 'the 9-5/8" x 13-3/8" casing annulus followed by 2 Bbls water and 54 Bbls of 10 ppg C~C12 water. Calculated top of cement is 964' MD ±. ' This plug was tested to 1,000 psi for 15 minutes. Test pressure did not decline by more than 100 psi. The BOP stack was nippled down and a blind flange was nippled up on top of the 'B' section. The blind flange has the following bead-welded identification. Exxon Company, U.S.A. OCS-Y-0191 Blk 654 Well 2 The wellhead cellar has been covered flush with the top of the island. JCC: b sw 220/000 4/5/82 Figure 1 'OCS-Y-0191 #2 'Wellbore After Temporary Abandonment DNFIIPENTI L Zone #4 11438'-11458' 11470'-11478' 11483'-11500' .:1-.I I ~_ ~0 ppg 9.8 ppg Mud 8 ppg Mud I '~ Hud 30" @ 128' Surface Plug 336'-110' MD Calculated TOC @ 964' MD 13-3/8" @ 2389' .~--~ Interface Mud-CaC12 @ 3000' MD 11EcEIVED OtS'l'alC'l' 12-1 / 4" Ho 10~L AND GAS oFFiCE APR 1 2 ~'~b'Z TOC @ 8000' MD (CBL) Cement ?etainer @ 11365' DIL .......... 150 sks cement squeeze thru retainer 25 sks cement on top of retainer Baker D packer @ 11373' DIL TOL @ 11589' MD 9-5/8" @ 12120' MD 8-5/2" Abandonment details of 7" liner shown on Figure 2 7" Lnr @ 13440' MD JCC 4/5/82 Zone #3 ..... 12,440,_576,.DiL Zone #2 12,700'-16' DIL Zone #1 12,764'-74' & 12,835'-44' DIL · . ~ Figure 2 OCS-Y-O191 #2 Wellbore After Abandonment of 7" Liner 12-1/4" Hole 9.8 ppg .,~. · Mud TOL @ 11,589' 9-5/8" @ 12,120' MD CONFIDENTIAL Baker F-1 Packer @ 12,415' DIL Retainer @ 12,410' DIL 137 sks cement squeezed thru retainer 13 sks dumped on top Retainer-@'12,643' DIL ....... 150 sks cement squeezed thru retainer ~aker F-1 Packer @ 12,645' DIL ~, Bridge Plug @ 12,729' DIL Baker F-1 Packer @ 12,732' DIL 8-1/2" Hole 7" 32#/Ft. Liner @ 13,440' MD Figure 3 'OCS-Y-0191 #2 l'~eilhead Arrangement TemporaryfOr Abandonment CONFIDENTIAL Blind 'Flange Labelled "EXXon Company, U.S'A. OCS-Y-0191 Blk 654 . Well 2" · , · ~~-~---~Blind Flange · ~llhead . B Section Wellhead ~3 3/~,, Sur --:.. 5' 6" + f. RECEIVED DISTRICT OIL AND GAS OFFICE Gravel Island 18 ' Thick ANCHORAGE, JCC 3/9/82 EXXON OCS Y-0191 NO. 2 WELL HISTORY REPORT SUMMARY CONFIDENTIAL Spudded well on December 27, 1981. Drilled a 17-1/2" hole to 2414' with 9.6 ppg mud. Set 13-3/8" casing at 2389' and cemented with 3000 sacks of permafrost cement. At a drill depth of 2424' a pressure integrity test was performed and leaked off at 13.6 ppg EMW. Drilled to 2500' where the hole was kicked off to east by jet drilling. Three cones were left in the hole after drilling with. a dynadrill from 3024' to 3639'. The hole was sidetracked at 3150' and directionally drilled with a 12-1/4" bit to 12,148' with 10 ppg mud. Ran open hole logs and cemented 9-5/8" casing at 12,120' with 2000 sacks of class G cement. At a drill depth of 12,163' performed a pressure integrity test to 15 ppg EMW and did not leak off. Drilled an 8-1/2" hole to 12,522' with 9.8 ppg mud and cut the following cores: Core No. 1- 12,522' to 12,551' Core No. 2 - 12,551' to 12,571' Drilled an 8-1/2" hole to 12,736' and cut Core No~ 3 from 12,736' to 12,776'. Reached a final total depth of 13,441' on February 11, 1982 and ran open hole logs. Cemented a 7" liner from 11,589' to 13,440' with 460 sacks'of class G cement. Drilled out cement to top of liner and tagged top of cement inside liner at 13,158 feet. After running a cement bond log the following intervals were tested: Test No. 1: 12,764' - 12,774' 12,835' - 12,844' Test No. 2: 12,700' - 12,716' Test No. 3: 12,470' - 12,576' Test No. 4A: 11,438' - 11,458' Test No. 4B: 11,438' - 11,458' 11,470' - 11,478' 11,483' - 11,500' A bridge plug was set above test interval No. 1 at 12,729'. Test interval No. 2 was squeezed below a retainer set at 12,640 feet with 150 sacks cement. Test interval No. 3 was squeezed with 150 sacks below a retainer set at 12,445'. Test interval No. 4B was squeezed below a retainer set at 11,365' with 175 sacks cement. Mud in the 9-5/8" casing was displaced with 10 ppg calcium chloride water from 3000 feet to surface and a 15 ppg permafrost cement plug was placed from 80' to 336'. Injected 500 sacks of 15 ppg permafrost cement down the 9-5/8" x 13-3/8" annulus followed with two barrels of fresh water and 54 barrels of calcium chloride water. The well was plugged and suspended at-0600 hours March 15, 1982. DATE: REPLY TO ATTN OF: SU~E~: TO: , memorandum Acting OCS District Supervisor Determination of Well Producibility OCS Y-0191 Well No. 2 DMM-OFO On Friday, March 12, Roy Longstreet of Exxon called the District Office and stated that Exxon has flow tested zone No. 4 in OCS Y-0191 well No. 2. Roy stated that Exxon believes the tested zone has well bore damage. Roy inquired whether, for the purpose of determination of well producibility, the ~D4S is going to ask Exxon to go back and acidize the zone or accept the adjusted production rate figures based on the "damage factor" values obtained in the pressure tests. He further stated that if required to acidize well No. 2, Exxon will not be able to test well No. 1 this season because of the current seasonal restriction on down-hole operations beyond March 31. After a oonference discussion with the R&O Supervisor, we told Roy that we will give him an answer after further consideration. After ~onferring with the Section Supervisors of E&O and R&O and the Acting DMM-OFO, I told Roy that we will accept the adjusted production rate figures, taking into consideration the "damage factor," but that Exxon has to submit both their interpreted and raw test data in order to allow us to utilize the raw data if we question their interpreted data. Nabil Masri cc: OCS Y-0191 Well No. 2 File 6B (Area & District) NMasri :peg: 3/17/82 :Nabil: 2: roy Buy U.S. Savings Bonds Regularly on the Payroll Savings Plan OPTIONAL FORM NO. 10 (REV. 7-76) GSA FPMR (4! CFR) 101-11 .a 5010-112 OFFICE OF THE SECRt~fARY Minerals ~anage~nt Service Alaska Region 800 A Street, Suite 201 Anchorage, Alaska 99501 - ~arch 12, 1982 Mr. A1 Herman Exxon Company, U. S .A. Pouch 6601 Anchorage, Alaska 99502 Dear Mr. Herman: The OCS Lands Act Amendments of 1978, the 30 CFR 250 Regulations, and OCS Orders set forth the functions, responsibilities and authorities of the appropriate District Supervisor, Mud] of this authority is further 'delegated to the Petroleum Engineering Technicians who perform inspections as the delegated representatives for the District Supervisor. Consequently, the on site Petroleum Engineering Technician has the authority to witness and inspect any and all operations performed by a Federal lessee pursuant to a Federal lease. Our delegated representatives are there primarily to inspect for safety, conservation of resources, and environmental protection. :Such representatives are performing inspection and witnessing of "-ii~11 !operations in accordance with applicable ~laws, regulations, /ahd iorders. -These inspections include all environmental ~ pro~ection equipment and all safety equipment' designed to prevent or ameliorate blo~)uts, fires,~spillages, or other major ~. ~; ~_ ~Inspectors are al~so there to ensure conservation of resources for · which the government has a royalty intere~.t..Land a public trust. .. An order for cessati°n of operations due to a delegated · 'representative being excluded from witnessing any or all ~.operations will come from the Distric~ Supervisor's office and {'from: the on site Federal inspector. In general, enforcement ~.'actions ensure that any incident of ngncompliance (INC) with isafety and pollution-prevention requirements observed during ~·~i~' .in--ion activities is corrected by the operator. 'fO provide objectivity, the .a~ro?riate rmtificatic~ and enforc~.~ent action for each INC observed is i~icat~d on the Potential Incident of Non~l iance (PI~NC) checklist. Enfor~t actions consist of (1) written warnings or (2) platform, zone (well), equipment, or pipeline shut-in, depe~nding u(x~n the nature and signific~_noe of ,3~ violation. In the case of a written warning, the oo.-.~pany representative .~ust certify to the District Supervisor within 7 days that the LNC has been corrected and must report cn the action taken to preclude recurrence. If an enforcement acticz] req~ires a shut-in, the inspector i~ediately informs the District Supervisor and . de.gcribes the situation and the consequ, ences of the shut-in. District Supervisor then authorizes the prescribed ~nforcement action. If, because of cagr~nicatic~% problems, the District S _upervisor cannot be-o~ntacted, the inspector is authorized to take the app~ropriate action a~ to notify the District Supervisor as soon as possible. The inspection team leader .provides the company representative with a written order to shut in the zone(s), platform, or other facility after explaining orally the reason for the ~hut-in. ~ the inspector reports a facility shut-in, the District Supervisor nOtifies the ~ of the action in ~TitJng, instructir~ them not to resum~ operations until the field site ba~ been reinspected. ~he well, item of equipment, or facility carunot res~e operation until the INC is corrected and the company has received clearanc~ from the District Supe~~ to resume operations. . . In the event an inspector m/st halt drilling operati~ on a well'" the District Supervisor notifies the ~ in writing.. However, in order to minimize t_he dangers of maintainirg an open hole, the inspector remains at the drillirg site or returns to it as soo~ as certification of compliance from the company. Ail enforcement actions taken during a specified m~nth and the ctmulative, actions take~ during the current calendar year are summari~ in monthly and annual field reports. -~ Enforcement actions ~%ioh are out of the ordinary, have wide impact, or result from a suspected k~owi~ and willful violation of rules or regulations are r~ported to the Director up0~ acomm~ation of accurate information in accordance with established procedures. t~ ti-4~s 1%.~11 desigm3te an en.~ir~.er or qeologist to observe certain operations, but at all other ti~es the Petroleum Enqineerir~ Technician is my designee. ' ~ ~i~ F. ~f C~ Distri~c Sut~Ni~r <~fs~m Field C~erati<~ cc: File /~ ~ -~ Chron Circulating Chron 101--02 BSchoof: dww: 3/11/82:S~f/2~e~ . Checked by Date /2 ~ 2 APD CHECKLIST Page 1 of 6 - ~ision date: 7/7/81 DATE APD RECEIVED DATE APD APPROVED LOCATION , A~A ~£ ~ ~ WATER SLOC~ K~ ~ WELL NO. P ~ .o.. ~. S~- Po !- oooo 2 zone = . ,,7~° 23' ./I.?~'" WATER DEPTH /~ _. PROP. DEPTH /P'OV~' ~ K/~IT~o 70.3F~33 ~0. oo3%? Iff?, ¢~33 + ~, · CheCk files for: A. Lessees 6'rr,.~ ~ W~ t o · . B. Designation of Operator' / C· -Field Rules 'A/A D. Oilspill Contingency Plan G. Restricted Lease H. Exploration Plan Approval and Restriction' /' Fo~ D4- 3/81 J Page 2 of 6 E. POD/POE Approval, , , . I. Shallow Hazards Report F. Lease Stips. Applicable K. Environmental Analysis J' ,, L. Platform Verification II. APD Program A. Evidence of Vessel Fitness 1. Design, drawings, equipment specs. & performance 2. Environmental conditions expected 3. Current classification or certification of f~tness with operational limitations ............... 4. Subfreezing operations / - ..,. 5. Recommendation from Structural Engineer · Bo' Rig approval date ~~.~.- C. oceanographic, Meteorological, and Performance Monitoring ~o~a~.. "" · ~' & ~,'/$ ~ ~, ....... '. · , · D. Environmental Training Program submitted 1o Anticipated surface pressure calculations: .3,, -- ----~4°,guCT""~'a,~" ~$].~ 2° Safety Factors (Proposed/~ws--~a~k) ..... -- - CollaP.se Burst Tension a. 'Structural b. Conductor C. SUrface 4o. 'Intermediate e. Liner Page 3 of 6 0.. Fo Go 3 · Setting Depths ao Structural Conductor c. Surface d. Intermediate e · Liner O?D./Prop,osed Setting Depth , . . 