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Home My WebLink About178-068October 5, 1983 Ms. Para Prusina H. K. van Poollen & Associates, Inc. llO0 W. Littleton Boulevard Littleton, Colorado 80120 Para, Enclosed are copies of the well tests for the Endicott Reservoir. Dnek Island Uni~-~No. 1. drill stem tests 1, 2A, 3, 3~, 5, 5B, 6, and 6A. Duck Island Unit No. 2 tests 1, 2, and 3. Sag Delta I~Io. 3 well test. Sag Delta No. 4 step rate test, Sail. Delta ?.Io. 7 production tests 1, 2, and 3. Sag Delta ,~o. ! well tests 1, 2, and 2A. These tests are marked confidential and should be handled as such. SincerelY, Russel! A. Doug lass Petroleur~ Reservoir Engineer be Enclosures EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION EXXON COMPANY, U.S.A. POUCH 6601 Anchorage, Alaska 99502 TRANSMITTAL OF DATA FROM' Roy Longstreet TO: Fran Jones Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Ak. 99501 Material transmitted Exxon Duck Island Unit #1 The material listed below is being transmitted via 5" Hi/R Dipmeter Log, Runs 1, Hand delivered 3, 4 2" 5" Dip Arrow Plot, Runs 1, 2 Directional Survey, Run 1 2" Microlaterolog, Run 1 2" Microlaterolog (TVD), Run 1 5" Microlaterolog, Run 1 5" Microlaterolog (TVD), Run 1 / .l~ea.se acknowledge receipt of the above material by v signing and returning the duplicate copy of this letter. Anchorage .J~o ' y Long sf-r eet August 31, 1983 Date E ON COMPANY, U'S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION D.H. JONES EXPLORATION COORDINATOR -- ALASKA July 26, 1983 Mr. C. V. Chatterton, Chairman State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached for your approval are Sundry Notices for one year extensions of the suspended status of the following Exxon wells. Point Thomson 1, 2, & 3 .Duck Island .~;~:'1~, 2, & 3 Alaska State C-l, D-l, F-1 We would be pleased to arrange an inspection tour of each of these locations for your representative sometime in late August. Please contact Mr. R. L. Westbrook at (907) 263-3742 to arrange a convenient date. Very truly yours, NB: rms 40/42 A DIVISION OF EXXON CORPORATION STATE OF ALASKA ........ ALASK,, OIL AND GAS CONSERVATION C,~MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator Exxon Corporation 3. Address Pouch 6601 ~ Anchorage; AI( 99502 4. Location of Well 700' NSL and 800', WEL, Sec. 8, TllN, R17E, UPM, North Slope, Alaska 5. Elevation in feet (indicate KB, DF, etc.) 3' WD at surface location 6. Lease Designation and Serial No. ADL 47502 7. Permit No. 78-68 8. APl Number 50]32q-~D2gD 9. Unit or Lease Name Duak Island Iln4t 10. Well Number No. 11. Field and Pool Wildcat 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Aband({nment see 20 AAC 25.105-170). We request a one year extension to August 1984 of the suspended status of this well. We will arrange to have the location inspected by your representative on a yearly basis or until final abandonment. 14. I hereby certify ~r~ the f, oregoing is true and correct to the best of my knowledge. Signed _ Title Alaska The space below for Commission use Date 7/25/83 Conditions of Approval, if anyReturned unsigned, P&A downhole. See letter cf September 29, 1983. By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate EXXON DUCK ISLAND #1 API-50-029-20280 5-TllN-R17E, UPM 1. Geological Completion Log, interval 110' - 12800' MD 2. Mud Log, interval surf -12800' MD 3. Drill Stem Test Summary Report 4. Well Complet'ion Report by D.L. Hargus 5. Completion Data, Drill Stem Test #6A 6. Completion Data, Drill Stem Test #5B 7. Completion Data, Drill Stem Test #6 8. Completion Data, Drill Stem Test #5 9. Completion Data, Drill Stem Test #3B 10. Completion Data, Drill Stem Test #3 11. Completion Data, iDrill Stem Test #2A 12. Completion Data,~Drill Stem TeSt #1 SOHIO ALASKA PETROLEUM COMPANY PAUL J. MARTIN VICE PRESIDENT. OPERATIONS & ENGINEERING Mr. C. V. Chatterton Cha i rman July 20, 1983 Alaska Oil and{:.~Gas Conservation Commission 31~; C" STREE~ , . , ANCHORAGE. ALASKA , . _ . TEt_EPHOh:E (907~ 26':. ,542 ', ' .4 ? ', MAIL POUCH 6.6~2 ,. ~ ,' ''_~ ANCHORAGE. ALASKA 99,502 .... ~ (_ h< ,' ",T.,', :' ' l ' [ ';7:".". ' HAND DELIVEREUi"' , C©t',t ~.'- " ! Fl! F- 3001 Porcupine Drive Anchorage, Alaska 99501-3.192 Re, Endicott Project Dear Commissioner Chatterton: With reference to your letter June 8, 1983 we are pleased to submit, on behalf of the Working Interest Owners in the proposed Endicott project, the basic well, geological and reservoir data which is listed on the attached Exhibit A. Please be advised that each page of this data has been marked "Confidential." We hereby request that the data be held confidential under the provisions of A.S 31.05.035(d) as engineering, geological and other information not required by subsection (a) of that statute, but voluntarily filed with the Commission. You should be aware, however, that some of the data submitted is identical to data previously submitted under the provisions of AS 31.05.035(a) and required to be held confidential for a period of twenty four (24) months under subsection (c). Accordingly, our request should not be viewed by the Commission as preventing the release of any data which was previously filed with the Commission under those sections, and which has been, or will be, released under the provisions of subsection (c). If you have any questions regarding the content of this data, or with regard to other matters, please do not hesitate to contact me as we agreed at our June 1, 1983 informal meeting. Very truly yours, · P. J. Martin Acknowledge receipt of above-referenced data SIGNED: ~ -- ..~..~_._~ .... /' ~--~ ..... ' "~' DATE: [2-,?.O ,? ? March 11, 1983 Mr. Richard C. ~ager Mobil Oil Corporation -~PSI P.O. Box 900 .. Dallas, Texas' 75221 ReT Preparation of Petrographic Thin-Sections on Core Chips from .~.~ ~ State-Sample~.. Aibrary~ Dear Rick: Pursuant to our March 9-11, 1983 discussions, permission is hereby .granted to Mobil 0il Corporation to extract a maximum 1 cc. of Core material per foot of core from the State's set of core chips for'the purpose of preparing petrographic thin sections in the following wulls, subject to the below listed conditions~ Sample Set No. __ 387 3P2 40O 423 Wel 1 Interval ,, , , Sohio Sag Delta %2 Sohio Sag Delta %3 Sohio Sag Delta #4 Exxon Duck Island Unit #1 9,590'- 9,855' 9,336'-10,901' 11,559 '-13,128' 11,044 '-11,604 ' I I . CONDITIONS Cuts of the core chips from the State collection are to be extracted only from those individual envelopes or bags in which total content of core chips is greater than 10 cc. (No cuts are to be extracted if the volume of material in the individual envelope is less than 10 cc.) 2~ Mobil will provide the Commission with a list of the depths in each well from which material was e:Ccracted. 3~ In the event that you wish to prepare blue-dyed thin- sections, it is requested that the core material be vacuum, impregnated with blue dye epoxy Prior to mounting on the thin-sections. ~ :. ', :: ,;. '-, 4 .'.'~ All ~otrographic th~n-se~o~s preheated are .... ~.~?.~>~$.?: ;, :AIl residue and excess cor~ ~terial ia to ~e returned ;.,no".~-al-~de or core ~t~rial is .to be ~[;~':)'~,~'6"?~"~.:"~O?'-additional~sli~es are to be prepared on the core , :~f~' .,"~:.~'~ '~-<-libra~ without speCific prior co~ent from tho Com~ission~ . ; - ,. ...... "~ ~:'.;'~ -",~.!i:,~,.;.,. copies of any r~rts resulting fr~ analyse= of tho s~pled core-~torial are to b~ submitted to tho C~mission. ,.T : .' .. ', ~ . . · ~ : 7. .... }iobil shall ~ar-, all costs entatlod. _ ::.Wo'are pleased to 'work with you in this be~efici~l proje~ and - . 'loCk,~:~forwrd ~o your co~anyVs continued exercise of cato and good Judg~nt .tn the handling of-this limited ~uantity of valuable well ~terial. I-~ wu ~th understand that tho State's w~ll '8~plo libra~ is' public prope~y and that granting ~obil "~sion"to e~ra~ ~ions of ~terial from this libra~ for. th~ peruse of preparing tho aubje~ ~terial o~anccs ~he value of the libra~ and is tn tho P~lic interest. 'j E ON COMPANY, U.S.A. POUCh 6601 o ANCHORAGE, ALASKA 99502 PRODUCTION DEPARTMENT ALASKA OPERATIONS March 23, 1982 Alaska OiZ and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attention: Mr. Lonnie Smith Dear Mr. Smith: Attached are Polaroid photographs showin~ fh~_~,q] ]bore markers for the ~xQ.r~ Point Thomson No. 1 and~&~,~S~nd ~,",-'.~%nd 2., wells as requested in your letter of September 11, 1981. Very truly yours, RGD:rms 25A/Y Attachments 295-651-100 295-641-100 295-642-100 A DIVISION OF EXXON CORPORATION E) ON COMPANY, U.S.A. POUCH 6601e ANCHORAGE, ALASKA 99502 E~LPLORATION DEPARTIV~ENT ALASKA/PACIFIC DIVISION March 18, 1982 Re: Exxon No. 1 Pt. Thomson Unit Sec. 32, T10N, R23E, UPM ADL 47560, Permit 76-85 Duck Isla~it. No.~_ ADL 47502, Permit 78-68 Duck Island Unit No. 2 Sec. 8, TllN, R17E, UPM ADL 47502, Permit 79-60 North Slope, Alaska Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Enclosed in triplicate are three Sundry Notice Forms 10-403, requesting an extension to June 1, 1982 to clean up the three locations captioned above. We request that you return an approved copy for our file. Very Jgr/~y yours, John A. Staffeld JAS: e t enclosures A DIVISION OF EXXON CORPORATION STATE OF ALASKA ALASKA ~,L AND GAS CONSERVATION CO,.'iMISSION SUNDRY NOTICES AND REI ORT$ ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. Exxon Corporation 78-68 3. Address 8. APl Number Pouch 6601, Anchorage, Alaska 99502 50- 029-20280 OTHER;III Wildcat 4. Location of Well 700' NSL & 800' WEL of Sec. 8, TllN, R17E, OPM 5. Elevation in feet (indicate KB, DF, etc.) / 6. Lease Designation and Serial No. 3 ft. water depth at surface 1°~. ADL 47502 9. Unit or Lease Name Duck Island Unit 10. Well Number No. 1 11, Field and Pool Wildcat 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] , Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Request extension to June 1, 1982 to clean up location. 14. I hereby certify Signed ~ The space be~ ~.~k.., ~t ,~/~~~~l~atflhe foxegoigg is,ltrue ap~ bommission use NJ.d.,' correct to the best of my knowledge. Title Sen ior Landman Date 3-18-82 Conditions of Approval, if any: Approved by Approved o~y Returned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate March 11, 1982. Exxon Company U.S.A. P.O. Mox 6~01 Anchorage, Alaska 99502 Re: P. equest for Extension of Time for Clean-up Gentlemen: This office informed you ~y letters on September 11, 1981 that a submittal .of form 10-403, Sundry ~otices and Reports cn ~ells, was necessary for Pt. Thomson Unit No. 1 and'~-'Duck~ iS'lan~ un~i-~~~i~'~il ~>and No. 2, to request an e>:tension of tir~ for clean-up. These requests have not been recaived. Please submit these 10-g03's promptly. Sincerely, / ,,~ Lcnnie C. Commissioner cc: Letters cf Septembe'r 11, 1981 /JET/g lh September 11, 1981 ~xon Company, U.S.A. 3301 "C" Street P.O, Pox 6601 Anchorage, Alaska 99502 ~e: Location Inspection of Clean-up, Luck Island [)nit No~.....!~.~nd 2, Sec. 8, TllN, ~.I7E, ~,~i"' Cent le~e n: Our representative inspected this site on August 11, 19k;1. 'ihe fo!lc:wing deficiencies %~ere noted.. 1. There was no well identification sign. Please notify this office when this deficiency has been corrected. Verification can be by close-up photographs or by a site inspection. There is a fuel pit remaining on the site and the cellar is at variance with regulations. Consequently it will ~.e necessary to request on form 10-403, Sund. ry Notices and Reports on for an extension of the final clean-up datc. Clean-up regulations apply until approval of final c!ean-uu or until the %.~elis arc assigned as producing ~ells. A subsequent inspection will be necessary for this site. Sin~gere]y, ~ -'¢", 42,'/. bonnie. C.'-Smith Commissioner ICStJ~T/g ]~h ALASKA OIL AND GAS CONSERVATION COMMISSION H oyle H. Hamilto Chairman THRU: Lonnie C Smith Commis s ioner Doug Amos Petroleum Inspector August 31, 1981 Conduct Clean-up inspection on Exxon's Suspended No. 1 & 2 Wells, Sec. 8, TllN, R17E, UPM. Permit No. 78-68 & 79-60 T__u_uesd~, August 11, 1981: I accompanied Mr. Dave Galloway, Exxon representa{iye, to the well site. As the attached pictures show, the island is in godd condition. However, there is a fuel pit remaining with liner still intact. There was no well marker post on either wellhead, nor was the re- quired well information bead welded to the cellar cover. Therefore, I recommend to the commission that approval for Clean-up not be granted until the well sign has been installed and verified. In summary, I conducted the clean-up inspection on Exxon's suspended Duck Island No. 1 & 2 Wells. I recommend that Clean-up approval not be granted until the well sign has been installed and verified. DA:vdl 20 A,,\(: '75, .',J.71'.LCLI:~ 2 FILE [ NFOt/HATiON: Surface 1,oration of Well ~0.0 ~ Ft F~ 1':' L, 52~ Ft F~/~~ Sen. ~ , T_~f ~, ~ ~ ~, :..,,~' X. Length ([0' l.lin.) Wu 1 d s 20 AAC 25.l';0:, hl;l~I, AI;ANI)Ov'',,,,[.~,,,''''l,.,,~*"",...kl.;' !{: 1)ia. 'Steel Post (4"Min.) Height Above Final Crade Levul (4' Top of Marker Pipe Closed with: Cement P~ug Set: On Well ttead , On Cutoff Casing .Distance Below Final Grade Level Side Outlets: All Valves and ~<ipples }<c~aoved All Openings Closed , With blinds ,Screw Cat~ Concrete ["t. , \?%th Cement , Other INFORHATION l{f,],\l)t.,'EI,I3}.]l) I) II[i.]CTEI,Y '['0 N?~RKER P()ST: (List hq~ere Different [~otn File InfOL-l'natioll) Operator UnLt or Lease Well Number , Surface Location of Well: Ft. F L, Ft., F L, Sec , T , R 20 AAC 25.170: LOCATION CI_,E,,\N-UP PITS: Filled In , Liners RemOved.or Buried , Debris Removed SURFAC}5 OF PAl) A,~;D/OR LOCATIOn': P, ough Other , Smooth ~ Contoured Fiat t~, Compacted CLEM': Ut' OF PAl3 A?;I)/OR IX)CATION' Clean t/, Pipe Scrap Paper , Other SURROUN1)]iNG ARF,.,\: Iron , ~c ca,) , .,.~ (.c c~ L.l (, Wooded , Brush , Tundra , Grass , Dirt , Cravel Sand __, Other /N~.-[e r. COND IT ION SUt~.[(OU~,;D [ N(i ,\}lI,l,.\: Clean ~,~, T'r'asl~ from Site Other , Trees and?or Bt'ush from Cle;irLng Site i ACCESS ROAD: CONI) ETIO>I ACCESS ROAD AND SLJRROUr;i)~.,,,_ "~'C' Clean , Rottgh , Sn'~ooti~ , 'l':ash from (-)l),:,u;ltLon~ , Trees and/or Brush from Clearing Road " , SpoL1 from Clearing Road Other REMAINING TO BE I')ONIC: ; -~r,[ ~ . - ~ : .:,,J. '." . ,X 7; . , ' 't ',,.:,, RECObtI'Ii'iNI("APPI~OVAL OF ABANI)ONblI~NT' Yes , No '/ Fin;ti Inspection 05/26/81 E j ON COMPANY. U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 PRODUCTION DEPARTMENT ALASKA OPERATIONS July 7, 1981 Mr. Lonnie C. Smith, Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 STAT IEC-- . i FllF: -- Dear Mr. Smith: In accordance with Alaska Oil and Gas Conservation Commission regulations, Article 2, Abandonment and Plugging, 20 AAC 25.120, Well Abandonment Marker and 20 AAC 25.170, Location Cleanup, it is respectfully requested that a program be initiated to inspect wellsites at Prudhoe Bay during the first part of the week of August 10, 1981 or during the week beginning August 17, 1981. Please notify us if these dates are convenient and if so, which is preferable. The sites to be visited and inspected are as follows: t_Duck _ and W_e!ls #1 and 2 on Duck Island Pad #1 Pt. Thomson #2 Pt. Thomson #3 Pt. Thomson #4 Canning River B-1 It is requested that the inspection of Duck Island Pad #2 (site of Duck Island #3 well) be deferred until the summer of 1982 since drilling on this location will resume during the 1981-82 winter season. Mr. D. E. (Dave) Galloway (263-3756) is our contact for finalizing the aforementioned inspections. Very truly yours, ALH:dag A DIVISION OF EXXON CORPORATION Drilling Manager JUNEI~ U, ALASKA 99 :: ,: ~~'~ OFFICE OF THE COMMISSIONER PHONE~ April 22~ 1981 Mr. Crandall D. Jones~ Manager Exxon Company~ UtS.A. Exploration Department Alaska/Pacific Division P. Oo Box 4279 Houston, Texas 77001 Dear Mr. Jonesz I am granting your request of February 11, 1981 fo]: an ex'tension of the confidentiality .period ]pursua]~t"~o AS 31.05.035(c) on well data from~Duck Island Unit We]_]. No. The data will be held con~mdentzaI'-'~-for'a ~ea'~onable~Lme after the State Supreme Court issues ~'~.; fins], ru]_ing on the Beaufort Sea Sale litigation. Sincerely, cc: ~Hoyle Hamilton Alaska Oil and Gas Conservation COKLmission 3001 Porcupine Drive Anchorage~ Alaska 99501 Glenn Harrison Director, DMEM 10-J9 L h E) ON COMPANY, US.A° POST OFFICE BOX 2180' HOUSTON, TEXAS 77001 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION CRANDALL D. ,JONES MANAGER K..I _. co,v, - April 16, 1980 ~ t_4 !r I U. S, Army Corps of Engineers J .~ STAT TZ Pe~it to Conduct Operations in I'--i STATT~ Navigable Waters [ .j '-~ Drilling Pad Construction ,---I-~~ Duck Isl and Unit Area J ~i~ ] Sec. 8, T11N-R17E NPACO No, 071-0YD-770229 Lt. Colonel Lee Roy Nunn District Engineer U, S. Army Corps of Engineers P. O, Box 7002 Anchorage, Alaska 99510 Dear Colonel Nunn' A permit for the construction of the captioned pad was issued by the U. S, Army Corps of Engineers on February 27, 1978. Two wells have been drilled from the pad during the last two w~nter seasons. Because Exxon plans to maintain the pad for exploratory purposes for three additional drilling seasons, we respectfu'lly request that the provision of the captioned permit ~equiHng disposi't~on or removal of the pad by June 1, 1981 be modified or:suspended untfl June 1,1983, Several factors have contributed to the need to maintain the pad for additional exploratory drilling past the June 1, 1981 date' 1. Exxon's Duck Isl'and Unit Well. No. I drilled from this pad has been determined to be productive by the Alaska DMEM, thus increasing the .probability tha'~t a~Jditi'onal exploratory d.Hlling from this pad may be required, 2, Litigation involving adjacent lease tracts included in the Beaufort Sea Sale is pending in Federal and Alaskan State courts, adding uncertainty to specific plans for future exploratory drilli'ng from the pad. A DIVISION OF EXXON CORPORATION 3. Plans for achieving a cost-effective exploratory program are currently being considered by the Duck Island Unit owners and owners of adjacent leases. RECE/V!-:D AP,R,, Ig O Alaska Oil & G:-~s ~. ,~, ,. ,, ...... ~isslorl Anohurau~ Lt. Colonel Lee Roy Nunn -2- April 16, 1980 We would be happy to discuss this matter with you at your convenience. If you have any questions or need additional information, please telephone Robert K. Riddle in Anchorage at (907) 276-4552 or O. C. Rath in Houston at (713) 656-1952. Sincerely, OCR'cb c: Tom C. Cook - Director, Division of Minerals and Energy Management Hoyle Hamilton - Chairman, Oil and Gas Conservation Committee Eben Hopson - Mayor, North Slope Borough Ernst W. Mueller - Commissioner, Department of Environmental Conservation bc° Robert K. Riddle E~ON COMPANY, U.S.A. POUCH 6601e ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION Re: March 5, 1980 Exxon Duck Island Unit No. ADL 47502 North Slope, Alaska ~o~~ [ 3 ENG ~_~_4 ENG 1 GEOL J STAT TEC I _ __ CONFER: FILF: Mr. Hoyle H. Hamilton, Chairman Alaska Oil & Gas Conservation Commission State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hamilton: Cq r Enclosed are your copies of digital magnetic tapes on the open hole logs from the captioned well. This data should be kept confidential in accordance with the provisions of 11 AAC 2.535(f). Very truly yours, RLL:et enclosures R. L. Longstreet [-:."..;:- ,5 A DIVISION OF EXXON CORPORATION E) (ON COMPANY, U.S.A. POUCH 6601e ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION Re: March 4, 1980 Amendment Duck Island Unit No. 1 Mr. Lonnie C. Smith Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Smith: In accordance with today's discussion with Mr. Blair Wondzell we have amended and enclosed herewith Sundry Notice of even date proViding for abandonment of Duck Island Unit Well No. 1. Three copies of said notice are submitted so that on your approval one may be returned for our file. Very truly yours, RKR:et enclosure i980 ArlohU~ 8,~,~ A DIVISION OF EXXON CORPORATION Form'10-403 REV. 1-10~73 · Submit "Intentions" In Triplicate / /* [ & "Subsequent Reports" in Duplicate STATE OF AI_~SIr~ 0IL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES .AND REPORTS ON WELLS (Do not use this form for proposals, to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) ~' o,- I--I GAS l---] WELLL.-I WELL OTHER W"i ldcat 2. NAME OF OPERATOR Exxon Corporation ADDRESS OF OPERATOR Pouch 6601, Anchorage, 4. LOCATION OF WELL At surface Alaska 99502 700' NSL & S00' WEL of Sec. 8, TllN, R17E, UPM 13. ELEVATIONS ~how whether DF, RT, GR, et~) 3 foot water depth at surface location 14. Check Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO: TEST WATER SHUTC3FF L__J FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) !-'-'-! PULL OR ALTER CASING ~ MULTIPLE COMPLETE ABANDON* CHANGE PLANS 5. APl NUMERICAL CODE 50-029-20280 6. LEASE DESIGNATION AND SERIAL NO. ADL 47502 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Duck Island Unit 9. WELL NO. No. 1 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., T., R., M., (BOTTOI~I HOLE OBJECTIVE} Sec. 5, TllN, R17E, OPM 12. PERMIT NO. 78-68 )ort, or Other Data SUBSEQUENT REPORT OF: WATER SHUT-OFF : REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. Well was suspended in accordance with Sundry Notice (form 10-403) filed 4-9-79 and approved 4-17-79. All details of abandonment procedure including perforations and plugs are fully described therein. This notice is filed for the sole purpose of changing the classification of the well. No further work is contemplated nor is any further work believed to be necessary to accomplish such purpose. Therefore, consistent with such stated purpose we consider the wel~l.officially abandoned ~September 25, 1979. 16. I hereby certlf~Y)that the foregoing is true and correct / SIGNED _ E (This space for State offic, e/'use) // ' , / CONDITIONS OF~/C/PPROVAL ,~(-A~Jy: TITLE ~ ~' 0F .~';: CO~ISSION R. P Bright Drilling Manager DATE 3/4/80 See Instructions On Reverse Side DATE Approved Copy Returned COMPANY. U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION Re: August 21, 1979 Exxon Duck Island Un LO/NS 79-45 (77-162) ADL 47503 Mrs. Ethel H. Nelson Leasing Manager Division of Minerals & Energy Management 703 W. Northern Lights Boulevard Anchorage, Alaska 99503 Dear Mrs. Nelson: FILF: Following the suspension of Exxon Duck Island Unit No. 1 well in accordance with the Sund~y Notice filed with the Alaska Oil and Gas Conservation Commission April 9, 1979, Exxon removed from the gravel island drilling platform all fuel and lube oils on April 24, in accordance with the conditions of your approval of the subject plan o'f operations. Plans are being consumated at this time with the unit participants which will permit the filing with you in the immediate future of a plan of operations for the drilling of a second Duck Island Unit well utilizing the bore hole of Duck Island Unit No. 1 and drilling a sidetract directional hole easterly to bottom hole location situated upon the adjacent lease ADL 47503. All appropriate applications and/or requests for concurrence will likewise at that time be filed with the Alaska Oil and Gas Conservation Commission, Alaska Departments of Environmental Conservation, Fish and Game and the Division of Forestry, Land. and Water Management of the Department of Natural Resources. In the meantime, however, to make the most efficient use of time consistent with the restrictions of our U.S. Army Co,ps':~ of Engineers permit and all past approvals by your of~'°f our plans of operations, we would greatly appreciate?yOur permission to undertake the following measures;,.~::',-..' 1. Move in on September 1, 1979, open camp and start generator. · Barge to location fuel, oil and water along . with necessary rental tools and drilling A DIVISION OF EXXON CORPORATION' MrS. Ethel ~- ~lson Page 2 August 21, 1979 3. Hook up fuel lines and test. install liner in day tank pit, reserve pit and sewer effluent pit. 4. start up rig engines and boilers- * 5. Pump out cellar, install BOP stack and test same. 6. install pipe rack cover- 7. Rig up mud cleaning equipment and related dr illing equipment- All transport of materials and personnel to and from the location will be by barge until September 15; after this helicopter will be used for transport until bottOm date a conditions permit the construction of a surface fast ice ice road from the mainland to the island- We greatly appreciate the cooperation which you have extended and assure you that the above actions as well as all aspects of our operations will be carried out in strict accordance with the conditions or stipulations which you may attach to your approval. · Yours very trulY, RKR: et cc: Mr. Hoyle H. Hamilton, Director Alaska oil and Gas conservation commission Mr. Hamilton: , Ample notice will be provided so as to permit your representatives to witness the installation and testing of the BOP stack. I~rm 1~o. lt~V. STATE O,- ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS SUBMIT I~ IDI_FPLICATE 1. o.. [--j G,. [] o,.zR Wildcat WltLL W~LL 2. NAME OF OP~:~ATOR Exxon Corporation ~i ADDRESS OF Pouch 6601, Anchorage, Alaska 99502 4 LOCATioN OF WF~ Surface: 700' NSL & 800' WEL of Sec. 8, TllN-R17E, UPM, North Slope, Alaska BHL (Proposed): 500' NSL & 800' WEL of Sec. 5, TllN-R17E, UPM, North Slope, Alaska i i co,v,,~ 50-029-20280 [~I R~-,:( -. ~L 47502 I J2 ,..:,,:OL ~ck Isled Unit [._. 13 ~ '~'~xo 'j [ STAT Wildcat ! !O~[?J 'i'~ SEC, T., R. M (~)~OM HO~ILF: Sec. 5, Ti]N, R17E, UPM PER_MIT k'O 13. REPORT TOTAL DE[PI'H AT END OF MON~'~r], CH~N(]F~ IN HOLE SIZE, CASING A~ C~TING JOBS INCLUDING DEPTH SET ~ VOL~ USED. P~O~TIONS, ~_STS ~ ~SULTS FISHING JO~ JLqqK LN HOLE AND SIDE-~..ACKED HOLE ~ND ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~DITIONS During the mOnth we rigged down the BOP stack, cleaned up the location and removed all fuel, gasoline and oil from the island. The rig was left on the island per approval received April 16, 1979, from Ethel H. Nelson, Leasing ~anager, Division of Minerals and Energy Management. All operations were suspended on the island on April 25, 1979. This will be the final report fr~n the well. RECEIVED i hereby certiiy~ ~oh~g ~he ~ ~ Acrea e ~d Well oi~and gas conservation commiffee bytbe 15~ of the succ~ding menm, u~l~ ~t~erwiss directed, E ON COMPANY, U.S.A. POST OFFICE BOX 2180. HOUSTON, TEXAS 77001 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION W.R. FUGE, JR. MANAGER ACREAGE/WELL EVALUATION Re' A~ 30, ADL 47502 ~ North Slope, Alaska Mr. Hoyle H. Hamilton Director, Division of Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 CONFIDENTIAL Dear Mr. Hamilton' We are attaching two copies of Form P-7, Well Completion or Recompletion Report and Log, for the captioned well which was plugged and suspended on March 29, 1979. Also, we submit the following data: (1) One set of washed and dried samples (in 5 brown boxes) from 1050' to 12,800'. (2) One blueline and one sepia print of the complete mud log from 1050' to 12,800'. (3) One composite sepia and one composite blueline print of the following open hole logs' Dual Induction-Laterlog BHC Sonic Long Spaced Sonic 8'-10' Long Spaced Sonic 10'-12' Compensated Neutron - Formation Density Compensated Formation Density (4) Core chips taken at 1' intervals (in 4 brown boxes) from the following cores' A DIVISION OF EXXON CORPORATION Mr. Hoyle H. Hamilton Page two April 30, 1979 Core No. 1 2 3 4 5 6 7 8 9 10 11 Interval CONFIDENTIAL 11,044' - 11,059' 11,059' - 11,089' 11,089' - 11,146' 11,530' - 11,567' 11,570 11,683 11,740 11,766 11,809 11,869 - 11,627' - 11,739' - 11,766' - 11,809' - 11,869' - 11,927' 12,770 - 12,800' (5) Summary of formation test data. (6) One copy of Eastman gyroscopic survey. Please note that the above material is marked confidential and should be kept confidential in accordance with the provisions of 11 AAC 22.535(f). WRF'RLL'et attachments SUBMIT IN DU. TE OF ALASKA ""'~ OIL AND GAS CONSERVATION COMMITTEE ~"~" OF' WELL: OF COMPLETION: ' ~.,~,~ ,_, ~.~..~,.,~. ,~, mh~ Suspended X~' E L I. ~ OVER ~ EN ~ NAME OF OPERATOR ~on ~r~ration ADDKES~ OF OPERATO~ P. O. ~x 2180, ~u~on, Tex~ 77001 LOC^TION OF WELL (Rel)ort location ctearl~l attd i~ ~ccordance with amy ~'tate require~e~lt~)* ,~c~ 700' N~ ~ 8~' ~ of S~. 8, Ti~N, ~, ~, Nor*h Slnn~ AI~ top prod. ~nterFa~repo?~low to~a~ d~ 436' N~ & 787' ~ of Sec. 5, ~, ~, ~M, North Slope, AI~ CONFIDENTIAL APl NU~IEILICAi., CODE 50-029-20280 6. I~E, AIE DESIGNATION A.ND SERLA~ ~tl~,' ADL 47502 ?. IF INDz.KN', KIiX)T1T_.~ O1t TRIBE NAIIJ[ 8. UNIT,FA.I~%I OR I-~E~$E NAA1E Duck Island Unit 9. WELL 1'¢O. -. 10. FIEI.I~ AND POOL, OH WII~DCAT - Wildcat 11. SEC., T., R., M., (BOTWOM HOL~ ~ OtLIEC~IVE) Sec. 5, TllN, R17E I 'bo 12. PEHMIT NO. I4~'xc~ ~-~5''7~1-17-79 [ ~-~9Z~jv ~ ~'"~ f¢~' 78-68[ 13. D.~ SPUDD~ DA~ T.D. ~C~ [15. DA~ CO~ SUSP OR ABAD. 16. ~EVA~ONS kDF, RKB, BT, GR, ~C)" '' 1~23-78 28' ,, ~. PRODUCING IN'r~VAL(S), OF THIS CO-MP~TION--TOP, BOSOM, N~E (~ AND ~)* ~. W~ DI~ON~ Perforations c~ented for p~oses of s~ety. S~ ira 28 t 29 for , s~v~~' perforation ~te~s ~d c~nt~g. See Attac~nts for te~ ~ta. [ Yes 24. T~E E~CTRIC ~ND OT~ LOGS RUN OIL, BHC Sonic, FDC-~gL, Micro-Microlaterolog, Dilara~ter CASENG RECORD (Repor't all strings set itl w~l_ 1)'~. " ' ~ 'J'' ".~' 30" '' 3Z0 ' / B i fl~i I 36" ;--tt'b ~f W/Ve~fr0s¢ i None 20" ' 94 '[ H40 J ' ~72i.'1 24" 'J212400 sx Pe~frost ]None 13-3/8" 72~ [N~0 [ $',~20~] !7~'(=1~,0,0 ~Pemfrost l~one, '"9'5/8';~ 43.0 ' / S~95 1 11,~91" I Class G 121"-,11850 ~ 12400' , 2 ,"" ,.' . ' ....' 28. PErORATiONS OP~ TO PRODUu'i'ION (interval size and number) 2~. ACID, SHOT, FRAC7 URE, C~IENT SQUEEZE] ~C. al Intervals ~ueez~ ~mm ,;a'mv.~ ¢~ axtou~r~'~x.-,~,~~.t.~~,, ...... ~-. S~ A~A~~ _ ~' A~A~,~ . :. , ~ I i i i . i i ii ii i [ i ii i _.. 30, / P~ODucTIOH DATE ~[RS~ PilODUC~ON ~ ~ODUCTION Mgl ifOD ~Flowi~g, ~a~ I~. p~mptna~size an~ ~ypu of pump, A~.~ ~[~V~Lg STATUS ~Producmg DaTZ aP T~ST. ~URS '!ES'F~ [CIiOXE SiZE [PROD'i~;~O~_ Oi~DL. G~ICF. W;Ji'E~BBL. [GAS-OIL P..%TIO ,. ~ ' ,., . ~XV. Im'EING UASLNG PRE~SURE ICALCUMT~ Oi~BBL. ~kOA~-RI~i WA~BL. JdI'L dRAVITY-~I ~ESS. 12.%HOU~ EA~ I % / J l- 'I · ' I , l .,.~,~:s,..,o~o..~ ,so,a.-..a;o~z.~.....,....~.,- ' / N 1':'?''''''~"'"'"' ' ~ke 32. LIST OF ATTAC'HMENT~ ' '~ ;~ ,..~,~ Squeeze ~nt Jobs, ~re Data, Te~ Data ' .';,q.'I herdby-ertii;~a~.g and"att~hed information Is 'complete and correct as determined from 'ali-available reeurds Acreage ad, Well ,8ICNE ~~' , _ TITLE Eval]m.tian Mansgar DATE April '... . (_., ..... .,, - ...... 7, ....... , '"". / ~ee'~lnstructions and Spaces lot Additional Data on Reverse Side) CONFIB INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ...' Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for .depth measure- meats given in cther spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separatc production from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the p~c. Jucing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional inte~ v~l to be separately produced, show- ing the additional data pertinent to such interval. Item26: "S~cks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the Cementing tool. Item 21{: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). ... WAT~ AND MUD ~ ~wer Tertiary 4,270' 4,270' ~ A~A~ ~ Sc~ader Bluff 8,420' 7,595' CONFIDENTIAL ~o-K/Kek~t~ 11,010'~, 820' ~e-~ss 12,3~5~ 10 ~40~ ~., , ,, ,,, . , ,,, , , ~ ,,. , , ,,. ~ ~ ,, ~ ~ , , ~ , ,,,~ , ae. co~E DATA. Al'rAcll nniE~ D~CRIPI~ONS OF LITIlOLOGY. POROSITY. FRAc~H~. APP~NT DIPS AND DETECTED SIIOWS OP OIL, GAS OR WA~I. C~ ............................... . ........................ , ................. , ,., TEST NUMBER DATE TYPE TEST INTERVAL CUSHION FIT NO. 1 2/2/79 Wireline 11,807' TE~DATA Exxon Duck Island Unit No. 1 1 2/3/79 Closed Chamber DST through perfs. 11,790' -11,810' (4spf) CONFIO NTIAL 2 2/7/79 Closed Chamber DST through perfs. 11,700'-11,720' (4spf) 2A 2/8/79 Closed Chamber DST through perfs. 11,700'-11,720' (4spf) Nitrogen Nitrogen Nitrogen PROD' N FOR TEST PERIOD 6~OKE SIZE FLOW RATE FLOWING TBG PRESS TBG SIZE IFP ISIP Rec 1 cfg, 7800 cc wtr, 500 cc mud 0.6 2-7/8" 3616 psi. Tool. did not open 2-7/8" 2.0 Rev out 24 BW 2-7/8" 2344 psi. 5112 psi. 2027 psi. FSIP 5700 psi 5124 psi. - 4958 psi. TEST DATA Exxon Duck Island Unit No. 1 CONFIDENTIAL DATE TYPE TEST INTERVAL CUSHION HOURS TESTED PROD' N FOR TEST PERIOD CHOEE SIZE FLOWING TBGPRESS TBG SIZE IFP ISIP FSIP 3 2/10/79 Closed Chamber Ds'r through perfs. 11,627 '-11,644' (4spf) Nitrogen 0.7 Rev out 45.5 BW & 2.5 BM 2-7/s" 1697 psi. 4520 psi. 5021 psi. 2/19/79 Closed ChamberDST through perfs. 11,627'-11,644' (4spf) Nitrogen Tool did not open. 2-7/8" 3B 2/21/79 Closed Chamber DST through perfs. 11,627 ' -11,644' Nitrogen 7.5 Rev out 38 BW 2-7/8" 2296 psi. 3680 psi. 4999 psi. (4spf) 4 Test Cancelled 5 3/1/79 DST through perfs ii, 502'-ii, 523' (2spf) Nitrogen (1)2.0 Rev. out 57 bbls heavy tarry oil. (1) 2-7/8" 6195 psi. 5020 psi. (1)After 3 bbls rec. flowline plugged & killed well. TEST DATA Exxon Duck Island Unit No. 1 CONFIDENTIAL TEST NO. DATE TYPE TEST INTERVAL CUSHION HOURS TESTED PROD' N FOR TEST PERIOD. CHOKE SIZE FLOW RATE FLOWING TBGPRESS TBG SIZE IFP ISIP FSIP 5B 13/24/79 DST through perfs 11,458' -11,482' (4spf) Nitrogen 4.2 316 BO !' ' (1)1900 BOPD (19. ?o Gty @ ~0°F)& 670 MCFG/D (OOR 350' 1) 540 psi. 2-7/8" 4707 psi. 4992 psi. 4691 psi. 4968 psi. (1 )Based on 2 hr. stabilized test. 6 3/8/79 DST through perfs 11,188'-11,203' 11,208'-11,219' 11,224'-11,234' Nitrogen Unsuccessful Test 2-7/8" (2spf) (2spf) (2spf) 6A FIT NO. 2 3/10/79 3/15/79 Prod'n through perfs Wireline 11,188' -11,203' (2spf) 11,208'-11,214' (2spf) 11,224'-11,234' (2spf) 11,066' Diesel/Nitrogen 9.0 3/4" (!)'265~. BOPD (26.8° Gty @ 60°F) & 2350 MCFG/D (GOR 887.1) Rec 54.4 cf g, 400 cc cond (49.2° Gty ~74°F), 300 cc mud. ,, 880 psi. 2-7/8" (2) (2) (2) (2) ~ ~-l~Based on 6.5 hr. stabilized test. (2)Pressures obtained on Test 6. 7 3/15/79 (1) 11,071'-11,081' (4spf) (1)Test Cancelled. -- .......... · '. _ .-... 1-z)~ IZ&OO hid ......... · FT×ON USA PROPRIETARY ',~ 4 4. C.,,'5."~ ? I · CALCIJLA¥:,ON SHEET' 15x5 GRID) : .- _. -.'_. :~ ~ - -~ . :" '-:----.-, .~:'-'_-L--.--: -.'- ..... -; ~_i:= '-~-:_ , ' :.-, -, '.~ ;-_:-)-~:: -.~::: ..- ??--:'_ ~" _'-: - *.%- .. ,:--- L~_~: ,'._ =~t-__: .~,;-_:: :~ :- . _.::_ ~ .t_.: '.:-.i ::-'t_ ::.: i~.-:--::.:. ,-: ~ -._: ~ .:157:7_ ' :- -' · :..__..-:~i -".':~ :,i_. ]':-'-_7'i-:'::~'. -~:?/-:!7i'!. · -- - ..... _ '_ ' -~: 7:- ':----'.:. ..:: : ... ~: .... :,:, .:: ~: , - -.. '-?::.'=. '.: =, :-- ' : ".-.' ':-. ':' .. -,--:.... · -'..~. ,=__. --- ,- :~_ --- ...: . ~ . .. - ·~ - _ ': .--. .... - : - . _ .- -!~ . : : -. _ _ . _ . ' '% _' '--.:: C 'i _' .... - " '~ · -: ._: .... .: ~. .,- .-~..,_ ...-...~., ...... _ ..: .... .: _. _.-,-'- . , ,.:.::._'_ ._-- _ -- -- :~:- :~ -'{"_1 ' ' '- - - : - '. - ' .' ..__~.~ :~_'-' .:..- -::. '..: .,3'-' --.. :'--,.:..-j.. '=:._ :- .... ,_ - . . _. -- ._ /,,/~/)_ - . .~..... -'_ ~.'. :_.. .-- :' ; -. _ :-~'- _ .' - : :-': --:: '"' ' ' ~ - ': - '-- L ._ .' _. :_ .~__., ., "...; :;-.?_ · . 2 .-- : .. . : .. . ..'- . : ---- ~ · _ · /"~ .T,O, . : ..... !'"'- ....... --; .... . ' '.-" -7:' "7 .... ! : i.': ..... ..... -" EXXON USA PROPRIETARY .. 7"@ /z ~.3' 7"2:) ~ / z goo'N/ CALCULAT,]ON SHEET (5x5 GRID) . _ -.._ ._, _: ----;: __:.- ,:, .: .... : :_ _.- _ .1." -. ~' -;;. - -- I * _'5---~-_ -- .-' '--'- /. ::: ::-7-;'~ .:':: ~ '- -: - - - ~ - : '---L- · _ --:i':.!'i: :-/'~:-': ~:-: ...... -:._~_ ._:' _ .... ~.. _ _. _ :1 . _ · _ · 'TZ/,O . 0___ /,t ~ oo' /V l .. ~,~LCULATION SHEET ¢5x5 GRID) &.72' _ · . _ '- i 7 ~Tb - .i .... ' .j ...... : ........ .~__.: .__ L ........................ · · . rvvnkl ~lq~ pp~PP!FT6, RY 7"0_ I z6~:~' C~LCULA'I'ION SHfF:T ISx§ GRID) SUBJECT -_ - :_ _ .. --- . - . ._ · ~_... . _ . . .. ~ - .. . . _ _ _ . --2 - _ _ . _ _ . . ..... _.._~..~'~0~' ~_ 6 72/_ '- _ _ _ ~.. ........... __ .. - ....... - .~ . -_ . .~_ _ _ ._ . .. -- _: . . . . _ . ....... · _ --f ._. __ . . _ . _ . : .7 - . .- .... ....... .. - ... - . -_ _ ::_ _..-~: _- ..... -~ '. ~_ - . ; J~-: -_.~.-....-~ ; .-- I .- ' . _;. -._'.- - : 'm - .... -~ .. _ .. . :--;-;- -::~? :-- f~Zt;. :.-.~ :- :-~.' - ' - -- ' - -- .... .___--~;- .~ -.. ....... - ..... - -.'-- ..... ' ~, ~--': -:<:~-::: - ;~:', -' ..... . .,;~-"~.-5.~ -- - :-----c "} ..-'::.. 7'- '- ' -.'-.. :. x'-.~-~-.-.T~7. ,:~- -- ~.: · ,~-_=~,;'; . :: _. .... . .... - . - . I ~ {._..'_;_: : :~_-~ -: F: -.:'- _.- ' . . .-- ... -_ _ - _- _~'.: - 7- _ - _ - . - 'T -: - z _ __ _ :: ._- .... -.:- -..~_ --- . · .. :_ - . .. . -_ - -.-_ - !~ : _::-:.-~.--:-:' - - - .... _-'-_--"' '"-'.-: '-'- ' -' - ._ = _- . _ __- . . -_ '~- . _ _ _ _ _ . - - _ - - .- _. - _ . - . c . . _ ._ _ . . : _ . . _ _ . _ -.. . _ .... ~ . . _ . ..... .. - -~.- ~ . ~ ~ _ .- . - . . ._ _ _ - . _ ~_ _ .. _ _ :- _-' '-_ -:-- - _ - . - - _ --._- - _ -- _ . _ _ ~ -- _ . _ _ _ : .. _ - _ ._ . _. - ...... .... _ ~_ ...... ..... ~- . _ - ACID AND SQUEEZE CEMENT SUPPLEMENT Exxon Duck Island Unit #1 CONFIDENTIAL 29. ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 11,730' - 11,734' 11,533' - 11,538' 11,530' - 11,535' 11,502' - 11,523' 11,188' - 11,190' 11,188' - 11,203' 11,208' - 11,219' 11,224' - 11,234' 11,071' - 11,081' 11,458' - 11,482' Attempted block squeeze. Could not pump into perfs w/3500 psi. Block squeeze w/40 barrels class G cement. Block squeeze w/37 barrels class G cement. Squeeze w/200 sacks class G cement. Squeeze w/98 sacks class G cement. Squeeze w/122 sacks class G cement. Squeeze w/73 sacks class G cement. Squeeze w/167 sacks class G cement. CORE DATA CONFIDENTIAL Exxon - Duck Island Unit No. 1 Core #1 11,044'-11,059'. Rec.~ 7' sandstone, lt. bm, f-cg, fair to good porosity, with oil staining; 8' shale, it gry, sdy. Core #2 11,059'-11,089'. Rec. 27' sandstone & conglomerate, it to med bm, m-vcg, good porosity with oil staining. Core #3 11,089'-11,146'. Rec. 46' sandstone & conglomerate, it to med bm, f-cg, good porosity with oil staining. 10' siltstone, it brn, very poor porosity with oil staining. Core #4 Core #5 11,530'-11,567'. Rec. 10' sandstone & conglomerate, dk gry to med bm, m-cg, fair to good porosity with oil staining. 4' siltstone, brn. 10' shale, med gry. 13' coal. 11,570'-11,627'. Rec. 30,sandstone & conglomerate, med to dk gry, vf-mg, fair porosity with spotty oil staining. 2' coal. Core #6 11,683'-11,739'. Rec. 44' sandstone & conglomerate, med 2o dk gry, f-mg, fair to good porosity with oil staining. 10' siltstone, dk gry, very poor porosity with oil/tar staining. 2' coal. Core #7 11,740'-11,766'. Rec. 20' sandstone & conglomerate, med to dk brn, vf-mg, good porosity with spotty oil staining. 1' siltstone, med to it gry, hard, no show. 1' coal. Core #8 11,766'-11,809'. Rec. 37' sandstone, med gry to bm, vf-cg, good porosity with very spotty oil staining. 2' claystone, dk gry to blk. Core #9 11,809'-11,869'. Rec. 54' sandstone, med to dk gry, vf-cg, good porosity with trace of oil staining. 7' claystone, med to dk gry. Core #10 11,869'-11,927'. Rec. 33' sandstone, it gry to bm, f-mg, poor to fair porosity with no to a trace of oil staining. 25' siltstone, dk gry to black, trace oil staining. Core #11 12,770'-12,800'. Rec. 30' sh, dk gry, no shows. 36 ii .i 6 j ~_.?sland BE/? UFOFF T Duck Island 18 ! 32 J I t I J PROPO SED j 34 35 ~o J BOTTOM HOLE 8oo' ----~ j~?CATION i ! 9 8 ', -'i~ PROPOSED i I~EXXON No.I DUCK ISLAND UNIT .j/,/~ LAT. = 70° 19'00.13 ' 8o0'.-~,,~) J-~-- LONG. = 147°5 '46.83 ' ~-J~-l-- ' X= 270,,85 ' Y :5,968,919 17 "'-. !6 2N. CERTIFICATE OF SURVEYOR I hereby certify that lam properly registered and licensed to practice land surveying in the State of Alaska and that this plat represents a Jocation survey made by me or under my supervision, and that all dimensions and other details are correct. Date Surveyor NOTE -- .i.~LOCATtON NOT FIELD SURVEYED AS OF THIS DATE - OCT. 20, 1977. Exhibit "A" ii PROPOSED EXXON N0.1 DUCK ISLAND UNIT L oco fed ~n SE I/4 PROTRACTED SEC 8~ T._l_! Surveyed for EXXONCOMPANY U.S.A. Surveyed by F.M. LINDSEY ASSOC, LAND ~ HYDROGRAPHIC ~!IRVFYOR~ 2502 We,;t North~.r~ I ;clhf~ No,~tew~r't Anchorage I i i i 11 _r . _ _ . Imtlats Date ' , '"N Prepared By . ., ......................... o 1 ....... ~~ l Eastman ~ Whipstock l~~ A PETROLANE COM~ REPORT of SUB-SURFACE DIREC TIONA L SURVEY EXXON COMPANY DUCK I ST,AND WELL NAME PRUDHOE BAY. ALASKA LOCATION JOB NUMBER A179 G0141 SURVEY BY Jim'DeMonia TYPE OF SURVEY Gyroscopic CONFIDENTIAL DATE 1-29-79 OFFICE ALASKA , CO~qPL'ETION REPORT ........ GYRO$.~OP!C SURVEY RAD~U3 OF (CURVATURE METHOD-OF-~O'MPI~¥ATioN5 FEBRUARY 06 AND A550(iA~5 RgCORD OF 'SURVEY UI, Jlll lULl! I IFIL- ALL CALCULAY'I-ON~-P-ERFORMED BY I B M--ELECTRONiC COMPUTER TRUE DOG LEG MEAS. DNI'PT 'D~PYM ANGL~ D M VERYiCAL SUB .... DR'IFT DEPTH DEG, TO T A~-C1DDRD'I'NA TES 0 0 0 iO0 0 ~5 200 0 ~o 300 0 30 ~00 0 0 ~UU 0 1~ ~00 0 i5 700 0 30 SOO O 90 ~00 0 0 lO0o o o LLO0 0 15 lZO0 0 15 0,--00-'----~2'~;36 ......... t~-O-.OOE 99,99 ?IT63---N13.00w I 199,99 171'III63 'N 8,OOE 299,9B 27i¥62 ....... N38-;-OOW 3g~,98 37~62----N O,OOE 5~9.98 89V.97 87i,6i --N-'O~OE 999,97 1099.97 1199.97 ~00 O 15 13~9,97 i500 0 i5 i~99,97 1~00 0 ~5 i599,96 i700 0 45 i699.96 l~O0 0 65 i799e95 1900 0 65 i899.94 2000 O 2i00 0 65 g09~.~2 2200 O' 0 2~Uu 0 15 2600 1 30 2399.90 iDYA.bi NT~.OOw i~7i,~i S 2.00W i57i.60 i67i.60 SiS.00E i87i'58 $iO.OOE 207i,D6 528.00E ZA7i,56 N O.OOE 2z¥1,56 s16.0o~ 2371.56 2;39 N 1,1~ E 2,69 2---z;5 N 0.55 E i~58 N 0 0,28 N 0,73 E 0~7 'S i,06 E 2,25 S i.33 E 4.72 4,60 5 Z,6~ ~.58 5 2,79 6,93 $ ~.00 EXXON DUCK !SLAND Z G'Y R 0 S~P-I-~ SURVEY ALL -. 'RECC RD-UF-SURVE¥ CAI. CULATIO-NS-PE-~~D BY I B -g-E-~-ECT,~-O'N-~C TRUE ...... MEAS. DIT~FT VERTiCAE- D SUB ....... DRI'F'r SEA-- ....... ~DI'REC.. C g'--O 5"--'U- R--E"'-'$ ................... 5EVER--Z-TY ............. SECT D'Z-STANCE .................. A'N G L E------DEGZ IUO F T ................. D I 51,../C D ~ .... .... 2500 "2600 '' 2700 2800 2900 3000 ' 31oo 3200 ........ 3300 "'3~00 3600 ..... 3700 3800 3900 ~000 4200 "' u300 4400 4500 4600 .... ~TuO 4800 ~900 5000 5i00 5200 5300 1-3~TB~~I~'SI---N36,0OE I" 30 Z599,8~' 1 30 2 0 - '1' 30 3 15 ~ o 5 0 ~ ~0 ~ 0 10 ~5 12 0 13 ~5 ~6 30 Z9 0 ~6 0 '30 15 33 ~ 33 ~5 ~'~5 3~ 30 2T~/6-'-S 2699,80 2671 .~ .......N'53.--00 ~ IY;"~ N 2'899,7i Z87i,3~ N56,00~ g;56 N 2999,62 2971,26---N32,00E 7.51 N 3 298,69 ~ 27 o ~33 ...... NIS';~E ........... ~'~- N 3~97.29 ~468,9~ N 4.oow- 52.~ N ~076.~ 4048.19 N 2.OOw ~i67.'54 4i39JI'8 ...... N i.00W ~255,71 4~4A.ZO ~312,8~ N ~,OOW ~42D,42 ~397e06 N 1.OOE ~09eA7 ~592.~b 45b~e20 N O,DWW 4~75.82 4759,09 ~8~2.iZ ~i3,/& N 1.UUW 492~,~0 48~6,94 N O,OOW 202'.20 m 2m 3';~5 N 29 0 ~-77 N 396.56 N 50~,39 N 50i.76 N 6i7,i4 N 67Z,87 N 728,97 N 7~4,5Z N ~0.22 N 5,72 E 9,39 E i1,75 E 20.i7 g Z~ .~2 E 26 ~~ 28-.0i E Zu,Oi ~ 26~-E 25.15 -E ZZ.24 ~ i9.06 E -- 16.67 E -- i~ ,7i E 6;'~'"'-S--'"'6'2 3'6 ...... 56 r. 0';26!' .................. '2 ;95 '9-;~ 2'--N--85--29 ...... 53---E ......0';2'0'9 ................... C, 7~' IZ'iUS'-E-77 ..... 8--';3 E ....... O'i'50O ................. 2 ~"6'g ~'8'~0 N 66 9 Z Z-~~X"~ .......................... 7;53 1-67-i-25 -N- 5----~-3-'l-g--E- ....--2-;502 ............. 166,43 g02.7~+ N ~ il ii E 4.012 2C2;-2I 2 ~ 4 ;'O'3--N .... -'3--i 3 .... I~-E-- 3 i-OOB ........ 243,6 e i 3 · 30-~I-iUS--N----2--37 ..... II -E ....... 12,~5 E 12.B5 E i3.32 E 13,08 k. ii.87 ~ ~1,39 E 10,90 E ~,~7 ~ ~';-2b'~ ...... 290 ~42,f59 N g 8 5-- c 2,020 39~.76 N 1--51- 2Z E 0-;-95-6 396.5'~ 50b,56 N 1 2'8-49 P. 0.52..3 5'0'5';z11 5 ~Ti-gu-'N I-T5 --~F'-E .... ~ ......... 561 i 617i2~~-~~ ' E O · 397 517, 672.97 N o 58 12 E 0.~0o ~ 8 ~, '5~-~~-~' 9-"5'---~~ ........... 7 ~ & '; 5-~ EXXON DUCK ISLAND GYROSCOPIC SURVEY 'RECORD OF SURVEY ALL CALCU'LA¥iONS-I:rER-FORlq-~I--B M ELECTRONIC D[PYH ANGL~ D M TRUE --DOG LEG VERT i CAL " SUB- .... Dl:~I~l TO'TA'L--COORD iNA TE$ C--L--O--~--[g-]q E""-~ S~-~TE-t~"['%'Y- DEPTH SEA DiREC DISTANCE ANG[.iE ........ 'D-E~71-O~FT ............. DEG. D M 9400 '35' 0 5173.23 5900 ~6 30 5~77,73 6000 ~6 ~5 5657.99 6%'00 ~7 15 5737.89 6200 36 30 5817.8~ 6~00 ~6 ~5 5898.10 6900 ~6 30 6058.7~ ~600 ~800 ~? 0 6299,i2 6900 M7 0 6378.98 7000 7100 ~8 0 6~37.65 7200 38 30 6616.18 7300 7~00 38 0 677~.5i 7500 M~ ~0 ~852 7700 37 0 ?0~0,i~ 7800 37 0 ?090o0~ ?900 36 ~5 7170.0~ 8000 36 30 7290,29 8i00 35'~5 7331.06 82~0 35 0 · 7i 6902.35 N 2.00W 22i6,90 N 51~';87 N 2";OOW 897,17 N ~ZZ6.~i N~2,00W 9~9,02 N ' ~307,~7--N 2,00W 1013,41N ~BSB,~7'---N--2,00W 1072,16 N ~6B.98 N 2,OOW 11~I.~ N ~9~9.37~M--~f,OOW 1190;89 N 9709e49 N 1,00W 1~10,71N 5789.48 N 5949.99 N 0.00~ 1~90.01N 6030,'3-8 N'--1-T00W 1549T~9 N 6110,64 N 0,00~ lbog.l~ N 6~90.76 N 2.0oW ~b~8,96 N 6270.7~'-'~~~I728.93 N 6430.22 N 2,00W 18a9,57 N 6587.82 ~-'~.OOW 1972;~6 N 24,36 W ~b.35 N ~.OUW 203~.2~ N 2~,b8 W 39.43 W --- 4i.59 W 9,98 E 3196 E 1,92 E 0,~2 W" 2.19 W 3.74 W 4;79 W '' 897.i9 N 101-3%-4-I--N .... 0 .... 10'72.I6--g U .... 0 .... 2'3 W 1131,43 N '0 -~'--3-9 W lI-g-0.--89-N ...... 0-I-0-'~g--W 1250TS~"-N ........ 0- I-3 .... I0-W ...... -0.-2'5-0 ............... 1250; 5.84 6-;.-88 W T,92 W 8.~5 W 8,96 W 9.z+8 W i2.62 W 14.72 W -'- 16.84 W 20.04 W l'~.T2 fC--0--IS--'f9' W ........ 0.5 O0 .............. ~T72 .... ~ -0 .... i7 .... I5 W U;75U ............ 1370;70 1 ~ 30 ;3'8- Nq-I9 ........ 3-"W ......0';250 ...................... I ~3 0,3'5 1609 i'I7--~--U0 'TW-W ....... NS]7 ............... 166g~~2I' ~1 W 1.I97-- ~9TI-4-' N 0-28 ...... I'W-'W ........... U;0 00 ........... 18~9.65 N '0' 3'I~8 W 0.500 I~-IU;'~-'- N ..... 0 3~ ....... 3--"~ .... ~O8 ........... 1972; 61'-N- ~- -~2--2T ~--~5~ ........ Z034,42 -N~--~8--2 o ~ 0.500 ~57i 56'-N ..... 1 ....... 2-50--W ........... 2;00~- 21 22i9.29 N i 4 ~l 0.7'~ 698i.82 N 2.00W--2279.5~ N ~,7i W 706i.68 N2,00W 2339.7i N ~5.8i W '~1~1.68 N 2,OOW 2399.~8 Fi 47.90 w 72~1.9~ N 2.00W 2459,~0 N 49.98 W ?302.70 N~'~18.22 N 52.04 W 7384.24 N 3.00W 2576.05 N 54.57 W 22 79T9'8 N .... I- .... 5-'5;''~ W ...... -0~TS~ ....... 2279 i 5~ 2 ~-~-O~l'5--qq---T 7-'-1-8-~ U-;Z;X;U ............ 233 Z~+00.-I5 N I---F--~7 W 0.250 2459.8I N 1 9-'~~ ..... OV25U 2~8~5~ .... I-Il ........ 2 ..... ~ ......0;'750 ................ 25 2575,63 N I"12 48 W 0.819 EXXON DUCK !SLAND 1 GYROSCOP!C SURVEY FEBRUARY 06~1979 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY ! B M ELECTRONIC COMPUTER. ...... MEAS' IDRIFT ...... DEPTH ANGLE , , D M TRUE VERTICAL 5FJB--~R]F1 TOT--AE-'COORDtNAYE,~ DEPTH SEA DIREC DEG. D M ,,5 DOG L E'G SEVERTTY- 8300 34 15 7494,89 840'0 34'15 7577;55 8500 34 0 7660.33 8600 3~ 15 7743.11 8700 34 4D 7825,52 8800 3~ 45 7907,'69 8900 35 0 7989.73 9000 34 45 8071.77' 7466,53 N 3,00W 2632,79 N 75~9';'1'9 N 3,00W 2689,00 N 7631.97 N 3.00W 27~5.0£ N 7714.75 N 3.00W 2801,04 N 7797,16 N 3.00W 2857.61 N 7879.33 N 3.0OW 2914.53 N 7961.37 N-3eOOW 2971'63 .... N 80~3.41 N 4.00W 3028.70 N 57,54 W 263::5%~2 N 60;4'8 ...... W' 63.42 W 66,36 W '69.3Z W' 72,30 W 75."'30 W 78.79 W 15---7 W 0.75U 26817~6~ N I 1'7- I9 W 0.000 2745.75 N i 19 25 W 0.250 2801.83-N "l 21 25 W ~50 Z~8,~5 N 1 g~ 23 W 0,~00 '2'~2'. 5'8 N--~7 ..... ~W--~~~ 30"z9~72 N 1 ~Z4~ W" 0.410 9100 34 45 8153 ' 9200'33 30 8236 .... 9300 32 30 8320 9400 32 45 840~ 9900 ~2 0 8489 9700 9800 MO 30 8746 ~0000 28 30 ' 89Z0 lOlO0 Z? 30 9008 ~ozuo z6 ~5 ~0~7 - lO300 26 30 9187 10400 26 0 9Z76 ' iu~uu ~6 ~5 9366 ' lO~oo 2~ 0 9456 10700 Z0900 -ZZOOO 31 .45 9811 .93 8125.57---N 5.00W 3085'52 .71 8208,35 N 4.00W 3141,~5 · 58 8292,22 N'4.00W 3195'78 .80 8376'4~ -N--5-;'OOW ~249,53 ,26 ~460e90 N ~.OOW 3302.91 .~ ~b,o5 N ~,OOW 3355,Z1 ,47 ,~0 ~O~,b4 N 3,00W 3506.94 8892,i0---~-2'00W 3~'5-i37 8980,39---N i,OOW 360Z~30 915~.79 N leOOk 36~2.?0 9248.48 N 1,00~ 3736.93 9~3u.07 N 1.00E 3~i,3~ 95i~,85 N Z,OUE 3866.83 ¥609.11 N 3.00E 3909.~3 9697,29--N 7.00E 3956.78 9783.22 N ~67.4~ N 6,OOE N - 8'3.26 W N 87.66 w N 91.46 W N 95'69 W N 99,89 W N 10~.55 w N iO~,b8 W N ii0.22 w N 113.7i w N ii5,82 w N 117.06 W 30 ~ 6-T6-5--N---i-'32'-i~4--~ .........U JST0-- ........... 3-0'85 ~' 45 ...... 3 Iai ;~ 3~ ---3i95'JTC ......... 3'30'7. ~. 8'2 ----33 ......... 3692 ' 6 ( N 116,29 W N 113.65 W N 111,7~ W N 107,67 W N 100.55 W N 9Z.~9 W ~825e7~ N ~858.~0 N 3911,43 N 3958.24 N 4008.67--~ ~061.78 N ........ 373'6 1 4~ ~9 w 0,750 3781-;ZZ i 43- 6 w 1,750 3-82 i ~+1 i W-- 0.529 ......... 386'6;7: 1 35 15 W 2,010 1 3~'~I w 3.~ 1 18 22 W 1.775 ~'U6UT6~ , EXXON DUCK GYROSCOPIC SURVEY RECORD OF SURVEY ALL CALCULATIONS PENFOR~.IEO BY ! t5 N ELECTRONIC COMPUTER 11 El nu [I~ITI 11 _lllL LII i TRUE MEAS'," DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB SEA DIREC DEG, TOTAL"COORD INAT~$ DOG LEG C L 0 ,$ O-'-R-'--~--,~ ........... -~-~'~-~'-Ty .............. ~S~'~''r ........ l1200-~a 15 9978,83 9950.--47 N 7.00E 4115'98 'N "11300 '35 0 i0061.11 10032~75 N 9~OOE ' 4'172.25 N 'I1'400 34 30 10143.28 10114,92 N 5.00E 4228,81 N ........ 11500 95 0"10225.44 10197;O~---N-5.00E 4285.59 N ~1"16'00"35 15 10307.23 10278,87 N 4.00E ~342.95 N "11700 37 15 10387,87 10359.51 N 4,00E 4401;94 N 118'00'37 0 10467,60 10439e24 N 6,00E 4~62.06 N' 85.31 W 77.40 W 70.46 W 65,49 W 60,98 W 56.85 W 51,59 W ~'1'72,97 N ..... i 3-16 W 4229,~0 N 0 57 16 W ~286.09 N 0 5~---~ W ~343;38 N 0'~B--16 W 44"02",'30 N 'o ~4 24 W 446~";~6--N----O-~T'~5 w 0.416 4~42.90 2 · 0 0-0 ........... 0 · 7-6-6 ........... 11900 37 30 10547.20 10518,84 N 4.00E 4522,35 N --12000 D5 0 10627.84 10599,48 N 4.00E 4581,34 N '"12100 ~1 0 10711.~9 10683.33 -~ 9.OOE 4635~42 N ' 1'Z200'30 0 10797,85 10769.49 N 9,00~ 468~,~5 N ......... 12~U0 29 0 10884.89 10856.53 N 8,0OE 4?34.25 N "lZ~O0 Z8 0 1o~?z,77 10944e41----~ 6eOO~ '~78i.6i N ' 12~OO E9 30 11060.~ 11032,08 N 9.OO~ 4829.29 N 1269~ ~0 i5 11ZZ9,53 llZOi,17 N 6,00~ ~9Z5.58 N 46,32 W 4522"59 N 0 35 12 W 0,89~ 42.19 W 4581,53-'N----0-]-%-~3~ W 2.500 36,03 W 4635,56-N-"-U--2'~ ~' W 4'.21~ 28,09 W 468b.63 N 0 20 36 W ..... 20.81 W 4734'30 N 0---%~ .... 6 W 1.027 i5,00 W ~781,6~ N 0 10---g7~- 1.093 ~,~ W ' ~829,~0 N 0 '& 12 W 1.667 3,95 E ~925,5'8 N z~925; 5'a I~.~OO 30 i~ ,IL/ G,OOE BOTTOM HOLE CLOSURE 4925.58 FEET AT N 0 2 aD E EXXON DUCK ISLAND 1 GYROSCOPIC SURVEY SEA bi tNPtl Ii-I 11 MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH' SEA DIFFERENCE CORRECTION TOTAL COORDINATES 128 128. 100 228 228. 200 328 328. 300 ~28 428. 400 528 528. 500 628 628, 600 728 728, 700 82'8 828. 800 928 928, 900 1028 1028~ 1OOO 1128 1128' 1100 1228 1228. i200-- 13'28 1328' 1300 1~28 1~28. 1400 1528 1528, 1.500 1628 1628, 1600 172B 1728. 1700 1828 1828, 1800- 1928 1928. 1900 2028 2028, 2000 2128 2128, 2100 2228 2228, 2200 2328 2328' 2300 2~2~ 2~2B. 2~OO 2528 2528, 2500 272g 272~, 2B2~ 2B28. 2800 2929 2928, 2900 ~029 ~028, 3000 312g 3128, 3100 ~ZZ9 3228, 3200 3330 3328. 3300 3430 3428, 3~00 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o 0 0 0 0 0 o o 0 u 0 0 0 0 0 0 0 0,99 N 1,9'6 N 0'-i3 W 0,06 W 2,72 N 0,~5 W 2,97 N 0,~8 W 3,28 N 0,42 W 3,18 N 0,06 W 2,~7 N 0,16 W 1'81'N 0,19 2.03 N 0.32 E ............ 2'05 N 0~3-3---E 2.12 N 0.59'E 2.0'7 N i';'O2 E 2,51N i'~I~ E 2,68 N 0'73' E ........ 2.29 N 0,55-~ ....... 1,-2-1---M 0';56-~ 0,06'5 0.82 E i .... 1.33 S I~I4 E ......... 2,61 ~ ~,40-E 3,86 $ le78 E 4,92 S 2~41 E 4.59--5 2¥~-E ~,16 ~ 2e90 E -- 2.38 $ 6.-1~--E 0,~5 $ 7,96 Z,21N IUFUI 3.31N 12,~7 k ...... 5.09 N 14,85 8,95 N 17,--8'~ 14,8~ N 21,--I2 22'~3 N 24,30 31,70 N 26;-~'3 28.33 E ~2,94 N 3531 3528,' 3500 3 1 56.69 N 27.69 E EXXON DUCK ISLAND 1 GYROSCOPIC SURVEY FEBRUARY 06~1979 -'MEAsuRED' DEPTH AND OTHER DATA FOR 'EVERY ~V'EN :i. O0'F'EET OF ,SUB SEA DEPTH. t i UF_I't I TRUE MEASURED VERTICAL SUB MD'TVD VERTICAL DEPTH DEPTH SEA'DIFFERENCE CORRECTION TOTAL CO--(JRUIN~TES 39~2 3928, 3900 - 13 ~'0~8 4028. 4000 4157 4128. 4100 28 4268 4228, 4200' 40 4503 4428, ~400 75 4623 a528;-- 4500 . 4743 4628, 4600 114 4863 4728, 4700- 134 4983 4828, ~800- 154 9104 ~9Z8, ~900 ~224 ~028. 5O00 195 ~3~9 51ZUe 9100 ~67 5ZZ~, 9zoO 239 ~1 5~z8, ~oO 262 ~838 ~28. 5500 310 fi963 56Z8, 9600 33~ &088 57'28, 5700 359 62i3 58Z~, 5~00 6~8 5928. 5900 409 6~62 6028. 6000 433 65~ &lZ8, 6100 67il ~228, 6ZOO ~836 ~3z8. 6300 508 6~62 6~Z8, 6400 533 7088 6528. 6500 559 ?Zi~ b628, 6600 587 7~ o72~. 6700 7470 6828, 6800 7597 6928, 6900 668 ~723 7028, 7000 694 9 ' 12 16 19 19 20 20 zl 2O 21 /~.b6 hi 26.~g--E FIg,4i:N-------'2U.-9'O .... E 2~ 25 25 2~ 25 26 27 26 v35,82 N ~+,63 1007.96 N 2TIY'-E 1080.~3" N ll~,O~ N 2.90 1303 · 45--'N ~ 71'~ 1452,91 N --~i'2~ W 1526,89-N ~'8-~-5 ~601,20 N 9,$8 1675,~ N 10~~ 1750.9~ N 13e38 W 1826,50 N 16.03 W ~903,34 N ~9,5~ W 1981,77 N 25,01 W ZO6Oe~Z N ~O,~O W Z138,~3 N 38F~ 2217.06 N 41,~2 W 2293.25 N ~.18 W .EXXON DUCK ISLAND 1 GYROSCOPIC SURVEY EE.BRUARY__06.,1919 MEASURED' DEPTH AND 'OTHER DATA FOR TRUE EVERY EVEN' 100 FEET OF SUB 5gA DEPTH, CO i in,[ iTiAl I~11 IULi~I I II-lL MEASURED VERTICAL' SUB DEPTH DEPTH"' ,.SEA MD-TVD DIFFERENCE VERT"I CAL CORRECTION TOTAL COORDINATES 7848 7128, 7973' 7228, 8097 7328, 8'219 74`28, '834O 7'.528' 8461 /628, 8582 7728, 8703 7828. 8825 7928, 89/+7 8028. 9069 8128, 7100 719 "720'0 7300 768 7/+00 790 7500 812 7600 832 7700 853 78OO 875 7900 896 8000 9t8 8100 940 9190 9309 9428 9663 ,,, 9779 9895 10009 1'"'0122 10234 ].0346 104`57 10'679 8228 8328 8428 8528 8628 8728 8828 8928 9028 9128 9228 9328 9~28 , 8200 961 , 8'300 980 , '8400 999 · 8500 1017 · 8600 1034 · 8700 1050 · 8800 1066 . 8900--10-80 . 9000 1093 . 9100 1105 . 9200 11'17 , 9300 1129 . ~400 1140 . 9500 ii5¢ lu~?o iu?O~ A102o 11139 11260 11382 11'503 9728. 9700 i27~ 9828, 9800 1191 '9928. 9900 12'10 10028, 10000 1231 10128· 10100 1253 10228, 10200 1275 25 25 2368'50 N 4-6.81 244,3,06 N 49,42 2516.26 N 51,97 22 20 "2 1 22 22 22 21 19 18 i7 16 ~6 14 13 12 12 12 i0 2586.92 N 55.13 W 2655,28 N 58'72 W 2723,21 N 62~-28 W 2790-~--9-~ N ~5.83 W 2859,31 N 69.41 W 2928,77 N 73,05 W 2998.50 N 75.82 W 3067.84 N 81',75 W 3135.91 N 87-~,~7 W 3200.-6'0-N 91 .-80 W 3264.56 N 96,97 W 3327 . 11 -N ..... I 0'T;-58- W 338'7.58 N I05J-63- W 3~46.4~ N 109.33 W 3504.31 N 113;-'~ W 3559.65 N 115.~ W 36i2.43 N 117.21 W 3663.17 N 117.~0 W 3713.1~ N 11~70 W 3762,10 N 115,85 W 3858.i0 N--- 3905.32 N "i~2,0i W 39 D 8 · Z6--N-----~O~-~g-W 17 19 21 22 22 4017.73 N 95;-94 4`082.13 N 89,65 4149.65 N 80,82 4218,58 N 7i,-;-4'2 4287.31N 65,34 11626 10328· 10300 1297 22 /+358.02 N 59.92 W 11751 11876 10428,. 10400 1322 ,, 10528. 10500 1347 25 25 4432.55 N 54,44 W 4507,80 N 47,40 W · ,, GYROSCOPIC SURVEY FEBRUARY 06,1979 "INTERPOLATED VALUE.5 FOE EVEN zOo0 FEET OF MEASURED DEPTH,, MEASURED " VERTICAL SUB DEPTH DEPTH SEA TOTAL COORDINATE5 lO00 ~'~9 e 97Y, -2*03 N 0,32 2000 1999e' i971, 3,53'5 - 1,65 3000 2999e' 2971e 7e51 N 17eO1 ~000 3983, 3954, 166,42 N 16,67 5000 4~42. ~813, ~72.87 N 11.39 6000 5657;' "5629, 1250,54 N' 4,79 7000 6~58, '6430, 1849,57 N 16,84 8000 72~0,' 7Z21, 2459,30 N 49,98 9000 807Z," :':8043, 30~8,7~ N ' 78,79 .... :. ........... 10000 8920, ' 8892, 3555,37 N '115,82 11000 981~," 9-783, ~007,40 N 100,55 ..... 12000 10627, 10599, 4581,34 N 42,19 · EXXON DUCK ISLAND GYROSCOPIC SURVEY FEBRUARY 06~1979 MEASURED DEPTH AND OTM'ER DATA'FOR EVERY EVEN iO0'FEET OF SUB SEA DEPTH, TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA IDIFFERENCE CORRECTION TOTAL COORDINATE5 12001 10628, 10600 '1372 29 ~581,69 N ~2.17'W ~2119 10728, '10700 13'90 18 ~'G45,06 N 12235 108'28' 10800 1406 16 4702.75 N' 1'2350 1092'8, 10900 1~21 15 4757,89 N 12~63 11028, 1i000 'i~3~ 13 4811,42 N 12578 11128, 11100 1449 15 4867,46 N 12694 11228, 11200~ 1~65 '16 4924,90 N 34,50 25~4-2W ~7,70 11~35 '~,08 3,87 ..... EXXON DUCK ISLAND No.I SCALE I"= I000' ,JAN. $1, 1979 GYROSCOPIC. SURVEY 112oo 10800 10400 ..................................................... I0000.? 9200 .................... 8800 .......... 8400 .......... 8000 .... 7600. -' -: - 6800- TVD: 11230' TMD: 12695; ............... CONFIDENTIAL ALL DEPTHS SHOWN 5600. 4800 4400' ="~eoo. 400 800 1200 1600 2400 ~200 :5600 · - : ........ 2000 2800 . EXXON _ . . ........... DUCK ISLAND No. I SCALE I": ,OO0' CONFIDENTIAL ....... dAN. :31, 1979 GYROSCOPIC SURVEY _ ALL DEPTHS SHOWN . . ARE ~T.VD 4400 _. . · _ . 4800 8400 96OO l~rm No. STATE ALASKA OIL. AND GAS CONSERVATION COMMll-I'EE ~ONTHLY ~EPORT O~ D~JLLI~G A~D WORgOVER OPERAT,'O~$ O,L ;--'q (;"~' ,~ Wildcat WXLL ~ WELL OT~IE~ 2. NA2~[E OF OP~[P~I~TOit Exxon ~rporat ion '~. ,~D~'~ESS OF OPhiR Pouch ¢~01, ~chor~e, Alas~ 99~02 SUBMrT IN I)L?LIC~TE 71.'%,1-~[ 1N'L"J.'IER. ICAJ,., CODE 50-029-20280 ~..~ s'~ DZS:O~.,~OX ADL 47502 LOCATION OF WELL Surface: 700' NSL & 800' WEL of Sec. 8, TllN-R17E, UPM North Slope, Alaska BKL (Proposed): 500' NSL & 800' WEL of Sec 5, TllN-R1ZE, UPM, North Slope, Alaska Sec. 5, TllN, R17E, UPM 12 Pt~hMlT NO 78-68 13, RF.,~O.~.T TOTAL D~ AT ~D OF MON~H. CH~NG~ IN HOLE SIZE. CA~ING AN~ C~IF~TING JOBS INCLUDING SET ~%~ VOL~ L'S~. F~OP~TIONS. ~STS ~ ~SUL~ FISHING JO~ JL~'K LN ~1o~ AND S1DE-~.ACi(ED HOLE &N'D kN'Y O~R SIGNIFIC~T ~G~ ~ ~O~ CONDITIONS After cleaning out c~sing ~th a 5-3/4" ~11 ~d cas~g scraper, a CI~ was set at 11,52~'. Perforated w/2 spf l~,_~g~'rll,523' and set ~ B~er Model F packer at 11,490'. ~ conventional DST using a nitroge~cushion. ~ened tool for 10 ~n IF.. Closed for O0 min ISI. Reopened for final flow. Fluid s~faced in 43 min. After 3 bbls recovery the s~fgce lines plugged and killed the well. Reversed out 57 bbls of he~ %m~y oil (t~ 7o ~I ~ ~0~, oil 1¢. 