3 4. Conductor and Surface Casing (Engineering, Geophysical, Geologic) 5. Pressure Tests, WOC (Proposed/Re~ired) Csg~ .T.est Press. Leak 'Off/Pre-Dete ,rmined WOC Tim.e a. Conductor Surface c. Intermediate '' d. Liner cementing 1. Structural 2. Conductor Casing Design' for Permafrost Use Surface J 4 · Intermediate . .. · : .. ~ . 5o Liner- Use of permafrost cement where required BOPE 1. Diverter System , , ' -2. Required Number of BOPs' o . 3. Test Pressures Required: Ram-type Blowout Annular-type Test Operation a. On test stump Preventers and' Related'Equipment Blowout Preventers Before drilling out. conductor casing c. Routine test below conductor'casing d. Before drilling out surface casing e. Routine test below surface casing · f. Before drilling out intermediate casing g. Routine test below _ 50~0 intermediate casing 4. Urilling conductor hole wo/Marine Riser? If so, Supporting data' Seismic data u, , Geologic ~ata - ¢o ~erator's geologic hazard s i ' ' ' · 4. Water depth ............. ., e. Schet~tic diagram from r~'t~ry t~ble to conductor casing seat ..... / ............ f. 'Mud weight / '' ., g, Contingenc~ p/n for moving off location Subfreezing Operations Page 5 of 6 . . Mud System 1. Tabulation of well bore volume versus minimum quantities of mud material 'to be maintained at well site~ ....... ~'f"" 2. Emergency mud resupply " 3. Constituents & concentrations list'' . . . 4. Redundant mud pumping and power generating systems 5. Mud temperature control I · Logging Program Coring Program J. Safety precautions in enclosed areas ~Date Oilspill Equipment Checked Last' -.-Training Documentation III. Action Needed ~ A. 'Post POE/POD & APD List' ' B. Make IWR C. Make Log Card D. Attach "conditions · .- E. Additional Requirements 1. Applicable Logs' 2. Washed Cuttings Samples 3. O~er '' IV. BAST Review Page V. Contingency Plans :' A. Emergency Procedures Plan/Critical Operations and Curtailment Plan(including energency evacuation) · B. Relief Well Plan C. H2S Plan / D. Oilspill Plan, Berms,.Equipment · E. General Welding, Burning, and Hot Tapping Plan F. Icing and Ice Loading. VI. Geological, Geophysical check lists and/or report(s) filled out and copies attached · ' .... Checked by: " Page: ! of 2 Revision Date: 3/21/81 OCS DISTRICT ALASKA REGION To: From: Supervisor, District Oil and Gas Office Subject: Geophysical" Analysis Well No. ~2_ water Depth l s u ow c .0P,Yszc AN Yszs 1. Water Column Anomalies: Present Lease No. Location Distance-Direction a. W.C.B.D. b. S.S. Sonar c. Profiler Fathometer e. - comments: 2° Water Bottom: a · Morph o lo gy ce Comments: 3. Overburden: ao Thickness bo Layered? c° Faulted? Disrupted? Voids? 4. Consolidated Section: · a. Depth BML b. Dip and direction ¢. Tentative age and lithology ~.' Trapping mechanism present: Simple closure Fault closure .Stratigraphic closure Combi~ation e. ..Evidence of gas? BSL Summary of potential hazards: ~0 ~4~O~.. IJoq~9~. ~6 /~T~C)~T~ . . .. .. . -' Form D2-3/81 . . ¥ . ~ , Page~ 2 off 2 Revision Date= 3/20/81 Well No. ~ · .e..e No. 06% '%'- O I "DEEP# SEISMIC ANALYSIS Trapping Mechanism: ao Anticline bo Fault= Up thrown? Down thrown? . Stratigraphic d° Combination C~9~ ~-V~L~~ -~q%~-~G~ · eo 2. Anticipated Target Depths: a. 1~ &,s~u~ fro. dS~0~;~o~% age ~ %~ ~ ' ~BSL OC ;~;1%~. iBML Co fm. age ~ ' sec/BSL ' BML d. fm. age / ' sec/BSL ' BML e° Comments: ~gT~ ~U ~1~9~~ ~ ~0S~' ~. Mi-. 3. Anomalous Conditions: a. ~"Bri ght Spot" Line SP's Time Line SP's 'Time Line SP's Time Depth 'BSL Depth 'BSL Depth 'BSL b. Overpressured zone?. C~ WAll borehole penetrate fault? 4. Other Comments: 5~---~ ~OP~'~",.%ICi%'I.., ,~I-O~I..,Y~I5 r-.,ol~- O~S Y"- 01~1 t, UEt. L. /Jo, I , ~O'TT'ot.,t I-W3t..E ~O4. A'T'~o~ 1.5 6x~P£c,'r'~-c, ~ -"/-E.~'r" UP Dt~ FIzot.'l ~e-t~/jo, I Signature: · . -.~ 'Date: Form D2-3/81 u ,'iDENTIAL Page: 1 of 1 Revision Date: 3/20/81 OCS DISTRICT ALASKA REGION To: Supervisor, District Oil and Gas Office From: Subject: Geologic Hazards Based on High Resolution Data Relating to an Application to Drill Operator Exxon Well Number 2 Area BF me Surface Hazards: A. Slope and Morphology Lease Number..0CS Y-0191 Location x = 1.53Q,848 y = 25,620,154 UTM Zone 6 B. Indications of Slumping C. Surface Faulting D. Seeps (water column anomalies) II. Subsurface Features: A. Overburden B. Faulting C. Closure D. Shallow Gas III. Seismicity (for bottom founded structures): A. Regional'Seismicity B. Fault Zone Activity Co Soft Soil Effects IV. Volcanic Activity: V. Recommendations: Signature: 'Date: Form D1-3/81 .. CONFIDENTIAL January 29, 1982 To: Supervisor, District Oil and Gas Office , From: District Geologist Subject: Report on Geologic Hazards Based on High Resolution Data Relating to an Application for Permit to Drill I. Surface Hazards A. Slope and Geomorphol .ogy3 Lease OCS Y-0191 is relatively flat, with water depths averaging 21 feet below mean sea level. The gravel island was constructed in 18 feet of water. Ice gouging is present on the site of the proposed island, strudel scour was observed 6000 feet SW of the proposed location. Sand waves on the sea floor were mapped 3000 feet due west of the site, roughly in the same area as gas-charged sediments. B. indica, tio. ns o.f _slumping: Ce None apparent. Surface Faulting: The presence of numerous bo61ders on the sea floor' created many spurious peaks on the fathometer record, and these peaks prevented the recognition of any potential fault scarps. D. See.p.s. (Water Column Anonolies): No seeps were observed on either side scan sonar or fathometer records. Interpretation of the data was extremely tentative due to shallow water. Identification of acoustic anomolies, interpreted as shallow gas-charged sediments, suggests that seeps could possibly be present. CONFIDENTIAL II. Subsurface Features A. Overburden: The site is free of the surficial lag deposits, exposed elsewhere in the area, associated with erosion of the underlying Pleistocene Gubik Formation. A marine stiff clay member of the Gubik Formation is exposed at the drill site. The deposit is about 65 feet thick at this location and overlies Pleistocene alluvium. Boulders, believed to be ice-raffed, have been reported in the' stiff clay unit in other nearby localities. B. Faulting..: Ce No shallow faulting was identified by either the hazard survey or the previous deep geophysical surveys Conducted by USGS and Exxon. The Alaskan Beaufort Sea OCS is tectonically stable, and therefore active faulting is not to be expected under present day conditions. ClOsure: , , No closure is present at the contact between the stiff marine clay and underlying alluvium. We would, therefore, not expect any shallow gas accumulation. D. ~hallow Gas: Near-surface acoustic anomglies, presumed to be shallow gas of either petrogenic or biogenic origin, were observed 3000 feet due east of the drill site. The acoustic anomolies are within 15 feet of the sediment Surface. III. Seism~city Regional Seismicit..y.: Regional seismicity on the Alaskan Beaufort Sea OCS is believed to be very_ low. - BI FaUlt Zone Activity: No-fault zones' have been identified, although the reSOlution of seismic data in the upper geologic section is very poor. Co Soft Soil Effects: The over-consolidated nature of the stiff .marine clay makes it an ideal foundation material. Adjustment to the further loading caused by the emp_!acement of the gravel island or failure due to seismically induced motion should be minimal. IV. ~Vo!canic _ActiyitY~ No volcanic activity is present. V. Recon~nendations Based on submitted data, no potential ge.hazards to exploratory drilling were identified. Boulders, if present within the stiff marine clay, may present a problem to drilling. Diverters should be able to handle any problem with possible shallow gas. Dipmeter records should be analyzed for evidence of faulting in the shallow section. EncloSure ~Norman Miller NMiller: dww: 1/29/82: Miller/1/data OCS DistriCt Alaska Region Page: 1 of 1 Revision date: 3/21/8!~~ Well No. 2 ' Lease No. OCS Y-0191 Location: x = 1,530,848 · y = 25,620,154 zones 6 Area: BF To: -. Supervisor, District Oil and Gas Office From: Subject: Report on Anticipated Depths and Thickness of Potential Oil- and Gas-Bearin~ Horizons (Including those above projeCted surface casing depth) 2. Freshwater Sands' Other Mineral-Bearing Formations (Cap Rock, Salt, False Cap Rock) 4. Possible Lost Circulation Zones 5. a) Possible Abnormal Pressure Zones b) Other Horizons Which May Need Special Mud, Casin~, or ~ementing Programs (including permafrost and hydrate zones) 6. Additional Logs or Samples Needed Signature: Date-. Form D3-3/81 CONFIDENTIAL January 29, 1982 Memorandum To: Supervisor, District Oil and Gas Office From: District Geologist Subject: Report on Anticipated Depths and Thickness for Exxon Well No. 2 on OCS Y-0191 · Potential Oil and Gas Bearing Horizons Targeted depths are the Sadlerochit Group at 9725', the Lisburne Group at 10,230', ana the Kekituk Conglomerate of the Endicott Group below 10,355'?¥0 ~ 2. Fresh Water Sands None anticipated. 3. Other Min_eral-.Be_ arin_q Fo_r~a~ ~tions None anticipated. · Possible Lost Circulation Zones Lost circulation has been reported onshore at Prudhoe Bay and will probably occur offshore. Within the Tertiary Sagavanirktok Formation and the Upper Cretaceous Colville Group, which comprise the first 8450' TVDto be drilled, the sandstones and conglomerates include many zones where lost circulation may also be encountered associated with fractures in the Lisburne Group and in some of the Endicott sands and conglomerates. 5a. Possible Abnormal Pressure Zones Abnormal pressures may be encountered in the Torok Shale (8450'TVDto 9720'TVD) if overpressured turbidite sequences are penetrated. CONFIDENTIAL 5b. Other }brizons ~,~ich May Need. S..~e._cial Mud, Casing, or '-C~m~r{t'ing Relic submarine pernm~rost ~s present 27' below the surface and estimated to be approximately t300' thick. This permafrost is thought to be n~tastable and extremely susceptible to thaw. Hydrogen sulfide has been encountered in isolated instances elsewhere on the North Slope when wells have penetrated the Lisburne Group. Precautions against hydrogen sulfide should be taken below 10,230'. iV~.~',',- 6. __Addit ional~ j _L~q_~ __s_ Forward field prints of mud and wireline logs to this office as soon as possible. The sample distribution procedure outlined in the Exploration Plan is acceptable. Norman Miller Enclosure NMill~r: dWW: 1/29/82 ~ Mil le r/1/report ~ I I /'-~,.,~1 IIVlI,~..I ~1 I EXPLORA- ~y PLAN OCS-Y- O189, 0190,.0191,0192, O193 PROPOSED I0¢$-Y-0191 No.I 0CS-Y-0191 · f '::,..: -.~q, . j.' .-:.-.'~ -- '"- . -: ~ '. ;~.': '--'? '4::--- : 'b'/;.i.'- . . · -.~ ~ · . · ....:?- -.-. -. - .:..- ~. -: .- :.' . -..--. ... ~ . ... ..... ..' ~.'~. ?': ..- ..... ~j.- - .. . ..... -' 'i ?"}-'} 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 other l~.xploratory 2. NAME OF OPERATOR Exxon Corporation Form Approved. Budget Bureau No. 42-R1424 5. LEASE '";' ~; ?, ,2,5 OCS-Y-0191 . ~;~: ** :~': :-~ 6. IF INDIAN, ALLOTTEE OR TRIBE'NAME .... f ,.3:. ~..:., ;,:, .~.~ ...... ,~ .:. . 7. UNIT AGREEMENT NAME. ': · . ..... · , .... : ,- · 8. FARM OR LEASE NAME _ '.': ..,..; -.. :.,- - .. ,~ ~." 9. WELL NO. 2"/. 6' ..-'" .:~ ..- 2 -',¢ !:!.." ',', " ; :' ~'-.,:,- 10. FIELD OR WILDCAT NAME ," ': 3. ADDRESS OF OPERATOR ..... Wildcat, 7...'!, ,.., .- .... ' /. :; .. Pouch 6601, Anchorage, Alaska 99502 11. SEC., T., R., M~:.QR'BLK. AND SURVEY oR 4. LOCATION OF WELL (REPORT LOCATION CLEARLY. See space 17 AREA 654, :.sec-. 20, T.1..0~, below.) R17E, UM ' ~, '~:.