5° ~I ~ ~0~). Set c~ent retainer at 11,242' ~d squeezed ~rfs 11,502' -11,523 ' with 200 sx ~t. Perforated w/4 spf 11,188' -11,190' and set a c~nt retainer at 11,085'. Stag into retainer and block :~ueezed with 98 sx c~. ~illed out retainer ~d ce~nt ~d clewed out hole to 11,242'. Perforat~ w/2 spf 11,188'-119203'; %%,~~11~'; 1~~~' ~d set a ~ker packer at 11,095'. Att~pte~~'f~'~'i D~ ~'S~hg-~- nitrog~ ~h{Jn. No test ~cause perforat~ tail pipe plugged ~th ce~nt. Laid do~ D~ t~l and r~ a conventional production test using a 41 bbl diesel ~d a 13 bbl nitrogen cushion. ~ened well to flow for 9 ho~s. ~ a ~~ stabilize~~t the well flow~ at ~ averse rate of ~650 ~ with ~ .... ' ~'~ ' '- ' ' 09 ' a ~g o~ ~~~ ~n ~2 ~s got pres~e build up. Set cemnt ret~'11, 3 ~d sque~d perfs from ~,188-11,23A' w/122 sx ~t. ~ cased hole FIT at 11,066'. ~eovered ~. ~ erg, A00 ee condensate ~d 300 ee mud, Pergorated w/~ ~g 1~, 071'-1~, 081'. ~elded not to test inte~al so a c~nt retainer ms set at 11,~'. Stmg into retainer ~d squeezed ~IT hole at ~,~6' ~d perfs ~,07~'-~1,08~' wlth 73 ~ em. ~llled out/3 c~ent retainers and ~ packer in the ~5/8" csg and ¢~11~ out e~nt in the 7" liner to the top of the packer at 11,~90'. Perforated w/A sp~ ~~ ,1}_ 482 '. ~d set a BAer p~ker at 11,422'. hna conventional D~ using a nitrogen cushion. ~ened t~l ~or 7 mln I~. Closed for 75 mln ISI. R~pened got ~ A ho~ 9 mln gina1 ~low. ~ing a~:~ the well ~lowed at an aver~e rate of 1900_~PD ,wlth ~~~,.3,~.~~h~. Took 6 ~ 15 min SIP. Kllled well. Set 9-5/8" retain~"~¢8'. Stag ~to retainer ~d squeezed per~oration with 167 sx ~t ~d ~ed 3 sx on top o~ retalner. ~t 9-5/8" csg at 2A00' and pulled out of hole. Placed a 250 viscosity gel p111 from 2296' to 2390'. Set a 60 sx c~ plug from 2213'-22~'. Set ~3-3/8" CIBP at 2200'. Dlsplaoed ~d in ~3-3/8" esg wlth 9.8 ppg calelm ehlorlde wager ~d set a pem~rosg e~mn~ pIug fr~ 90' to 150'. Installed bi~ flange on 'A' seetlon. ~spended we11 at ~ ho~s 3/29/79. CONFIDENTIAL m ~~~ .. ~= ~al~tion ~~er ~ April 12, 1979 oil/~d 9os~onmervat~on commt~ee by t~e !~ of the $u~c~din9 month, unl~ nth~rw;~ d;~cted, E ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 907/276-4552 April 6, 1979 Suspension Procedure Duck Island Unit No. 1 Mr. L. C. Smith Chief Petroleum Engineer Department of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Smith: Attached for your information and files is Sundry Notice providing the suspension procedure for the Duck Island Unit No. 1 well. Messrs. R. L. Longstreet and J. B. Willis of Exxon's Anchorage office discussed this procedure with you on March 23, 1979 at which time you provided verbal approval of the procedure. Although duplicate filing is all that you require, we have included three copies of the notice so that you may return to us a signed copy for our files. Very truly yours, RGD:jrh Attachments 295-600-112 (A20) cc: R. L. Longstreet R. K. Riddle A DIVISION OF EXXON CORPORATION Form I ~.~403 REV. 1-10o73 Sui3ml t "1 ntentlons°° In T~'lpllcate & "Subsequent Reports" in Dupltca[e STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE .SUNDRY NOTICES AND REPORTS ON WELLS (Do not u~e this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) 5. APl NUMERICAL CODE 50-029-20280 LEASE DESIGNATION AND SERIAL NO. ADL 47502 7. IF INDIAN, ALLOTTEE OR TRIBE NAME O,L r-] GAS ~] Wildcat WELL I.-J WELL L~J OTHER NAMEOF OPERATOR 8. UNIT, FARM OR LEASE NAME Exxon Corporation Duck Island Unit ADDRESS OF OPERATOR P.O. Box 2180; Houston, TX 77001 LOCATION OF WELL Atsurface 700 ' NSL & 800 ' TllN, R17E, UPM e WEL of Sec. 8, 13. ELEVATIONS (Show whether DF, RT, GR, et~) 3 foot water depth at surface location Check Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO.' 9. WELL NO. No. I 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., T.. R., M.. (BOTTOM HOLE OBJECTIVE) Sec. 5, TllN, R17E, UPM 12. PERMIT NO. 78-68 ~)ort, or Other Data SUBSEr~UENT REPORT OF: TEST WATER SHUT-OFF L------ FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) Suspend PULL OR ALTER CASING L.-.J MULTIPLE COMPLETE ABANDON* CHANGE PLANS WATER SHUT-OFF FRACTURE TREATMENT SHOOTING OR ACIDIZING (Other) REPAIRING WELL ALTERING CASING ABANDONMENT* {NOTE-' Report results of multiple coml31etion on Well Com01~tlon or Recompletion Report an~l Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIO:~IS (Clearly state all i;)ertlnent ~etall~, anc$ give pertinent dates, including estimated date of · starting any proposed work. Reason for suspension - Well suspended for possible re-entry. Suspension plugging procedure as described in attachment hereto. . :,':,;- ";Il · ! 16. I hereby certify that the foregoing ts true and correct SIGNED~~i~ TITLE Drilling Manager {Tt315 space for State office use~ . CONDITIONS OF APPROVAL, IF ANY: TITLE ~ : :. - See Instructions On Rever~e Side Copy' Re','urned SUSPENSION PROCEDURE DUCK ISLAND UNIT NO. 1 This procedure begins after the test string has been pulled following the last test. Trip in hole with 9-5/8" casing scraper on drill pipe to 11,110 feet. Circulate bottoms-up and pull out of hole. Pick up Halliburton EZ Drill SV cement retainer for 9-5/8" 43.5 ppf and trip in hole.on drill pipe. Run Halliburton latch-in collar 1 stand above retainer. After squeeze, the drill pipe will contain approximately 0.7 bbl of cement, which will fill approximately 9 feet of casing above the ~etainer. Set packer at 11,000 feet, wireline measurement. Packer must be at least 50 feet above highest perforation. 4~ Pull out of retainer and circulate displacement of drill pipe (82 bbi). Prepare to mix 35 bbl class G cement (15.8 ppg) in recir- culating blender as follows: 170 sks Class G cement (yield 1.15 ft3/sk) 24.2 bbl (850 gal) fresh water 160 lbs (1.0%) CFR 2 48.0 lbs (0.3%) Halad 22A 16,0 lbs (0.1%) HR7 (5:20 TT @ 220°F BHST)' 6, Pump the following into the workstring: 15 bbl fresh water 35 bbl cement (mix and pump above slurry) insert latch in wiper plug 3 bbl fresh water 28 bbl 9.6 ppg mud Sta~ into retainer 50 bbl 9.6 ppg mud Squeeze the perforations using the above cement. Do not exceed 5000 psi. Suspension Procedure Duck Island Unit NOo 1 Page Two If squeeze pressure is achieved before plug is latched in, pick up 9 ft. above retainer and reverse out excess cem~ent~.~e~in'q~me~ plug above retainer with tOp ~a~t'~/- 10991 ft EL. --~ If squeeze pressure is not reached by time plug latches in, pick up 9 ft, pressure up drill pipe to .... Sh~ar-~~verse out, leaving cement plug at +/' 10~91 ft EL', ~ .... 9~~revefsing clean, pull out of hole. Inject all waste fluids on location down 9-5/8" x 13-3/8" ~asing annulus. Double-check all tanks to be sure all Waste fluids are injected. Pick up 9-5/8" casinq cutter on drill pipe and measure in hole to 2400 ft. Actuate mechanism and cut 9-5/8" casing. Record exact depth of casing top. Measure out of the hole. ~2. Unbolt "B" section from "A" section and 12 foot spool (see figure 3); remove secondary 9 5/8" casing seal and "B" section; and replace "B" section with 26" spool (see figure 4). Temporarily bolt in place. With 9 5/8" casing spear, latch onto 9 5/8" casing. At the same time, connect the BOP stack to the bails. Then, simultaneously lift the BOP stack and casing high enough ~o release and remove the casing hanger. Lower BOP stack and casing, nipple up BOP stack, and pull 9 5/8" casing out of hole (approximately 2400 feet). Casing fs 43.5 ppf, Soo95 grade. 14. Spot gel plug at 2300' (100' above top of 9 5/8" casing Stub) as follows: Mix 15 bbl gel pill to approximately 300 second vis- cosity using existing mud. This pill is to be mixed to the highest viscosity possible and still be , pumpable. Suspension Procedure Duck Island Unit No. 1 Page Three 15. 16. 17. 18. 19. 20. 21. b) TIH with open-ended drill pipe and plug catcher one stand above bottom to 2400' (top of 9 5/8" casing stub). c) Establish circulation, pump 15 bbl gel pill and displace with 17.1 bbl of mud. Do not overdisplace. Slowly pull up 100 feet. Prepare to mix 10 bbl cement plug in recirculating blender as follows: 60 sx Permafrost cement (15.0 ppg) 5.0 bbl (210 gallons) fresh water Thickening time = 7 hr 15 min. Pump 10 bbl cement plug as follows: a) Drop bottom plug in drill pipe. b) Pump 10 bbl cement (mix and pump above slurry). c) Drop top plug. d) Displace cement with mud until top plug lands (approximately 16.4 bbl). e) Pull up 70 feet, pressure up drill pipe until plug catcher pins shear (approximately 2000 psi). f) Pull up 1 stand and reverse out. Pull out of hole. Pick up cast iron bridge plug for 13-3/8", 72 ppf casing and trip in hole on drill pipe to top of cement. Set bridge plug as far dOwn as possible but not higher than 2000 feet. Displace mud in casing with 9,8 ppg CaC12 as follows: a) Clean the rig suction pit and mix 340 bbl of 9.8 ppg CaCi2 by adding 28,900 lb High Test Flake Calcium Chloride (95% CaCl2) to 316 bbl fresh water. b) Heat the mixture to +70°F. Suspension Procedure Duck Island Unit No. 1 page Four ¢) With drill pipe at 2200', pump 50 bbl fresh water followed by 325 bbl CaCI2. Displace the CaCl2 with 16.3 bbl fresh water. Trip out of the hole to 150' keeping the hole full with ~aCl2. With ..... the drill pipe at 150' , mix and pump a 10 bbl perma- frost cement slurry (specified in Step 16) as follows: 3 bbl fresh water Pump 10 bbi cement Drop top plug D~splace cement with 1.1 bbl CaCl~ Trip out of.the h°l.e to 70' and reverse out. Trip out of the hole. After waiting on cement for 8 hours, run in the hole and tag the cement plug top. ~67 D~splace liquid in casing with 9.8 ppg CaC12. 27, Remove BOP stack, 12 foot spool, and 26" spool. Install 13 .... 5/8", 5000 psi blind flange on "A" section. Leave _~ide Qu~!et val~ues on "A" section. (See Figure $). ~GD ~ !m ~20~79 FIGURE 1 -~ WELLBORE SKETCH AFTER TES'£ING DUCK ISLAND UNIT NO. 1 · NOTES: 1. Ail depths are measured relative to rotary kelly bushing(ele~28') '. 2. Primary casing cement not shown 3o Test 4 deleted RGD 3/15/79 · 42" Conductor (70' long) 30" Grade B, 1" wall Conductor (80' long) · 20" 94 ppf, H40 Conductor @ 672' 13 3/8" 72 ppf, NS0 Casing @ 2720' 11066'-1 shot for Formation Test 11071'-11081" 4 spf (Test 7) 11188 '-11203' 2 spf (Test 6) .11208'-11219' 2 spf (Test 6) 11224 '-11'234' 2 spf (Test 6) Top of 7" Liner @ 11256' 9 5/8" 43.5 ppf, Soo95 Casing @ 113~1' Baker Model F-1 Packer @ 11422' 11458'-11482' 2 spf (Test 5B) · Baker Model F-1 Packer 811490' 11502'-11523' 2 spf (Test 5) .CaSt ~Iron Bridge Plug @ 11526' 11530~-11538' 4 spf (For squeeze) Cast Iron Bridge Plug @ 11578' Baker Model F-! Packer @ 11607' 11627'-11644' 4 suf (Test 3) Cast Iron Bridce Plug @ 11609' Baker Model F-i Packer @ 11675' ~ 11700'-11720' 4 spf (Test 2) Halliburton Cement Retainer @ 11724' 11730'-11734' (For saueeze) Cast Iron.Bridge Plug @ 11760' Baker Model F-I. Packer @ 11768' 11790'-11810' 4 spf (Test 1) 7" 29 ppf, Soo95 Liner @ 12663' 8 1/2" hole Total Depth @ ].2800' PROPOSED ~ ~LBORE SKETCH AFTER SUSPEN~ ON DUCK ISLAND UNIT NO. 1 NOTES: 1. All depths are measured relative to rOtary kelly bushing(elev=28') 2. Primary casing cement not shown 3. Test 4 deleted 9.8 ppg. !CaC12 [[ 42" Conductor ~70' long) 30" Grade B, 1" wall Conductor(80' long) Cement from 80' to 150' · 20" 94 ppf, H40 Conductor @ 672' Cast Iron Bridge Plug @ 2000'-2300' Cement from 2230-2300' TOp of 9 5/8" Casing @ 2400' 13 3/8" 72 ppf, N80 Casing @ 2720' HalliburtOn Cement Retainer @ 110.0.0' 11066'-1 shot for FormatiOn Test 11071 '-11081' 4 spf (Test 7) 11188 '-11203' 2 spf (Test 6) 11208 '-11219' 2 spf (Test 6) 11224 '-11234' '2 spf (Test 6) Top of 7" Liner @ 11256' RGD 3/15/79 o · 9 5/8" 43.5 ppf, Soo95 Casing @ 11391' Baker Model F'I Packe~ @ 11422' · 11458'-11482' 2 spf (Test 5B) Baker Model F-I Packer @114'90' 11502'-11523' 2 spf (Test 5) Cast Iron'"Bridge Plug @ 11526' ~ ' 11530'-11538' 4 spf (For scueeze) Cast Iron Bridge Plug @ 11578' Baker 5!odel F-1 Packer @ 11607' 11627'-116~4' 4 sDf (Test 3) Cast Iron Bridse Plu~ ~ 11609' Baker 5:odel F-i Packer @ 11675' 11700'-11720' 4.spf (Test 2) Halliburton Cement Retainer @ 11724' 11730'-11734' .(For £cueeze) Cast Iron Bridge Plug @ 11760' Baker Model F-1 Packer @ 11765' 11790'-11810' 4 spf (Test 1) 7" 29 ppf, Soo95 Liner @ 12663' 8 1/2" hole Total Depth @ 12800' 15~ -8" See note belay =bout kill line 14 ' -10" 15'-8" 2" I0" M IN. I~IOTE' One kill line fo be Connected · to rig pumps .end one to be connected to line at NE edge ef island. BOP and WELLHEAD ASSE~-~r-LY BEFORE PULLING 9 5/8" CA .NG DUCK ISLAND UNIT NO. 1 BASE OF ROTARY BEAMS ANNULAR TYPE PREVENTOR RAM TYPE PREVENTOR RAM TYPE PREVENTOR _t 26" 12'- O" RAM TYPE PREVENTOR TOP OF CELLAR GRATING SPOOL B Section 13-3/8" WELLHEAD SEA FLOOR , ,,CELLAR WALL 9 5/8" CASI'N~ , '"'": 13-3/8" '""- 20" CON~)UCTO~" BOP and WELLHEAD ASSE?--,LY AFTER PULLING 9 5/8" C~._£NG DUCK ISLAND UNIT NO. 1 BASE OF ROTARY BEAMS 15'-8" See note below olx~f kill line 14'-10" 15'-8" NOTE' One kill llne fo be connected lo rig pumps and one to be connected to line at NE edge of island. 12'- O" SPOOL ANNULAR TYPE PREVENTOR RAM TYPE' PREVENTOR RAM TYPE PREVENTOR -CELLAR WALL RAM TYPE PREVENTOR TOP OF CELLAR GRATING SEA FLOOR ,, SPOOL ,, , t 13-3/8" WELLHEAD 1'-9" 13-3/8" CASING 20" CONDUCTOR 30" CONDUCTOR ~"]:GURP. 5 SUSPENSION SKETCH SHOWING LOCATION OF WELLHEADS RELATIVE TO SEA FLOOR DUCK ISLAND UNIT No.I 15'-6" 4 'i8" ISLAND SURFACE LEVEL WATER LEVEL SEA FLOOR R WALL WELLHEAD AND COMPANION, FLANGE ~- - 13-3/8" CASING "20" CC~'4DUCTOR '- 30" C0NDUCTOR COMPANY, $.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 907/276--4552 March 30, 1979 Alaska Department of Environmental Conservation P. O. B°x 1601 Fairbanks, AK 99707 Attention: Mr. Doug Lowery Gentlemen: A crUde oil spill occurred at Exxon's Duck Island Un~l drill- site location at 05:00 AST on March 24,~. Pursuant to 18 AAC 75.100 under authority of AS 46.03.020 (10) (A) and AS 46.03.755, this letter constitutes written confirmation of the telephone report made by Mr. J. F. Greve to your answering service at 09:50 AST on March 24, 1979. The information'required by 18 AAC 75.110 follows: Date and time of discharge: March 24, 1979 at 05:00 AST. · Location of the discharge: Flare pit on the Duck Island Unit #1 drillsite. Section 8, TllN, R17E, UM. 3. Persons causing or responsible for discharge: None. · Type.and amount of discharge: Approximately five gallons of crude oil. · Cause of discharge: During production testing opera- tions, a carryover into the flare scrubber caused a discharge of crude oil through the flare line into the flare pit. · Environmental damage: None.~ 100% of spilled fluid was recovered. 7.. Cleanup actions undertaken: Spilled fluid was picked up with absorbent material from the.~pond Of water in the flare Pit. Contaminated water'was recovered.~ith a vacuum truck ~" .......... ~ A DiViSION OF EXXON Alaska Department'of Environmental Conservation Page Two · Location, method, and date' of disposal of discharge and Cleanup material: Absorbent material will be incinerated at the Duck Island drillsite. Contaminated water will be injected into the wellbore annulus at a later date. ~ Action taken to prevent recurrence: None. Spill was not due to mechanical malfunction or error. Please 'contact me at 907-276-4552 for any additional information you may.require. Very truly yours, jrh 240-910 cc: Mr. Hoyle Hamilton Department of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99504 R. K. Riddle ~~,~.~.~ COMPANY, U.S.A. POUCH 6601 - ANCHORAGE, ALASKA 99502 907/276-4552 March 22, 1979 Alaska Department of Environmental Conservation P. O. Box 1601 Fairbanks, AK 99707 Attention: Mr. Doug Lowery ~_o_-? t?:.l 'f co~ I I 12 I~ ~EO~ F- I ~v F- l DRAFT l J SEC J CONFER: FILE: ~"; Gentlemen: A fuel oil spill occurred at Exxon's Duck Island Unit drillsite location at 8:30 AST on March--~,--~g79"[ ................. ~ ....... Pursuant to 18 AAC 75.100 under authority of AS 46.03.020 (10) (A) and AS 46.03.755, this letter constitutes written confirmation 'of the telephone report made by Mr. D. R. Amonsen to Operator #32 of the Alaska Department of Environmental Conservation at 13:56 AST on March 4, 1979. The information required by 18 AAC 75.110 follows: 1. Date and time of discharge: March 4, 1979 at 8:30 AST. ~ Location of the discharge: 700' NSL, 800' WEL, Section 8, TllN, R17E, UM or the Exxon Duck Island Unit drillsite. · Persons causing or responsible for discharge: None. Spill was due to mechanical malfunction of equipment. · Type and amount of discharge: Approximately 20 gallons of Arctic Grade Diesel 'Fuel. · Cause of discharge: The spill was the result of a loose fuel line connection on the return line from a snow melter generator engine t° the snow melter day · tank. e Environmental damage: None. 100% of the spilled fluids were recovered. · Cleanup actions undertaken: Spilled fluids were recovered with absorbent cloth.m ~%~%Q.a~ted snow and ice was picked up and placed in~'~q.~[6.6~iners. ,N~ka Oil & Oas Om'is. u~laaJsslOll Alaska Department of Environmental Conservation Page Two 8. Location, method, and date of disposal of discharge and cleanup material: Spilled fluids will be stored in the slop oil tank and will be injected into the wellbore annulus at a later date. · Action taken to prevent recurrence: Leaking connec- tions have been repaired and the fuel lines to the snow melter will be inspected on a regular basis. Please contact me at 907-276-4552 for any additional information you may require. Very truly yours, jrh 240-910 cc: Mr. Hoyle Hamilton Department of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99504 R. K. Riddle STATE of ALAS KA OIL & GAS CONSERVATION COMMISS£ON TO: F- DATE: ~k ~ ~" ~'\ SUBJECT: OIL SPILL at (iota'zion) NOTIFICATION TO O&GCC Date & Time of Notification:~ ~'Y; .~Person Notified: ~"~ b'~ Information require~ by 18 AAC 75.110 Date and time of discharge: 2. Location of Discharge: 3. Person or Persons causing or responsible for the discha~-ge: 4. Type (s) and amount (s) of hazardous substance (s) 5. Cause of Discharge: ,.r- 6. Environmental damage cause by the discharge to the tainab le: , Cleaning actions undertaken: Location and method of ultimate disposal of the hazardous and contaminated clean-up mater±Ms ±ncluding data o~ · Actions taken to prevent recurrence of the discharge- COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 907/276-4552 March 19, 1979 Alaska Department of Environmental Conservation P. O. Box 1601 Fairbanks, AK 99707 Attention: Mr. Doug Lowery ., Gentlemen: / / A oil spill occurred at Exxon's Duck Island Unit drillsite location at 1700 AST on March 11~ .... ~9~79. Pursuant to 18 AAC 75.100 under authority of AS 46.03.020 (10) (A) and AS 46.03,755, this letter constitutes written confirmation of the telephone report transcribed by Mr. J. W. Jackson to your ~u~u~atic r~rd~ at 2230 AST cn ~arc~ ii, i~7~. The information required by 18 AAC 75.110 follows: I. Date and time of discharge: March 11, 1979 at 1700 AST. Location of the discharge: Exxon's Duck Island Unit drillsite. 700' NSL and 800' WEL, Section 8, TllN, R17E, UM. . Persons causing or responsible for discharge: Mr. Tom Chuinbley, pump operator for Halliburton. 4- Se 6. Type and amount of discharge: Approximately ~5~allo.ns of oil. Cause of discharge: A suction valve between the tank and pump on a cementing unit partially froze open. This allowed fluid to enter, fill the tanks and run over while injecting fluid down the well.annulus. Environmental damage: None. A DIVISION CF EXXON CCRPORATION Alaska Department of Environmental Conservation Page Two · e Cleanup actions undertaken: Spilled oil was cleaned up with absorbent material and placed in a 50 gallon drum. Contaminated snow was picked up and placed in a 50 gallon drum. Location, method, and date of disposal of discharge and cleanup material: Contaminated absorbent materials will be incinerated at the Duck Island drillsite location. Contaminated snow will be melted and injected into the wellbore annulus at a later date. e Action taken to prevent recurrence: Valves on cement pu_mp units will be checked for proper operation before injection begins. Please contact me at 907-276-4552 for any additional information you may require. Very truly yours, jrh 240-910 cc: Mr. Hoyle Hamilton Department of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99504 R. K. Riddle SUSPENSION PROCEDURE DUCK ISLAND UNIT NO. 1 This procedure begins after the test string has been pulled following the last test. le Trip in hole with 9-5/8" casing scraper on drill pipe to 11,110 feet. Circulate bottoms-up and pull out of hole. e Pick up Halliburton EZ Drill SV cement retainer for 9-5/8" 43.5 ppf and trip in hole on drill pipe. Run Halliburton latch-in collar ! stand above.retainer. After squeeze, the drill pipe will contain approximately 0.7 bbl of cement, which will fill approximately 9 feet of casing above the retainer. e Set packer at 11,000 feet, wireline measurement. Packer must be at least 50 feet above highest perforation. · Pull out of retainer and circulate displacement of drill pipe (82 bbl). · Prepare to J~ix 35 bbi class G cement (15.8 ppg) in recir- culating blender as follows: 170 sks Class G cement (yield 1.15 ft3/sk) 24.2 bbl (850 gal) fresh water 160 lbs (1.0%) CFR 2 48.0 lbs (0.3%) Halad 22A 15.0 lbs (0.1%) HR7 (5:20 TT @ 220°F BHST) 6. Pump the following into the workstring: 15 bbl fresh water 35 bbl cement (mix'and pump above slurry) Insert latch in wiper plug 3 bbl fresh water 28 bbl 9.6 ppg mud Stab into retainer 50 bbl 9.6 ppg mud · Squeeze the perforations using the above cement. exceed 5000 psi. Do not RECEIVED Aillel~ll 011 & Gas (.,ohs. ~,om,m,~.sifm Suspension Procedure Duck Island Unit No. 1 Page Two 8. a) If squeeze pressure is achieved before plug is latched in, pick up 9 ft. above, retainer and reverse out excess cement, leaving cement plug above retainer with top at +/- 10991 ft EL. b) If squeeze pressure is not reached by time plug latches in, pick up 9 ft, pressure up drill pipe to shear plug and reverse out, leaving cement plug at +/- 10091 ft EL. 9. After reversing clean, pull out of hole. 10. Inject all waste fluids on location down 9-5/8" x 13-3/8" casing annulus. Double-check all tanks to be sure all waste fluids are injected. 11. Pick up 9-5/8" casing cutter on drill pipe and measure in hole to 2400 ft. Actuate mechanism and cut 9-5/8" casing. Record exact depth of casing top. 12. Measure out of the hole. 13. With 9-5/8" casing spear, latch onto 9-5/8" casing and pull 9-5/8" casing out of hole (approximately 2400'). Casing is 43.5 ppf, Soo95 grade. 14. Spot gel plug at 2300' (100' above top of 9-5/8") casing stub as follows: a) Mix 15 bbl gel pill to approximately 300 second vis- cosity using existing mud. This pill is to be mixed to the highest viscosity possible and still be pumpable. b) TIH with open'ended drill pipe and plug catcher one stand above bottom to 2400' (top of 9-5/8" casing stub) . Establish circulation, pump 15 bbl gel pill and displace with 17.8 bbl of mud. Do not overdisplace. 15. Slowly pull 100 feet. 16. Prepare to mix 10 bbl cement plug in recirculating blender as follows: 60 sx Permafrost cement (15.0 ppg) 5.0 bbl (210 gallons) fresh water Thickening time = 7 hr 15 min Suspension Procedure Duck Island Unit No. 1 Page Three 17. Pump 10 bbl cement plug as follows: a) b) c) d) e) f) Drop bottom plug in drill pipe. Pump 10 bbl cement (mix and pump above slurry). Drop top plug. Displace cement with mud until top plug lands (approximately 16.4 bbl). Pull up 70 feet, pressure up drill pipe until plug catcher pins shear (approximately 2000 psi). Pull up 1 stand and reverse out. 18. Pull out of hole. 19. Pick up cast iron bridge plug for 13-3/8", 72 ppf casing and trip in hole on drill pipe to top of cement. 20. Set bridge plug as far down as possible but not higher than 2000 feet. 21. Displace mud in casing with 9.8 ppg CaCl2 as follows: a) Clean the rig suction pit and mix 340 bbl of 9.8 ppg CaC12 by adding 28,900 lb High Test Flake Calcium Chloride (95% CaC12) to 316 bbl fresh water. b) Heat the mixture to +70°F. c) With drill pipe at 2200', pump 50 bbl fresh water followed by 325 bbl CaCl2. Displace the CaC12 with 16.3 bbl fresh water. 22. Trip out of t~e hole to 100' keeping the hole full with CaCl2. 23. 'With the drill pipe at 100', mix and pump a 10 bbl perma- frost cement slurry (specified in Step 16) as follows: a) b) c) d) 3 bbl fresh water Pump 10 bbl cement Drop top plug Displace cement with 0.75 bbl CaC1 24. Trip out of the hole to 20' and reverse out. Trip out of the hole. 25. After waiting on cement for' 6 hours, run in the hole and tag the cement plug top. Suspension Procedure Duck Island Unit No. 1 Page Four 26. Displace liquid in casing with 9.8 ppg CaC12. 27. Remove BOP stack, 12 foot spool, and "B" section. Install 13-5/8", 5000 psi blind flange on "A" section. Leave side outlet valves on "A" section. RGD: j rh 3-16-79 FIGURE 1 ~ WELLBORE SKETCH AFTER TESTING DUCK ISLAND UNIT NO. 1 JJ NOTES: 1. Ail depths are · measured depth. I'~'1 Primary casing l?i l cement not shown RGD 3/15/79 42" Conductor @ 70' 30" Grade B, 1" wall Conductor @ 80' · 20" 94 ppf, H40 Conductor @ 672' 13 3/8" 72 ppf, N80 Casing @ 2720' 11066'-1 shot for Formation Test 11071'-11081' 4 spf (Test 7) 11188'-11203' 2 spf (Test 6) 1120R'-1].219' 2 spf (Test 6) 11224'-11234' 2 spf (Test 6) Top of 7" Liner @ 11256' 9 5/8" 43.5 ppf, Soo95 Casing @ 11391' Baker Model F-1 Packer @ //~nz · -Baker Model F-1 Packer @11490' 11502'-11523' 2 spf (Test 5) CaSt Iron Bridge Plug @ 11526' 11530'-11538' 4 spf (For squeeze) Cast Iron Bridge Plug @ 11578 Baker Model F-1 Packer @ 11607' 11627'-11644' 4 sDf (Test 3) Cast Iron Bridge Plug @ 11609' Baker Model F-1 Packer @ 11675' .' 11700'-11720' 4 spf (Test 2) Halliburton Cement Retainer @ 11724' 11730'-11734' (For squeeze) Cast Iron Bridge Plug @ 11760' Baker Model F-1 Packer @ 11768' 11790'-11810' 4 spf (Test 1) 7" 29 ppf, Soo95 Liner @ 12663' 8 1/2" hole Total Depth @ 12800' FIGURE 2 PROPOSED ~,.LLBORE SKETCH AFTER SUSPENb£ON DUCK ISLAND UNIT NO. 1 NOTES: 9.8 ppg ~CaC12 % (''.' · · 1. All depths are , ,. measured depth. ':' ' ' ' 2. Pr±mary casing cement not shown 42" Conductor @ 70' 30" Grade B, 1" wall Conductor @ 80' Cement from 30' to 100' · 20" 94 ppf, H40 Conductor @ 672' Cast Iron Bridge Plu @ 2000'-2300' Cement from 2230-230~' Top of 9 5/8" Casing @ 2400' 13 3/8" 72 ppf, N80 Casing @ 2720' Halliburton Cement Retainer @ 11000' 11066'-1 shot for Formation Test 11071'-11081' 4 spf (Test 7) 11188 '-11203' 2 spf (Test 6) 11208 '-11219' 2 spf (Test 6) 11224 '-11234' 2 spf (Test 6) Top of 7" Liner @ 11256' RGD 3/15/79 9 5/8" 43.5 ppf, Soo95 Casing @ 11391' Baker Model F-1 Packer @ ,-Baker Model F-1 Packer @11490' 11502'-11523' 2 spf (Test 5) Cast Iron Bridge Plug @ 11526' ( or Cas ron Bridge Plug @ 11578 Baker Model F-1 Packer @ 11607' 11627'-11644' 4 sDf (Test 3);," Cast Iron BridGe Plug @ 116 09 Baker Model F-1 Packer @ 11675' 11700'-11720' 4 spf (Test 2) Halliburton Cement Retainer @ 11724' 11730'-11734' (For squeeze) Cast Iron Bridge Plug @ 11760' Baker Model F-1 Packer @ 11768' 11790'-11810' 4 spf (Test 1) 7" 29 ppf, Soo95 Liner @ 12663' 8 1/2" hole Total Depth @ 12800' FIGURE 3 SUSPENSION SKETCH SHOWING LOCATION OF WELLHEADS RELATIVE TO SEA FLOOR DUCK ISLAND UNIT No.! 18'-6" 6'-6" 4'j8 WELLHEAD AND COMPANION FLANGE ISLAND SURFACE LEVEL WATER LEVEL $[A ~LOCR fCELLAR WALL 13-3/8" CASING 20" CONDUCTOR 30" CONDUCTOR ~,,~ ~ro. ~,-4 STATE ALASKA I%EV. ~- 1-70 OIL AND GAS CONSERVATION COAMAI~EE SUBMIT 1~ DU'PLIC&'i~: MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS $ APl I~L~.[EI:~CAL CODE 50-029-20280 S LE~.SE DES:CItATION AND SERIAL ,NO ADL 47502 o.. ~ o,,, ~ Wildcat ~LL W~LL ~ OTH~J ~ N~E OF OP~TOR 8 L~IT F.~I OR LEASE NAME ~on ~~ration ~ck Isled Unit ~ ~Da~ss o~ opera Pouch 6601, Anchorage~ Alaska 99502 4. lOCATION OF WF.L.L Surface: 700' NSL & 800' ~EL of Sec. 8, TllN-R17E, Ul%l North Slope, Alaska BHL (Proposed): 500' NSL & 800' WEL of Sec. 5, TllN-R17E, UPM, North Slope, Alaska 9 WELL NO No. 1 10 FIF_~D A_ND POOL. OR WILDCAT ...Wildcat 11 SEC. T., R., .M. ('BOT'T'O,',.! HO1J~. o~JEcrrv~ Sec. 5, TllN, R17E, UI~! 12 PE!R.MIT NO 78-68 13. R~ORT TOTAL DKPTH AT END OF .MONTH, CHA..'~GE, S IN HOLE SIZE. CASING AN~ C~I~NG JOBS INCLUDING DEP~ SET ~N~ VOLL~ US~. P~ORATIONS. ~TS AN~ ~SUL~ FISHING JO~ JL~K LN HO~ ~ND SIDE-~CKED HO~ ~D ~Y O~ SIGNIFIC~T ~NG~ ~ HO~ CO~ITIOHS. ~ cas~ hole FIT at 11,807'. ~vered 1 cf g, 7800 cc ~ter ~d 500 cc md. Perforat~ w/4 ~f 11,790'-11,810' ~d set a ~er M~el F packer at 11 768' ~ Clos~ ~~r D~ using a nitrogen cushion ~ned tool for 36 ~utes. ~vers~ out 57 b~rels water. Set ~er CI~ at 11,760' Perforated w/4 spt 11,730'-11,734' ~d set a c~nt * reta~er at 11,724'. Stag ~to retainer ~d att~pted a bl~k ~uld not p~p into perfs w/3500 psi. Perforated w/4 spt 11,700'- 11,720' ~d set a ~er Model F packer at 11,675'. Att~pted closed o~r D~ us~g a nitrogen cushion. T~I did not open. ~ ~other ~ tool ~d opened to flow for 2 ho~s fr~ perfs 11 700'-11 720' ~versed out 24 b~rels water. Set ~er CI~ at 11,669' Perforat~ w/4 ~f 11,627' -11,6~ '. ~t a ~er M~el F packer at 11 602 ' closed cheer D~ using a nitrogen cushion. ~ened t~l for 42 m~utes. ~versed out 45.5 b~rels water ~d 2.5 b~rels md. ~illed out packer . , at 11,602' w/5-3/4" ~11. Set a c~nt reta~er at 11,617' ~d. squeezed ~rfs 11,627'-11,~' ~_th 5.5 b~rels c~ent. ~illed out retainer ~d c~nt ~d clewed out c~g to 11,669'. Perforate w/4 spt 11,627'- 11,6~'. ~t B~er M~el F packer at 11,618'. Attempted closed c~ber ~ us~g a nitrogen cushion ~d t~]. did not open. ~ ~other D~ t~l ~d o~ned to flow for 7 ho~s 28 ~utes. Reversed out 38 b~rels ~ter. ~t ~er CI~ at 11,578'. Perforate w/4 spt 11,533'-11,538'. Set c~nt reta~er at 11,528'. Stag into reta~er ~d perfo~ a bl~k squeeze with 40 b~els of c~ent. ~uld not pull out of retainer. Bled off pres~e ~d recovered ~.5 b~rels md. ~led up to 11,490' ~d ~ able to pull out of reta~er. Reversed out ~. 5 b~rels c~nt. ~ip~ in hole with 5-3/4" ~11, ~11~ up reta~er ~d c~nt to 11,537'. Perforat~ w/2 spt 11,530'-11,535'. ~t c~nt reta~er at 11,492'. ~u~ze c~nt perfs with 37 b~rels c~nt. Milled out reta~er ~d c~nt to 11,528'. ~uld not get below 11,367' with a CI~. Now ~ hole ~tha 5-3/4" mill ~d ~s~g scra~r. '-7/~~.-. / /~' ~cre~e & ~ell Evalm~t~on s~c~ /~~ ~~-:~ 1. ~ ,~tq,lm?tar ' o.~ March ,!2',, - . / .J / /6 -- , ......... oiled ~o~er~t~n comml~ee b~the I~of fha $ucc~ding ~n~,~le~ Otherwise directed. STATE of ALASKA ~o: F-FILES NOTIFICATION TO O&GCC OIL & GAS CONSERVATION COMMISSION DATE: March 12, 1979 SUBJECT: OIL SPILL RE~ORT at (location) Duck Island Unit Exxon #1 Sec 8/T11N/R17E/UM Date & Time of Notification: 10'48 PM 3/11/79 - Answering 9'41 AM -[sther Person Notified: Esther,M. Ivey, Clerk Iypist II via Answering Service Information required by 18 AAC 75.110 1. Date and time of discharge: 1700 hours 03/11/79 2. Location of DisCharge: Duck Island unit Exxon #1 · · · .· · Per,~:on or Per'sons causing or responsible for the Reported by John Jackson, Exxon 276-4552 (no other name eiven) Type (s) and amount (s) of hazardous substance (s) c![scharged: 15 gallons of oil Cause of Discharge: Suction valve between tank and pump on haliburten unit was frozen partially open, allowing fluid to enter and fill tank and run over while pumping fluid. EnVironmental damage cause by the discharge to the extent asce~;- tainab le: NONE Cleaning actions undertaken: Spill fluid was picked up with absorbent material and placed in 55 gallon barrel, contaminated snow was being picked up. · Location and method of ultimate disposal of the hazardous subs~:ance and contaminated clean-up materials including data of disposal- Absorbent material to be bUrned and contaminated snow will. be melted and pumped down annulas. Actions taken to prevent recurrence of the discharge: ??? ~-rm N'o. P--4 ~. $-1-70 STATE Or- ALASKA OIL AND GAS CONSERVATION COMMII-I'EE SUBMIT IN 'DUPLICAT~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. WELL ~:LL 2. NAME OF OPI~ATOR Exxon Corporation _ _ ~ESS OF OPEP. A~ll Pouch 6601, Anchorage_~, Ak. 99502 ~ wr~ Surface: 700' NSL & 800' WEL of Sec. 8, TllN-R17E, UPM North Slope, Alaska BHL (Proposed): 500' NSL & 800' WEL of Sec. 5, TllN-R17E, UPM, North Slope, Alaska AP1 NUA{ER1CAL CODE 50-029-2O280 '6 LEASE DESiGNA~ON AND S~IAL NO ADL 47502 IF INDIA~, ALOTTEE OF TI~IBE NAME 8. L,~IT F.~ OR LEASE NAME Duck Island Unit g WELL NO No. 1 A_ND POOL, OR %VILDCAT .. Wildcat n SEC, T.. R., M. (BoT'roM HOLE OB.TECTrV~ Sec. 5, TllN, R17E, UPM 12 PEP~MIT NO 78-68 13. REI~ORT TOTAL DI~/~4 AT ~ND OF MON/"rI, CHiNG~ IN HOLE SIZE, CASING Al%TMC~VIENTING JOBS INCLUDING DEPTH SET AND VOLLqVIES USED, p~O~TIONS, ~TS ~ ~SULTS FISHING JO~, J~K ~ HOLE ~D SIDE-~CKED HOLE ~D ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~ITIONS. 1-1-79 a ~ro s~vey~s ~ in the 9-5/8" csg. At a ~ill depth of 11,739' a pres~e ~te~ity test ~s perfo~d with le~ off occ~ring at 12.2 ppg ~, ~ the 9-5/8" csg shoe ~s squeez~ ~low a retainer with 415 sx class G c~nt. After the squeeze, two additional inte~ity tests were perfo~d with le~off occ~ring at 14.8 ppg on the first test and 13.9 ppg on the second. ~ 1-17-79 a final total depth of 12,800' ~ (11,320' ~) ~s reached ~d the follow~g open hole logs were ~' ~al Induction; BHC ~nic; ~ng Spaced ~nic; Fomtion ~nsity - ~m~nsated Neutron; Micro-Microlaterolog; Di~eter; Cement ~nd ~g. Also 83 sidewall cores were recovered from 108 att~pts. Inte~als cored in this well 'Core #7 11,740' to 11,766' Core #8 11,766' to 11,809' Core ~9 11,809' to 11,869' Core #10 11,869' to 11,927' Core #11 12,770' to 12,800' are as follows: Core #1 11,044' to 11,059' Core #2 11,059' to 11,089' Core #3 11,089' to 11,146' Core #4 11,530' to 11,567' Core #5 11,570' to 11,627' Core #6 11,683' to 11,739' A 7" liner was set from 11,256' to 12,663' and cemented with 360 sx class G cement. The 7" liner was pressLwe tested and leaked 1½ BPM at 2100 psi. After squeeze cementing the liner top with 150 sx class G cement, it was pressure tested successfully to 3000 psi. Cement inside the 7" csg was drilled to a PBD of 12,572' and a cement bond log was run from 10,000' to 12,531'. While running a 7" circulating casing string, a 7" "rabbit" fell in the hole. After failing to recover the "rabbit" with a magnet it was pushed to 12,547' with drill pipe At the end of the month..preparations are being made to test and and left in the casing. evaluate the well. CONFIDENTIAL ,RECEIVED ~Acreage ~tion ~^h-~'ar" 9 1979 '" 3'_i .... .... status of operations, and must ~ filed In duplicate with the ..... ;[l~ gas con~rvatio~ commiff.e byth. 15~ of the ,uccflding monffi,unl,~ oth.rwis, dir.cted. E ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION Mr. Lonnie C. Smith Chief Petroleum Engineer Alaska Oil and GasConservation Con~nission 3001PorcupineDrive Anchorage, Alaska 99501 January 23, 1979 Exxon Duck Island Unit No. Permit No. 78-68 Dear Mr. Smith: Attached is a Sundry Notice covering the slight changes in our casing program and in the total depth of the subject well which we discussed with you on January 22. Such changes are reported herewith by way of a "Subsequent Report" following the prior Sundry Notice of October 6, 1978. Although duplicate filing is all that you require we have included three copies of the notice so that you may return to us a signed copy in the event of your approval for the completion of our file. Yours very truly, Robert K. Riddle RKR' jal Ehclosures cc' R. P. Bright w/encl. Harry Brown w/encl. A DIVISION OF EXXON CORPORATION Form 10-403 "REV. 1-10,.73 , Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) WELL L.J OTHER Wildcat 2. NAME OF OPERATOR Exxon Corporation 3. ADDRESS OF OPERATOR P. O. Box 2180, Houston, Texas 77001 4. LOCATION OF WELL At surface 700! NSL & 800' WEL of Sec. 8, TllN, R17E, UM 500' NSL & 800' WEL of Sec. 5, TllN, R17E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 3 ft. water dePth at surface location 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20280 6. LEASE DESIGNATION AND SERIAL NO. ADL 47505 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Duck Island Unit 9. WELL NO. No. 1 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 5, TllN, R17E 12. PERMIT NO. 78-68 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER 5HUT-OFF E~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFFI i~ REPA' RING WELL FRACTURE TREATMENT ~ ALTERING CASING SHOOTING OR ACIDIZlNG ~ I ABANDONMENT* (Other) casing program, Sundry Notice Oct (NOTE: Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 1978 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all Pertinent (letall$, and give pertinent dates, Including estimated date of starting any proposed work. Set 9-5/8" casing @ 11,391' MD (corrected to wireline measurement) Set 7" liner top @ 11,256' MD to 12,663' MD Total depth of well 12,800' MD 16. I hereby certify that the foregoing is true and correct (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY.' TITLE DATE See Instructions On Reverse Side F~rm No. ~---4 RL'~. ¸1. STATE OF AJJ~KA OIL AND GAS CONSERVATION COMM1T[EE MONTHLY REPORT OF DRILLING' AND WORKOVER OPERATIONS Wildcat 2. NA/~F. OF OPEI~kTOR '~,-4~n'q C.n'r~n'r'nl-'in'n ,,, Pouab ¢~01, .~ahora~e, A~. 99502 LOCATION OF WELL Surface: 700' NSL & 800' WEL of Sec. 8, TllN-R1ZE, Ut~, North Slope, Alaska BHL (Proposed): 500' NSL & 800' WFL of Sec. 5, TllN-R1ZE, UPM, North Slope, Alaska 50-029-20280 ADL 47502 ? IF INDIAN][. ALOTTEE OR TRIBE 8. L~IT F.~RM OR LEASE NA3~E Duck Island No. 1 WELL NO No. 1 FrF. i3~ A.N'D POOL, OR WILDC~ SUBMIT IN DUPLICATE _ Wi] de~t_ .. Il. S~--C, T., R., .~.. (BOSOM HO] oa~--rrv~ { 4 ENG CONFSR: -- FILE: Sec... 5 .... T!I~..,.R17E, UPM 12. PIgP~VIIT lq'o 78-68 13. REPORT TOTAL DEPTH AT tLND OF MONTH, CttA.NGE.B IN HOLE SIZE, CASING AN'D CILMENTING JOBS INCLUDING DEPTH SET AN'D VOLUM]~ USED. PERFORATIONS. TESTS A1N-D P,.ESULTS FISHING JO~. JL."NK L~I HOLE AND SIDE-TRACKED HOLE AND ANY o'r'H~l:i, SIGNIFICANT Ci~A~GE;~ IN HOL,~, CONDITIONS. At ad rill depth of 11,567' the following open hole logs were run' Dual Induction BHC Sonic Long Sp~ced Sonic At 11,627' the followin~.open hole logs were run' Dual Induction Formation Density - Compensated Neutron Dipmeter Also 84 sidewall cores were attempted and 37 were recovered. Then 9-5/8" csgwas set at 11,403' and cemented with 1850 sx class G (15.8 ppg) plus I%CFR-2 and 0.2%HR7, displaced with 842 bbls 9.8 ppg mud. Did not bump plug and had good returns throughout job. Pumped 778 bbls of mud down the 13-3/8" x 9-5/8" csg annulus to establish injectivity into the open hole interval between the 13-3/8" csg shoe and the top of cement behind the 9-5/8" csg. 5~aximum injection rate was 4 BPM at 550 psi. After drilling out of 9-5/8" csgwith an 8-1/2" bit, a velocity survey was run and a pressure integrity test was performed. Leak off occurred at 12.7 ppg H~'. At the end of the month we are at a drill depth of 11,627' tripping in the hole with an 8-1/2" bit. Mud weight is 9.5 ppg. , . CONFIDENTIAL s~s~ ~.[,~ ?"J~----~ ~/~/~f/J Acreage & Well Evaluation .......... .... -r: ' , l x ' ' ......... NOTE --Report on th~s fo~ il rsquiJed for each calendar ~nth& regardless of the status of operatiOnS, and must ~ file~ J, duplicQla with the oil and gas conservation comml~ee byth~ 15~ Of t~a ~u~c~ding mon~.unle~ otherwise directed. January 10, 1979 To witness BOP test Exxon Duck Island Unit No.1 Permit %78-68 12~.27~8_}~ ~_: - I left Anchorage by Wien Airlines at 11:30 AM and ~-riv~d in ~ at 1:00 t~4. Exxcn's Expedi~ picked me up and drove me to f~ack Island %~t No. 1, arriving at location at 2 PM. Purpose of trip to witness BOP tests on Duck Island Unit !,D. 1, nippling up BGP's was in progress. I toured the location and found all fuel pits, still well b~_rnmd and lined with h~rculite ok. The location was clean and free of debris. The well sign was up with all data ok. The oellar was pumped out and was dug to five feet below mud line, as drilling rm~d had filled cellar up about 8 feet abcv~ casing head. This was dc~e to set slips & hanger to land 9 5/8" casing. 12/28/78 - Nippling up BOP's was finished and the testing, was started at 0~-~-6-~--~ finished at 12 noon. The upper pipe rams inside kill valve and inside choke valve ~ tested first to 5000 psi. Next, with the upper pipe rams still closed, the outside kill valve and outside choke valve (!~/R) ~ tested to 5000 psi. With the upper pipe rams still closed, there w~re two kill lines connected to the outside kill line valve, one was the standard mud kill line, the other was an emergen~ kill line with check valves c~ each. These were tested to 5000 psi. The manifold had six 5000 psi valves and 17 flanges, plus one super~ke that was tested to 5000 psi. The annular preventer was tested to 3000 psi. The next test was a perfonmance test c~ the accumulator while the test ste~ was still in test plug. The master gauc3e read 3000 psi. Tbs manifold gauge read 1500 psi. The regulator c~ annular preventer was set to 1500 psi. With all power ~hut off the a~tor, the annular preventer, tt~ two sets of pipe rams were closed, and the HCR valve was opened at c~e tin~. The accumulator pressure dropped to 1300 psi and did not ~, indica~ the a~ator p~ge was ok and that there were no leaks. Accun/lator tested satisfactory. The mast~ and remct~ ccFfcrols ~ted satisfactory. There were five backup ni~ bottles connected to the accumulator; each had 2200, 2300, 2400, 2600 and 2300 psi ~. The test stem. was pulled and the blind rams were tested to 5000 psi. The upper and I~_r kelly w~re tested to 5000 psi. Thrcu~.hout the tests ~ was c~ly one failure w~ch vms a check valve on tbs kill line that was r~~ and retested to 5000 psi. A dart valve and ball drill stem safety valve on the floor w~re ok. ~-~%en all the test/ng was done, I Jnf~ l.~fle Eckols who was supervising for Exxon tb~t ~ cellar had to be resealed as water was seeping into the cel~. Haliburtnn ~ proceeded to .mix and ~ 20 sacks of barite around. the ba~ of the cellar. -2- in ~ 1_~1, ~cat/ng that the cellar was sealed frc~ Lntrusi~ of sea water. I witnessed ~ BOP ~ ~ ~ Island Unit #1 for Exxc~ and also witne~ ~he sealing of ~ cellar. When I left the locatic~ all BOP equi~t ~ locatic~ ~ in %~ry good shape. Tests were sat/sfac- Alas Oil and Gas Conservation Committ Drlg. Per'lit No.~'~ ~ Field Inspection Report Well/Pla tfm Se c.~_..l Operator .J~:__S~..~~ "~::"'Represented by~/~~~$ ~ame & Number~/~ !~~ ~"~,~/ Satisfactory Ty_pe Inspection SatisFactory Type Inspection Yes No Item ~) Location,General Yes No I~_ ~) ( ) 1. Well Sign ~) ( ) 15¢~/~'Cas'ing set ( ) 2. General Housekeeping ~) ( ) 16f~t f'luid-~wtF~( )mud ( ) oil } ( ) 3. Reserve Pit-( )open( )filled ~) ( ) 17 Master Hyd. Control S,ys.~~psig ( ) 4. Rig (~) ( ) 18 N~ btls~,~,~O,~s-iq ( ) Safety Valve Tests ~) ( ) 19 R~mote Controls ) ( ) 5. Surf~c'~'-'No. Wells ~) ( ) 20 Drilling spgol-~w "outlets ~ ) ( ) 6. Subsurface-No. Wells ~) ( ) 21 Kill Line-(~) Check valve ( ) Well Test Data ~ ~ ~ 22 Choke Flowline ~) HCR valve ( ) ( ) 7. Well Nos. , , , '" 23 Choke Manifold No. valvsg flgs/7 ( ) ( ) 8. Hrs. obser , ,__ ~~'~ ~ ~ 24 .Chokes-~Remote( )Pgs.(~dj. ' ( ) ( ) 9. BS&W , , , ~ .... 25 Test Plug-( )Wellhd~)cs9( )none ( ) ( ) 10. Gr. Bbls.~, , ,~ .... ..2,~ Annular Preventer~psi~ ( )Final Abandonment ~) ( ) ' 27:'B~ind Rams~,~psim ( ) ( ) 11. P&A Marker ,~ ~ ( ) 28. P~p~'Rams~m~ psig ( ) ( ) 12. Water well-( )capped( )P~u'gged~ (:) 29 Ke]"I.Y & K~li~Ecock~ psig ( ) ( ) 13. Clean-up (~ ( ) 30. Lower Kelly valve~ psig ( ) ( ) 14. Pad leveled (~" .~( ) 31. Safety Floor valve~BV ~)Dart Total inspection observation time /days Total num~e.~ ~eaks and/or equip, failures Remarks ~/]~/~ ~~ ~)~_ ~/~?~ ~ ~'~ ~A ~ .~/~!~F/~ ~ v ...... cc: or'w en December 18, 1978 Exxon Company U.S.A. Pouch 6601 Anchorage, Alaska Attention' Robert K. Riddle Reference' LO/NS 78-134 Expansion of fuel storage area (77-162) LO/NS 78-139 SPCC Plan (77-162) Gentlemen' Thank you for your letters of September 29, 1978 and October 4, 1978. The Spill Prevention Control and Countermeasure Plan for the referenced lease operation is approved. The expansion of the fuel storage capacity to approximately 155,00~3 gallons of fuel is approved, however these activities should not exceed the proposed expansion plan as outlined in your plan of operations letter dated September 29, 1978. A completion report shall be submitted with 15 days upon termination of permit activities. This report shall contain the following information' Ae Actual routes of travel, actual location of shot lines and actual location of all camps depicted on a USGS topo map. Be All additions to original application. 10-J3LH '-~ C. .Statement of clean up activities. D. Time spent in each campsite. E. Methods of disposal of garbage and other camp debris. Sincerely, Ethel H. Nelson Leasing Manager r.o,-m .~o. ~-.~ STATE O, ALA$KA .".L"~V. :~- I-?0 SUBMIT ]2g IDU?LICATE OIL AND GAS CONSERVATION COMMITTEE ~M, ONT'H~.Y REPORT OF DRiLLiNG ANO WO~R. OVER OPER. ATJON:~ NU,'~iERIC AL CODE 50-029-20280 o._ ~] o.,,, ;--~ Wildcat "~' Ei..L ~rELL ~ OTHER NkME OF OP~TOR 8 C~IT FA~I CT( LEASE Exxon Corporat ion ,, ~DbasgS'~F o~a ~ wz~ NO Pouch 6601, Anchorage, Ak. 99502 Duck Island 10 FrF~D .~ND P~)L. OR WiL'OCA~' 4 ~CA~ON OF WF, IJ~ Surface: 700' NSL & 800' WEL of Sec. 8, TllN-R17E, UPM, North Slope, Alaska BHL (Proposed): 500' NSL & 800' WEL of Sec. 5, TllN-R17E, UPM, North Slope, Alaska LEASE DESiG~XA'FION AND SEHIAL NO ADL 47502 iF INDIA~ AiX)Ti~iE OR TRIBE ,. NO. ] Ii SEC. T., R, .k.! (P_,.O2~: OM HOL~ Sec.., 5~ 12 PI~R~MIT NO ._, 78-68 Ti. iN, RIVE, 13. RF-~ORT TOTAL DEl>TH- AT F~D OF ,¥1ON~'iX4. CH~XG}%S IN HOLE SIZE. CASING A~ C~D,I~NT!NG JOBS INCLUDING DEW'~ SET ~N~ VOL~ USED p~OP~TIONS. ~TS A~ ~SUL~ FISHIN'G JO~ JUnK LN HO~ AND SIDE-~ACKED HOLE ~N~D ~N'Y 0~ SIGNIFIC~T ~G~ ~ HO~ OON~ITIONS UPM A 12¼" surface hole was drilled to 2738' and Dual Induction and Long Spaced Sonic logs were run. The 12¼" hole was then opened up to 17½" and 13-3/8" surface casing was set at 2720' and cemented with 2400 sacks Permafrost. On 11-11-78 drilled out of 13-3/8" casing with a 12¼" bit. At a drill depth of 2748' a pressure integrity test was performed. Leak off occurred at 13.4 ppg EMW. At a drill depth of 2900' a gyro survey was run and showed a bottom hole closure of 9' N58°E at 2700'. At 2900' the hole was kicked off to the north using a Dyna Drill and a 12¼" hole is now being directionally drilled at a measured depth of 9920'. ONFIBENTIAL 1",. I ,~¢r~by certify lb~[ the £oregOing~true anYJ ~ Acreage & Well Eval- ~ ~~~~~~~,~ ~ uation Manager .~.~_ 12/13/78 SI~ ~ ....................... oil end gq) conservation commiHee bythe 15th of the succ~ding month, unie~ nfher~is~ dlr~cfed. Tom Cook, The Oil & Gas Conservation Committee and Fred Boness AVRUM M. GROSS ATTO~{EY GENERAL December 8, 1978 Jeffrey B. Lowenfeis ~ // Duck Island lawsuit Assistant Attorney .'Gener~l i '30~OL~ Sznce I ~;z!l be zn ~ashzngton D.C. next week I ~n puttzng down some thOUghts zn thzs ~aemo zor your during my ~sence. The Duck Island lawsuit is still pending before the Superior Cour~ ~ ~ ~ate of Alaska. Some time "~- during late Deck, er and early .J~u~y we will begin receiving applications for ~rilling b~ Sohio at ~iakuk an~ ~{eindeer Islana. The-notice issues involvea in the Duck Island lawsuit will most probably not be resolved by the tzme ~tes~ applications are ~de. Specifically, ~he Superior court will not have decided whether the Division of Oil ~ Gas need give "[~lic" notice pursuant to AS 31.05 before it can issue a drilling perz~t. Nor ~'ill the superior court have determined whether the approval of Surface operations is a disposal of an interest in land pursuant to AS 38.05.305 and 3~. The question which needs to be considered is whether ~ should issue so,ne form of notice for both of the activities covered by your agencies. W~ would, of course, note that the notice was being given because of the pending Duck Island law- suit and that the state was not a~itting, by any means, the need for such notice 'in the absence of a lawsuit. I will return Monday~ December iSth and would like th~s matter w~th you on either Monday or Tuesday. to talc about ¢ ' i have had some conversations with Paul De Stephano zc~ ~my, Guess & Rudd who is working for Sohio on this matter. I agreed with Paul to allow him to speak with any of you about this matter during my absence. Incidentally, !~' feel we have a good shot at winning the lawsuit. Should Alaska Legal Services lose before the federal court there is a 'likelihood that the state suit will fall by the wayside I Will k~p you JBL:sa COMPANY U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 907/276~4552 ,.,: . · .4/(;/,.,.,,r;.,,,,. ".',,, Alaska Department of Environmental Conservation P.O. Box 1601 Fairbanks, Alaska_ 99707 Attn t Mr. Doug Lowery November 15, 1978 Dear Sir: A gasoline spill occurred on Exxon's Duck Island Unit #1 drill site location at approximately 9:08 pm AST, November 1, 1978.' Pursuant to 18 AAC 75.110 under authority of AS 46.03.020 (10) (A) and AS 46.03.755~ this letter constitutes written confirma- tion of the telephone report made by Mr. D. R. Amonsen to Mr. Paul Bateman of the Department of Environmental Conservation at 8:28 am AST, November 2, 1978. The information required by 18 AAC 75.110 follows: t · Date and time of di'scharge: Exact time unknown; the spill was discovered at 9:08 pm AST, November 1, 1978. · Location of the discharge: Exxon's Duck Island Unit 91 drill site location (latitude = 70°19'00 127" longitude = 147°51'46.800"). 3. Persons causing or responsible for discharge: Unknown. Type and amount of discharge: Gasoline; approximately 20 gallons. · Cause of discharge: Fuel transfer hose was replaced with the shut-off valve in the open position. e¸ Environmental damage: No environmental damage was observed as a result of the spill. 100% of the spilled gasoline was recovered or evaporated. e Cleanup actions undertaken: The spilled~..g.~soline was recovered with absorbent material· Thee resid~al¥~ . apparently evaporated. There was no gasoline re- "~ ' maining on the pad. · Location, me%hod and date of disposal of discharge and cleanup material: The contaminated material was placed in a 55 ga].lon drum and will be incinerated in accordance with the permission of Mr. Paul Bateman. A DIVISION OF EXXON CORPORATION Alaska Department of Environmental Conservation Page Two November 15, 1978 ~ Action taken to prevent recurrence: The catch that holds the nozzle valve open has been removed. The master shut-off valve will be padlocked in the closed position after each use. Please contact me at 907/276-4552 for any additional information you may require. Very truly yours RGD:jrh 240-910 cc: Mr. Hoyle Hamilton Division of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99504 R. K. Riddle ;11 COMPANY, U.S.A. POUCI'! 6601 · ANCHORAGE, ALASKA 99502 907/276-4552 November 15, . 1978 Alaska Department of Environmental Conservation P. O. Box 1601 Fairbanks, AK 99707 Attention: Mr. Doug Lowery Gentlemen: A diesel fuel, antifreeze, and motor oil spill occurred near Exxon's Duck Island Unit #1 location at 13:30 AST on November 2, 1978 due to the accidental dropping of an oilfield compressor onto the sea ice during helicopter transport operations. Pursuant to 18 AAC 75.100 under authority of AS 46.03.020 (!0) (A) a~d AS 46.03.775~ this letter is written confirmation of the telephone report made by Mr. D. R. Amonsen to Mr. Paul Bateman of your office at 14:51 AST on November 2, 1978. Below is the information required by 18 ACC 75.110. 1, Date and time of discharge - 13:30 AST, November 2, 1978. · · · 5. A DIVISION OF EXXON CORPORATIOI'~ Location of the discharge - Approximately 1/4 mile southwest of Exxon's Duck Island Unit #i drill site. The drill site location is defined as: latitude ~ ..... i!~ 70°19'00.127", longitude = 147051'46.800". ':':~ Person or persons causing or responsible for'the discharge - None. Spill was due to mechanicai failure of helicopter sling loading equipment. Type(s) and amount(s) of hazardous substance(s) discharged - Estimated 2 quarts motor oil, 2 gallons Ethylene Glycol/water mixture and 1/2 gallon diesel fuel. Cause of discharge - An oilfield compressor was dropped 200' when the sling load hook release mechanism on the helicopter malfunctioned. The compressor was demolished upon impact creating a ~. 4' x 6' hole in the sea ice Mr. Doug Lowery Page Two November 15, 1978 · Environmental damage caused by the discharge to the extent ascertainable - Undetermined. Contaminates leaked to the ocean through the hole created in the sea ice. · Cleaning actions undertaken - Floating oil on the water was cleaned up by use of absorbent materials. Contaminated snow and ice recovered and placed in containers. All dropped equipment was retrieved off of the ice. · Location and method of ultimate disposal of the hazardous substance and contaminated clean-up materials~ including date of disposal - The contaminated snow, ice, and absorbent materials has been placed in 55 gallon drums in the drill site burn pit pending future disposal by burning during testing operations. · Actions taken to prevent recurrence of the discharge - The sling load release mechanism was inspected and will be routinely inspected prior to commencing future sling loading operations. If you require any additional information, please contact Mr. R. P. Bright of the Exxon Anchorage office at 907/276-4552. Very truly yoUrs, DRA:RGD:jrh 240-910 Division of Oil, and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99504 R. K. Riddle STATE C~- ALASKA OIL AND GAS CONSERVATION COMMITTEE REPORT Wildcat :2. 1'¢,.%¥I!~. OF Exxon Corporation ADDRESS OF Pouch 6601; Anchorage, Ak. LOCA~ON OF Surface' 700' NSL & 800' TllN-R17E, UPM, BHL 50-029-20280 LEASE DESiGnATION kND ~D~ ~7502 99502 (Proposed)' WEL of Sec. 8, North Slope, Alaska 500' NSL & 800' WEL of Sec. 5, TllN-R17E, UPM, North Slope, Alaska Duck Island 9 %VELL No. 1 10 FfF~D Y~nlD POOL. OR Wildcat o~ Sec. 5, TllN,R1 78-68 I3. REPORT TOTAL DEP~ AT F_~ND OF MONT'H. CHA~NGES IN HOLE SIZE. CASING A~NrD CE-?¢IFJ~T!NG JOBS INCLUDING DE!~TH SET A.'ql~ VOLIi1V[F~ USED. pF_2R~OFLa. TIOI~S. T~v~STS .~-D Iq~ESUL'FS FISHIN'G JO]Pa~ JUnK iN HOLE AND SIDE-ii~R~,CKED HOLE A~X,'D A~%'Y O~4~;Fl SIGNIFICA2qT CHA~GE,5 IN HOLE CONDITIONS During the month liners were installed in the fuel, reserve and effluent pits and an ice seal was formed over the island by spraying the gravel pad with sea water. A one foot gravel berm was placed around the island, general rig up was completed and the well was spudded at ~ hours October 23, 1978. A 12~" conductor hole was drilled to 1050' and Dual Induction and Long Spaced Sonic logs were run. The conductor hole was then opened up to 24" and 20" casing was set at out the fl test was p end of the mud. 672' and cemented with 2400 sacks permafrost. After drilling oat collar, 20' of cement and float shoe, a pressure integrity erformed to 12.6 ppg EMW. Leak off did not occur. At the month we are drilling at 2707' with a 12~" bit and 9.4 ppg CONFIDENTIAL 14. I hereby certify~//;,~ ~%h~A~lhe foregoing K~ t~e ~ ~ Acreage & Well Eval- .... .= ....... - - . ......d.- (/- ,~-~ - · ..... - .......... -=- ...................-- - all and gas conlervation commtffee by the lS~ of the succ~dingmen~.u~ls~ nf~etwi~ dlr~cfed, Hoyle H, tlamilton~ Director Lonnie C. Smith ~,/c.~.~.)/'~ Chief Petroleum Engineer Harold R. Hawkins Petroleum Inspector~'~ff DEPT, OF NA.TUg~tL RESOURCES DIV, OF OIL & GAS CONSERVATIOn' November 14, 1978 Witness BOP Test Exxon t s Duck Island No. 1 Sec 5, TilN, R17E, UM Permit No. 78-68 11/5/78 I left Anchorage at 8:00 AM via Wien Air to Prudhoe Bay, ar- riving in Prudhoe at 10:25 AM. Bill. Van Alen of Division of Oil and Gas Conservation phoned me to inform me that Exxon was ready for BOP tests, I called Exxon at Duck Island and talked to Harry Thompson, Assistant to the Supervisor Wyle Eckols to confirm this. ~en I arrived at the location Duck Island No. 1,-another problem had surfaced. Exxon decided to deepen the cellar so that the casing head would be 5 feet below the mud line. I,~en this was being done, sea water started coming in, Pumps were set up. 11/6/78 Digging out cellar and pumping water out still in progress. 11/7/78 Digging cellar out and casing head put on by 8:00 PM, nippling up BOPs started. 