~ ,..::' "... :L .;. .... ... AT SURFACE: 1777' SNL, 683' E;~, Blk 654 Z2. COUNTY OR PA'~sHI 13. STATE'" AT TOP PROD. INTERVAL: Offshore AT TOTAL DEPTH: 5880' FI~, 6390' ~¢~, Blk 654 z4. APl NO. 16. CHECK APPROPRIATE BOX TO INDICATE NATURE OF NOTICE. 55-201-000'02': · o-- :.. - .-~' -, ~". REPORT, OR OTHER DATA 15. ELEVATIONS'.}(~HOW DF/{ KDB~ 'AND WD) ~~. HSL;' ~D-18' :" REQUEST FOR APPROVAL TO: SUBSEQUENT REPORT OF: ~:~] C * · AND GAS OFFICE· TEST WATER SHUT-OFF -r-] [] DISTRIC~ ........' FRACTURE TREAT 'r-] r-] OIL c ..... :~. SHOOT OR ACIDIZE ~ r-] res~lli~ ~f multiple completion Or zone REPAIR WELL [] [] I?[,~,~(N~T~: ~.t PULL OR ALTER CASING .r-] E] change on' Form 9-3300. :~ ..~ ,,~.. L., ' ...... :' ~.'.: MULTIPLE COMPLETE [] [~ " ": 'i~; :.'.'. " --, = .... il; CHANGE ZONES E~ E] --: r - - '~ :. -. ..- . ...... " ~-.~ . ~.~ ABANDON* [] E~] AI~AsKA.; ':~ ' "" ANCHORAGE, (other) -. .. ... 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:sUbsurfa_ce locations and . .. . .... ' ,,;, .~: :.. measured and true vertical depths for all markers and zones pertinent to this work.)* '~ ~-i!!. j-i '2. '2. '" '~' . will. abandoned in accordande with OCS order number 3 per the at'ta.cbed de~cri~tign. The attached Figures 1, 2, & 3 detail the welibore as proposed for ~hi~ ...... - .-- ,' abandonment. ' ' ~" '; ~. '-..: ~.~ :; Subsurface Safety Valve: Manu. and Type N/A 18. Ihe~_j,~rl~yth/a)t~oi~]~rueandcorr~ec~,~..' ,....~,,~], .space for Federal or State office use) APPROVED ~ TITLE DAT~ CONDITIONS .. , ..' .~.: ,'~ ..: ~; t J, ~.. :~- ..~- ~.. : ~. ~ .., ., ,~ .,,.~ ... ~ -G K '-" :';' ::E "'- '" ._ · .... :~ -7¢Z~ '-", {;': Set. ~' ~ ,~ F.';':: ~. :-'-,' ,:.' ;~ ~ o '"' ~' . '.; , ; .' ; '' ,-~ .- '. CONFIDENTIAL 'See Instructions on Reverse Side OCS-Y-0191 #2 Temporary Abandonment CONFIDENTIAL · · · · · · · · · A cement retainer will be set at 11,368' DIL ± and 132 sacks of Class G cement will be squeezed through the retainer and 18 sacks dumped on top. Calculated top and bottom of cement are 11,167' ± and 11,318' ± 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 46 Bbls of 10 ppg CaC12 water. Calculated top of cement is 855' MD ±. This plug will be tested to 1,000 psi for 15 minutes. The BOP stack and 'B' section will be nippled down and a spacer spoOl with a blind flange will be nippled up. The blind flange will have the following bead-welded identification. Exxon Company, U.S.A. OCS-Y-0191 Blk 654 ' Well 2 The wellhead cellar will be covered flush with the top of the island. JCC: b sw 220/FFF-2 3/9/82 Figure 1 OCS-Y-0191 ~2 Wellbore After Temporary Abandonment CONFIDENTIAL · . Zone f~4 11438'-11458 10 ppg CaC12 9.8 ppg Mud 9.8 pp Mud I - ~., I i , 10 ppg Mud 30" @ 128' Surface Plug 336'-110' MD Calculated TOC @ 855' MD 13-3/8" @ 2389' Interface Mud-CaC12 @ 3000' MD 12-1/4" Hole TOC @ 8000' MD (CBL) ' 'cement retainer @ 11368' DIL 132 sks cement squeeze thru retaine 18 sks cement on top of retainer Baker D packer @ 11373' D%~ TOL @ 11589' MD 9-5/8" @ 12120' MD 8-1/2" Hole Abandonment details of 7" liner shown on Figure 2 7" Lnr @ 13440' MD JCC Figure 2 OCS-Y-0191 #2 Wellbore After Abandonment ~f 7" Liner CONFIBEI TIAL 12-1/4" Hole TOL @ 11,589' MD 8" @ 12,120' MD 'Zone #3 -12,440'-576' DIL Zone #2 · .~ 12,700'-16' Zone #1 12,764'-74' & 12,835'-44' DIL 10.0 ppg Mud Baker F-1 Packer @ 12,415' DIL Retainer @ 12,410' DIL 137 sks cement squeezed thru retainer 13 sks dumped on top Retainer'@'12,643' DIL 150 sks cement squeezed thru retainer '~aker F-1Packe~ @ 12,645' Bridg~ Plug @ 12,729' DIL Baker F-1 Packer @ 12,732' DIL 8-1/2" Hole 7" 32#/Ft. Liner @ 13,440' MD 5 ' 6" + Figure 3 OCS-Y-0191 #2 Wellhead Arrangement for Temporary Abandonment Blind ~l~nge Labelled "Exxon Company, U.S.A. OCS-Y-0191 Blk654 Well 2" , L Blind Flange Spacer Spool I ...... '" : 13-3/'8" surfak,e ~' · Casing ' '-I ,ii.~-':' ~;:; ~;] 30" Conductor -- _ __ Gravel Island 18' Thick JCC 3~9/82 Form Approved. 9-331 Budget Bureau No. 42-R1424 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 [] Exploratory well [] well other 2. NAME OF OPERATOR Exxon Corporation 5.. LEASE OCS-Y-O19I ~ 6. IF INDIAN, AI~L~TEE OR ~'RIBE NAME "* --- ~ .~ ~ ~.,., : .., ~; :.~ 7. UNIT AGREEMENT:~AME.~ -, 8. FARM OR L~SE ~AME 9. WELL NO. . .~ -~ .; .~ .. 10. FIELD OR wIfD;CAT:NAME~' 3. ADDRESS OF OPERATOR Wildcat :7.5 L~ -~z 2.,. ~:_~ '~- :,;" ~ f; ,,-- Pouch6601,. Anchorage, AK 99502 1:1. SEC., T., R., M.; OR~BLK.~ND SURVEY OR 4. LOGATION OF WELL (REPORT LOCATION GLEARLY. See space 17 AREA Blk 654~:Sec'~ 20, :.~2N, below.) R17E ~ .'~ ::: ',. .... ... ": ii!, AT SURFACE:iT77' SNL, 683' EWL, Blk 654 12. COUNTY OR 'PARiS'HI 13IsTATEF.'.~ AT TOP PROD. INTERVAL: Offshore--.'.~ AT TOTAL DEPTH:5880' ENL, 6390' FWL, Blk 654 14. APl NO. '.t ,< "a :'" '":'~ .... 16, CHECK APPROPRIATE BOX TO IN.DICATE NATURE Of NOTICE, 55-201-00002' - "::~..- REPORT, OR OTHER DATA 15. ELEVATIONSf*(s. HoW DF,!.KDB~iAi~ID WD) RY~=43' MSL;'~ ~D=l.8' '?~' REQUEST FOR APPROVAL TO: SUBSEQUENT REPORT OF: TEST WATER SHUT-OFF 'E~] FRACTURE TREAT 'E~] [] SHOOT OR ACIDIZE [] '~-] REPAIR WELL [] E~] PULL OR ALTER CASING .E~] MULTIPLE COMPLETE [-I CHANGE ZONES r-] [] ABANDON* (other) (NOTE: Repo~ results of ~ultipl~ completion'or zone chan~e :[8. ' hereby th~ L_e ff e. APPROVED C 0 N D I T I O N ~l~;~'At;-t~A N 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details; a. nd give:pertin, ent' dates;' including estimated date of starting any proposed work. If well is directionally drilled, give,.SUlbsurface locations and measured and true vertical depths for all markers and zones pertinent to this work.)* Notification of abandonment of test interval //3, 12576-470, .DIL. retaine~: a't",~ 12410, Abandonment will be performed by setting a cement retai~er ~he attached f±gure dep±cts the wellbore abandonment to :or ro e ure =om ac 16:30 hrs, March 6, 1982. ...~ Subsudace Safety Valve: Menu. and Type ~/A "'" ' Set ...~ % Ft. s~rueand correct n ~ ' 0'~ TITLE ~~~~~~ AT E .// (~ space for Federal or State office use) .,, ..'? ,-..-.,- ~ ?. :: .?_: ':', ~:.:. £:. :! .:z *See Instructions on Reverse Side OCS-Y-0191 #2 - \ - ~ Wellbore After /%bandonment of' Zone #3 12-1/4" Hole ! TOL @ 11,589' MD 9-5/8" @ 12,120' MD Zone #3~' -12"~40' ~576"-~DIL ........ Zone #2 ........ ;: ............. 12,.700'-16".. DIL ':' '":" zone #1 '~ '" 12,764'-74' ": ...... & 12,835'-44' !! ..... .. fBaker F-1 Packer @ 12,415' DIL ' etainer @- 12,410' DIL 37 sks cement squeezed thru retaine~ 13 sks dumped on top ' ' ' ..... Retaine~' @' 12,643' DIL .............................. 150 sks cement squeezed thru retaine: Baker F-1 Packer @ 12 645' DI,L . Bridge Plug @ 12,729' DIL Baker F-1 Packer @ 12,732' DIL 8-1/2" Hole 7" 32#/Ft. liner @ 13,440' MD ~-$31 1973 :DiSTF{IC'T O~N.D GAS OFFICE 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 [-] 2. NAME OF OPERATOR Exxon Corporation other Exploratory 3. ADDRESS OF OPERATOR Pouch 6601, Anchorage, Alaska 99502 4. LOCATION OF WELL (REPORT LOCATION CLEARLY. See space 17 below.) AT SURFACE: 1777' SNL, 683' EWL, BLK 654 AT TOP PROD. INTERVAL: AT TOTAL DEPTH: 5880' FNL, 6390' FWL, BLK 654 16. CHECK APPROPRIATE BOX TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA REQUEST FOR APPROVAL TO: CONFIDENI AL Form Approved. .. ~.B.udget Bureau No.. 42-~R1424 6. If INDIAN, ALLOTTEE OR'TRIBE NAME 7. UNIT AGREEMENT'NAME.'. :{ 2_ ~ 8. FARM OR LEASE NAME ;.~: <:. -'":/~. , ,.~ U-~ . -. 9. WELL NO. F ' -., ~'.~, . ~...; '::..-~ .._ :; ~; 10. FIELD OR WILDC:A,T NAME .... '"' Wildcat ..... 11. SEC., T., R., M.', OR; BLK. AND sUlkiLY OR AREA BLK 654,) SEC..~O.,:'":;~.12N R17E, L~ ..i~ ': ,' .... j-=:.'~' i_:. ;~,."~,;~ ' 12. COUN~ OR PARISHI ~3;' SlAtE'~ ~. 15. ELEVATIONS"(sHOW DF;;~;.KDB, iAND WD) AYe=43' MsL;.' WI)=18': i:.' ::~..5 5' SUBSEQUENT REPORT OF: .... -.-~ TEST WATER SHUT-OFF E] [] FRACTURE TREAT 'ti [] - .... ~-.~ -.-" SHOOT OR ACIDIZE REPAIR WELL ~ ~ (NOTE: Repo~ resultS of multipl~:'com~efi~ or zone PULL OR ALTER CASING MULTIPLE COMPLETE CHANGE ZONES ~ ~ :- . ....... - ABANDON* ~ ~ -~ :"~" "~ .F : c' :,, o .-- (other) Request Deoartura :' 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, ~nd give-pertinent'.dates,' including estimated date of starting any proposed work. If well is directionally drilled,·give Subsurfa'ce locations and · measured and true vertical depths for all markers and zones pertinent to this work.)* Request departure from OCS Order No. 2, Section 5.3, Surface'."BO~ ~Req~-~r~m'e~ts, for abandonment of production test interval ~2, located at ~2','7~0'-716' -~ ,.. ., ~ .,..~ :., ,~: Departure will be from note 2, Pipe Ram Configurations. -~ -- ~.... Approval is requested to wireline set a cement retainer abo'+e :p:6rforatig~ST;"ijRIH with a 5" x 3-1/2" tapered drillpipe string, and squeeze cement. the test':'i, int.'erval without changing the drillpipe rams from the current 3-1/2", pipe will be laid down after squeezing and 3-1/2" drillpipe ~sed-l. for i:sub.'s~'~ent operations. ~.: .-~ .., -. :: ::- .'._; ....:;..:,; ~ .~. : ::.. ::, -.: t:, '"' :,: :~ o -- :-: Justification for departure: 1) No hydrocarbons are exposed ':; '2)' K{ll"W~Lght · . · fluid will be in wellbore 3) Retainer with closed sliding valve will be .... .'_::, above perfs 4) Annular preventer is available. .-_-. :~-.i.: ..... Subsurface Safety Valve: Manu. and Type N/A ... :7 "-.~ set @:'...._~ r.< [~i' ::': '~. Ft. ;; o i':" ,'.',:. :'t % ..~ 2) -- ,~, .~.", 18. I hereby~e~ify tl~t the f/~regQ~g is true and corre~;t __ _ "~---~L / -~ //~7 '~' ~ IS S ace for Federal or ' ' '"' ~~ / ~ // ~' P State office use) " . *See Instructions on Reverse Si~e OCS-Y-0191 #2 Wellbore After Abandonment of Zone #2 CONFIDENTIAL Zone #3 12,440'-576' DIL 12-1~4" Hole '~ TOL @ 11,589' MD 9-5/8" @ 12,120' ~) (N°t yet perf'ed) Zone #2 . ~ , 12,700'-16' DIL ~' ~ ~ I ~~ Bridge Plug @ 12,729' DIL Zone #1 ~/ ~y 12,764'-74' & i2,835'-44' DIL .' Retainer @ 12,643' DIL 150 sks cement squeezed thru retainer ~__._~ Baker F-1 Packer @ 12,645' DIL ~ Baker F-1 Packer @ 12,732' DIL 8-1/2" Hole 7" 32#/Ft. liner @ 13,440' MD JCC:bsw 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 other Wildcat 2. NAME OF OPERATOR Exxon Corporation 3. ADDRESS Of OPERATOR Pouch 6601· Anchorage· Alaska 99502 4. LOCATION OF WELL (REPORT tOCAI~ON CLEARLY. See space 17 be~ow.)Blk 654; 1777' SNL; 683' EWL. Lat. 70° AT SURFACE: 23 ' 11.79"W; Long. 147o53 ' 28.71"N AT TOP PROD. INTERVAL: X=1530864 Y=25620219 AT TOTALDEPTH:Blk 654;5880' FNL; 6390' FWL 16. CHECK APPROPRIATE BOX TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA REQUEST FOR APPROVAL TO: SUBSEQUENT REPORT OF: TEST WATER SHUT-OFF [] [] FRACTURE TREAT 'E~ [] SHOOT OR ACIDIZE [-'] [] REPAIR WELL [] [] PULL OR ALTER CASING [--] [] MULTIPLE COMPLETE ['--J [] CHANGE ZONES [] [] ABANDON* O~~ (other) set 7" liner a~nd producti test Form Approved. _BqdEet Bureau No..4~-_.R1424 5. LEASE ;'~ ~ ~.3 ,~. ~ ~ OCS ¥-019],: ?'.':~ = ~'~ ~' 6. IF INDIAN, AL.L.o.TTE,,iE OR TRIBE N~ME 7. UNIT AGREEMENT ~IAME'- =' '.+' .,5 ~ 8. FARM OR LEA'SE NAME 9. WELL NO. 10. FIELD OR WILDCA'T.-NAMEi ~ ~:; 5 Wildcat :;= ~ ,:L . ~_~ ~ · *-..- r', ~ 11. SEC., T., R., M.~: oR'eLK. AND suI~VEY OR AREA B1k.:i'65.4; Sec. 20..,:~12N, R17 ~,i .... ' :':- .."- _, 12. COUNTY OR'PARISHJ 13.; sTA'EE Offshore~:'7. ~- -_~.J, ~=.'A 1~ s kla.?-;'.: 14. APl NO. 55-201-00002.~ 15. ELEVATIONS..(.S'H0..W DF,.:!KD.B.,'~AN~ WD) WD=18' ...' {-~RKB=42'< ~ ~.c 5~ .... ~ ..; ~ ~; '.' ~-. (NOTE: Report results of multiple~%omp[~ti~j~or zone 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details; arid give'pertin~e6t':date~, including estimated date of starting any proposed work. If well is directionally drilled, give subsurface [ocat. iP~s and measured and true vertical depths for all markers and zones pertinent to this work.)