11/8/78 7:55 PM. BOP tests started. Wyle Eckols was the supe~¢isor for Exxon on the tests. The flanges on the riser next to the spool above the casing head leaked, also the graylock flange leaked below the lower rams. The stack had to be pulled to replace a ring seal. Upper and lower kelly valves were tested next and failed, Time 11:45 PM, 11/9/78 7:40 AM. Tests resumed. The annular preventer, inside kill valve and four low pressure valves on down stream side of choke manifold were all closed and were tested to 3000 PSI. Next to be tested was the upper pipe rams, but a bull plug on the spool below the riser leaked and was repaired. Also a s,~tch on the accumulator was malfunctioning and pressure was being lost on the control lines, the switch was worked on and accumulator pressure was back to no~nnal, While BOP's were being worked, Exxon's manager, Bob Bright and John Jackson, Superintendent, Wyle Eckols, Supervisor and Jim Dubose, Engineer and I had a meeting on how to solve the problem of sea water intruding into the cellar. The problem was discussed at some length. I agreed with them to let the cellar fill up to sea level until the water in the cellar was static, then grout the cellar with gel and barite, and see if this wouldn't seal the intrusion of the sea water. Gel and bari~e,,~:ware~_thgp added to the cellar, which was filled with water to three:feet above force the gel and barite mix into the fractures, and was observe~far 24 hours. Insp. Exxon's Duck Is. U. #1 2 November 14, 1978 In the meantime, BOP tests were ready to resume. Separate tests on eight valves, one superchoke and one inside kill valve were tested to 5000 PSI with the upper pipe rams closed. A bar was put into the check valve to disable it. The outside kill valve and the outside choke (!ICR valve) were tested with the upper pipe rams still closed to 5000 PSI. On the first test, the outside kill valve leaked and was found to have a nut inside the valve and wouldn't test, The next test was the check valve and the inside choke valve with upper pipe rams still closed to 5000 PSI. The lower pipe rams didn't hold on the first test, were replaced and tested to 5000 PSI. I witnessed a performance test on the accumu- lator, with all power shut off. The upper and lower pipe rams, HCR valve and annular preventer were closed at the same time. 1250 PSI remained on the master gauge indicating the accumulator to be in very good shape with no leaks in the line or preventers. The master gauge read 2750 PSI. The manifold gauge read 1500 PSI before the performance test. The test stem was pulled and the blind rams tested to 5000 PSI. There was a dart type safety valve and ball type safety valve on the floor but both had to be replaced, because they were washed out. The location had quite a bit of debris, but during my stay was cleaned up and in very good shape. The fuel tanks were steel but well bermed and lined with herculite.. There were three steel mud pits inside the rig enclosure. Also, the open pit outside was lined with plastic to be used only in emergencies. The well sign was up with all data okay. About 5 gallons of hydraulic oil ran out of the ac~amulator from being overfilled, but was cleaned up satisfactory. 11/10/78 The upper kelly, the lower kelly and two floor valves arrived on location and I observed them tested to 5000 PSI each. BOP tests were finally tested satisfactorily. In the meantime, the water level had dropped in the cellar about one and a half feet indicating that the leak was not sealed off, at 4:00 PM. A decision was made to mix another batch of gel and barite and pump it into the cellar, as the leak showed signs of partially sealing off with the first grouting. The water level was observed and recorded every half hour. 11/10/78 ~ith sea level in cellar at 6'9" from top of cellar, water was pumped into the cellar to put pressure on gel and barite, the level of water finally quit dropping and stayed at 39 1/4 in~'~from top of cellar from 6:40 AM to 2:30 PM, indicating the leak had finally ~been sealed. I called Lonnie Smith, Chief Engineer for the State division of Oil and Gas Conservation and informed him of the progress of the work. Th~s~wa~ at 9:30 AM 11/11/78. I explained to Lonnie that/the gel and barite mix appeared to have stopped the intrusion of water.~re was over three. feet of water pumped above sea level into the cellar t~,help push seal~ ant into the fractures. The water level stayed fifty twg {~~above sea level, without falling, indicating intrumion of sea wate~~$~- ped. I also informed Lonnie that I requested that Exxon put a the cellar and leave water level at one foot above sea level at all times during drilling and purap out excess fluid only. Exxon agreed to install an automatic pump and a floa~ control switch Insp. Exxon's Duck Is. U. #1 3 November 14, 1978 within five days. In the meantime, a manual pump was installed with a man assigned to operate it and keep one half hour surveillance until the automatic pump can be installed. They will also record the observa- tions. Drilling was held up until Lonnie Smith, Chief Petroleum Engineer gave his approval for them to go ~ead with the drilling as long as they carried out my stipulations. Time 9:40 ~M. I made out a field report and gave one copy to Wyle Eckols, supervisor on site. One copy was to be sent to John Jackson, Superintendent. In summary: I witnessed the BOP tests and cellar repair problems on Exxon's Duck Island Unit No. 1 well. When I left, the BOP and related equipment along with the sea water intrusion into the cellar was in very good shape. LCS/HRH:emi At--t, 9:20AM,~ ~29, 1978: I called John J~, Super~~t for Exxon. ~ told ~ that ~ .au~tic pump an~:..~eve]ar was installed.Sunday 11/12/78 and that ~he no water was leaking in, indi~ that th~ barite and gel is still ho/ding ~ th~ bot~ of ~ ~llar. Drlg. Permit No. 7~'~'~ Operator ~?~X..)( ()~ ~! ~ Al,' ~a Oil and Gas Conservation Commif ,e Field Inspection Report Well/Platfm Secj' T///~' R/~,:, ~ H ,Represented by~v~ E~.~Name & Number.' ~ .' , Satisfactory ~y. pe Inspection~ SatisFactory Type In.t~pection Yes No Item~) Location ,General Yes No Item ~) BOPE Tests 1. Well Sign (~) ( ) (~) () (x) () (x) () () () () () () 2. General Housekeeping 3. Reserve Pit-(X)open( '}filled 4. Rig ( ) Sa. fet~ Valve Tests 5. Surface-No. Wells 6. Subsurface-No. Wells ( ) Well Test Data 7. Well Nos. , , , (~) () (X) () (x) () () (X! () () () (~) () 15. i~as'ing set @~!,7 16 Te--e~Ft f'lui.~-(~wtr.--~--~ )mud ( ) oil 17 Master Hyd.'Control Sys.- .psig. 18. N2 btls.:~0 ,' ~,_2~&~,~.51~_ psig~ 19 Remote Controls 20 Drilling spool-__]~~ "outlets 21 Kill Line-O~) Check valve .- 2, 22 Choke Flowline ~) HCR valve 23 Choke Manifold No. valvs/~_flQs~_~__ ( ) ( ) 8. Hrs. obser (~) ( ) 24 Chokes-(~)Remote( )Pos.(~Adj ( ) ( ) 9. BS&W ,- i ','~'-'~ (~) ( ) 25 Test Plu~-~)Wellhd( )cso( )none ( ) ( ) lO. G[.,B~ls.~- ~, ,_ ~,~ '~ '~?-'?~ ..... ~.,.)~ 26 Annular ~rev'enter,~ps~ k ) final Abandonment (~)' ("):~' .... ~7~. ~lind Rams~O~siq - ' () () ll. P~~~ (~) ()28::.!~Pipe Rams~~psi~ ( ) ( ) 12. Water well-( )capped( )plugued (~ ( ) 29"~Kelly ~ KeilY'~ck~opsiq ( ) ( ) 13. Clean-up ~ (~) ( ) 30,."lower ,~elly valve~~siq' ( ) ( ) 14. Pad leveled (~) ( ) 31., Safety Floor valv6~-(~BV ~)DartS~ Total inspection observation timel~ hrs/days Total .numb~r~'leaks and/or equip, failures cc: LT~a ~r~sa~-~otify in da~s or when ~eady Inspected by HAM~)~ .~ Ala.,~,a Oil and Gas Conservation Commi'~ .e Field Inspection Report Drlg. Permit No.j;~'f.-~b" Well/Platfm Opera tor_~,~ gl ~,c~ ~/4 ' Represented byujvi.2~ Satisfactory Type Inspection Yes No Item ( ) Location,General ( ) (,~:.) () ..... () .() () () () () () () () () () () () () () () () () () l. Well Sign 2. General Housekeeping 3. Reserve Pit-( )open( )filled 4. Rig ( ) Safety Valve Tests 5. Surface-No. Wells 6. Subsurface-No. Wells ( ) Well Test Data 7. Well Nos. , , , 8. Hrs. obser , , , 9. BS&W ~,~, .,. lO. Gr. Bbls. ( ) Final Abandonment ll. P&A Marker Satisfactory Type InsF)ection Yes No Item ( ) BOPE Tests () () () () () () () () () () () () () () () () () () () () () () ( ),- (,.) () () () () 15. "Casing set g 16. Test f'luid-( )wtr.--7--~ )mud ( ) oil 17. Master Hyd. Control Sys.- psi9 18. N2 btls , , , psig 19 Remote ~ontrol~ -- --' 20 Drilling spool- "outlets 21 Kill Line-( ) Check valve 22 Choke Flowline ( ) HCR valve 23 Choke Manifold No. valvs flqs 24 Chokes-( )Remote( )Pos.(-~dj. 25 Test Plug-( )~tellhd( )csg( )none ~6,. Annular Preventer,_~psiq 27~ Blind Rams, psig 28' Pipe Rams psig ( ) ( ) 12. Water well-( )capped( )plugged ( ) ( ) 29.'Kelly & Kelly-cock psig ( ) ( ) 13. Clean-up ( ) ( ) 30. Lower Kelly valve psig ( ) ( ) 14. Pad leveled ( ) (.) 31. Safety Floor valves-( )BV ( )Dart Total inspection observation time hrs/days Total number leaks and/or equip, failures Remarks /xfl,j'jo~'x'T/~A, O l~ L,A TEI'~ ~ L:~~ ~:ZZ~ ~~ ,'S~~ ~T~ ~ ,~' .. cc. O~w ~m~z~ubo~ify in - days o> w~en ~eady ~ns~eC~6~- bY'~m~Z~ ' D~t.e~i/z//~ ~ E ,,ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC ~IVISION Mr. Lonnie C. Smith Chief Petroleum Engineer Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 November 6, 1978 Re' Exxon No. 1 Duck Permit No. 78-68 Dear Mr. Smith' Attached herewith is the Subsequent Report of the operations performed by Exxon under Sundry Notice filed with you October 5, 1978. In addition to the required duplicate copies a third is also included which we ask that you return for our file in the event of your approval. Yours very truly, Robert K. Riddle RKR'et attachment cc' Mr. R. P. Bright w/encl. Mr. Harry Brown w/enclo. A DIVISION OF EXXON CORPORATION Forrr- ' J-403 REV -'~ 0-73 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA 01L AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to ~leepen Use "APPLICATION FOR PERMIT---" for such proposals.) O,L I--'1 GAS I--'1 WELLi i WELL i i OTHER Wildcat NAME OF OPERATOR Exxon Corporation 3. ADDRESS OF OPERATOR P. O. Box 2180, Houston, Texas 77001 4. LOCATION Of WELL At surface 700' NSL & 800' W~L of Sec. 500' NSL & 800' WEL of Sec. 8, TllN, R17E, UM 5, TllN, R17E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 3 ft. water depth at surface location 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20280 6. LEASE DESIGNATION AND SERIAL NO. ADL 47505 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Duck Island Unit 9. WELL NO. No. i 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., T., R., M., (BOTTOM HOLEOBJECTIVE) Sec. 5, TllN, R17E 12. PERMIT NO. 78-68 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (oth.n . .~..erat ions und. Sund. Not. 10-5-78. (NOTE-' Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all Pertinent ~letalls, and give pertinent dates, including estimated date of starting any proposed work. Spud 2200 hrs, 10-23-78. Drilled 12¼" hole to 1050'. From2030 hours, 10-24-78, to 0700 hours, 10-25-78, ran logs. At 2030 hours, 10-25-78, con~nenced opening 12¼" hole to 24" to depth of 1050'. At 1930 hours, 10-26-78, attempted to run 20" 94# H-40 STC casing to 1000' but hit bridge at 672'. After consultation with John Miller on 10-27-78, attempted to pull up 20" casing to proceed; stuck casing @ 672', 2200 hours, 10-27-78. Cemented in place to surface w/2400 sx of Permafrost Cement. Cementing completed 1030 hours, 10-28-78. 16. I hereby certify that the foregoing is true and correct SIGNED ~~ - TITLE Drilling Manager i OATEiNovember 1, 1978 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY-' T IT LE. DATE See Instructions On Reverse Side COMPANffl U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 907/276-4552 November 3, 1978 Alaska Department of Environmental Conservation P.O. Box 1601 Fairbanks, Alaska 99707 Attn: Mr. Doug Lowery Dear Sir: A fuel oil spill occurred on ~xxon'.. s Duck Island Unit #1 drill site location at 7:30 pm ADT, October 27, 197~ Pursuant to 18 AAC 75.100 under authority of AS 46.03.020 (10) (A) and AS 46.03.755, this letter constitutes written confirma- tion of the telephone report made by Mr. J. W. Jackson to the Department of Environmental Conservation at 9:41 pm ADT, October 22, 1978. The report was taken by a tape recording machine. The information required by 18 AAC 75.110 follows: le Date and time of discharge: October 27, 1978; 7:30 pm ADT. · Location of the discharge: Exxon's Duck Island Unit #1 drill site location (latitude = 70°19'00 127" longitude = 147°51'46.800"). · Persons causing or responsible for discharge: Discharge was c=usea by equipment malfunction. None. e Type and amount of discharge: fuel, five gallons. Arctic grade diesel~ · · Cause of discharge: Fuel transfer hose fitting disconnected during fuel transfer operations. Environmental damage: No environmental damage occUrred as a result of the spill. 100% of the spilled fuel was recovered. ~ Cleanup actions undertaken: The spilled fuel was recovered with absorbent material and by picking up contaminated snow and ice. DIVISION OF EXXON CORPORATION Alaska Department of Environmental Conservation Page Two Location, method and date of disposal of discharge and cleanup material: The contaminated snow, ice, and absorbent material is being held on location pending disposal instruction from the DEC. e Action taken to prevent recurrence: The fuel transfer hose fittings will be wired in the locked position prior to beginning transfer operations and the transfer pump will be located within the secondary containment berm, which surrounds the fuel storage tanks. Please contact Mr. Ro P. Bright at Exxon's Anchorage Office (907/276-4552) for any additional information you may require. Very truly yours, RGD:jrh 240-910 cc: Mr. Hoyle Hamilton Divison of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99504 ~~ 6, 1978 R. L. Bottom, District Manager Exploration ~. ~f~ho~e/Alaska Divisic~ ~ ~, U.S.A. P~.h 6601 Anchorage, ~ 99502 It !~s been brought to my att~ntic~ that Exx~m has not ccmplied with field ~ to utilize a prop~_r diverter s~ while drilling surfaoe ~hole at ~ ~ Island UDit No. I exploratory ~11. This occured in spite of ~ ~ll's locatic~ ~ an env~tally sensitiva area and this division's efforts to p~t it. Sin~e I consi~ this a serious safety rule, I researched ~ ~ ~ up to your failure to ~ly with it to see ~ this cottld have been avoided. By yo%~ letter of Deo~4~r 19, 1977 (c~py attached) you amended your Permit to ~ill or 1~ (~ 10-401) to ccr~ply with the for a diverter system %Rtile drilling the surface hole for the captic~ed well. ~ purpose of this requirement and the system design to achieve rig ~cti~ in ~ event of abnormal flc~ ~o ~he surface frcm a ~llow pressured formation is set out in !~.~]~ 4 (b) c~ page 9 of Con- se~mrati~n ~ 5%0. 137 (~ attached). Your Decem%be~ 19, 1977 modifi- cation to ~ly with C.O. }~o 137 fo!lo~ discussions of the subject between L~a~kie Smith of this divisic~ and, ~'s John Glaeser. On October 6, 1978 ~, approved, anmndmants to your form 10-401 cna Sund~I N~tice (form 10-403, ~ attached), including item. 3, changing ~he diver,_er piping size. SLnoe y(~r atta~t 4 drawing st .oppec_ ~ a feet fron ~he w~ll casings, it was not evident to t~ that your intemtion v~ to elimLnate one of the valved divert~r !~nes to a pit and. thereby e!i~Jnate rig protsction in ~ event of a change i.n wind (~irection at the tJg~ of on e~.~erg~acif. In any e~nt, any confusion ~~en E~e~n o~. ~is ~ivisi~ sho~.d hav~ I~ r~ on ~~ 23, 1978. ~ ~hat ~y o~ ~~or, H~old H~k~s v~.si~ ~ ~~ c~z!!~ ~ v~ll while ri~'~o' r~ was pr~ess. I~ v~l ~e ~-md~~ ~mr~ sygt~:~ ~s~nlla~on, dlrect~. cP~g~ ~ ad,eve ~1~ v~J'~ C.O. ~. 137 field ~es, ~nd e_~plaLned R. L. ~, District Manac3er -2- ~ 6, 1978 Supervisor~ ~. ~ a~ to the change and ~ the pipe and valv~s to install ~ 60 foot long alternate outlet, ~ ~y Mr. Haw~dns, which ~u]~ provide safe div~_~sicm of well effluent regardless of wind d/rection. Mr. ~ provi~ copies to Mr. Ashwood and John Jackson of ~s Field Tr~ ~ which included written direction to notify this office within five days, or by October 28, 1978, that tb~ This office did ~ recei%~ notificaticm of ccmlplianoe and Mr. Hawkins ~ Mr. J~ at the ~ Island drill site ou November 1, 1978. ch~ng~ pursuant to ~ ~~al of the Fc~n 10-403 cn Oct~ 6, 1978. John ~ller ~ ~ Mr. Jackson at 9:30 AM c~ the sar~ day and ~if~ that ~ w~s ~ng the hole to 2700 feet preparatory to ~muting ~ 13 3/8" ~orface casLng. ~. Miller tried to impress the ~ of a proper div~er ~tem cm ~. Jackscm. ;~d our inspector not visi*~d your drilling operat/cm durir~ rigging up and discov~-ed ~ apparent mimmderstand/ng in the ap~mm~d diverter system design, ~ ~tiance with C.O. No. 137 could be unders~. ~, aftmr an on site directive by our ir~r and verbal accep- tance by your ~pervisor, I fir~ no excuse for not making the ~ piping chancre withouwc first cc~~ this office. it is not our intertron to ~ unreasonable ~r impracticable demands cn operators and I don't think ~ did in this case. t'~e do insist on ~ plJmnc~ with ~ regula~ ~nd with remscmable directives ~ frc~ authorized rep~tatives of this division. If you questic~ a regulation or directive ~ a specific case, myself or my staff can be con~ to discuss th~ prob~. Should a violation of this type occur in the Dature it will pzubably result in a n~e~ penalty being imposed.~~ S~ly, Hoyle H. ~11 D. J(x~es, Manager EXXC~ Company, U.S.A. P.O. Box 2180 Houston, T~_xas 77001 FILES November 6, 1978 Petroleum En~ Duck Island Unit F~xcn - Oil Spill Becei~ a call frc~ Doug Amc~sen 11/02/78. He informed me about twenty gallons of gasoline had been spilled on location at appr~tely 9:08 ~, 11/01/78. A fuel line oD_ the storage tank had been imp~ly stored and a valve not closed correctly. Fluid ~s recovered using absorbent pads with 100% recovery estimated. COMPANY. U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 907/276-4552 November 3, 1978 Alaska Department of Environmental Conservation P.O. Box 1601 Fairbanks, Alaska 99707 Attn: Mr. Doug Lowery Dear Sir: A hydraulic oil spill occurred on Exxon's Duck Island Unit #1 drill site location at 3:00 am AST, October 30~-I~978'% Pursuant to 18 AAC 75.100 under authority of AS 46.03.020 (10) (A) and AS 46.03.755, this letter constitutes written confirma- tion of the telephone report made by Mr. J. W. Jackson to Mr. John Jansen of the Department of Environmental Conservation at 10:46 am AST, October 30, 1978. The information required by 18 AAC 75.110 follows: Ze Date and time of discharge: October 30, 1978; 3:00 am AST· · Loca'Uion of the discharge: Exxon's Duck Island Unit #1 drill site location (latitude = 70°19'00.127'', longitude = 147°51'46.800"). · Persons causing or responsible for discharge: None. Spill was caused when a hydraulic line on rolligon unit burst. · Type and amount of discharge: Hydraulic oil; approxi- mately three gallons. · Cause of discharge: Hydraulic control line on rolligon vehicle burst. · Environmental damage: No environmental damage was observed as a result of the spill. 100% of the spilled oil was recovered. · Cleanup actions undertaken: The spilled oil was re- covered with absorbent material and by picking up contaminated snow and ice. RECEIVED A DIVISION OF EXXON CORPORATION · OMl~m ~ Q~I and knchara~e Alaska Department of Environmental Conservation Page Two Location, method and date of disposal'of discharge and cleanup material: The contaminated snow, ice, and absorbent material were placed in plastic bags and then into a 55 gallon drum, which is being stored on location pending final disposal directions from the DEC. e Action taken to prevent recurrence: The broken hydraulic line was replaced with a new line. Please contact me at 907/276-4552 for any additional information you may require. Very truly yours, RGD:jrh 240-910 cc: Mr. Hoyle Hamilton Division of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99504 DEP~ OF ~ RE~ DMSION OF OIL & C~%S CONSERVATI~ Nov~nber 2, ~78 William Van ~~ Petroleun C~olog~st ~tinor Oil Spill Duck Island No. 1 Sec. 8-T!]N-R17E-UPM (Surface) about 1/4 mile due south of the subject locatic~ at 1:30 PM, November 2, 1978. The spill occurred when an oil field ccmpressor being carried in a sling load beneath a helicopter was accidantly released and fell about 200 feet c~to the Beaufort Sea ice. The release was due to a malf%mction of the sl/ng load mechanism. The cc~TA~or was demolished upon impact and the skid fran~ cut a 4' x 6' hole in the sea ice. The ice at that locatic~ ~as about 12" thick. The fluids spilled ~re about two quarts of e~gine oil, two gall~ of ethylene glycol and 1/2 gallon of diesel. Most of these fluids went into the w~ter. No parts of the co,presser were lost. At the ~ of Mr. ~'s 3:05 PM call, Exxon ~ were swabbing up the oil c~ the water. The plan is to .break out the ice around the ~Deriphery of the bole and ~ any oil that might have. ~ere ~re no injuries. The spill has also been r~~ tO EPA and the NEC. FILES DEP~ OF ~~ RF..~~ DMSIC~ CF OIL & GAS (~NSERVATIC~ November 2, 1978 William Vmn ~le~z~ Petroleum Geol~~ Mu~ Spin Duck Island No. 1 Sec. 8-TllN-R17E-UPM (Surface) Doug ~sen, Exxon, called this date to report a spill of approxgmtely 15 barrels of spud mud on the drill pad at the subject well site. Mr. Am~ms~-n ~eported t~hat the spill occurred at 1:25 PM, November 2, 1978 and that the spilled fluid consisted of gel water slurry, X-C polymer, caustic and ~cals. ~here was no oil in the mud. The spill occurred when a valve in a Ht~'~O unit was inaptly opened and the n~d emptied out onto the pad from a flexible hose. At 3:01 PM, the ~ of Mr.. ~'s call, the mud was being scooped up. off the ice. lton Lonnie C. Smith Chief Petroleum Harold R. ' ~,~vember 1, 1978 Inspection of Diverter and. Location, F~xon Oil Company 5/Tlm/m7EA ~lT~it #78-68 Duck Island Unit 81 10/23/78 I left Anchorage by Wien Aires ~ by AN~) to Pn6hoe Bay at 8:50 AM, I arrived in Prudhoe Bay 10:30 AM. I arrived at ARCO base camp where I was to stay at 10:45 PM. I mint Roy Adams, Supervisor at Flc~ Station ~2 for AI~ZO. ~ told me testing of safety valves would be delal~d until the next day because the operator ~mt was supposed to be testing valves on DS-4 was sick and was being sent hcme. I tele- phoned Lonnie Smith~ Chief Petroleum Engineer and told him the situa- ticn. I the~ telephoned Gordon Ashwood, Drilling For~n3n for Exxon and infcrmmd him I was available to inspect their diverter system and loca- tion for standards set for t~m to oonfozm to. C~rdcn Ashwood said that eu~day would be fJ~ne. ANZO's Security Guards took me to Exxc~'s office. Frc~a there, I went to Duck Island #1, Exxon's location, by Skycrane I n~t C~)rdc~ ~ and proceeded cn the inspection. The fuel storage unit had a capacity of 112,000 gallcns, the tank was sitting in a pit six feet in depth and w~ll b~nv~d. The gravel pit had been saturated with gel and ~ ~ (covered) with herculite with no open seams. (Photo ~1) A fu~l tank of about five to six thousand gallons for the rig ~s also in a ~ pit ~ %zith herculite. (PDDto ~.2) A reserve pit lined with hea~ vi~ ~ms abotfc 40' x20 ' wide by about 15 ' deep, northeast of rig. (Photo ~4) This w~s whare the single dior 1/ne ~s installed. After inspectic~, I told Gordon As~ that the diverter s~ did not conform to the rules. There was only one pipe frc~ the blowout ~t to the reserve pit. (Photo ~4) At the time of my visit, the wind was blowing directly frcm the reserve pit where ~. diverter system vented, ~ toward ~/%e rig and. would have been a fire hazard if ~i~ be/ng%~nted. I /nfonTed Gordc~ Ashwood that frc~ the 6 5/8 inch pipe at the pit, another 6 5/8 inch div~er piFe had to be attached 180 degrees about 60 feet long to the lee side or to th~ east of the rig, with t%~ more valves added, for diversion of flow. .Gordon agreed I was right 'and orde~nsd the pipe and valves frcm Anchorage ~,~le I was there. I told him that i found all other probl~s, fuel storage and fuel tank for rig plus pit to be satisfactory. The location was in very good shape. ~ Is~ U~it ~1~ Permit ~78-68 November 1, 1978 The rig was clean, and th~ well sign was up. The inspection took 1.5 h~s. ~ are t~ee steel mud tanks enclosed ~ the rig. .Pictures will be attached. I ~nspec~ed the fuel storage area and fuel tank for rig area and pits plus ~ locatic~ ~ .fu]~, and found. ~ to be satisfactory. Gc~dc~ Ashwoc~ has fi~ days to attach a 60 foot long, 6 5/8 inch line %o the exi~ di~ pipe at pit at 180 ~ to lee side, and then call our divisi~ that ~his is dc~e. 11/01/78 I tele~ Ex,oh's drill site at Duck Island, and talked to Jc~m Jack~ Dri~ Superintendent. The purpose of the call was to find ~ if ~ (~) had conf~ to my directions on installing the di~ system correctly. John Jackson told me they had not. He said t~ (Exxon) l~ad a supp~t frc~ the Sta%e that ex~used the~ frc~ ~ the ~ I direr. I inf~ John C. Miller, Acting Chief Petroleum ~gineer about the Ex~nn Representative's reasons for not ccnfor- ming to i~ directi~. There ~ill be a followup letter for nc~~~ce. At~c~t: A/S " .:' Alaska 1 and Gas Conservation Committee ,. ,.. Field Inspection Report D~lg. Permit No.~.T~' , Well/Platfm Sec~ Operator ,/~', .~'O~? Represented by~OR~J/~.,3'~//~ame & Number~/jF~___~~~ Satisfactory Type Inspection Satisfactory Type Inspection Yes No Item ~ Location,General Yes No Item ( ) BOPE Tests ( ) 1. Well Sign ( ) ( ) 15 "Casinq set ~ ( ) 2. General Housekeepinm ( ) ( ) 16 (~) ( ) ~. Reserve Pit-~(~)open( )filled ( ) ( ) 17 ~ ( ) 4. Rig ( ) ( ) 18 ( ) Safety Valve Tests ( ) ( ) 5. Surface-No. Wells__ ( ) ( ) 6. Subsurface-No. Wells___ ( ) Well Test Data ( ) ( ) 7. Well Nos.__, __,__, ( ) ( ) 8. Hrs. obser , , , ( ) ( ) 9. BS&W , , , __ ( ) ( ) 10. Gr. B~ls. , , , ( ) Fina~andonment ( ) ( ) 11. P&A Marker ( ) ( ) 1Z. Water well-( )capped( )plugged () () 19 () () 20 () () 21 () ( ) 22 TesL fluid-( )wtr.-----C )mud ( ) oil Master Hyd. Control Sys.- psim ~'!2 btls. , __, , psi.q Remote Controls Drillinm spool-~"outlets Kill Line-( ) Check valve Choke Flowline ( ) HCR valve ( ) ( ) 23 Choke ~!anifold No. valvs flms .... ) ( ) 24 Chokes.-( )Remote( )Pos.(-~dj. ) ( ) 25. Test Plum-( )Wellhd( )cs.q( )none ) ( ) 26. Annular Preventer,~__?sim ~'~ !? 28. 'PiPe Ram~:, ~ psiq · ), ( ) 29. Kelly'& Kel:ly-cock psig ( ) ( ) 13. Clean-up .) i ) 30. Lower Kel, ly':valve psio ( ) ( ) la,. Pad leveled ..) ( ) 31 Safety Fllo'Or valves--2(-'-)-BV '~ )Dart Total inspection observation time /~_~[j~)/days To~t!~l numb~r .l.~a,~k.~; Remarks ~A pF ~d ~ ~ ~~/~ or 0 /. ,/ E~OA/ 0//_ / ,P G_ ? ££ ' !~/~ · . ~,~ - · · · · · ! ? · E ON COMPANY, U.S.A. POUCH 6601e ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION October 30, 1978 Re' SPCC Plan Exxon No. 1 Duck Permit No. 78-68 Mr. Hoyle H. Hamilton Chairman, Oil & Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hamilton' Attached is a revised Page 2 for the Duck Island Unit #1 SPCC Plan. This is the management approval page. This revision is necessary because the plan previously transmitted was approved by a Parker Drilling Company employee for Mr. A. T. Cooper Jr., Parker's Operation Manager, This page has been signed by Mr. Cooper. Please replace Page 2 in the SPCC Plan transmitted to you on October 4, 1978. Very truly yours, Robert K, Riddle RKR' et attachment cc' Mr. Thomas Cook w/attachment Mr. Douglas Lowery w/attachment A DIVISION OF EXXON CORPORATION ~PCC PLAN FOR PARK! DRILLING CO[IPANY RIG NO. CONTRACTED TO EXXO'~.. U.S.A. F. OIL SPILL HISTORY This facility experienced no reportable oil spill prior to January 10, 1974 (effective date of 40 CFR, Part 112). Forms are included in this Plan for future use, if needed, for reporting spill events, as Attachment No. 1. G. MANAGEMENT APPROVAL This SPCC Plan (with revisions) will be implemented as herein described. Parker Drilling Company approves this SPCC Plan; and .agrees to meet the requirements of 40 CFR, Part 112; agreeing to accept their respective repsonsibilities under these regulations and as specified by contracts with the Government of the United States of America. o Name: Title: Name: Title-. PARKER DRILLING COMPANY A. T. Cooper, Jr. Operations Manager Signature: Date: EXXON U.S.A. Signature: Date: ENGINEERING CERTIFICATION I hereby certify that I am familiar with the provisions of 40 CFR, Part 112; attest that this SPCC Plan has been prepared in accordance with good engineering practies. This certifi- cation is made under the terms of the agreement between the IADC and the EPA and interpretations of the Regulations and the Agreement by the IADC. ~ ,.) .- .~ ;.~, ,. ~ Signature: ,-~.,,~ .... ~ .... r/ ~/ 3f , Registration N.: 1750-E -~- ~ -' - ~. ~:- ~ [~ State: Alaska ...?. Date: STATE of ALASKA DEPAR~ OF NATURAL RESO~S Division of Oil and Gas Conservation TO: [-- FROM: The Files Wzlliam Van Alen~f Petroleum GeologiSt--- DATE: FILE NO: TELEPHONE NO: SUBJECT: October 30, 1978 Minor Oil Spill Exxon Duck Island No. 1 Surf (8-11-17, UPM) At 11:10 AM, Monday, October 20, 1978, John Jackson of Exxon reported to the State Division of Oil and Gas Conservation via phone call to William Van Alen that there had been a spill of approximately 3 gallons of hydraulic fluid at the subject well site. Mr. Jackson reported that the spill occurred at 3:00 AM, Monday, October 30, 1978 on the frozen surface of the gravel drilling pad. The spill occurred frc~ a broken hydraulic line between the hydraulic pump and the cab controls in a Rollogon unit. There was no movement of the spilled fluid. The temperature was 0© F and the wind was 340© at 8 knots. The spill was 100% recovered and there was no environmental damage. The spilled fluid was picked up with absorbent material and the contaminated snow and ice were picked up and placed in ~ plastic bags and put in a 55 gallon drum. The residue will be burned in an incinerator on location. DEC has given approval for this burning. DEPARTmenT OF NATURAL EES(N3t~CES Divisic~ of Oil and Gas Cca%~_rvatic~ The Files Octd0er 30, 1978 Minor Oil Spill Exxon Duck Island No. 1 ~Surf (8-1I-i7, "UPM) .... At 10:00 PM, Friday, October 27, 1978, John Jackson of Exxon reported to the State Division of Oil and Gas Conservation via phone call to William Van Alert that there ,had been a spill of appr~tely 5 gallons of diesel oil at the subject ,.~11 site. Mr. Jackson reported that the spill occurred at 7:30 PM, ~ 27, 1978 on tb~ frozen surface on the gravel drill/ng~pad. There was no ~t of the spilled, oil. Air. tempera~are was -8u F, the w=~nd was calm and visibility was 12 miles. The spill occurred in the course of transferring~ fuel frcm a Rollogc~ to t_he rig fuel tanks. The transfer lines had been pressure tested to 50 pounds prior to pump~. When pumping started, a cam-loc fitting sprung loose, s*~g the spill. The pumping was ~ately shut The spill was ~ately mopped up with absofoent material. The ice and snow on which the spill occurred was picked up, placed in plastic bags and placed in 3 barrels. There was 100% recovery of the spill. Mr. Jackso~ re~~d that henceforhh all cam-loc fittings on fuel lines will be w~ closed to prevent a ~ence of any leakage frc~ that SOtlrce. I thanked Mr. Jackson for his ~y's prc~pt action, their remed, ial proced~ ~ud their p~ reporting. October 23, ?q7© Lonnie C. Smith /~-~. Chief Petroleum Engineer · LO/NS 78-139 (77-162) Duck Island Unit ~1 SPCC Plan - E~3[on We have reviewed the comprehensive SPCC Plan submitted by Parker Drilling Company for Exxon and have no further com- ments. We recommend approval of the plan. LCS/RAD: emi STA. TE of ALASKA / F- ~-/Hoyle H. Hamil ton DOGC Doug Lowery DEC FROM: Pete Nelson DMEM~~ DATE: FILE NO: TELEPHONE NO: October 16, 1978 SUBJECT: LO/NS 78-139 (77-1 62) Duck Island Unit #1 SPCC Plan-Exxon The Comprehensive SPCC Plan prepared by the drilling contractor, Parker Drilling Company for Rig No. 97 was mailed directly to you by Exxon. Please review and send us your comments as soon as possible. If we ,have not heard from you by November 1, 1978 we will assume that you have no objections and will proceed with the approval. RECEIVED OCT !978 Division E ,ON COMPANY. U.S.A. POUCH 6601e ANCHORAGE, ALASKA 99502 EXPLORATION DEPA"TM~ENT ALASKA/PACIFIC D I V I S i 0~"1~.? October 4, 1978 · Exxon No. 1 Duck Island Permit No. 78-68 Mr. Hoyle H. Hamilton Chairman, Oil & Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hamilton' In accordance with the plan attached to the subject Form 10-401 Permit to Drill or Deepen filed with you December 2, 1977, approved August 31, 1978, we enclose herewith a comprehensive SPCC Plan prepared by the drilling contractor, Parker Drilling Company for Rig No. 97 which is on location and preparing to commence drilling operations together with a complete contingency plan comprised of the following: 2. 3. 4. Pollution Control Plan Oil Spill Containment and Clean-up Plan Relief Well Plan Emergency Evacuation Plan Yours very truly, RKR'et attachment s cc' Mr. Thomas Cook w/attachment Mr. Douglas Lowery w/attachment RECEIVED A DIVISION OF EXXON CORPORATION , .Form ~EV. i-10-73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASK~A OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to cleepen Use "APPLICATION FOR PERMIT--" for such proDosals~) OIL !---1 SAS I----I WELL g-J WELL L_J OTHER ~¥ildcat NAME OF OPERATOR Exxon Corporation ADDRESS OF OPERATOR P. O. Box 2180, Houston, Texas 77001 ¢. LOCATION OF WELL At su~ace 700' NSL & 800' WEL o£ Sec. 8, TllN, R1ZE, UM 500' NSL & 800' ~ of Sec. 5, TllN, R!ZE, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 3 ft. water depth at surface location 14. Check Appropriate Box To Indicate Nature of Notice, Re APl NUMERICAL CODE 50-029-20280 6. LEASE DESIGNATION AND SERIAL NO. ADL 47505 ?. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME: Duck Island Un_ii, WELL NO. No. 1 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 5, 'fl]N, R17E 12. PERMIT NO. 78-68 3orr, or Other Data TEST wATER SHUT-OFF : FRACTURE TREAT · SHOOT OR ACIDIZE REPAIR WELL (Other) NOTICE OF INTENTION-Cd pULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS -'~JBS EQUENT~,.R EPO RT OF: WATER SHUTqDFF REPAI RiNG WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other} (NOTE.- Report results of multiple completion on Well COmlDletlon or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all I~ertlnent d~t~ll~, and give pertinent dates, including estimated date of starting any proposed work. We wish to amend the Pe~nit to Drill or Deepen. From 10-401 in the following particulars' ( ? ~r ~ /-t -4o 1. To include a string of 20'kcasing not previously provided for, to ]De set at 1000' and cemented'to the surface as shown on the attached well bore sch~natic diagram. 2. To change the depth of the 7" production liner from 12,800' to 12,900'. 3. To substitute the diverter assembly and the well control procedure to be used therewith attached hereto as Attachments 4 and 5 for the assembly and procedure submitted with our letter of December 19, 1977 requesting amendment of the Form 10-401. 4. To change the total measured depth of the well as was stated in section .%9 of the Form 10-401 from 12,80_0' to 12,900'. 5. To provide for the capability~ to inject liquid. ~:~ i~~.i~ waste hych~ocarbons and test hydrocarbons into the fo~m~/%~O~ldW ~%lTe 13-3/8" casing and behind the 9-5/8" casing. I6. I .hereby certify that th~foregolng Is true and correct _..~:_~:~:'.~. ?~ ~-~Z . -'.'~-- ,, ,~ .... ? :::? .......... _ (This space for State of.fl.~; use) ~;;:: ?.'/ '-"?' ,/K/fi APPROVEDBY.~/~_~ ~'7~ TITLE Rhi~__+ P~d-~-r~l~ur~ CONDITIONS OF APPROVAL, IF See Instructions On Reverse Side Attachment 2 Z,,XON NO. '1 DUCK ISLAND UNI wELL BORE SCHEMATIC .... I I ~.'L ~ '3~°" set ae 1 o o' +_ ! ! [ l~!~[ -permafrost 'C&men% to Surface 20" Conductor_8 1000 ...... ; ....... , Permafros '-~ me~'t ~tO surfac '.~;~-.,' 9 5/8" FO'...0 2000'.. ; ..... ~ . . ~'[.)1 ':- .... t 9 528;" F0' 0--2200'.-:. - -~ - ...... ' 'Injection Interval TOC @ Approx. 70 Cement into 9-5/8" 7" Production Liner @ Approx. .].2900' Attachment 4 · FLOW DIVERTER ASSEMBLY DUCK ISLAND UNIT ~1'~' . . Annular BOP 20" 2000 psi WP ' |-,-' T-Handle at Butterfly Valve To Trip Tank Rig Floor 6" Line to Reserve/ Contingency' Pit Attachment 5 ~. Well Control Procedures Before setting 13-3/8" Casing - Do Not Shut in Well: 1. Close 20" Hydril. Diverter valves to be open. 2. Pump mud or water at high rate as availability permits. After Setting 13-3/8" Casing: 1. Follow Exxon well control procedure. 2. -Hydril hydraulic regulator should be set at 1500 psi minimize closing time° After bag is closed, closing pressure should be reduced, to_minimum required to maintain seal wh:ich will permit slight leakage while work_i_~g~t~he~ pi~e. · ~ -. ~ If well flow cannot be controlled initiate contingency plan. RGD:cm 9-18-78 SPILL PREVENTION CONTROL AND COUNTERMEASURE PLAN PARKER DRILLING COMPANY R~G No, 97 0PERATING FOR EXXON U, S','A',' SPILL PREVENTION CONTROL & COUNTE~ tSURE PLAN PARKER DRILLING COMPANY RIG NO~ 97 OPERATING FOR EXXON U.S.A, TABLE OF CONTENTS PART I - GENERAL INFORMAT I ON RIG & RIG OWNER IDENTIFICATION Parker Drilling Company Personnel EXXON U.S.A. OIL SPILL HISTORY MANAGEMENT APPROVAL OF PLAN Parker Drilling Company EXXON U,S,A. ENGINEERING CERTIFICATION PREDICTION OF FLOW RATE & DIRECTION Fuel Storage Tank Capacities Mud'Storage Tank Capacities FhysicaI & Chemical Properties. of Fuel CONTAINMENT & DIVERSIONARY STRUCTURES INSPECTION & RECORDS PERSONNEL TRAINING & SPILL PREVENTION RIG INVENTORY RIG PLOT PLAN PART II - DESIGN & OPERATING INSTRUCTIONS DRILLSITE CONSTRUCTION DISPOSITION OF OILY WASTE PRIMARY CONTAINMENT EQUIPMENT CASING & BOPE DRILLSITE LAYOUT DIAGRAM, FIGURE 2 PART III - OIL SPILL REPORTING PROCEDURES OIL SPILL REPORTING PROCEDURES DIRECTORY FOR OIL SPILL REPORTS OIL SPILL REPORTINGs'PROCEDURE CHART DIRECTORY OF REGULATORY OFFICES SAMPLE OIL SPILL REPORT OIL SPILL ACTION PROCEDURES CHART ~,pi~.~.,~ OIL SPILL CONTINGENCY PLAN ~.. .... n~'m~ ..... "~ CHECKLIST FOR KEEPING SPCC PLAN CURRENT Page 1 4 5 5 6 9 10 11 13 14 ~ 14a 15 17 18 19 20 23 24 34 SPILL PREVENTION CONTROL & COUNTERMEASURE PLAN PART I ~' GENERAL INFORMATION A. NAME OF RIG: Parker Rig 97 B. TYPE OF RIG: Mobile Onshore C. LOCATION OF RIG: Sec. 8, TllH, R17E U.M. Do NAME AND ADDRESS OF OWNER AND OPERATOR: PARKER DRILLING COMPANY P O. Box 455 8 East Third Street 512 W. International Airport Tulsa, Oklahoma 74103 Anchorage, Alaska 99510 ~9t8) 585-8221 (907) 279-0476 E. DESIGNATED PERSONS ACCOUNTABLE FOR OIL SPILL PREVENTION AT RIG: Name Gene Evans Name Jesse Curl, Name Name PARKER DRILLING COMPANY John Edwards Johnny Taylor Title Drilling Superintendent Title Toolpusher Title Toolpusher Title Drilling Superintendent SPCC PLAN FOR PARKER DRILLING COMPANY RIG NO. 97 CONTRACTED TO EXXON U.S.A. F. OIL SPILL HISTORY This facility experienced no reportable oil spill prior to January 10, 1974 (effective date of 40 CFR, Part 112). Forms are included in this Plan for future use, if needed, for reporting spill events, as Attachment No. 1. G. MANAGEMENT APPROVAL This SPCC Plan (with revisions) will be implemented as herein described. Parker Drilling Company approves this SPCC Plan; and agrees to meet the requirements of 40 CFR, Part 112; agreeing to accept their respective repsonsibilities under these regulations and as specified by contracts with the Government of the United States of America. PARKER DRILLING COMPANY Name: Title A. T. Cooper, Jr. Operations Manager EXXON U.S.A. Name: Signature: Title: Date: H. ENGINEERING CERTIFICATION I hereby certify that I am familiar with the provisions of 40 CFR, Part 112; attest that this SPCC Plan has been prepared in accordance with good engineering practies. This certifi- cation is made under the terms of the agreement between the IADC and the EPA and interpretations of the Regulations and the Agreement by the IADC. Name: ' , ..Z Signature: ,.x>-.', '.......,.. t'/' ../~L/ Registration N.- 1750-E State: Alaska Date: · · SPCC PLAN FOR PARKER DRILLING COMPANY RIG NO. 97 CONTRACTED TO EXXON U.S.A. I. PREDICTION OF DIRECTION AND RATE OF FLOW The direction of flow of any spills escaping the drillsite is estimated and shown on the Exxon-As-Built-Map attached to this SPCC Plan. The actual direction of flow, should a spill occur, may vary from ~that predicted. Surface conditions at the location vary from summer %o winter, and change during the winter. Personnel responsible for oil spill contai~unent at the drillsite will be prepared to construct flow barriers for any flow direction encountered. The prediction of the potential rate of flow of an oil spill at the drillsite is not possible. This SPCC Plan .provides for the capability to contain rates of flow excee~in~.tha~ possible f~om the~t~at storage tank listed below. The total volume of a potential spill can be predicted only to the extent of the fluid storage capacity shown below. TANK OR TYPE OF VOLUME STORAGE FAILURE 1. MUD TANK 2. MUD TANK 3. -MUD TANK 4o FUEL TANK 5. FUEL TANK 6. FUEL TANK See Note No. 1 See Note No. 1 See Note No. 1 See Note No. 2 See Note No. 2 See Note No. 2 200 Barrels 200 Barrels 200 Barrels 400 Barrels 400 Barrels 900 Gallons NOTES Steel Mud Tank failures are almost non-existent during rig operations. Not a pressure vessel. Tanks are inspected and repaired (if needed) during rig moves. Total normal drilling fluid storage (Mud) is 1000 Barrels. The drilling mud normally contains no oil. Under this condition, drilling mud is not considered a hazardous substance by the EPA. SPCC PLAN FOR PARKER DRILLING COMPANY RIG NO. 97 CONTRACTED TO EXXON U.S.A. t,, . Steel Fuel Tank failUres are almost non-existent during rig operations. These. tanks are not pressure vessels and have relief vents. The total fuel storage capacity, is normally approximately 36,000 gallons. Any change in the fuel storage capacity at the drillsite will be noted in the space provided on the following page. The Steel Fuel Tanks contain Arctic'Heating Fuel of JP-5 Aviation Fuel. The fuel source will vary. Typical fuel properties are shown below. The chemical composition of the various fuels in use are enclosed wi'th this SPCC Plan. TYPICAL PHYSICAL SPECIFICATIONS FOR ARCTIC HEATING FUEL [Tesoro,Alaskan DF-A) . API GRAVITY CLOUD POINT POUR POINT FREEZE POINT SULFUR VISCOSITY, KIN. @ 100°F VISCOSITY~ KIN. @ -30OF DOCTOR TEST CALC. CETANE FLASH POINT, P.M. CORROS I ON BTU/GAL. GROSS BTU/LB. GROSS DISTILLATION: 1BP 5% 10% 20% 30% 40% 5O% 60% 70% 80% 90% 95% EP Recovery Residue Loss 42.6 ~56 F. -60°F. -60OF. 0.03% of 1% 1.6 cs 7.5 cs NEG 45.5 ll0OF iA 133,500 [[9 ~720 330 330 367 375 385 395 406 419 432 448 469 485 5O6 99.0 1.0 0.0 SPCC PLAN FOR PARKER DRILLING COMPANY RIG NO. 97 CONTRACTED TO EXXON U.S.A. 3. Drillsite Fuel Storage Modifications Date 9/78 9/78 9/78 9/78 4/78 4/78 4/78 . · Tank Tank Add or Volume Type Delete 30,000 gal. Steel 30,000 gal. Steel '30,000 gal. Steel Added by Exxon U.S.A~ Added by Exxon U.S.A~ Added by Exxon U.S.A~ 30,000 gal. Steel Added by Exxon U.SoA. 500 gal. Steel 300 gal. steel. Added by Exxon U.S.A. Added by Exxon U.S.'A~ 300 gal. Steel Added by Exxon U.S.Ao J. CONTAINMENT AND DIVERSIONARY'STRUCTURES Containment or diversionary structures and equipment to prevent oil from reaching navigable waters are practicable. Typical secondary containment for the Drillsite is shown in Figure 2. Equipment available for containing spills at the Drillsite is listed in Attachment No. 2. This list of equipment is designated to deal with any large spill volumes which could be~reasonably ant~.cipated. K. INSPECTION AND RECORDS The inspections made each tour by the Rig Crews follow the written procedures shown on Attachment No. 3. These procedures are enlarged upon verbally, as required to meet existing operating conditions, by the Rig Toolpusher during scheduled training sessions. Inspections made daily by the Rig Toolpusher include those shown on Attachment No. 3. Additionally, each Toolpusher conducts an industry developed and accepted inspection of the entire rig, daily. SPCC PLAN FOR PARKER DRILLING COMPANY RIG NO. 97 CONTRACTED TO EXXON U.S.A. 2~ A record of the inspections outlined above is to be kept by making %he following entry on the IADC Daily Drilling Report for each tour. "SPCC Rig Inspections Complete". By signing of the IADC Daily Drilling Report, both the Driller and the Toolpusher authenticate that the inspections have been completed. L. PERSONNEL TRAINING AND SPILL PREVENTION PROCEDURES Ail Drillsite personnel will receive training covering Oil Spill Prevention and Control Procedures outlined below, each week.. . l· The operation and maintenance of all'equipment utilized on the Drillsite which stores, transfers or consumes fuel and/or lube oils, Manufacturer's equipment manuals, films and other training aids will be used as applicable. e ExPlain the specifications for construction of the Drill- site. This includes the construction and maintenance of the reserve ~pit, berm around the Drillsite~ and the drainage ditches on the Drillsite. These specifications are listed in Part II and on Figure 2 of this Plan. 3~ Give to all Rig Crews an explanation of the Minimum Inspection Procedures included in this Plan as Attachment No. 3. Additional specific instructions should bepr0vided the Derrickmen and Motormen regarding the execution of the inspections and reporting the results, as well as special instructions required for abnormal operating conditions. · Familiarize all Drillsite personnel with the utilization of all special oil spill containment and clean~upmaterials and equipment listed on Attachment No. 2, "Oil Spill Contingency Plan". Utilize manufacturer's representatives and literature for this purpose. Familiarize Drillsite personnel who operate support equipment listed on Attachment No. 2 with their work assignments during an oil spill containment and clean=upoperation. SPCC PLAN FOR PARKER DRILLING COMPANY RIG NO. 97 CONTRACTED TO EXXON U.S.A. 5~ 6~ o Review with all Drillsite Personnel, this Spill Control and Countermeasure Plan, as required by Environmental Protection Agency Regulations, 40 CFR, Part 112. Review the following excerpt from the "Federal Water Pollution Control Act of 1972" Sec 311, (b), (1), reads as follows: "The Congress hereby declares that it is the policy of the United States that there should be no discharge of oil or hazardous substances into or upon the navigable waters of the United States, adjoining shorelines, or into or upon the'waters of the contiguous zone." Note: "Navigable Waters" have been defined in such a manner that virtually all lakes, streams, ocean and sea shore lines are included in the meaning of the section quoted above. SectiOn. 311 (b) (5) reads in'print: "Any person in charge of a vessel or of an onshore facility or an offshore facility' shall, as soon as he has knowledge of any discharge of oil or a hazardous substance from such vessel or facility in 'violation of paragraph (3) of this subsection, immediately notify the appropriate agency of the United States Government of such discharge." Note: Reporting procedures are given below, and in Part III. Review with all Drillsite Personnel, the following excerpts from 50 CFR Part 110 of the Environmental Protection Agency Regulations. Paragraph 110.1 (1) reads: "Sheen means an iridescent appearance on the surface of the water.~' Paragraph 110.1 (m) reads: "Sludge means an aggregate of oil or oil and any other matter of any kind in any form, other than dredged spoil having a combined specific gravity equivalent to or greater than water." Paragraph 110.3 reads in part: "discharge of such quantities of oil into or upon the navigable waters of the United States of adjoining shorelines determined to be harmful to the public health or welfare of the United States, at all times and locations and under all circumstances and conditions,--include discharges which: Cause a film or sheen upon or discoloration of the surface of the water or adjoining shorelines or cause a sludge or emulsion to be deposited beneath the surface of the water or upon adjoining shorelines." Paragraph 110.5 reads in part: "---no person shall discharge or cause or permit to be discharged into or upon the navigable waters of the United States, the adjoining shorelines,. SPCC PLAN FOR PARKER DRILLING COMPANY RIG NO. 97 CONTRACTED TO EXXON U . S. A. or into or upon the waters of the contiguous zone, any oil~ in harmful quantities as determined in paragraph 110.3 and 110.4 of this part,---.. NOTE: Simply stated; causing a sheen on any water surface or sludge in any waters is a violation of Federal Regulations. 8. Review with all Drillsite Personnel; excerpts from Title 46 of the Alaska Statutes. Sec. 46.03.740 reads in part: "No person may discharge, cause to be discharged, or permit the discharge of petroleum, acid, coal or oil tar, lampblack, aniline, asphalt, bitumen, or residuary product of petroleum, into or upon the waters or land of the state---." Sec. 46,03.760 (a) reads in part:. "A person who violates Sections 710,730, 740 or 750 of this Chapter is guilty of a misdemeanor' and upon conviction is punishable by a fine of not more than $25,000 or by imprisonment for not more than one year, or both." 9' Ail Drillsite personnel are to be specifically instructed that the policy of Exxon U.S.A. and Parker Drilling Company is that, "Any and all Personnel will report any and all oil spills to their immediate supervisor." This policy is to be implemented by: a. Oil Spills shall be immediately reported to the individual's Supervisor. ~- b. The Supervisor will immediately report any and all oil spills to both the Parker Drilling Company Toolpusher and the Exxon U.S.A. Drilling Foremen on site. 10 Ail Parker Drilling Company Rig 97 personnel will follow the "Contractual BOPE & Well Control Procedures" as designated by Exxon U.S.A. DRILLING UNI'[ DESCRIPTION 1. Drilling Unit Name- Parker Drilling Company, Rig 97 2. Drilling Unit Description and general dimension- Make and model' National 80 Mechanical Rig with torque tube driven catworks Height below rotary beams 16'6" 3. Fire Fi§hting Equipment and Safety Equipment to comply with Alaska Government Re§ulations 4. Hand extinguishers' No. 30, 30 lb. anusul with ABC&BC, 1 150 lb. wheeled with ABC Powder - 1 150 lb. wheeled with BC Powder. 5. Air compressors' 390 Quincy with 10 hp Pacemaker electric motors 6. Rig floor dog house- 8'X26' Heating Unit' I DFlS. Giaga BTU 8. Boilers' 2'100 hp Cleaver Brooks 9. Steam heaters' 16 modine size' 400,0,00-BTU · STORAGE FACILITIES lO.. Mud pits' 3 8'X38'X6.5' Total of 600 bbls ll. Fuel 2 '40(]':bbZ..tanks FRESH WATER 12. 2 400 bbl. tanks ' POWER 13. Prime movers' No. 3, make Caterpillar D379-525 hp GENERATORS 14. No. 2, D353 Caterpillar - AC 250 KW DERRICK AND SUBSTRUCTURES 15. Mast' Lee C. Moore 16. Nominal capacity' 1,025 M Height' 142 ft. 18. Wind residence ¥~'ith.18,000 ft. pipe setback and wind break in place, lO0 HPH at -OF DRILLlt';G UNIT UE$CRIPTION Page 19. Height of rig floor - 19'9" 20. Static hook load with l0 lines-670 M 21. Wind breaks on substructure HOISTING AND ROTARY EQUIPMENT 22. Dra~orks' 'National 80 23. Parkersburg 46" hydromatic 24. 27 1/2" bore rotary table driven ~y torque tube thru catworks (Parker) with square split Varco .XDL bushings 25Z 6 sheave~crown with 1 - 56" and 5 52" dia sheaves grooved for ~ 1-3/8" ~dri'l 1 lng line 26. 350 ton 5 sheave Erasco traveling block with 350 unimatic hook 27. National t~pe E wireline anchor 28. · BJ weldless link 2-3/4 X 68" bails 29. Emsco LA 400 swivel 30. 5000 PSI WP Kelly (bck) 31. 2 5000 PSI WP lower kelly cocks 32. I 5000 PSI WP ~nside BOP 33. 1 5-1/4 OD Hex Drilco Kelly 40' long '34. Wooly type B tongs 35. I HDL 40 Ingersol Rand air hoist (rig floor) DRILL STRING AND TOOLS 36. 8450 ft. 5" OD 19.5 lb/ft, nominal range 2 'E' drill p'ipe with q 1/2 IF tool jts. 37. 3131 ft. 5" OD 19.5 lb/ft nominal range 2 S135 drill pipe with 4 1/2 IF tool jt.s 38. 3317 ft. 5" OD 19.5 lb/ft nominal range 2 XI05 drill pipe with 4 1/2" IF tool jts. MUD SYSlEM 39. 3.8 in. bore stand pipe 5000 PSI WP w/3 in.bore rotary hose 40. Brant vibrating shale shaker 41. Mud system with 600 bbl capacity 42. Desander: Demco w/2-8" cones 43. Desilter: Demco w/8-4" cones 44. Degasser: Drilco Unit with submerged cement pump w/7 1/2 hp pump PUMPS 45. Independent drive Gist 750 Triplex 6 1/2 X 8 Triplex Operating Press 2000 PSI 525 GpM 3500 PSI' 300 GPM Dr~,en by KTA 2300 - 12 cylinder Cummins. : 46.. See attached page BLOWOUT PREVENTERS 47. 2 Shaffer 13 5/8 5000# LWS POS Lok single gates 48. 1 - Hydril 13 5/8 5000# GK .~,~o -- Accumulator' Koomey T15080-35 160 gal. 24 Amebean Petrolcu~n Institute · SCIIEDULE D SLUSH-PUMP PERFORMANCE CAPABILITY Slush-pump ratings are to be Based on hydraulic horsepower they are capable of delivering continu- ously during normal drilling operations. Itydrau!ic horsepower is determined in the field by using: stand- ard test procedures, xvhereby pressure-gage observa- tions and either mens,red or calculated mud ¥olume~. are used to calculate pump hydraulic horsepower output. l~ig identification' Pump Spedficationa (1) l~fain EMSC0 Make (manufacturer) ...... F-750 }Jodel designation ........ 750 Rated'input. horsepower ...... 90 x Rated RPM X stroke length ..... Service Conditions-- High. %rolume 6 Liner sizes: Max.-rain ...... 1955 Corresponding rated WP .... 367 GP/~I displaced @ rated RPSJ[ Observed Performance Dates tested Yes Engines connected to pumps* . . Yes Do the same engines drive rotary? 100 317ax. no-load pump RPM 90 Pump RPBI during tests .... 1100 ]Engine RP~f during test .... 6 Liner sizes durlng tests ..... 1955 Standpipe pressure, psi ..... 367 GPA[, measured . , . .~ . . · GPM, calc. @ ~ '-% vol. eft. o . 180 Pump output, HHP .... ~ . 8 ~n. High Pressure ~ 1/2 3470 2O6 , lO0 , 90 1100 6 347.0 206 180 (2) Stand-by EMS CO F-750 750 90 .x 8 Volume Pressure 6 4 1/2 1955 3470 367 206 Yes Yes Yes Yes 100 100 90 90 1100 1100 6 6 1955 3470 367 206 180 180 (3) Stand-by in. High H/gh Volume Pressure *Engines supplying power to slush pumps: No. ~lake 3[odel 1. Caterpillar D-379 Caterpillar D-379 2. Caterpillar D-379 8. Manufacturer's Continuous-duty Rating at Owner's Governed Speed 482 .lip ~_ 1100 _mPN[ 482 }{p @_ 1100 482 DUCK ISLAND UNIT 91 SECONDARY CONTAINMENT PIT BERM AND LINING DESIGN Gravel Notes: 1. · Impermeable Liner Absorbent Pad 2. Original Gravel Layer Bentonite/Gravel Volume of pit to be equal to or larger than the combined volume of the tanks contained. Slope of sides to be a ,minimum of 1-1/2:1. ...... 94t-5 JDESANDER, DESILTER, DEGASSER J MUD PIT NO. 2 JJ MUD.PIT NO. I PUMPS SUITCASE 5'- 5" 24" :- -: ....... 55"'5 5L 5" ......... TOLERANCES J (£xCC~T AS NOT[O) J F/~A G'rIoNAt. j TIT~ ~ ~ PARKER DRI LLI NGCO. RIG 97 lO '$PCC PLAN FOR PARKER DRILLING COMPANY RIG NO. 97 CONTRACTED TO EXXON U.S.A. PART I I DESIGN AND OPERATING INSTRUCTIONS ONSHORE DRILLING OR WORKOVER RIG a~ LOCATION OF DRILLSITES Parker Drilling Company Rig No. 97 is located on the Drillsite designated by Exxon U.S.A., under the terms of the existing Drilling Contract between them. B. CONTROL AND DRAINAGE FROM DIKED AREAS The Drillsite is constructed as shown in Figure 2, enclosed with Part II of this SPCC Plan. The material utilized for Drillsite construction is from local sources. The type of material utilized is coarse sand and gravel which exhibits limited permeability. Additional reserve pit capacity will be available for emergency use from the snow berm constructed around the pad, and from pillow tank utilization. · All fuel and/or hazardous materials transfer lines which are buried in the pads will be constructed of a minimum Schedule 40 Fipe. Ail joints and connections will be welded. All piping and lines so installed will be hydro- statically tested to 80% of the rated working pressure for the particular piping installed. Equipment layout and operations procedures will be designed to provide the minimum burial of oil or hazardous materials transfer lines. . The routing of all hazardous materials-transfer lines will be visibly marked. The placement of these lines will provide maximum protection from damage from external sources. · Construction equipment and liquid pumping and transport equipment is kept operational at the Drillsite. This support equipment is available for the maintenance and repair of all secondary containment structures and for recovery and clean-up from oil spills. This equipment is listed on Attachment No. 2. 11 · CONTROL STA. "STUCK" 8 DUCK ISLAND UNIT NO. ! LAT. -- 70 19 O0 12 LONG.= ~47°51'47;S00''~' L.~o_o' X = 270,186.10 Y = 5,968,918.61 ' B E,4LtFOF~ T 17 2O CERTIFICATE OF SURVEYOR SE~ 16 21 i hereby certify that lam properly registered and licensed to practice land surveying in the store of Alaska ond that this plat represents o location survey made by me or under my supervision, and that all dimensions ond other details are correct. /, ...:///':- :"q; nY - Surveyor 'i :.:'~' '-:.~ " .... '-j~.:. '... c . .~ ,.:~ :: -.' . _.. ' C~':q::'"' .~ ....; ., ._,. ............ ,..~ ..... '~- .~:: · -:. ;..: - ~¢ f' .....' . .'. .._, . /'. ,... .,, -~ ...'.~ . . - ~ -::. "~ .. ~ -'. .;. .. ~ ~:..',. :....-: .,. ~: .'... Date LEGEND: 22 . ~ SET LATiIE AND 55 G&L DRUM ON ICE A.'~.P.C..S ( ALASKA STATE PLANE COC/RD- AS STAKED DUCK ISLAND UNIT NO. Locmted in ................... ~_~ ~:_~._,~ ~J._~=_8._LL~.= u, ~. A N. Surveyed for EXXON COMPANY U.S.A. Surveyed by F. M. LINDSEY 84 ASSOC. L../',ND ~, HYD,~),OGRAPHIC SURVEYORS Z::)~.),_ c'~,f I',Iorlhern t.~,.lht~ [3o~Iev..nrd Bo~ 4 .0'3: SPCC PLAN FOR PARKER DRILLING COMPANY RIG NO. 97 CONTRACTED TO EXXON U.S.A Additionally, absorbent materials are available on the Drillsite, as listed on Attachment 2. These materials are availaible for oil spill control and clean-up. The Parker Drilling Company Toolpusher and Exxon U.S.A. Drilling Foreman will immediately utilize %his equipment, materials and the'on-site manpower for control and clean-up of any spills occurring. The equipment, materials and manpower on-site is adequate for the complete control and clean-up of any spill volume up to the total fuel storage capacity on the Drillsite. The Parker' Drilling Company Toolpusher and Exxon U.S.A Drilling Foremen will jointly direct operations to follow. The procedures given on Attachment NO. 2, Major Oil Spill Contingency Plan, for any Oil Spill occurring outside the confines of the Drillsite and/or Campsite. C. DISPOSITION OF OILY EFFLUENT FROM SECONDARY CONTAINMENT The inventory'of Drilling equipment for Parker Drilling Company Rig No. 97 includes an incinerator. Disposition of oily waste materials will be according to the following procedures: Ail used engine oil, machinery lubricants of any kind and small volumes of spilled and recovered fuel oils will be burned in the incinerator. 