* :~; ~. ~!,~ ~' ~ ~ :'-' .~ ;~ ~ ~ b~ A 7" liner will be set in accordance with the ADP from 115.8~;':'.;c~ 13440:'.:~D~~ (11136' TVD) and be cemented with 460 sacks of Class G cement'..~SubSeq~en't,'-i' to setting the liner it is anticipated that the following..=in~e~r~alsi~.wil~,i~b~ --:' '.. ~ .. i~ ;' .. ~- · production tested: Zone 1 12835'-44' and 12764'-74' DIL, <Zone..·2 12700~'~i~2.,~16' · ,. ,...., ,_<. £.. .-.~ DIL, Zone 3 12470'-12576' DIL Zone 4 11438'-11458' :~ '~-' :,*~, -:; ~ · -. '..T ~ ..... '"' -- CT'-~., ...'?.,, .-,, ~ Subsurface Safety Valve: Manu. and Type 18. I hereby ~r~.jfy tlhat the fPregojpg is true and correct SIGNED ~"'~"~ TITLE Senior Landman DATE <_:':::':~~~~~ ' ~ (This space for Federal or State office use) ........ *See Instructions on Reverse Side 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 other Wildcat 2. NAME OF OPERATOR Exxon Corporation 3. ADDRESS OF OPERATOR Pouch 6601, Anchorage, Alaska 99502 4. LOCATION OF WELL (REPORT LOCATION CLEARLY. See space 17 below.)Blk 654'; 1757' SNL; 683' EWL AT SURFACE: Lat. 70u23' 11.79"W; Long. 147o53 ' AT TOP PROD. INTERVAL: 28.71" N. X=1,530,864; n~PTH. Y=25,620,219. BHL: Blk 654; 16. CHECK APPROPRIATE BOX TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA Form Approved. Budget Bureau No. 5. LEASE OCS Y- 0191 6. IF INDIAN, ALLOT~;E OR 7. UNIT AGREEMEN~ NAME ..-' 8. FARM OR LEASE NAME · 9. WELL NO. -' ".':~ ." 10. FIELD OR WILDCAT NAME Wildcat~ ~' -~. .... " 11. SEC., T., R., M.~OR,BLK. AND AREA Blk :654;: Sec. 12. COUN~ OR PA~fSR 13,'STATE. 14. APl NO. .. ~ ~ ' 55-201-0'0002: 15. ELEVATIONS :(~HOW DF, KDB,.~A~D REQUEST FOR APPROVAL TO: SUBSEQUENT REPORT OF: TEST WATER SHUT-OFF [] [] .F . '"~ :i' '?'~.: ...~?' ~.-'?~.~ : .:.'.. : .~ ':...'~ !...' FRACTURE TREAT 'ri [] SHOOT OR ACIDIZE [] 'ri ;'. ".: ' ~:; ".:" REPAIR WELL 'ri [] (NOTE: Report result~ o.f multiple comPletion;or zone PULL OR ALTER CASING [] ri change on.F.~'rm 9-330.) MULTIPLE COMPLETE [] [] ' '~':-: ' . .. CHANGE ZONES [] [] ~. - ' . .: ~ :; .:~ ABANDON ~' [] [] ' - .~.': . ' 5.~ ~' .... (other) plug back to test -~ .! 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details,' a.'nd give pe~irient.dates;; including estimated date of starting any proposed work. If well is directionally drilled, ~ive/s~bsurface Iocatioris and measured and true vertical depths for all markers and zones pertinent to this work.)* '. '-': ~ !!. 'i. "; .i ~ ~' :: .} ii . .:T'.'- ': Work will be performed to plug back the 8-1/2" open hole :t0 :.~he shoe ~0~f~ithe 9-5/8" casing for future testing work inside the 9-5/8. ~ .A~,.,r¥.%ainer 'w.i~l!/ be set at approximately 12,045' measured depth inside of t~e' ~9r'5'/8'' CaS'i.h.g~ A cement plug consisting of 125 sacks will be pumped throu~h:~the re~ain~r · .,., '.~ :. ;, ,- ...._ and spotted on top of the retainer. This work is further de.t-.ailed on'~ the attached pages. · -' $ i'- a,-. :' ' Subsurface Safety Valve: Menu. and Type :~.!: ~:' 18. I hereby ~(~r~i)fy that the f~reg~i~B true and correct ;' ' ": ,~. ~ -;~ ;~ .'~' ' ' ~' .~ , , ) .~ ....... /~'~/( ~~ ..... Senior Landman /'~ , .~ . · *See Instructions on Reverse Side Ft. ~rocedure t_~_~_~ Back to Test ,OCS Y-0191 #2 OIL AND GAS OFFiCH FEB 1 2 1982 AN C,"{O RA,:~,", ALA,SKA Submitted By: Date -------- ApProvals: Date / -- Date OCS-Y-0191 #2 PLUG BACK TO TEST PROCEDURE This procedure begins after logging of the 8-1/2" hole has been completed. · Run a gauge ring and junk basket for 9-5/8" 47# casing to 12,070 on wireline. · Run a Howco EZSV retainer to 12,045'± and set. Pick up the following cementing'string and run in the hole to the EZSV retainer: Stinger for Howco EZSV retainer 3 stands 5" 19.50 lb/ft Grade E DP Howco DP wiper plug-catching sub 5" 19.50 lb/ft Grade E and G DP to surface While running in the hole, rig up Howco cementing lines to the rig floor cementing manifold and test to 5000 psi. · Run in to 12,000' and circulate 500 bbls. Run in and sting into the EZSV retainer. · Close the annular preventer and put 2000 psi on the dril1 pipe annulus and monitor pressure. · Rig up Howco single plug cementing head with a 5" DP wiper plug loaded. Rig up cementing lines to the head and test to 5000 psi. · Establish injection at 3-4 bpm. Do not exceed 4000 psi. Anticipated injection pressure is 2800 psi (15.5 ppg). Inject 20 bbl mud. 8. Immediately follow the mud with the following cement slurry: · Cement Amount Yield Water Ratio Density Class G + 1% CFR-2 + 0.15% HR-7 125 sks (25.6 bbIs) 1.15 cf/sk 5.0 gal/sk (14.9 bbIs) 15.8 ppg Immediately follow the cement with the DP wiper plug and 209 bbls of 10.1 ppg mud. Inject at 3 to 4 bpm. This should bump the DP wiper plug. Do not shear the plug. If the plug does not bump, stop pumping. OCS-Y-0191 #2 Plug Back to Test Procedure Page 2 10. 11. 12. 13. 14. 15. Release 2000 psi from the annulus, open annular preventer, and pick up 5' out of the wiper plug. Bump and shear the wiper plug. \ Pump 3.5 bbIs. Slowly pull 10 stands wet. Reverse circulate 250 bbls. Watch for cement contaminated mud. If mud is very badly contaminated, divert cement and/or cement contaminated mud to the reserve pit. Circulate normally at least bottoms up. POOH. JCC:sjm 100/s CAPACITIES 9-5/8" Csg - 0.0732 bbl/ft 5" DP - 0.01776 bbl/ft Open Hole - 0.1313 bbl/ft OHxDP - 0.1135 bbl/ft OCS-Y-0191 #2 CASING SHOE PLUG DETAILS 10.1 ppg Mud fRetainer at 12045' MD± ~ Plug - 125 sks Class G +0.15% HR-7 + 1% CFR-2 TOC 11980 MD BOC 12235 MD 9-5/8" @ 12120 MD 9937 TVD 8-1/2" Hole @ 13441 MD 11142 TVD JCC 2/11/82 ~aarcn 18, 1982 Acting. Detern&na~J Dt~OFO On Friday ~ Distric~ Supervisor on of %~11 Producibility OCS Y-0191 Well No. 2 ~rch 12, Roy Longstreet of Exxon called t~e District stated that Exxon has flow tested zone No. 4 in OCS ¢~fiice and Y-0191%~11 No. 2. Roy stated that Exxon believes ti~e tested zone has ~11 bc're d~acje. Roy inquir~ed whet_her~ for ~ae pu .rpose of determination o~ well producibility, the ~,~ is going to ask Exxon to go back and acidize the zone or accept the adjusted production rate figures based on the "dm,nage factor" values obtained in the pressure tests. He further stated that if required to acidize well No.' 2, Exxon will inot be_ able to test well ~. 1 this season because of ~he o~rren~ seasonal restriction on do,~-hole ~operations beyond ~.~c'n 31. ] ~ter a co[~ferenc~ discussion wi~n the R&O Su.pe~;isor, we told that we will give him an answer after further consideration. After cDn.~erring with the Section Supervisors of E&O and R&O the Ac~cing i'Y~4-OFO, I told Rcyf that w~ will accept the adjusted productionS, rate figures, t~king into consideration the "damage factor~" bat ~hat Exxon has to submit bot_h their interpreted and raw test d&ta in order to allow us to utilize the raw data if ~ question their interpreted data. Nabi! Masri cc: OCS Y~0191 ?.~311 No. 2 File 6B/(Area & District) N~sri: peg i 3/17/82: Nabil: 2: roy E) ON COMPANY, U.S.A. POUCH 6601 - ANCHORAGE, ALASKA 99502 907/276-4552 December 29, 1981 IIEG};1 OIL AI;D C.,'.L C' klCE DEC 2 OONS£RVATION DIVISICN NOTED JAN 0 4 Mr. Brian Schoof USGS Supervisor, District Oil and Gas Alaska Region 800 A Street, Suite 201 Anchorage, Alaska 99501 SC;HooF. Dear Brian: Attached you will find a revised Critical Operations and Curtail- ment Plan for our OCS Y-0191 #2 well as requested by you in our meeting with you 12/24/81. Very truly yours, J. A. Staffeld JCC:bsw 220/DD Attachment 295-632-100 cc: A. L. Hermann F. L. McCollum A D:Vt$~ON OF EXXON CORPORATION Section (3) CRITICAL OPERATIONS AND CURTAILMENT PLAN BEAUFORT SEA, BEECHEY POINT OCS-Y 0191 Certain operations performed in drilling are more critical than others with the 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 occurring at this time will likely lead to an °il spill. It is the Drilling Superintendent's respon- sibility to ensure that proper procedures are imple- mented 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. Be 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. De 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 Superin- tendent's responsibility to ensure that the following special procedures are carried out during the 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. Be Review test procedures and equipment operations with all involved personnel just prior to start of the test. Ensure that everyone knows his ~ob assignment. Ce Double check positions of flowline valves prior to commencing testing. De Check equipment for leaks after testing is initi- ated. Monitor pressures and flow rates during the test. Shut down operation immediately at any indication of leakage. III. Drilling in Close Proximity to Another Well. The first wellbore has been suspended. The necessary surveys and precautions will be taken to avoid hitting the existing wellbore. IV. .Running and Cementing Casing. The following guidelines shall apply: ao Careful monitoring for well flow should be taken during the last trip in the hole with drill pipe. Be The mud weight shall be greater than, or at least equal to, that with which the last drilling took place. Ce 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. ne Prior to cutting any casing, the absence of annulus pressure will be verified. Be 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. Co The mud weight shall be equal to or greater than the mud weight used to drill the interval at the depth of the cut. ~ De 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 wild- cats covers only the drilling and evaluation phase. If well completion is anticipated at a later date, the well will be plugged and temporarily abandoned in accordance with OCS Arctic Order No. 3. VIII. Drillinq 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 surface casing. IX. Determininq Formation Pressure Integrity. Formation pressure integrity tests will be run after setting 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 Surface Pip~. Well control contingency plans will be in effect while drilling below the surface pipe. Drilling will be discontinued if: ae 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. 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 an H2S contingency plan implemented. S detectors will be placed on the rig floor, in the llar, on the shale shaker and mud pits. These detec- tors will be continuously monitored below surface casing by the mud loggers. Also, automatic alarms will be placed on the rig floor and in the camp. JCC:bsw 220/DD-1 CRITICAL OPERATIONS AND CURTAILMENT PLAN OCS Y-0191 #2 This supplement details location specific conditions under which critical operations may be curtailed per the USGS request on 4/13/81 and revised for the second location 12/28/81. I. Severe Weather. High winds usually cause whiteout conditions and can affect drilling operations due to both wind activity and lack of visibility. Per our exploratory plan, maximum probable sur~ faCe winds are 81 mph. Although winds of this magnitude are uncommon, slower velocities are often encountered that are capable of producing whiteout conditions. The Chukchi- Beaufort Sea Climatic Atlas shows that winds capable of pro- ducing whiteout conditions almost never occur for a duration of more than 4 days. Severe weather conditions can affect drilling operations in the following ways. · '2. Downhole Operations - Although Nabors Rig 27-E has a mast loading factor of 100 mph, high winds may lead to the curtailment of downhole operations. This depends, though, on how much movement the wind induces in the travelling blocks through the drilling line. If a mod- erate amount of movement is experienced, only tripping may be curtailed. If more significant movement is encountered, the blocks will be tied back and all down- hole operations curtailed until weather permits. Cur- tailment of downhole operations will be left to the discretion of the Exxon Drilling Superintendent. Drillsite Operations - Although Nabors Rig 27-E compo- nents are enclosed and designed for operation in the Arctic environment, Certain outside operations may be curtailed when high winds cause unsafe working condi- tions. Curtailment of movement about the location will be left to the discretion of the Exxon Drilling Superin- tendent based on whiteout conditions. Fuel transfer from the fuel storage tanks to the rig day tank or other location equipment will not take place unless visibility permits. · Transportation - In addition to whiteout conditions, high winds may cause the ice road from Deadhorse to the drillsite to blow in with snow, which may shut down all transportation to the drillsite. This includes transpor- tation by helicopter, rolligon or truck. In this case, rig operations may or may not be shut down, depending on the conditions listed in 1. and 2. above. Normally, lack of transportation to the drillsite would not deplete the water supply. This location will be equipped with a desalination system capable of producing 700 barrels of fresh water per day. Additionally, 2200 barrels of water storage will be available which will last about 5-1/2 days with no resupply. Whiteout condi- tions would have to persist simultaneously with a desal- ination system malfunction for 5-1/2 days to deplete the drillsite water supply (worst case blow is 4 days). Also, spare parts will be available on the~ site 24 hours a day along with a technician capable of repairing the system. II. Ice Conditions This drillsite is designed and certified in accordance with OCS Order No. 8 and under normal conditions is not expected to be displaced laterally by ice at any time. Therefore, we can expect that ice conditions will never affect the drill- site operations. Despite this, an ice pressure and movement monitoring program will be conducted for the duration of drilling operations. Exxon does have a portable bridge capable of supporting 150 ton loads, which can be deployed from Deadhorse in about 6 hours. Ice movement can cause leads to open up in the sea ice road, which would stop transportation to the rig by truck and pos- sibly by rolligon. In the event that the ice road is tempo- rarily lost, the primary means of transportation would be by helicopter which would have nothing more than minor effects on drillsite operations. III. Rig Lighting During Well Tests .Ail well test surface equipment including rig floor equipment and separation equipment will be located inside enclosed, heated and well lighted areas. Well test surface equipment for this well will be unitized into a single enclosed facil- ity designed for operation in an Arctic environment. Since testing operations may occur in the winter and therefore in the darkness, areas around flowline and storage tanks that are exposed to the environment will be maintained with ade- quate lighting with portable light fixtures in addition to the standard location lighting. Well testing will be curtailed during whiteout conditions. IV. Rig Fuel System Nabors Rig 27-E is equipped with an 8000 gallon rig fuel day tank. This tank is double-walled and is built into the rig structure. It is filled under manual control by fuel trans- fer pumps located on top of the large fuel storage tanks located in the main fuel pit. The main fuel pit and storage tanks, the fuel transfer system and the rig fuel day tank are considered a permanent installation and are shown schemati- cally in Attachment No. 5 of the rig SPCC Plan. This location will originally be supplied with 375,000 gal- lons of diesel fuel, which is the capacity of the tanks .in the main fuel pit. Although we anticipate no fuel shortage due to the maintenance of a large supply on location, 4 days usage has been set as the minimum supply based on the worst case blow. Drilling operations will be curtailed if the fuel supply is reduced to this minimum, and will remain so until additional fuel is available. JCC:bsw 220/DD-2 Conservation ~)ivision ~-tiask a Region .~0~.~ A St reet, Suit e 201 A~chora~e, AlasKa F~9501 fJecember 24, ~ ~'~= ~ Exxon Corporat ion P.O "~ · '-~- F.'.oom Houston, Texas 77u0~ Attention- .~qr. W. R. ~arnack [)ear ?r. ~Jarnack: Along with your Application, for Permit to Drill OCS Y-0191 No. 2 v~lt, dated Decembmr 23, 1981, you .have submitted a "Welding, Burning, and Hot Tapping Safe Practices and Procedures Pla.,:". Also, you have submitted a request f.~r four departures from OCS Order No. 2. Your request states: OCS Order 2 Section 5.4.1, Cirilline Operations from Bottom-Suppgr~ed ~io.~, states'~~ ~=a-rt~'~~ "The divert~- syst~ shall ~e eouip~ed with r~mote-control valves in the main and diver~e) flow lines tna_ can he operated from the control panel prior to shutting in the well." EXXOF; .......... reques~ a uepar~ure fr~--~ the above to provide for the attached diverter arranoem~r,t.~. ...~. and operating procedure. Signs will be placed next to the manual valves as follows' KEEP OPEN EXCEPT WHE N--b-i~E R T I NG These valves will have mechanical latches to keep t~em in the open position while not in use. Ii. Order 2 Sect i on ~. !. !u, ..~l owout-Preventer Requirements, states in part, "The ~,as~ei'' ¥..~iV~ Shall not nOrmallY be used for opening or closin~ on flowing fluid. The second valve shall be located adjacent to the master valve. This valve shall be used as the control valve." As shown in the BOP sketch, the kill line will be equipped with two valves, with the innermost being hydraulically actuated. We propose that the rlor~ ~$ i hydraulic valve re~,ain closed ourir~,.S operations and that adjacent manual valve remain open. Using the hydraulic valve adjacent to the BOPs as a control valve will preve,-.t barite and drilled solids from accurm~!ating in either of the valves, whic[~. ~)ay obstruct their o~r~eration. iii. OCS Order 2 Section $, ?~%drogen Sulfide, requires that, "When driltin~ operations are planned which will penetr&te reservoirs known or expected to contain hydrogen sulfide (H2S), or in those areas where the presencs of' ~2S is unknovm, or upon encountering H2S, the preventive measures the operating practices set forth in USGS ~)uter Continental Shelf Standard "Safety Requirements for Drilling Operations in a Hydrogen Sulfide Environment," No. 1 (CSS-OCS-1), First Edition, February i976, or subsequent revisions thereto, shall ge followed." ExxoF; ,eels T.j~at this area is a proven no.___~n-HzS area on t~e basis of the OC ~1, Duck Island ~i ar, d :;' wells as welt as the adjacent Sohio ~.~ells; therefore, only the roi)owing equipment and measures will be done: H2S detectors on the ri(! floor, in the cellar, on the shale shaker and ~nud _~)its. These detectors will be continuously monitored below surface casing by' the .mud loggers. Automatic alarms wilt be placed on the rig floor and in the camp. These al arms will sound if H2S is detected in Quantities greater than 10 pp~. IV. Section 3.3.1, Conductor and Surface Casin_g..Se.ttin9 Depths, OCS Order 2, effective January 1, 1980,- requires that "conductor casln~ shall be set immediately prior to drilling into formations known to contain oil or ~as, or if unknown, upon encountering such formations. These casing strings shall be run and cemented prior to drillincj below the specified setting depths." Exxon requests a departure from this requirement to eliminate the conductor casing. This well will be drilled from a surface location 25 feet west of the OCS Y-0191 No. I well where shallow hydrocarbons and hazards were not encountered. At your request, electric logs and mud logs will be available." Yo~.,r ~plication for permit to drill OCS Y-0191 No. 2 well~ your request for approval of the departures from Order No. 2; and the "Welding, Burning, and Hot Tapping Safe Practices and Procedures Plan" are approved effective December 24, 1981. This well "OCS Y-0191 No. 2" has been assigned API No. 55-201-00002. Sincerely, Orig. Sgd. by Brien F. School Brian Schoof Supervisor, District Oil and Gas A1 aska Region Enclosure bcc Copy to: John Stafford, Exxon Anchorage cc' OCS Y-0191, Well No.? File 6B (Ar.~ea and District) ( w/enc 1 o sure ) Chron Ci rcul at ~ ng Chron 101-02 CM Chron NMasri: dv~: 12/24/81: Di strict/Depart ~ · ', .CATE* Forth 9-331 C / , SUBMIT IN /"~ (May 1963) (Other instk ,ons on UNITED STATES reverse side) DEPARTMENT Of THE INTERIOR GEOLOGICAL SURVEY APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK la. TYPE OF WORK DRILL I~ PLUG BACK b. TYPE OF WELL [~ SINGLE [-~ MULTIPLE ~'~ OIL GAS [~] OTHER ZONE ZONE WELL WELL 2o NAME OF OPERATOR Exxon Corporati on 3. ADDRESS OF OPERATOR P. O. Box 4279, Room 201'; Houston, TX 77001 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.*) At surface B1 k 654; 1777' SNL; 683' EWL at70°23'.11.79" W Long. 147°53' 28 71"N-X=l 530 864; gproposedprotl. ~on§HL ; - ' ' Y=25,620,21 - Blk 654' 5880' FNL; 6390 FWL DEEPEN F-I 14. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICES Approximately 7 miles NNE of Point Head 1~. DISTANCE FROM PROPOSED* LOCATION TO NEAREST 683' EWL of PROPERTY OR LEASE LINE, FT. (AlSo to nearest drlg. :nit line, if an,~0CS-Y 01 91 is. DISTA,CE FROM PROPOSED LOCATION* 25 ' We s t o f TO NEAREST WELL, DRILLINO, COMPLETED~ o, ~,P~ FOR, oN THIS '-"WE, ~. Wel 1 No. 1 Form approved. Budget Bureau No. 42-R1425. 5. LEASE DESIGNATION AND SERIAL NO. OCS Y-O191 21. ELEVATIONS (Show whether DF, RT, GR, etc.) Water Depth : 18" RKB = 42" .IF INDIAN, ALLOI'~'~E OR TRIBE NAME · 7. UNIT AGREEMENT NAME , , . 8. FARM OR LEASE NAME 9. WELL NO. 2 -10. FIELD AND POOL, OR WILDCAT Wi 1 dcat' - 11: BEC., T., R., M., OR BLlr. ~AND ~URVE~ OR A]~EA~ ~eacny ~o~n~: t~ock 654 (Map NR-63) : ' . '. 12. COUNTY OR PARISHI 13. STATE · Offshore I Alaska 16.NO. OF ACRES IN LEASE 17.NO. OF ACRES ASSIGNED TO THIS WELL . · ,=v-r -~,~l~qA.Aq F. ' PROPOSED DEPTH 12,000' TVD 20. ROTARY OR CABLE TOOLS * - Nabors Ri.q 27E II 22. ,APPROX. DATE WORK WILL START* : December 26,. 1981 23. PROPOSED CASING AND CEMENTING PROGRAM :~' ' PropoSed Cas'ing Please see attachments: Blow ut Prevention rogram and BOP TestlProgram, and Cementing Program, Casing Design Criteria and Safety Factors; Mud Program and Mud ~. Components, Minimum Quantities of Mud, Mud Program for Permafrost Drilling, Wellbore and Casing Design Sketch, Diverter System, Arrangement of a Four-BOP'Stack, Directional. Plan Request for Departures- . A. OCS Order 2, Section 5.4.1 - Drilling Operations from Boti~om;SuppOrted Rigs B. OCS Order 2, Section 5.1.1D - Blowout Preventer Requirements' . C. OCS Order 2, Section 8 - Hydrogen Sulfide , . - ~_~t~.. D. OCS-2 Section 3 3.1 Conductor and Surface Casing Setting ' ; _."13b~ ' · , ]N ~ova s~AcE PmSC2~eE ~O~OSE~ ~OGaA~: If proposal ts to deepen or plug back, give d~ on present P~C~ z~n~., ~d proposed new ~roduet~e zone. ~ proposal is to drill or deepen directio~ally, give pertinent data on subsu~aee locations and measu~e~'n'~ true ~ertieal depths. ~ive blowout preventer pr~r~m, ~A an~ ~ j ~/~. , ~ ,~,~ [xplorat~on Superv~sor ~,~ Becember ~, 1981 (This space for Federal or State office use) Rp..z o · APPROVAL DATE DIS_T_RIC:'[ SUPERVIS°R DATE *See Instructions On Reverse Side APPROVAL SUB_]ECT TO ATTACI-IED !ll~QUIIIEMi~i~'fS 3 9 I ,o EXXON 0CS-Y-0191-2 Lot. : 70°2~'11.79,'' Long. = 147 o 5~' 28.71' x : 1530464 y :2562021 9 (See Detail Foq Location Within 16 J 15 28 Proposed Bottc 33 / ?';"5'~.'''' ',~., ,- ~**. :,~5 ;~1 "'~k~'%.~.