2. Ail absorbent materials used for oil spill clean-up, which are combustible will be incinerated. ~ The Parker Drilling Company Toolpusher and the Exxon U.S.A. Drilling Foreman will jointly direct operations for the control and clean-up of any oil spills having volumes exceeding the incinerator disposa!~capacity as shown below. a. Immediately contain the Oil Spill. b. Recover the spilled materials for use, if salvageable. C · If the material is not salvageable, burn the material;~ if such burning at its present loca'tion presents no hazards to any personnel or equipment. d. Transport the spilled material to either a pre-selected burning site or the Drillsite reserve pit. SPCC PLAN FOR PARKER DRILLING COMPANY RIG NO. 97 CONTRACTED TO EXXON U.S.A. ee Utilize absorbent materials as required, for final clean-up of spill area, after removal of spilled material. · The Exxon U.S.A. Drilling Foreman will supervise the execution of burning operations for~the disposal of all oil waste materials remaining in the Reserve Pit upon completion of drilling operations at any other time justified. This procedure will be followed for disposing of any oily waste residue on any portion of the Drillsite and/or Campsite. D. PRIMARY CONTAINMENT EQUIPMENT The layout of Parker Drilling Company Rig No. 97 as assembled in an operating status is shown in Figure 1, included in ~his SPCC Plan. ~ The placement of this rig on the Drillsite is as shown on Figure 2, included with Part I of this SPCC Plan. An inventory of rig equipment is included with this part of the Plan. Any changes in major items of primary containment equipment (fuel and/or mud tanks) will be recorded in the space provided in Part I to reflect changes in equipment from that listed there. The following specifications apply to the fuel storage and transfer equipment included in Parker Drilling Company Rig No. 97 inventory. Ail fuel storage tanks are of steel cgnstruction. All fuel storage tanks are atmospheric vessels, with permanently installed vents~ 2. The fuel discharge connection on each tank is equipped with manually operating valves. · The fuel tanks have no automatic fluid level control devices. These tanks are installed, unprotected from the weather. Arctic conditions frequently cause failure of automatic control equipment. The tank fuel levels are observed and controlled manually. · Fuel is transferred to and from the storage tanks through steel lines, and/or flexible arctic grade fuel handling hoses. Expansion, contraction and vibration is not transferred through these flexible sections. All lines have threaded connections, including quick connect coup- lings and/or unions. All threaded connections are accessible for inspection and repair, if required. Ail fuel transfer lines meet or exceed the maximum fuel transfer pressure of 100 psi, with a 2:1 design margin. SPCC PLAN FOR PARKER DRILLING COMPANY RIG NO. 97 CONTRACTED TO EXXON U.S.A. 5. Ail liquid mud storage tanks are of steel construction. The mud tanks are atmospheric tanks with open tops. The fluid level is controlled manually in each tank. e Ail liquid mud is transferred through steel and/or high pressure steel braided hoses, specifically designed for this application. 7. Drip pans are located under rig machinery. E. CASING AND BLOWOUT PREVENTION EQUIPMENT 1. The well Casing programs are designed by Exxon U.S.A. The casing programs are designed to provide the capability of controlling any wellhead pressure that is expected to ~be encountered by each individual component. The programs -are in accordance with the requirements of the State of Alaska Division of Oil and Gas, Department of Natural Resources. 2. The Blowout Prevention Equipment listed in the Parker Drilling Company Rig No. 97 inventory, meets the known requirements for well control of the Alaska Division of Oil &.Gas. ~ ~ Each well program is designed, utilizing the most current data available, regarding subsurface conditions, to meet the requirements of sub-paragraph 1 and 2, above. Casing and BOPE of greater containment capacity will be utilized at any time the need develops. Testing of all Blow Out Prevention Equipment will be regularly tested in accordance with the testing pro- cedures and frequency' specified by Exxon, U.S.A.~ but not less often than required by the State of Alaska. 14 SPCC PLAN FOR PARKER DRILLING COMPANY RIG NO. 97 CONTRACTED TO EXXON U.S.A. PART III OIL SPILL REPORTING PROCEDURE The policy of Exxon, U.S.A. and Parker Drilling Company is that: "Any and all Oil Spills will be reported." Oil Spills will be reported as shown on the enclosed Oil Spill Reporting Procedure Chart and the following instructions: 1. For the purpose of this policy, oil ~pill is defined as an accidental spill of unrefined crude oil and all refined crude oil products. This is intended as a simplified definition for implementation of this SPCC Plan and does not supercede the meaning or intent of the definitions given in the regulations. .. 2. Any and all Oil Spills will be reported by any and all .. personnel having knowledge of such oil spills~ to their immediate supervisor as soon as possible. Parker Drilling Company rig crew members will inform their Driller of such events. Other Drillsite personnel will notify their immediate supervisor or the Exxon U.S.A. Drilling Foreman. This applies to all miscellaneous individual Service and/or Support Personnel; either permanent or transient. ~ The Parker Drilling Company Drillers will notify the Toolpusher on-site, as soon as possible. Other Foremen or Supervisors will notify Exxon U.S.A. Drilling Foremen on-site, at once. The Parker Drilling Company Toolpusher will notify the Drillin~ Foreman as soon as possible. · The Drilling Foreman and the Toolpusher will, either jointly or separately, evaluate the reported oil spills and make all verbal reports which the conditions warrant. The attached Oil Spill Reporting Chart and Personnel Directory will be utilized. 5. The Exxon U.S.A. Drilling Foreman and the Parker Drilling Company Toolpusher will each complete the Oil Spill Report; Attachment No. 1 to this SPCC Plan, a~d·._.submit to their respective Managements as shown on the Oil~ Spil!..Reporting Chart. ThiS report must be completed for each Oil Spill. 6. The information required for an Oil Spill Report is shown on Attachment No. 1; "Record of Oil Spills." This form will be completed by both the Parker Drilling Company Toolpusher on Rig No. 97 and Exxon U.S.A. Drilling Foreman on-site; and sent to their respective Managements, as shown on %he Oil Spill Procedure Chart. One copy of the Report is to be kept at the Drillsite in each working copy of this SPCC Plan. 15 SPCC PLAN FOR PARKER DRILLING COMPANY RIG NO 97 CONTRACTED TO EXXON U.S.A. PART III 7~ Exxon U.S.A. and Parker Drilling Company Mangement will process all verbal and written Oil Spill Reports and notify the local manager for Exxon U.S.A. The staff of Exxon U.S.A. will provide all liasion and administrative support required for the up-dating, revision and submission of all Oil Spill Reports, Containment Efforts and Restoration Operations. All Final Reports will be submitted by Operations Manager, Exxon U.S.A., with the concurrence of Mr. A. T. Cooper, Jr., Operations Manager, Parker Drilling Company. 8.- The subsequent written reports required by the EPA Regulations mean that: A written report will be submitted, in addition to the initial "verbal" noti- fication of an oil spill, given to the EPA. Exxon U.S.A. will submit these reports as outlined in paragraph 7., above. Refer to "Summary of Procedural Requirements for SPCC Plans and Related Environmental Regulation" which is included with this SPCC Plan under SPCC Plan Checklist. ~ The Parker Drilling Company Toolpusher and the Exxon U.S.A. Drilling Foreman will record on their respective morning reports, the making of verbal oil spill reportsl The recorded information should include the name of the individual receiving the verbal report, time of day given ~.nd a summary of all verbal instructions received. 16 SPCC PLAN FOR PARKER DRILLING COMPANY RIG ~O. 97 CONTRACTED TO EXXON U.S.A. DIRECTORY FOR OIL SPILLS REPORT Area Code 907 EXXON, U.S,A. NAME TELEPHONE NO. EXXON~ U,S.A. Anchorage Office 276-4552 R. P. Brigh% J. W. Jackson J. B. Willis R. G. Dragnich Anchorage Office A. T. Cooper, Jr. G. A. Frost PARKER DRILLING COMPANY Office Home 276-7462 344-9782 276-7266 276-4305 276-7955 349-2843 276-7955 333-1707 279-0476 349-4241 344-6488 17 OIL SPILL REPORTING PROCEDURE CHART , U.S. ENVIRONMENTAL PROTECTION AGENCY ALAKSA DEPARI]fENT OF ENVIRONMENTAL CONSERVATION U. S. COAST GUARD Ii,~DIVIDUAL SERVICES .- EXXON U.S.A. DRILLING FOREMAN SUPPORT & EQU!Pb~N~. EXXON U.S.A. MANAGER, OPERATIONS PARKER DRILLING 0PER. MGR.J ~.T.Cooper~r. SUPPORT EQUIPMENT CONTRACTOR FOREMAN PARKER DRILLIN~ SUPT. ~ "Gene Evar~s .'Johnny PARKER TOOLPUSHER Jesse Curl Jim Kothe John idwards _ PARKER RiG 97 CREWS SPCC PLAN FOR PARKER DRILLING COMPANY CONTRACTED TO EXXON U.S.A. U.S. ENVIRONMENTAL PROTECTION AGENCY Anchorage Office Night Number NOTE: MR. R. W. MORRIS: Mailing Address: This night nUmber is the FAA Duty Officer. Reports given to this number are transmitted to the U.S. Coast Guard Duty Officer. The report is recorded, screened and transmit%ed to the EPA. Chief, Oil Programs Alaska Operations Office Region X U. S. Environmental. Protection Agency 605 West Fourth Avenue Anchorage, Alaska 99501 U. S. COAST GUARD Captain of the Port and Marine Inspection Office Night (FAA Duty Officer) ALASKA STATE DEPARTMENT OF ENVIRONMENTAL CONSERVATION Northern Regional Office, Fairbanks Mr. D. LOWERY: Nor%hem Regional Environmental Supervisor MR. J. JANSSEN Mailing Address: Alaska State Department of Environmental Conservation Northern Region P. O. Box. 1601 604 Barnette Street Fairbanks, Aiaska 99707 (h) Denotes Home Telephone Number 19 265-4881 272-8812 344-9327 (h) 265-5371 272-8812 452-1714 456-4861 (h) 488-2834 (h) SPCC PLAN FOR PAPdIER DRILLING C0~iPA/~ CONTRACTED TO EXXON U.S.A. SPCC PLAN, ATTAC~R~ENT NO. 1 OIL SPILL REPORT Instructions: This FOrm ig designed to provide all initial report information. More information may be required at a later time; should initial report conditions change. The Drilling Foreman and the Toolpusher should keep notes (including times and dates) of subsequent occurrences, orders received and given and actions taken by the various individuals and organizations involved in an Oil Spill. Fill in this Form completely. Should any information blanks "not apply", mark then N/A. . 1~. Time of. DAY'& Date Spill Occurred or First Observed 2. Date of This Report' 3. Location of Spill (Describe Location, give map coordinates, name of site, etc.) Present Location of Spill (Describe movement, if any, of Spill; cause of movement). 5. Estimate of Spill Volume 6. Type of Material Spilled ~ Environmental Conditions Sun, nary (Give ground condit~ions, water conditions, including currents or tide, temperature, ~e~.nd direction and speed, visibility, ice and/or snow conditions and d~P.t~h) ._ · SPCC PLAN FOR ~ ~LKER DRILLING COlfPA~Y CONTRACTED TO EXXON U.S.A. ATTACHMENT NO. 1 7. (con' t. ) · Barge &/or Vessel Data (give name of crafts), registry, owner or lessee, deadweight tonnage or draft, total storage capacity of spilled material, etc.) ~ Area Likely to be Further Affected by This Oil Spill (describe terrain such as beaches, ponds,, wildlife areas, streams, etc,) 10. Cause of Spill 11. Action(s) Taken to Combat Spill SPCC PLAN FOR PARKER DRILLING COP~PANY CONTRACTED TO EXXON U.S.Ao ATTACHMENT NO. 1 11. (con' t) ' ' ' . 12. Agencies Notified of Oil Spill Occurrence Signature Print Name 22 This Report Prepared by I_ AC'I'ION I~ROC! .... SlJl'iI-S (}l-IAI-ti- MAJOR CONTAINh;ENT Al'aD CLEAN-UP . EFFORT E~ON 'U-:. S. A. MANAGER OF ' OPERATIONS ' DRILLING FORt:MAN F ti:- I_ D FO I? E M A N' OIL SPiI.L I)I:_T F:CT 101~1 PARKER OPERATIONS MANAGER PARKER TOOLPUSIIER .... MO~,ILIZE OTItER NEEDED RESOURCES MOBILIZE ALL LOCAL - PERSONNEL AND " ~_. : EQUIPMENT :.. I M MEDIATE CONTAIN,',',ENT AND CLEAN-UP EFFORT l--IMt,~EDIA'FI-~lY INSURE i~F:It~ONNF-.I_ AND L-QUI~I,;E-NT :_;;-CC PARKER DRI. T,I,.I;iG CI 1P,\NY SPCC PLAN FOR PARKER DRILLING COMPANY RIG NO. 97 CONTRACTED TO EXXON U.S.A. ATTACHMENT 2 OIL SPILL CONTENGENCY PLAN A. RESPONSIBILITY AND AUTHORITY This Oil Spill Contingency Plan; as a part of the SPCC Plan for Parker Drilling Company Rig No. 97 contracted to Exxon U.S,A., constitutes an assignment of responsibility and authorizes ac%ions to be taken in the case of any oil spill. The included Oil Spill Action Procedures Chart summarizes these assignments. The actions assigned and authorized will be implemented in case an oil spill occurS on any Drillsite associated with Parke~ Drilling Company Rig No.. 97, during the term of the existing contract or subsequent contracts between Parker Drilling Company and Exxon U.S.A. Any and all individuals, contractors, support personnel, service personnel and employees associated with Parker Drilling Company Rig No. 97 opera%ions are responsible for and authorized to take the following actions in the case of an Oil spill. The maintenance of well control is included as part of the oil spill prevention procedures of this SPCC Plan. The loss of well control is considered an oil spill. 1. Preserve human life. 2. Protect equipment. 3. Immediately contain the spill to the extent of their capacity. ~ Report the event to their immediate on-si-re Foreman or Supervisor. The EXxon U.S.A. Drilling Foreman and the Parker Drilling Company Toolpusher are assigned the responsibility for, and authorized to implement the action listed below. i . Detect, contain and clean-up all oil spills of any size occurring on any Drillsite associated with Rig No. 97 operahions, and the immediate vicinity thereof. SPCC PLAN FOR PARKER DRILLING COMPANY RIG NO, 97 CONTRACTED TO EXXON U.S.A. ATTACHMENT 2 1 The Parker Drilling Company Toolpusher will not commit equipment and/or personnel beyond the immediate vicinity of the Drillsite for oil spill countermeasures unless so doing will not jeopardize current on-site operations, and/or such action is authorized by the Exxon U.S.A. 3. The Exxon U.S.A. Drilling Foreman will coordinate all oil spill countermeasure operations with the Manager, Drilling and Engineering, which are beyond the immediate vicinity of an existing drilling operation or when per- sonnel and equipment requirements exceed those locally available. .4. -The Exxon U.S.A. Manager of Operations will direct the .. mobilization of additional manpower, equipment and imaterials required for any oil spill countermeasures. He will also provide overall direction of countermeasure operations. St The Parker Drilling Company Operations Manager will direct the mobilization of additional drilling personnel, equipment and materials required. This effort will be coordinated with the Exxon U.S.A. Manager of Operations. ~ The Parker Drilling Company Rig No. 97 crews will i~mmediately implement the well control PrOcedures outlined in the "Contractural BOPE & Well Control Procedures" upon indication that a loss of well control conditions exists. The Parker Drilling Company Toolpusher and/or the Exxon U.S.A. Drilling Foreman will direct subsequent well control operations. ~ The Exxon U.S.A. Foreman will coordinate all Well Control OPerations with the Exxon U.S.A. Manager, Drilling and Engineering. · The Exxon U.S.A· Manager of Operations will exercise overall ultimate direction of well control operations; coordinating with the Parker Drilling Company Operations Manager. Ail required equipment, personnel and materials will be mobilized under their direction. B. SPECIFIC OIL SPILL COUNTEP~EASURES TO BE EXECUTED The actions listed below are authorized and their implementation- directed by the'Manager of Operations, Exxon U.S.A., and the Operations Manager, Parker Drilling Company. These actions are to be supervised by the Exxon U.S.A. Drilling Foreman and the Parker Drilling Company Toolpusher, as appropria'he, according to their judgment of conditions, for oil spill coun'termeasures. Spcc PLAN FOR PARKER DRILLING COMPANY RIG NO. 97 CONTRACTED TO EXXON U.S.A. NORTH SLOPE SUPPLIES & SERVICES The following equipment and supplies are located in the Deadhorse Area that may be used in emergency: 1. High Pressure Pumps, Cement and Bulk Handling Equipment A. Dowell Telephone 659-2434 B'~ Halliburton Telephone 659-2492 2. Mud' and Weight Materials · A. IMC Telephone 659-2492 3. oiifield Trucks,.Floats, Tank Trucks, Vacuum Trucks, etc. A. Mukluk Telephone 659-2686 B. Kodiak Telephone 659-2648 · Construction Equipment - Dozers,-'Fork Lifts, Scrapers, Dump Trucks, Front End Loaders, Water Trucks, Belly Dumps, etc. A. Frontier Rock and Sand Telephone 659-2565 B. Kodiak Telephone 659-2648 C. Alaska General Telephone 659-2445 D. S&C Construction (Equipment on remote North Slope Wellsite) 5. Helicopter and Air Transportation A. ERA Avionics Telephone (101-659-2465) B. Sea Airmotive Telephone 659-2656 6. General - BP Alaska and ARCO have large stockpiles for materials that they will make available for emergencies. A. BP Alaska Telephone 659-3101 B. ARCO Telephone 659-2659 SPCC PLAN FOt ARKER DRILLING COMPANY RI~-NO. 97 CONTRACTED TO EXXON U.S.A. ATTACHMENT 2 1. Utilize any and all equipment and personnel available locally. · ~ Mobilize personnel, materials and equipment, which are known to be resources of Exxon U.S.A. or Parker Drilling Company and located on the North Slope of Alaska. Execute any action deemed necessary for the preservation of human life. 4. Construct any dams, ditches or other flow controls which will provide immediate containment. 5~ Burn any and all unsalvageable oil spill materials and/or waste, under conditions of maximum personnel and equipment safety. Repair and/or modify any equipment as require~ to stop any leaks or spills. C. MINIMUM OF SITE COUNTERMEASURE EQUIPMENT AND MATERIALS TO BE FURNISHED BY EXXON U,S,A, The following list of materials and equipment will be maintained at the active Drillsite with Parker Drilling Company Rig No. 97. This minimum list, or its equivalent, will be always available for oil spill countermeasures. 1. Equipment On-Site At Deadhorse 1 Caterpillar 966 Front Loader 1 Caterpillar D-7 Bulldozer 1 Whittaker Expandi-Boom Spill Containment Boom(1000'long) 1 Komura Mini-skimmer Front End Loaders Rolligons Belly Dumps 21' Boston Whaler Boat Labor Crews Graders Dozers Trucks 2. Materials On-Site Polyethylene Sheeting 10 - Roils 5/8" X 3' X 150' Absorbent Sheeting Barite Lost cirCulation Materials (Walnut hulls, cellulose, etc.) Bentonite 27 SPCC PLAN FOR PARKER DRILLING COMPANY RIG NO. 97 CONTRACTED TO EXXON U.S.A. ne ATTACHMENT NO. 3 MINIMUM INSPECTION PROCEDURE FOR DRILLING FLUIDS SYSTEM MOBILE ONSHORE DRILLING RIG EACH TOUR BY DERRICKMAN Check drilling nipple, flowline, and shale shaker box for leaks and flow stoppages. Shale shaker screen, back side of shale shaker including by-pass and overflow should be checked for proper functioning and fluid flow. Inspect Blowout Preventor equipment, including kill-line and choke manifolds with its associated relief lines to burn pit and reserve pit for fluid flow and presence of frozen fluids. Position of each valve in the system should be determined in ~'~accordancewithBOP.operating~procedures. Inspect outside of mud'tanks including bottoms for fluid flow, verifY that there is no fluid below drifted cuttings, snow or'ice. All discharge jets and cleaning hatches between tank flowlines should be free of leaks. 4. ~.Check mud pumps, pump suction lines, pressure safety valve relief lines and high pressure mud lines in sub-structure to the' rig floor, cement units and mud hoppers for leaks and/or freeze-up. Check equipment on top of each mud tank for proper operation. Mud by-pass troughs and lines should be clear to prevent over- flow. De-gasser inlet and discharge lines and associated con- trol valves should be open for flow and unfrozen. De-sil%er and de-sander inlet, discharge and underflcw lines should be unblocked with control valves free. Check for excessive fluid underflow. Check mud hopper(s) for proper operation. Dry mud materials should be protected during storage. Any large quantities of concentrated chemicals lost from dry storage or while transporting on rig site are to be recovered. e Derrickman should report results of inspection to his driller. The driller will give instructions, as required, to the rig crew for completing action to correct noted discrepencies. The driller will also report all abnormal conditions to the toolpusher immediately. 8. The completionof this inspection procedure is to be recorded on the IADC report for each tour. 28 SPCC PLAN FOR PARKER DRILLING COMPANY RIG NO. 97 CONTRACTED TO EXXON U.S.A. CHECKLIST FOR KEEPING SPCC PLAN CURRENT Note: Minor Revisions to the SPCC Plan may be made at any time without engineering re-certification. This SPCC Plan should be kept current by making revisions when applicable. 1. Fuel Storage Revise the Plan to show you any additions or deletions of fuel storage tankage. The physical and chemical properties of the stored fuel should be inserted on a current basis, in Part I of this Plan. 2. Drillsite Area As-Built Revise the Plan at each new drillsite to show the "Predicted directiOn of flow" for any spills which escape the drillsite. This should be done by inserting into the Plan, an As-Built Contour Map of the area within approximately 2500 feet of the well. The As-Built Contour Map, used together with a USGS'Topo Sheet, 1:6336, which includes the drillsite vicinity; should be marked to show the predicted direction of flow. Sites should then be selected along the predicted flow path for construction of flow barriers (dams). This dam construction would then take place, should a major spill occur. These drawings and maps should then be inserted into this SPCC Plan under Part I. 3. Drillsite and Campsite Specifications and Drawings The drawings and specifications prepared for the construction of each location should become a part of this SPCC Plan fcr that particular operating location. These are to be inserted under Part II. 4. Changes of Rig Equipment Any additions or deletions of fuel or liquid mud storage equipment must be recorded in the space provided in Part I. 5~ Add/change names of Exxon U.S.A. personnel to Oil Spill Reporting Chart, and Directory of Oil Spill Reporting and to Part I of SPCC Plan as reassignments are made. This should be done for Parker Drilling Company and the governmental agencies also, but is required for Parker Drilling Company and Exxon U.S.A. 6. Each working copy of the SPCC Plan must include a copy of. all Oil Spill Reports. 7. Copies of the SPCC Plan must be kept at the Site of operations by Parker Drilling Company. SUMMARY OF PROCEDURAL REQUIREMENTS FOR SPCC PLANS & RELATED ENVIRONMENTAL REGULAT IONS A. GENERAL This summary provides a "checklist" of actions required by the U. S. Environmental Protection Agency Regulations 40 CFR; Parts 109, 110, & 112. The instructions and information provided herein is compiled from these regulations and from data furnished by'local U. S. EPA and Alaska DEC officials. B. ENVIRONMENTAL PROTECTION REGULATIONS ~ 1. Applicability The U. S. EPA Regulations apply to every individual person, government agency and commercial entity who store more than 1320 gallons of any hydrocarbon or hydrocarbon derivative above ground or more than 42,000 gallons below ground, and the most extremely remote possibility exis~ ~ ~s for this material to be "discharged" into any territorial waters of the United States. "Discharge" is defined as the creation of a "sheen" on any waters of the U. S. or the release of 1,000 gallons or more hydrocarbons at one 'time into any waters. All "Discharges" are reportable to the U. S. EPA. The Federal Water Pollution Control Act (as amended) prohibits the alteration of the quality (naturally existing physical and chemical properties) of any U. S. Waters by discharging any material into them. SUMMARY OF SPCC PLANS Page Two The Alaska SPC Regulations state: "No person may discharge, cause to be discharged, or permit the discharge of petroleum, acid, coal or oil tar, lampblack, aniline asphalt, bitumen, or a residuary product of petroleum, into, or upon the waters or land except"---as provided by permits. Those who are included in any of the above categories must take one or more of the actions which are.listed below: References. a. The Federal Water Pollution Control Acts; as amended~ Public Law 92-500, 92nd Congress, S. 2770, October 18, 1972. b. Environmental Protection Agency Regulations, 40 CFR, Parts 109, 110 -& 112. NOTE: These regulations apply to all but transportation related facilities. See 40 CFR Part 112.2. c. Department of Transportation Regulations, 33 CFR, Parts 154 & 155. NOTE: These regulations apply to transportation related facilities. 46 CFR Parts 10, 12, 31, 71, 91, 175, 176, 187, 188 & 189. NOTE: These regulations apply to inspection certification and licensing of vessels and vessel personnel as related to pollution prevention. d. "Suggested Procedure for Development of Spill Prevention Control & Countermeasure Plans". API Bulletin D16, American Petroleum Institute. e. Alaska Statutes: Title 46, Chapter 03, Water, Air and Environmental Conservation. C. ENVIRONMENTAL PROTECTION PROCEDURES 1. Spill Prevention Control and Countermeasure Plan (SPCC Plan) a. Ail who fall within the limits of paragraph B.1, above, must prepare a SPCC Plan within six months of initial facility operation and complete implementation of same within one year. SUMMARY OF SPCC PLANS Page Three b. The SPCC Plan must be on site at the facility. c. The SPCC Plan must follow guidelines of 40 CFR, Part 112 in preparation and implementation. d. The SPCC Plan is Submitted to the U.S. Environmental Protection Agency, "officially", when a "discharge" occurs. e. The SPCC Plan must be certified by a Registered Professional Engineer. f. The SPCC Plan must be amended for the following reasons: (1) When required by the EPA after review of the Plan, submitted because of a spill event, (2) (3) Whenever there is a change in facility design, construction, operations, or maintenance which materially affects %he potential for an oil spill, or, The owner or operator is required to review each SPCC Plan at least once every three years, and an amendment is required if such review indicates more effective control and prevention technology will significantly reduce the likelihood of a spill event (and if such technology has been field proven). See 40 CFR, Part 112.4 for details for amending. Generally, SPCC Plans may be amended to reflect minor equipment or operational changes without re-certification by a registered engineer. This type amendment should be made as soon as they are applicable to operating conditions. The SPCC Plans must be kept current. 