~:~2 "~ Sec. 20, T. 12 N., R.17 E.,UM. " DETA I L N.T.S. CERTIFICATE OF SURVEYOR I hereby certify thor I em properly registered ond licensed to practice Iond surveying in the Store of Alosko ond that this plat represents o location survey mode by me or under my direct supervision ond that oil detoil$ ore correct. DATE SURVEYOR T. 13 N, IT. 12 N. ~ Dinkum Sands I II 12 13 22 27 ~ Ho'le Location 34 ~-~ BLOCK 654 24 26 25 35 36 I": I Mile T. 12 N. NOTE' x ,y coordinetes are UTM, Zone 6 in feet. Revised Bottom Hole Locotion 12 -22 -81 AS STAKED WELL LOCATION EXXON OCS-Y- 0191-2 Locoted in Block 654 Locoted in Sec. 20~T. 12N.,R.17E.,U.M o FOR EXXON COMPANY U.S.A. BY BESSE, EPPS 8~POTTS ANCHOR AGEIALASKA , :544-1:552 __ Na~ or'.~ Rig 27£ Id£LL OCS-Y 019} ~. 2 __ _ t gl~ _ J i I ii ~ :.-g : ~ _ 7~ · D;V£HTER 8L~T BOP S;'STEH BLOWO,T I~[¥ENTIOK PP. OGRAW 20", 2000 psi GP Hydrl{ HSP' Annular Preventer uith 10-]/~" Dlverter 5yst~ an{ h~driull~lly p~rated majn.ya}ye.'~d t~ .mae,~!ly ~oper~ted branch valves, · . ~: .- ~ ~-~ ,:::.~ ~'::~'~[~:-'.~.:~:~.~ ':-.::::? :~:~..~-~<~: :~ ~,~ ~.~:' ~*,~ · : · · ..-.... . ... : · , , %. .... . .:..::;~.:.~:::.,~:;:~T~. ,.;:~<.,;~,:~[..l: '-;.?:L::::,? '~:~:', ~> '~-~.:~'/~.,. ,' ' '" '.: ':;e q.~:~,~:2- .: ..... :~ "~.. · '- '..~ ~ q', ~.1-.., . . "' - -' · ' :. "".~,- ~'~, ;4,.."::::FkC~'~ ? ~ ,' - ~:. . ..,,.. , .. .... ~...... ~,....~, ~..,. .. ..... . ..... : ..... . ....,. ~.?~.?:,;~ '. . ? ?..~ ....... ... .- . ::~?~.~:.- .. .... ~.;-? ~ ~::: ,~',-'.:-'~,~..-.: . Ga! - 13-516', 5,~ psi UP Hydrt{ I St~91e P~v~tor utth ri IKks e~tpped with'pipe rtl, 9.~e - ]]-5/8','6~0C psi 5haff~r Drtlllng S~1 with t~ side outlets e~lpp~ with 4, c~ke ][ne ~nd 3' kill 1 tho eGch ~tt~ one 10,~ ps1 ~nual valve ~ one I0,000 pst hydraul ic valve. T~ - 13-516", 10,0~ psi tip flydrll ] Single Preventers utth ram l~ks e~lpp~ with pipe i blind Ross Htll H~r~ultc ~c~lator 80P Control Uott, 3,000 psi syst~ wtth one re~te control panel. ~ SUi~FACE lO,OOO'psl choke mntfoldtn9 systm with t~o Willis hand adjustable chokes a~ one ... ::.. ~ = __~ _._.. :. - ....... ~ ~. - _ ._ ~ ~ · ·, ~ , 1... 11 L:_ - : :- ' ....' ' '" ' - - '- ~. ~. ~oP TEST. P~~ ~ B, C, D, E,.and F to 50ffi psi. . ,, i 1. lntttal BOP glpple Up Test - A to 3500 .following low pressure test. 2. Additional Testing as follows: Hin, F1in. ~ Size tit. Grade Yteld Yield F {Surface ]§-3/8~ 72 T.-80 5560 ~rot. 9-5/8 47 L-B0 6870 4809 ._lProd._, 9-5/8 47 L-80 6870 4809 Prod. 7 32 PllO 11640 8148 ANNULAR Anttc. SurF. Press. 1445 3470 3955 ]955 Planned Test Pres..sures_ .... .... Pipe B1tnd r Castng Rams Rams Annular 1000 1686 NT 1400 2200 3470 HA 3500 2200 3955 NA 3500 2640 3955 NA 3500 PIPE bELL OCS=Y 019! 14e1! No. 2 ~xPLOJ~Ik'TiON :PLAN" AND ~'ELL-tHFOit~T~:oN ~ PROPOSED cA._STPlG AND CElqE_N1,.!NG PiqOG!~LJ!~_ SIZE ~7-1/2 S~FACE 13-3/8 0 2350 72 ~-80 BTC X X X Pe~fmst ~ surface. .......... ~ ........... : ...................... ""~* . . Class G to ~7,000' RKB o~ 492' above 12-1/4 I~EDIATE 9-$/8 0 ~50 47 L-80: BTC X X · X ~95T LTC top HC zone, whichever ts shall~er. _~ , ?,, ~ , ,? , .............. . 8'1(2 ...... pROD~TION 7 9850 11950 ...... 32 ...... P-llO LTC X X X Class G to top of ltner. 3.1 BOP AND CASXHG DESZGN CRZTERIA FOR ANTICZPATED SURFACE PRESSURE SurFace Casing: Ant, Surf. Press. · [(Est. PIT) 052 Gas Gradient] Casing Die th RKB Surface Csg: Ant, Surf. Press . - [( 13.$ ) :052 ~ 0.1 pst/fi] (2,400, ~ __ ~,44 .... ps~ ' P~tection Casing Through TO: Ant. Surf. ~ess. - ~(Est. PIT) .052 -Fresh Uater Gradient] Casing Depth Protection Csg: Ant. SurF. Press. - [( ~5.0', .052- 0.433] ( 10,000 ) -_3,470 . pst Production Casing at TD: Ant. Surf. Press - [(Est. PP) .OS2 - Gas Gradient] Castng Depth .RgB (~D) ~roductton C~g: Ant, Surf. Press. - [( 9.8 ) .052 - 0.183 (~g,O00) , '37~5b.. pst ~fety Facets used where check~: Burst (B) - 1.312 applted against mlnlm~ Internal ~teld pressure. Collapse (C)- 1.0 applied against mfnlmm collapse pressure. Tension (T) - 1.50 applied against ultfmte Joint strength. · Estt~ted ~ter depth: ___ 18 feet; estlmted RKB to water line: 42 feet. · ~ _ BEAUFORT SEA~BEECHEY POINT AREA · OCS-Y 0191 WELL NO. 2 '(ii'SING DESIGN CRITERIA AND SAFETY FACTORS - -.F~'~ · ...z~j. {See Attached Wellbore Sketch) · .: i~- . .?~. · Burst - C~i~ gas gradient to the surface causing lost returns at th ~h~ a~ing maximum expected leakoff gradient. External fluid Cas i~~ .:~fac e.:.:~:~.~. Pressure ( COSP ) ~"~':"~~-~ leakoff gradient - gas gradient) casing depth - o. o) ,4oo . .:. ~.q 5 .~--- . .-r . . Pe~.f~~~~ack - Considers maximum external collapse gradient of 1.~: ~,it~~-'minimm internal fluid weight of 9.0 ppg. MaX.~ ~. Pressure (MCP) ~ - (~:~ternal gradient - min. fluid gradient) max. permafrost d Pemafros~:'~: ~bsidence - 13-3/8"72~/ft L-8Ogutt post yield strain perfomane~.~ the requirements for Prudhoe Bay field rules, bas,d ~rst case. ~~ing. Exx~. ~tn.i~::~'fety Factors Burst 1.312 Collapse 1.00 Tension 1..~0 pth pROTECTI~TION - g-5/8" e 10,000' TVD (1.],g96' MD) . . Burst-~ect-~:~- Considers gas kick of sufficient intensity and vol cause.:~t..~ret~ assuming maxi.,u~,~', exK~.cted leako?l' gradient and cas ftll~~--~~ Extm.nal fluid weight g.O ~pg. Cas i~'~f~-i~:'~face Pressure (COSP) . .... C~ -" (~. ~e leakoff gradient - water gradient) ca, lng 'FD ;.[~". .' .j . CASIIIG I~-St~'~..I_A AND SAFETY FACT.ORS (Continued) :: 4:~i,,. :.".'~i .... ·.. 'i.':.':,:;~.,-- .' - - Burst-~t~,-.-. Considers shut-in gas well surface pressure and exte~ formatto~:-:~ of 0.8 ppg. : -: C~tng ~~ $~'face Pressure COSp.. (atari. antlcip, ated formation pressure - gas gradient) well TD · = (~!.~-x ,052 0.18) 12,000 -' Co'l. lapse~tton * Considers surface pressure = 0 psi, internal flui ~e.~ght O~i-.:~d external fluid weight 10.0 ppg. · ' ..-.' ~ ~~ Pressure (MCP) NCP - (E~ fluid gradient - internal fluid gradient) casing depth ~~.ipressure . - - o) lo,oeo - o ' Em ~t~~ety Factors - Protective and Production . * .... "~,:~:.,:~'.~4 T~~f~' 1.50 . ':.. /."2 ~.' . ~ .. . Burst - S.am~-~ as.~.~or protective/production casing. Cotl apse- '.-'~~de -- ..... rs surface pressure = 0 psi, inLernal fluid weight = and e~-ternal:.~ftUid weight - 10.2 ppg. Naximu~-"~)'i~ Pressure (MCP) MC"- (E~te~ fluid gradient - internal fluid gradient) ::as iw,g TVD SU~~ pressure - (~~:OS~ .- O) ZZ,OOO - 0 · Exxon ~ini~:-~ety Factors Burst 1.312 Col 1.a~ 1.125 Tees ~'~: 1.50 · '" '.'. ..: ... .' .: · . .... .. PPg, ~.ter Loss'. !. ,-?.....:. · ~ .. '~:..~e ~. . :. ,., ... .:~r~ · . '.. · ....:z, ::,,. ~.~::?~ ~ ' i -. a~ .... . . · T~IcAI KUD COFFPONENTS· A. I~stc ~d CoGI~. ~nts: A~ ~.Hu~gf te (Sa1 tMater Dispersible Clay} C~rtte (O3rt~ G~t~nlte (~dt~ ~n~rtllontte Clay) Ltg~sul forte (Chr~o Llgnosul fo~) Lignite (L~rdlte-bm~ Coal) Caustic ~da (~dl~ H~xtde) XC Pol~,r (Xanth~ ~ Olop1~~ O~l-ex (Pol~ Flocculant and Clay C,~ltc~ ~ ~ (~3r~x~n~i Cellulose) B. Hud Addt_tl.ves: Soda Ash ($odtum Carbonate) SAPP (Sodium Acid Pyrophosphate) .,%dlu~ ~,lca~'bor~ te [tme (Calcium tl~oroxtde} Surfactaflts: -~' P-i-pa [aX~(X~pth~ Base Surfact3nt) Lubra-Gltde (Copol~er Beads) Torque-Trf~ (Vegetable 011 Base) Black Haglc (Oil Base Surfactmnt) Lpst Circulation lbterl~l: 14iCj .... - - ' ..... Hut ttulls Defo~aming Agents:** ---A~ hum stea-rate octal Alcohol Defoa~ers H?S_ Scavenqer Zinc [a~--~a te ¥t$cost'ffers So,tun ~nt~ortllofltti Clay) hcterfacldes Aldacfde-' (Hlcrobf acfdg} 9-5/6' annulus or will he properly disposed of ashore. **Cottonseed otl will be used tn trace aamunts to enhance the effective- ness of the defoamlng agents. go3 PPG )<bi 17-1 ~le Barite BenTonite ..... L lgnosu fonate Li, nile OC5-Y 0191 Well Ho. 2 ~U~T SEA, BEECIIEV PO]~ ~l~ BASIC I~P~NEttTS C~,.~EN~TION - _-_ ....;:,;t, .~.!.~-,',':' ,,.. · ....: :. :,..-, - ........ : '. '- = : ~i '::i':i ~,~i~i'~ii: ti~!,::~':F~-:..:,::':~-. ...... ' ......... :.--;~':'.-:-.,:~,:~:~ ~ ~:~,~,.:~i~F-:~ .-.,'~. ..... ~ L." ~ ~.~:';:~l~m' ' '~ ' :'~'~'~" '":~' :~ "' ' .~ . ~' :~;t~-~,~ :..~ T. "< '.~'- .... .. ~.,.,~...~:~.:;~ . · ' ':".~ ~:.':.~;~k~:'~ F:' :':' '~ ' · · '.. · '.'" ")' .. ....... · :' 42 21 1 1 I 1500 *mm. 400 35 20 Intermediate Csg Depth ", O. J p~g P,W _ 12J/4" Hole Total Oepth '-'~,-~' :- R-KB ~ 10.2 ppg )4W Based on 2600-bbl Active Sys t~l Based on 2400-bbl Active System '" ' '" ';" 21 . !-::;';-:'.:-:'~'-~~-'-'~:::: ;---_ :': ::~ . ~-- "'."~6 ~-: '-' ~--:-- :-s~. ::__~ l- ~l~"T~'t 1 ~ ~ ........................ - _ · ""'_ ~ .... .~ ~ .... , .... The ~o~o:eC ~I~ ~ the ~ollo~ng mud syst~'capacltles: !O00-bbl Active Pits and ]50'bbl t~tp tank. PER~FROST DRILLING OCS-Y-0191 WELL NO. 2 Permafrost is expected to be encountered to approximately 1500 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 OCS-Y-0191 No. 1 well located adjacent to this area had permafrost to approximately 1,500 feet RKB but did not encounter gas hydrates. Since this well is located only 25 feet from the OCS-Y-0191 #1 well and since no shallow gas was encountered, a mud logging unit will not be used on the surface hole. A mud logging unit will be in operation from below surface casing to TD, and a flow diverter will be installed on the 36 x 32 x 28-inch insulated refrigerated conductor casing. The planned surface casing depth of 2,400 feet is expected t© cover all potential gas hydrate zones. !.!;.i..-.:L;: '?:*'' .RI~AUFORT SEA,, B£ECH£Y POZNT AREA 3' '~ -J · .... :" "':'~':': ':"' OC$-Y 0191 WELL NO. ~,,, ::-"-.!:..:. ::-.-". ;..?-! . · · .. .. tIELLBOR£ & CAS%NG DES]GN SKETCH · ".'3~' x 32" x 28" Insulated Refrigerated Conductor ~ +_ 1!I' RKB (108' &~, Est. permafrost,depth 1500-'Rrd) (950' ~L) 1~3/8" 72~/ft L-80 Butt Surface Castng ~ ~2400' RK~ K~ 2500' eKB (2350' ~ste ~utds, drilling mud, and hydrocar~n injection zone. T~ e app~xJmately 7000' R~ (TVD} 808U ~D-R~ ~:Prior ~o ~11 ~bandon~n~, the ~n3ectton ~nn~ be cemented from 2,400' ~o 1,900' f~'llo~ed to surface, and the casing will be filled wtt~ a non- T~p of ltner ~ 9,900 RKB (9,850~) ~!l g-518" 471/ft L-80 BTC O ! 7500' R~ ( 7,qSO B~O TVD 9-5/8" 47~/ft SMgST LTC 10,000' RKB ( 9950' F, XL) .. : 7" 32~/ft P-110 BTC e +- 12,00b R~ (1i,950 )~.,~1 ) 14,469 M!) - RKB ,:. D PLAN OOS-h 0 F31 NO. ~ :';.."" :1 · ..] BEAUFORT SEA, BEECHEY POINT AREA [ :Y 0191 WELL NO. 2 '. D!¥ERTER $¥ST£M , For Use o~. IR* Structural and 20" Conductor Casing SHAKER 20" HYDR! L · HSP 2000 20" 2000 PSI /~x SPOOL 20" BUTTERFLY VALVE TRIP TANK 10" HYDRAUL! C YALVE 4' Spacer Spool 10" Manual Valve To West Bull Plug WELLHEAD OR 20" CASING ( IR* not shown) *36"x32"x28" Insulated Refrigerated Conductor OPERATING PROCEDURE TO RESERVE PIT . I To East The diverter system consists of a 20" annular preventer, one 10" .hydraulically operated main valve, tuo 10" manually operated branch-valves, and a 10" diverter line. The annular preventer and main diverter valve are hydraulically actuated '.together from one BOP control so the main diverter valve autoF, latically epens before the annular is closed. The manual valve to tha reserve pit will reF..~ain open at all tin. es, while the overboard valves will also remain open. In a ¥~ell control situation, the annular preventer ¥,,ill be closed, autcmatically opening the main diverter valve, The well will initially be diverted through all lines. The appropriate valves will be closed as wind conditions dictate. .'-':'"~'. * ?'?;~~ANGEMENT OF A FOUR-BOP STACK .... i,y · ~,--:;~,.;?~!? :,'~i~i' - - , - · .k. .*.*.. .... ....::- · . . .'.: : · .' . · . ,_,.:* -..:... ... · ':: *.... · .';. ;... · . · . '.. .~.,: · .i*.. * 5:'-:; . -'-- ' ~.~2'."~.';' · =' ~0~ S~C~ ~ [ ~ O~S 3. ~~'.:~ ~aCe v~ve - 2" st=e - sa~e ~r~ng pressure ~s cop ~I '~' aec~o: ~~:~.':~ pzessure ~u~e ~d/or conne~cion co cas~S press,Jze ~au~e on 8. ~ov~[~'~:i:~o~ Co choke ~n~fc~d - ~" ~'ntn~ sL~e - a~ cn~"nec~ons muse ':: 10. ~ ~';~~~ ~ppie an~ c~anion fly-se zust n~c be le~s ~har. the I~ of ',~ CHOKE REQUEST FOR APPROVAL OF DEPARTURES AND CLARIFICATIONS FROM ARCTIC OCS ORDERS NO. 1 AND 2 BEAUFORT SEA, BEECHEY POINT AREA OCS-Y 0191 Well No. 2 I · OCS Order 2 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 the attached diverter arrangement and operating procedure. Signs will be placed next to the manual valves as follows: KEEP OPEN EXCEPT WHEN DIVERTING These valves will have mechanical latches to keep them in the open position while not in use. II. Order 2 Section 5.1.1D, Blowout-Preventer Requirements, states in part, "The master valve shall not normally be used for opening or closing on flowing fluid. The second valve shall be located adjacent to the master valve. This valve shall be used as the control valve." As shown in the BOP sketch, the kill line will be equipped with two valves, with the innermost being hydraulically actuated. We propose that the hydraulic valve remain closed during normal operations and that adjacent manual valve remain open. Using the hydraulic valve adjacent to the BOPs as a control valve will prevent barite and drilled solids from accumulating in either of the valves, which may obstruct their operation. ~ III. OCS Order 2 Section 8, Hydrogen ~ulfide, requires that, "When drilling operations are planned which will penetrate reservoirs known or expected to contain hydrogen sulfide (H2S), or in those areas where the presence of H2S is unknown, or upon encountering H2S, the preventive measures and the operating practices set forth in USGS Outer Continental Shelf Standard "Safety Requirements for Drilling Operations in a Hydrogen Sulfide Environment," No. 1 (GSS-OCS-1), First Edition, February 1976, or subsequent revisions thereto, shall be followed." Exxon feels that this area is a proven non-H2S area on the basis of the OCS-Y-0191 ~1, Duck Island 91 and 2 wells as well as the adjacent Sohio wells; therefore, only the following equipment and measures will be done: Request fOr Approval of Departures and Clarifications from Arctic OCS Orders No. 1 and 2 Beaufort Sea, Beechey Point Area OCS-Y-0191 Well No. 2 IV. O . H2S detectors on the rig floor, in the cellar, on the shale shaker and mud pits. These detectors will'be continuously monitored below surface casing by the mud loggers. Automatic alarms will be placed on the rig floor and in the camp. These alarms will sound if H2S is detected in quantities greater than 10 ppm. Section 3.3.1, Conductor and Surface Casing Settinq Depths, OCS Order 2, effective JanUary 1, 1980, requires that "conductor casing shall be set immediately prior to drilling into formations known to contain oil or gas, or if unknown, upon encountering such formations. These casing strings shall be run and cemented prior to drilling below the specified setting depths." Exxon requests a .departure from this requirement to eliminate the conductor casing. This well will be drilled from a surface location 25 feet west of the OCS-Y-0191 No. 1 well where shallow hydrocarbons and hazards were not encountered. At your request electric logs and mud logs will be available. Page 1 of 3 Revision date' 12/24/81 UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY CONSERVATION DIVISION ALASKA REGION OCS OPERATIONS BEAUFORT SEA AREA SALE BF CONDITIONS OF APPROVAL TO DRILL FOR OIL OR GAS le e e All drilling operations shall be conducted in accordance with applicable regulations, the OCS Operating Regulations, 30 CFR 250, and the provisions of Arctic Orders. The casing, cementing, blowout prevention, and mud programs shall comply with the minimum requirements outlined in Arctic OCS Order No. 2, unless otherwise established by field drilling rules. In the event the well is plugged and abandoned, the work will be conducted in accordance with Arctic OCS Order No. 3. A daily chronological drilling and progress report (one copy, no prescribed form) must be submitted to the OCS District Supervisor, Alaska Region, P.O. Box 259, Anchorage, Alaska 99510 (or by telephone if preferable). This report shall commence with the spud date and shall include drilling depth, bottom hole location, if a directional well, mud weight, and principal items of work done during the previous day (running casing, testing, coring, sidewall sampling, logging, etc., and including zones of abnormal pressure, lost circulation, depth of kicks, or other hole difficulties encountered, which caused cessation of operations or modification of the approved drilling plan). This report must be continued until the final status of the well is established (shut in or producing oil or gas well, temporarily abandoned, suspended, etc. ). The applicable reports and logs required under 30 CFR 250.38 and 250.90 through 250.95 of the OCS Operating regulations will be properly and timely submitted. One copy of all field prints of individual runs of all well logs (electrical, radioactive, directional, etc.) must be submitted as soon as available, but no later than 30 days after running of the logs. Two copies (one blueline and one sepia) of all the final logs must be submitted as soon as available. The Completion Report, Form 9-330, in duplicate and a Well History Report Summary must be submitted no Form D5-3/81 e e e e Page 2 of 3 later that 30 days after completing of the approved work. Public Information copies, Form 9-330, shall be submitted pursuant to OCS Order No. 12. The above submittals should be made to the OCS District Supervisor at the address shown in Paragraph 2 above.. All changes to the approved submitted plan, plans for suspension of operations, plugging or plug back, should be filed in a written notification of such intent and approval from the District Supervisor should be received prior to implementing these changes. Form 9-331, in triplicate plus the public information copy, "Sundry Notices and Reports on Wells", will be used for this written notification. Emergency approval may be obtained verbally, but such approval does not waive the written notice requirement. The same Form 9-331 shall also be used by the operator for filing a subsequent report with details of the completed operation. To accomplish the purpose of 30 CFR 250.38, 250.95, and other pertinent regulations, all occurrences of oil, gas, sulphur, and other minerals of potential geological interest, will be noted on the Completion Report to include all important zones of porosity and contents thereof, cored intervals, and complete details on all drillstem or formation tests. Exact copies of any analysis of cores must be submitted. The identity of rock units in time-stratigraphic terms will be established by showing, as accurately as the present state of the art allows, the depths to the top of the upper Pliocene, middle Pliocene, lower Pliocene, upper Miocene, middle Miocene, etc., on the Completion Report or on a marked electric log. At the discretion of the District Office, a paleontological identification of all foraminifera, nannoplankton, and/or palynomorphs by depth, shall be reported to the District Office. Before completion, suspension or abandonment procedures are commenced, the District Supervisor shall be given sufficient lead time to examine well records and give approval of the proposed disposition of the well. Cores, representative cuts, unwashed bulk and washed (dry)of all ditch samples shall be collected for the U.S. Geological Survey. Ship samples to: Deputy Conservation Manager, Offshore Resource Evaluation, USGS, 800 A Street, Anchorage, Alaska 99501. Before coring or testing operations, notice will be given to the Geological Survey so that such operations may be witnessed. e e Page 3 of 3 Meteorological, oceanographical, ice, and performance data will be collected in accordance with the "Guidelines for Collection of Meteorological, Oceanographical, and Performance Data." The permittee shall, furnish quarters, subsistance, and transportation for a Federal representative(s) in accordance with NTL 80-1. Office and mailing addresses: Supervisor, District Oil and Gas Office, Alaska Region U.S. Geological Survey 800 A Street Anchorage, Alaska 99501 Deputy Conservation Manager, Offshore Resource Evaluation U.S. Geological Survey 800 A Street Anchorage, Alaska 99501 (Samples and core cuts only) Telephones: Offshore District 271-4348 Answering Service for nights, emergencies, and weekends 271-4303. LEASE Y-O19! Meteorological: Wind Direction Wind Velocity Ambient Temperature Barometric Pressures Oceanographic: Ice Pressure Ice ?4ovement 'Island Performance: ' Final report for well should cc, ntain brief su~-:mary of protective measures such as slott~.ng or ~ce ~,qrriers which :~ere e~nployed to protect the shc~u]d .~7~o describe any ~c3~cnts of ;~e c, verr~de ,:,r /. . · / EXXON COMPANY, U. S. A. Welding, Burning, and Hot Tapping Safe Practices and Procedures Plan OCS-Y-0191 ~2 December, 1981 TABLE OF CONTENTS I. FACILITY DESCRIPTION II. PERSONNEL QUALIFICATIONS III. WELDING EQUIPMENT IV. PERSONNEL DUTIES Page 1 1 V. WELDING AREAS VI. WELDING AREA FLOOR VII. WELDING IN AN APPROVED SAFE WELDING'AREA VIII. WELDING IN AN UNDESIGNATED WELDING AREA IX. SPECIAL CONDITIONS X. SPECIAL ~SITUATIONS XI. CUTTING AND WELDING PERMIT 10 XI. LOCATION DRAWING SHOWING WELDING AREAS 11 I. FACILITY DESCRIPTION Well OCS-Y-0191 92 will be drilled from an artificial island constructed of coarse sand and gravel, located in the Beaufort Sea approximately 7 miles NNE of Point Heald in 18 feet of water. Nabors Alaska Drilling Rig 27E, rigged up as shown on the location drawing, will be utilized to drill and test the well. II. PERSONNEL QUALIFICATIONS Exxon Drilling Superintendent Safety The Exxon Drilling Superintendent must be familiar with the Exxon Production Department Safety Manual and the Welding, Burning, and Hot Tapping Safe Practices Plan. Fire Fighting The Exxon Drilling Superintendent must be qualified in fire control techniques and use of the rig fire fighting equipment. Regulations The Exxon Drilling Superintendent must be familiar with Section 5.4 "Welding and Burning Practices and Procedures", of OCS Order No. 5. Welding The Exxon Drilling Superintendent must be familiar with Exxon welding procedures and the operation and handling of welding equipment. Drilling Site The Exxon Drilling Superintendent must have a working knowledge of the drilling rig and associated rig equipment. He must also have a working knowledge of all communications and transportation systems associated with the drill site. Bo Rig Welders Ail rig welders will be qualified according to the applicable provisions of ANSI B31.3, Petroleum Refinery Piping. Documentation of the rig welders qualifications will be kept by the Drilling Contractor and made available to Exxon upon. request. III. WELDING EQUIPMENT A. Electric Welding Machines Welding machines shall be constructed in accordance with the National Electrical Code, Article 630, Electric Welders. IV. Machines shall be diesel engine driven or electric and shall be equipped with drip pans and spark arresting mufflers. Controls and Accessories Controls and accessories shall be in good operating condition. The governor shall maintain adequate speed control relative to the speed specified on the name plate of the generator. Cables and electrode holders shall be properly insulated and in good operating condition. B. Gas Equipment Gas welding and burning equipment shall be in accordance with appropriate standards of the American Welding Society. Regulators, gauges, and hoses for acetylene and oxygen shall be in good condition and of a type designed for use in industrial welding operations. Gas Cylinders Cylinders shall be transported and used in racks or carts designed to maintain the cylinders in a vertical position. Oxygen and acetylene cylinders will be separated by an impervious barrier during offshore transportation. Oxygen and acetylene cylinders will be separated by at least 20 feet for storage at the drilling location. PERSONNEL DUTIES A. Exxon Drilling Superintendent Safety The Exxon Drilling Superintendent is responsible for the safe usage of all cutting and welding equipment on the drillsite, and for the protection of all combustible materials from ignition. Welding Area Inspection The Exxon Drilling Superintendent will personally inspect any undesignated welding area for Potential fire and explosion hazards prior to any welding activity. Appointment of Fire Watch The Exxon Drilling Superintendent is responsible for, but may authorize the Tool Pusher to appoint a fire watch for welding in an undesignated area. Written Authorization The Exxon Drilling Superintendent must give written authorization for welding in an undesignated area by signing the Cutting and Welding Permit. Be Ct De Welder Qualification - The Exxon Drilling Superintendent will verify and retain in writing the qualifications of any welder who performs any welding in an undesignated area. Toolpusher The Rig Tool Pusher reports to the Exxon Drilling Superintendent and is responsible for directing the activities of the welders and welders helpers. He is also responsible for inspection of the approved safe welding areas prior to any welding activities. Welder The welder will be the only person to operate the welding machine or burning equipment. His duties include the following: Weldinq Equipment - Maintain the welding equipment specified in Section III and operate it in a safe manner. Welding Area Inspection - Inspection of the Approved Safe Welding Area and the affected area outside prior to any welding or burning. Welders Qualification - Maintain documentation. that he is qualified per Section II of this plan. Fire Watch A Fire Watch, consisting of one or more persons, will be assigned when welding is being conducted in any area other than the welding shop. The Fire Watch will have no other duties during welding activities and will not be a member of the welding crew. He will have in his immediate possession a portable gas detector and a portable fire extinguisher that have been tested and are in condition ready to use. He must be trained and qualified in the use of all equipment to perform this duty. His specific duties are as follows: Welding Area Inspection i · Inspection of drip pans within 35 feet of welding operations to ensure they are free from combustibles. · Check of welding area with a gas detector immediately before welding and periodically during welding. Ve Fire.Surveillance Observance of welding operations from a strategic location. Fire Control i · Maintenance of.an appropriate fire extinguisher in good operating condition at the welding site. · · Maintenance of an operating fire water pump with a hose station~if accessible to the welding site. Remain in the welding area for 30 minutes after completion of welding to detect and extinguish possible smoldering fires. WELD ING AREAS A. Designated Safe Welding Area Requirements for designated safe welding areas were established using National Fire Protection Association Bulletin No. 5lB as a guide. These areas are designated on the attached location drawing, which will be posted in a prominent place on the drilling location. Class A Area This is an area that does not require special preparation to isolate it horizontally from other areas that contain combustible materials or to make the floor suitable for welding. A Class A Area must meet one of the following conditions: le The area boundary is at least 35 feet horizontally from any combustible material, and the floor is~entirely steel plate or gravel. · The welding area is separated by a permanent fire resistant barrier from .any combustible material closer than 35 feet, and the floor is entirely steel plate or gravel. Class B Area This is an area that requires special preparation to isolate it horizontally from other areas that contain combustible material or to make the .floor suitable for welding. A Class B area must meet one of the following conditions: le · The area boundary is at least 35 feet horizontally from any combustible material, but the 'floor is not entirely steel plate or gravel. In this case, the floor area within 35 feet of the 'welding location must be covered with a fire-resistant tarp. The area is separated by a temporary fire resistant barrier from any combustible material closer than 35 feet, and the entire floor is steel plate or gravel. B. Undesignated Welding Area An undesignated welding area is any area outside a designated safe welding area and is considered unsafe to cut or weld in. Cutting or welding in these areas will take place only when absolutely necessary and in accordance with the procedures outlined in this plan. On the drilling rig, this includes the following areas: - Main Fuel Pit - Rig Substructure - Rig Floor - Mud Room VI. WELDING AREA FLOOR The welding area floor and adjacent floor areas within 35 feet of, but not isolated from, the welding location shall be one of the following: 1. Solid steel plate. '2. · Steel grating covered with fire resistant tarpaulins. Drilling pad gravel. VII. WELDING IN A DESIGNATED SAFE-WELDING AREA Authorization - Written authorization must be given by the Rig Tool Pusher by signing the Cutting and Welding Permit. Area Inspection - The area must be inspected by the Tool Pusher, Welder, and Fire Watch per the requirements of Section IV, Part D, prior to any welding activity. .Fire Watch - A Fire Watch must be appointed by either the Exxon Drilling Superintendent or the Rig Tool Pusher and shall perform his duties per the requirements of Section IV, Part D. Weldinq Shop - Welding shop is considered a designated safe welding area, although it is not subject to the above requirements. Since this building is designed specifically for conducting welding operations, and is completely separate from any other drilling rig components, no written authorization, permit, or Fire Watch is required. Area inspection will be done by the welder prior to welding activity. VIII.WELDING IN AN UNDESIGNATED WELDING AREA Welder Qualifications - The Exxon Drilling Superintendent will personally check the qualifications of the welder(s) to insure they meet Exxon standards. Authorization - Written authorization must be given by the Exxon Drilling Superintendent by signing the Cutting and Welding Permit. Area Inspection - The Exxon Drilling Superintendent, Welder and Fire Watch will inspect the welding area per the requirements of Section IV, Part D, prior to any welding activity. Fire Watch - A Fire Watch must be appointed by either the Exxon Drilling Superintendent or the Rig Tool Pusher and shall perform his duties per the requirements of Section IV, Part D. Testinq Operations - No welding shall ~take place in an undesignated welding area during well testing operations while hydrocarbons are being flowed to the surface. Welding may commence after the well has been reversed out. IX. SPECIAL CONDITIONS i · Personnel operating arc welding or cutting equipment in an. area with wetted flooring shall be protected from possible electrical shock. · The area within 35 feet shall be free of drums or other portable containers that contain or have contained combustible materials. · The welding operation shall be adequately sheltered from wind. Tarpaulins used as windbreakers shall be a minimum of three feet from the welder. Mo · Edges of covers at the floor should be tight to prevent sparks from passing under them. This precaution is also important at overlaps where several covers are used to protect large objects. · Ail confined spaces.in which welding or burning must be conducted shall be adequately ventilated and supplied with a continuous source of fresh air while work is in progress. Caution should be taken to position air supply blowers so that the intake will not pick up exhausted gases, fumes, or vapors. SPECIAL SITUATIONS Vessels and piping that contain or have contained combustible fluids require special p~eparation prior to being welded on. Also, solid materials such as paint, tar, asphalt, paraffin, plastic, plastic coatings, and rubber may produce combustible vapors when heated. A. Existing Piping l· Connected piping shall be isolated by valves, skillets, blinds or other means of positive sealing. · · Piping shall be washed with water and purged with inert gas or filled with water before welding. Before welding on a completely sealed pipe or assembly, provisions for expansion of contents shall be made. B. Vessels A vessel that has been in hydrocarbon service shall be assumed to contain vapors, liquid, and solid residues. Only after careful preparation and inspection can welding be performed. The internal configuration of baffles, traps, sumps, weirs, packing, and compartmentation should be determined. The welding procedure shall include the following: i · Procedure A written procedure shall be submitted from engineering prior to welding on a vessel. C· 2. .purging a. Drain all vessel compartments. 0 Fill the vessel with water. Drain the water out if steaming is to be performed. C · Internally inspect the vessel if possible. d. Disconnect and seal all openings. e. Connect steam to top of vessel and exhaust from bottom. f· Steam vessel until zero percent (0%) L.E.L. is indicated by a gas detector. ge Fill vessel with water, hook up supply of inert gas, and drain vessel only to level required to perform work while displacing water with inert gas. Hookup should include bubble tube in bucket of water or other means of determining that purge gas maintains positive pressure as vessel drains. he Flow purge gas.through vessel to prevent entry of air while welding or cutting operations proceed. ie Fill vessel with water when work cannot commence immediately after steaming. HOT TAPS i · Authorization Approval of the appropriate Exxon engineering supervisor and the U. S. Geological Survey District Supervisor shall be obtained prior to making a hot tap. A written procedure shall be provided by engineering and the Exxon Drilling Superin- tendent shall be at the job site when hot tapping is performed. Prior to conducting the hot tapping operations, the Cutting and Welding Permit must be completed. · Procedures Hot tapping shall be performed with all precautions common to position welding and in accordance with the following codes and procedures as applicable. so be c · d· ee ANSI B31.3, Petroleum Refinery Piping Code, except that all saddles shall be full encirclement type. ANSI B31.8, Gas Transmission and Distribution Systems Piping Systems. ANSI B31.4, Liquid Petroleum Transportation Piping Systems. "HOT TAPPING", A.E. Clark, Exxon Co., U.S.A., South Texas Division, October 15, 1969. An Ultrasonic testing device will be used to determine actual pipe thickness at location of hot tap. Exxon Production Department Safety Manual. 211F/C XI. PERMIT FOR CUTTING AND WELDING WITH PORTABLE GAS OR ARC EQUIPMENT Date: Work To Be Performed: .Area: Special Precautions: Permit Expires: Signed: Exxon Drilling Superintendent or, Rig Tool Pusher Time Started: Time Completed: SAFETY CHECKLIST: Authorization Received Fire Watch Appointed Welding Area Inspected Welding Area Sniffed Fire Control Equipment At Site Area Clean of Combustibles, or Combustibles Properly Protected KSO/rms 211F/C · 30* I ~o' I (1) I-,- 00000 00000 OOO ;. 00'~