2. Reporting U. S. Environmental Protection Agency a · All "discharges"or "reportable spills" must be reported to the U. S. EPA immediately. These are defined as: (1) Discharging more than 1000 U.S. Gallons (24 '~ barrels) into U.S. Waters at one ~ime; or SUMM~RY OF SPCC PLANS Page Four b· C · (2) Creating a "Sheen" on U.S. Waters (discharged oil in harmful quantities as defined in 40 CFR, Part 110) on two occasions with a 12 month period. Creation of "sludge" in U.S. Waters is reportable in the same manner as a "sheen". The reporting of the release of "oil" other than described above is not required under Federal Regulations. Immediate verbal reports should include the following: (1) Date and time spill occurred or was first observed. ~2) Where spill occurred and present location. (3) Estimate of amount spilled and type of material. (4) Environmental conditions: temperature, wind direction and speed, wave action, currents, ice, snow. (5) If from barges'or vessels, name of craft, registry; owner or consignee, deadweight tonnage or draft. (6) Description of area likely to be affected such as river banks, beaches, properties, wildlife areas. (7) Cause of spill, if determined. (8) Action being taken to combat spill. (9) Agencies or persons notified. Subsequent Written Reports. Written reports of "discharges" are required as shown by the following regulation excerpts. However, the written report should be submitted' as soon as possible. Within 60 days of the occurrence of either of these two conditions the operator must submit to the EPA Regional Administrator the following: (1) Name of the facility. (2) Name of the owner or operator of the facility. ii 33 SUMMARY OF SPCC PLANS Page Five (3) (4) Location of the facility. Date of initial facility operation (date of first production of first gas plant start-up). (5) Maximum storage or handling capacity of the facility and current normal daily throughput. (6) Description of the facility, including maps, flow diagrams, and topographical maps. (7) (8) (9) (10) (11) A complete copy of the SPCC Plan with any amendments. The cause of' such spill, including a failure analysis of the system or subsystem in which the failure occurred. Lease production facili- ties may be divided into drilling, production, and gathering systems for identification pur- poses in reporting to EPA. These major systems can be broken down into various components or subsystems. The failure analysis is to examine and explain the reason for the failure resulting in the spill event. The analysis should be explicit, definite, and not general. For instance, it would be adequate to report simply that the cause of a spill was the failure of a storage tank. The failure analysis should indicate in some detail the nature of failure that caused the spill. The corrective actions and/or countermeasures taken, including an adequate description of equipment repairs and/or replacements. Additional preventive measures taken or contemplated to minimize the possibility of recurrence. Such other information as the EPA Regional Administrator may require. SUMMARY OF SPCC PLANS Page Six d. Reports are to be made to: Mr. Raymond W. Morris; Chief Oil Programs Telephone at Anchorage Office: Day - 265-4881 Night- 272-8812 Note: Night number is FAA Duty Officer. A report to this number is transmitted to the U. S. Coast Guard Duty Officer, who in turn screens the report for the EPA. Home: 344-9327 Address: Alaska Operations Office Region X U. S. Environmental Protection Agency 605 West Fourth Avenue Anchorage, Alaska 99501 Alaska State Department of Environmental Conservation a~ EPA Regulations 40 CFR, Part 112.4 requires all information provided the EPA "shall be sent at the same time to the State agency in charge of water pollution control activities in and for the State in which the facility is located". b~ Alaska SPC Regulations 46.03.750 (d) state: "A person in charge of a sea-going vessel or of an onshore or offshore facility, as soon as he has knowledge of any discharge from the vessel or facility in violation of a provision of this chapter shall immediately notify the department of the discharge. Ce Immediate Verbal Reports should include the same information listed for submission to the EPA. d. Subsequent written records which are furnished the EPA should be furnished the Alaska SPC. e. Reports are to be made to: Mr. Douglas LOWERY Northern Regional Environmental Supervisor Telephone at Fairbanks Office: 452-1714 Night: Mr. John Janssen Home: 465-4861 488-2834 35 SU~LMARY OF SPCC PLANS Address Northern Region Alaska State Department of Environmental Conservation P. O. Box 1601 604 Barnette Fairbanks, Alaska 99707 3. Implementation of SPCC Plan The SPCC Plan must be implemented within one year after initial facility operation. See 40 CFR, Part 112.3 for exceptions. The regulations intend that at such time as a "dis- charge" occurs; the SPCC Plan has been actually implemented at the facility in its existing form. Revisions to 40 CFR, Part 112 are now under way to eliminate both the six month preparation period and the one year implementation period. It is extremely important to note that at such time as a "discharge" occurs, the validity of a SPCC Plan will be tested. SUbsequent EPA investigation can require SPCC Plan and facility revisions. The history of SPCC Plan implementation will bear on potential penalties levied. No prior approvals or suomission of SPCC Plan is required by the regulations, in order to begin · implementation. In the event of a "discharge" the applicable SPCC Plan must be submitted with the written "discharge" report for review. At this time, amendments to the Plan may be required. 36 CONTINGENCY PLAN · · EXXON NO. 1 DUCK ISLAND UNIT CONTENTS Pollution Control Plan Oil Spill Containment and Clean--up Plan- Relief Well Plan Emergency Evacuation Plan Exxon No. 1 Duck Island ~nit Spill Control and Countermeasure Plan ~cope The scope of the Pollution Control Plan outlined below is as follows: ae To define normal operating procedures to be followed during move, drilling, testing and related operations undertaken at the Exxon No. 1 Duck Island Unit loca- tion. To detail all necessary special procedures and pre- cautions to be followed during critical operations such as fuel transfer etc. To outline preliminary plans for containment of pollutants should an oil spill occur. To describe action to be taken in the event of an uncontrolled oil spill, either major or minor, including- - Governmental Agency Notification and Requirements - Designation of Authority - Immediate spill control response actions - Location clean-up plans - Disposal of recovered fluids and materials To outline remedial actions to be taken in the event · of an uncontrolled well flow including plans for construction of an additional relief well location. Objectives ... The objectives of the attached plans are: Insure the safety of all personnel involved in oper- ations at the Duck Island #1 location. ¸2, Minimize the environmental impact of operations. Comply with all current Federal, State and Local standards in effect and anticipated in the future including those related to the Flaxman Island settlement. · Protect the integrity of the rig, location and ancillary equipment. -1- The rules and procedures set out in this document are to be followed by all operations personnel, support personnel and visitors on-site at Duck Island. It will be the Exxon Drilling Superintendent's responsibility to see that environmentally sound practices are followed on this well. The procedures outlined in this document are to be considered minimum standards for operation. It is up to all personnel involved to conduct their work in a manner minimizing environmental impact. In compliance with federal regulations, a copy of this document shall be available for inspection at all times on the Duck Island drill site. Personnel ~nd Organization ~.~ Norma_! OP~erations During normal operations (ie: drilling, testing, abandonment and move operations) the primary goal of all personnel shall be to minimize system upsets and pollutant discharges, specific responsibilities are: Exxon Anchorage Engineering - Responsible for review and dissemination of information regarding applicable Govern- ment regulations and development of procedures necessary to insure regulatory compliance. Engineering is also responsible for developing technology for clean operations. Exxon Dri~l!%.ng Superintendent - Responsible for daily activities including support operations for rig supply, construction etc. The Exxon Superintendent. is also responsible for insuring that all personnel are aware of regulations and procedures pertinent to their activities. Contract Superintendent - Responsible for the main- tenance of the rig and training of crews to insure sound operations. Ancillary Contractors - Responsible for knowing and following procedures applicable to their individual operations. ~, Eme?_.gency _ Operations During emergency operations (ie: uncontrolled well flow, oil spill etc.) the main effort should be toward minimizing the effect of pollutant discharges. Major areas of responsibility are: ~' ~ -2- ~e~dquarters Drilling - Responsibx~ for overall management ~f drilling efforts including well control and relief well operation. Will advise Anchorage Drilling regarding action ~equired to comply with Federal, State and Local statutes. Anchoraqe Operati. gns. Mana.ger.- Has overall responsibility for emergency response team. Transmits pertinent data to Western Division management. Anchorage Public Relations - Will act as the single point media contact. Anchorage Drilling - Advises management of the extent of the emergency. Additionally will be responsible for filing all reports required for regulatory compliance. Plans well control and relief well operations. Exxon Drilling Superintendent - Advises Anchorage Drilling of situation and coordinates on-site efforts. Contract.Superintendent - Responsible for safety of contractor personnel and rig. -3- Exxon No. 1 Duck Isla --Unit Pollution Control ~an Objective 'The following plan outlines actions and procedures considered essential to conduct operations while minimizing exposure to pollution. These plans should be supplemented by the experience and knowledge of those involved in the operation. General Site Details Fi'gures 1 and 2 describe the general location and pad config- uration of the Duck Island site respectively. The location is constructed as a 400' diameter artificial gravel island. The pad is located in 4' nominal water depth and has a total 'thickness from sea floor to pad level of 10.5'. A 3' high (approximate) gravel berm surrounds the outer perimeter of the pad and the outer slopes of the island are constructed 'with a 1:7 beach slope to prevent erosion. Major pad features include: - Reserve/Contingency Pit - A 20' x 48' x 5.5' contigency pit capable of containing 2020 bbls. of fluid is located on the east side of the drilling pad. This pit provides space for emergency discharge of fluids and will normally be pumped dry to maximize emergency storage capacity. Fuel Pit - A 57' x 70' x 6.5' pit is provided to contain the four 30000 gal. steel fuel tanks to be used in drilling operations. This pit has a triple layer lining (sho%~ in figure 3) to prevent any leakage of spilled hydrocarbons or other pollutants. Storage capacity of this pit is 7050 bbls. __Day Tank Pit - A 15' x 44' x 3.5' pit is provided to contain the 400 bbl. rig day tank supplying gravity feed for the Parker rig. This lined pit has a total capacity of 650 bbls. of fluid. Effluent Pit - A 12' x 42% x 4' pit is provided for emer- gency storage of sewer plant effluent. Storage capacity of this pit is 360 bbls. ~ig Liner - A single layer liner composed of Herculite rein- forced plastic has been buried in place beneath the Parker 97 rig to act as containment for fluids spilled in the general rig area. Ice Containment - At freeze-up during the fall/winter period of 1978, the location will be coated with an ice coating as a final boundary to trap spilled pollutants. Figure 4 shows the general topography of the. Duck Island location and the anticipated direction of flow in the event of pollutant discharge. Sea currents in the vicinity of the location are expected to be strongly influenced by run off from the · I 'e I I 'o I PROPOSED ,, BOTTOM HOLE $0o'-.~ CATION I I ~_ I I I I . I I I I I t , I · i I~EXXON No.I, DUCK,, ISLAND UNIT Howe I A ~ ..._ ! . . ,,L,,'~ t t.: ?o°,~ 00.,3' . ¢_..~'"o °1 I ' ~~ ~ LONG =!47°51'46.83" ~---~--~:- ~- ---~ x: ~o,,~ --~1 .... / i ' ~,. ~ ,0%, ,. ~,. ',. I". , SCALE I": I MILE I I 1 .o CERTIFICATE OF SURVEYOR · · I hereby cerlify thor l em properly regislered.o'r~'d. licensed lo practice lond surveying in the Store of Alesko ond lbo! lhis plot represents o locolion survey mode by me or under my supervision, and thai oll dimensions ond other .details ore correct. Dote Surveyor NOTE .i. LOCATION NOT FIELD SURVEYED AS OF 11415 DATE - DC[ 20, 1977. T. 12N. T. il fi. ~z.~. ,.:.~,-,'~..,-.~/-.,. ) ., ea. F~GURE 1 ' PROPOS[D EXXON No.I DUCK ISLAND UNIT Locoted SI ,/4 Protracted scL.9, Surveyed /or EXXON COMPANY U.S.A. :~_:~ -' ~ _ c_:__~ .... Suf vexed EM. LINDSEY G ASSOC. LAND 5 HYDROGRAPHIC Table 2A ./ I ° ' 7 i 9 /0 JCK ISLAND UNiT EXXON N'o.i (SURFACE SITE) · '" ""' o · ' 'i ~-;""" / 'i' .',~- ' ;I, ..... t ' ' r-, ~;-%k-. ,~. I ~ ~. ..... 'r_;. :-~.'.', ~:' "-' '''! ,. FIGURE 2B ,~/..~ . AREA :.< '~,ff DUCI~ ISLAND ., Ev,,~N /\ t\ ~../ "l SCALE' -- ,'-,~ ! DATE: OCTOBER I977 ,¢ g',. , ,'k) "..:<t . LEGEND . + · e. .o OPERATIO,=S I.',.,P , -- X! %/ ' ,! · Ui,]l I , E/,,,O~I ,.o. 1 u.s.,. Jlf[,' I,: i · _~ i11111 i i ifil i ill ii. l_ i . i i ii ii i i i i i . ii i ii i i i · .. "· · .. ? .! e ANTICIPATED CURRENT DIRECTION ~i W~I(I i~ I0 iI i FIGURE 4 , __ DUCK ISLAND UNIT EXXON COMPANY U. "-: ~ ~-vDn~rk~ok River. Spills reaching th~ ~cean are expected a-northerly direction. Since there is no natural ~.oD.~ain~m~n~ ~rap at this offshore location, mechanical devices spill booms and skim~ing equipment outlined in the Containment and Clean-up Plan will be used to contain ~a~r spill. After freeze-up, snow berms or other will be used to contain pollutants. Equipment and Materials for deployment of pollution control 6quipment and con- .of dikes, berms and other structures, the following will be maintained on location and at Deadhorse. On-site At Deadhorse Caterpillar 966 Front Loader Caterpillar D-7 Bull Dozer Whittaker Expandi-Boom Spill Containment Boom (1000' long) Komura Mini-skimmer2 Front End Loaders Rolligons Belly Dumps 21' Boston Whaler Boat1 Labor Crews Graders, Bulldozers, Trucks A~d. ition~al spill clean-up equipment including Oil Mops and ~o~be.nt materials can be mobilized from Anchorage within hrs. ' n In additlo., to equipment shown above, the following construction a~d absorbent materials will be maintained on location to combat · ~1 ~pi!ls: ~olyethylene Sheeting Roils - 5/8" x 3' x 150' Absorbent Sheeting B~.ntonite Circulation Materials (Walnut hulls, celulose, etc.) Operations Procedures Site Surveillance ~nder normal drilling operations the Exxon Drilling Superintendent will be responsible for conducting frequent reviews of the drill site to insure that equipment maintenance is kept up to standards and that proper on-site procedures are followed. The items to be checked during site surveillance include, but are not limited to: The Boston Whaler will be maintained on location until September 15, 1978 after Which it will be available in an emergency from ARCo. Operational information for the Komura skimmer is included in Appendix C. - Mechanical condition of tankag~ nd lines - Correct positioning of flowline valves - Condition of flexible hoses - Operation of relief.valves - Fluid levels in drip pans, containment pits, etc. - Condition of drains (insure clean and unfrozen) - General condition and cleanliness of rig - Proper operation of sewage treatment facilities - Snow removal status In addition, the following procedure will be followed while oper- ating on this location: The Exxon Drilling Superintendent will designate "Briefing Areas" where all personnel will meet in case of emergency and where emergency equipment will be kept. - The site will be equipped with an Exxon operated radio system. B· A list of current emergency telephone numbers and a map of the local area will be maintained by the Drilling Superin- tendent. , Pit Level Maintenance Procedures As part of our operational plan, injection capability to the 20" x 13-3/8" and the 13-3/8" x 9-5/8" annuli (pending approval by the State of Alaska Department of Natural Resources) will be established immediately after the respective casing strings are set to facilitate disposal of excess fluids on location. An injectio~ fluid gathering system interconnecting the pits to the injection pumps will be constructed and pit fluid levels will be maintained at minimum practical levels at all times. The following procedures will be followed to prevent overflow of pits on the Duck· Island drill site. · Ail pits will be monitored daily to ascertain fluid level. Utilize the supplied fOrms to record fluid levels in each pit daily. · Fluid will be automatically pumped to the injection system surge tank from the drill site pits. The fluid will be metered to measure the amount pumped to the well. Forms provided will be used to record volumes transferred. After the 9-5/8" casing string is set, injectivity tests will be conducted down this annulus using drilling mud and make-up water, limiting injection~ pressure to below the collapse rating of the casings. The cementing pump will be used to inject all fluids. -6- o ~e the supplied forms to injected into the well. 'ord daily the fluid Prior to injecting any fluid down the annuli, notify the Drilling Superintendent. Any removal from the pits must be injected down the annuli or retained on location in the mud or make- · up water systems. C. Fluid Testing At least four times monthly, water samples from the sewage treat- ment plant and drinking water supplies will be transported to Anchorage for testing. D. Snow Removal - Dike Construction In order to limit the amount of potential water drainage on location and to add back-up containment, snow will be removed periodically and inpermeable dike constructed by windrowing this snow around the location perimeter. The initial dike will be formed as a perimeter containment structure on a 400' radius from pad center. Dike construction will follow methods outlined in the oil spill and clean-up section of this document. Critical Operations Procedures A. Fuel Transfer Procedures 'Operations involving fuel transfer are critical in''that mistakes occu~ring at this time will likely lead to an oil spill. Appendix A contains a detailed procedure checklist which shall be followed before fueling operations commence. General guidelines for these operations are: le Insure by testing or inspection that all equipment and lines are in proper working order before transfer begins. Lines are to be pressure tested to 1.5 times the maximum anticipated transfer pressures. Review procedures with all personnel involved to insure ~ha% everyone knows his job. Double check that all valves are positioned correctly before transfer begins. 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. -7- It is the r~"~lling Superintendent's re~oonsibility to insure that proper procedures are implemente~ ~ring each fuel transfer. Well Testing Well testing operations have a high risk of oil spill occurences. Special procedures to be carried out during well testing are: 1, Insure that all test vessels are inspected prior to testing. Flowlines should be tested to 1.5 times full working pressure to minimize the possibility of line breakage. Provide containment as deemed necessary. Temporary snow/ice dams could be constructed around equipment not protected by gravel pits. Provide methods for diverting fluids to the reserve pit should equipment failure lead to an uncontrolled flow situation. · 5, Review test procedures and equipment operations with all involved personnel prior to start of the test. Insure that everyone knows his job assignment. Double check the position of flowline valves prior to testing. -8- Exxon No. 1 Duck Islan~ Unit Oil Spill Containment & Clean-up Plan Objectives The purpose of this section is to outline action to be taken in the event of an oil spill on the Duck Island #1 location including: - Notification and compliance with all regulatory agencies - Construction of additional containment structures - Spill clean-up procedures - Recovered fluids disposal procedures Notification Reauirements In the event of an oil spill, the Drilling Superintendent shall immediately contact the Anchorage Drilling office and issue a report including the following information: .. Date and time spill occurred or was first observed Where spill occurred and present location Estimate of amount spilled and type of material Environmental conditions, temperature, wind, etc. Description of area likely to be effected Cause of spill Action taken to combat spill Anchorage Drilling will be responsible fOr making.contact with Headquarters Drilling, Law and all required governmental agencies. General procedures for Anchorage Drilling to follow in this regard are: 1. Contact EPA by telephone and notify that spill has occurred and is being investigated. Notify Headquarters Drilling of the spill providing available details. Notify Alaska Department of Environmental Conservation by telephone. ~ Notify Alaska Division of Oil and Gas Conservation by telephone. 5, Notify by telephone the U.S. Coast Guard and Alaska Division of Minerals and Energy Management as re- quired. Coast Guard notification is required in cases where oil is spilled to open water or on the ocean ice pack. ~ -9- A % tten report of the spill-hall be drafted and ~lecopied to Headquarters Dr~ _ing. Additional %~ritten follow-up reports will be written to the following agencies as directed by Headquarters Drilling: - EPA (Draft notice on plain white paper telecopied ~o ~eadquarters Drilling. Headquarters will handle further contact with the EPA.) - Alaska Department of Environmental Conservation (w/ CC to the Alaska Division of Oil and Gas Conser- vation - U.S. Coast Guard .. - Alaska Division of Minerals and Energy Management A list of contacts for government agencies involved is provided in Appendix B. All involved agencies shall be contacted as ~oon as possible after the oil spill occurs so as to comply with regulatory requirements. Failure to report oil spills can result in prosecution. Oil Containment Plan .. . General Upo;~ sufficient continuous sea ice buildup in the general vicinity of the Duck Island location, a perimeter snow containment structure shown in figure 5 will be constructed according to techniques out- lined in this section. The outside wall of this structure will be on a 400' radius from the center of the island. Materials for the structure will be obtained from the area inside this outer perimeter. The area inside the structure will be kept free of snow at all times. A. Before Freeze-up In the event that an oil spill occurring before freeze-up at the Duck Island %1 location cannot be contained on the drill site or in the contingency pit and pollutants reach open water, the following steps will be taken to contain the oil spill. 1. Stop the spill at its source. Mobilize all equipment required to contain the spill fluid. 4~ Ascertain the direction of current (general direction in which the spill is moving). ~sing boats, deploy the Whittaker Expandi-boom to · surround the spilled fluids, block the fluid flow ~%d collect thc spilled fluids. As the 1000' of bosom will not surround the entire perimeter of the ~sland, it will be necessary to place the boom to block ~e expected path of spill migration. A typical deploy- ~w~ ~iagram is shown in the attached figure 6. Perim~r Reserve Pit FIGURE 5 PERIMETER DAM CONSTRUCTION DETAILS ON-SHORE ANCHOR DIRECTION OF SPILT, FLOW BOAT N FIGURE 6 TYPICAL DEPLOYMENT OF THE WHITTAKER "EXPANDI-BOOM" ~.~ce the spill containment ~--'~om is in place, deploy the Komura Skimmer directin~ it into the location of the highest oil concentration. Make a sweep periodically of the outside perimeter of the containment boom to assess whether any oil has escaped to open water. Mop up any residual fluids with absorbent materials and recover all contaminated ice, snow and gravel placing contaminated materials in steel containers for disposal. B. During Freeze-up During freeze-up, limited operations may be possible to contain and mop up spilled fluids depending upon the'extent of the ice cover and ice conditions. 1· If sufficient ice leads exist to allow navigation of small boats in and through open ice, the following procedures may initiated. - Deployment of the Whittaker boom may be feasible if open water exists around the drill site area. - The Komura Skimmer may be deployed in large ice leads to mop up isolated spills. Sorbent materials should be used where applicable clean up oil spilled in small ice leads. - An oil mop (available from Crowley Environmental Services, Anchorage) can be used in conjunction with a small boat to recover floating oil slicks in ice leads. If sufficient ice leads do not exist and/or only a thin continuous ice layer exists, the general perimeter of the spill should be staked and movement of the spill area closely monitored. In this case, the procedure will be to allow the ice pack to freeze sufficiently so that equipment and personnel can be mobilized for clean up procedures identified in the after freeze-up section. NOTE: SAFETY OF PERSONNEL IS A b~JOR CONSIDERATION WHILE CONDUCTING CLEAN-UP OPERATIONS DURING THE PERIOD OF FREEZE-UP. PERSONNEL SHOULD NOT OPE~'~TE ON ICE PACKS HAVING QUESTIONABLE INTEGRITY OR ON FREE-FLOATI:~G ICE- BERGS. C. After Freeze-up (Consolidated i, pack existing) · After freeze-up the major emphasis on clean-up will be con- struction of temporary snow/ice containment structures to minimize the areal extent of pollution. The primary line of defense will be the snow-ice berm around the perimeter of the island. This berm should be sectioned off as necessary with walls to confine the spill to as small an area as required. The ice area used for containment should be checked for fis- sures and all discontinuities should be packed with snow wetted with water as a repair. Accumulated snow on the ice in front of the advancing spill should be removed. Clean-up operations after freeze-up should be aided by the increased viscosity of fluids at low temperatures. Recovered fluids and contaminated clean-up materials (snow, ice, absor- bents, etc.) should be placed in steel containers for disposal. __SPill Clean-up ProcedUres The spill clean-up efforts at Duck Island #1 will be directed toward returning the effected area to as near natural state as possible. Minor spillage of fluid will be cleaned by use of absorbent materials and recovery of contaminated materials such as gravel etc. These soaked materials will be placed in steel containers for future disposal. Major oil spillage will be handled by use of conventional skimming equipment. Snow, absorbent materials and other contaminated materials (including tundra) will be recovered and processed by incineration. Snow Berm Construction Construction of the outer snow berm will commence a's soon as a sufficiently consolidated sea ice pack exists to allow construc- tion equipment movement on the ice. Ail dike and dam construction will use snow and ice for materials. Snow held within the containment area will be sufficient for all construction necessary. The dike walls will be constructed utilizing cats and loaders by windrowing the snow, spraying water on the windrow, mixing the snow and water, and then placing this material on the wall area. Ensure that the wall material is well compacted. This procedure is to be carried on until a minimum height of 5' has been obtained. - The level of the dam is to be consistent throughout its entire length. The walls should have a 3 to 1 slope front and back. -12- Exxon No. 1 Duck Island Unit Relief Well and Pad Construction In the unlikely event of an uncontrolled well flow occurring, an additional location will be constructed to facilitate drilling of a relief well as follows. Location The optimum location for a relief well pad will be on Duck Island located in the NE 1/4 of Section 18, .TilN, R17E, UM. From this location a directional well having a 52° maximum angle will be drilled to span the 10000' throw to the target bottomhole loca- tion for the Duck Island #1 well (assuming a 2700' KOP and 2-1/2° /100' angle buildup rate for the relief well). This location is %he nearest point of land to the Duck Island #1 location and will require minimum preparation time. Pad Construction · . Before freeze-up the relief location will be constructed using a piling and board design with~ contingency pits being excavated using existing gravels on the Island. Construction equipment would be transported via rolligon or helicopter. Approximate pad size will be 300' x 330' to accomodate the drilling rig, camp and storage of pipe and supplies. After freeze-up either a gravel location or the board location can be constructed depending upon available equipment and mater- ials. Should gravel be used as material, an estimated 22000 yd3 will be required. Proposed gravel sources for this work are located in Section 32 and 33 of T10N, R16E, UM having an esti- mated total gravel supply of 95000 yd3. Construction of the relief pad and drilling operations will be undertaken using equipment mobilized from Deadhorse either via ice road, rolligon or helicopter depending upon the state of tundra conditions and weather considerations. In the event that weather conditions preclude surface transportation, a helicopter transportable rig will be mobilized from Deadhorse along with all necessary supplies and additional equipment. Support operations for the.rig will be conducted using helicopter or truck transport depending upon conditions. -13- EXXON NO. 1 DUCK ISLAND UNIT EMERGENCY ISLAND EVACUATION PLAN Exxon Production Research Company (EPRCo) has determined that in the event of rare sea ice and storm conditions, the potential exists for the sea ice pack to severely damage the Duck Island location, (by shearing and/or movement) resulting in cessation of'operations, evacuation of the location and a potential pollution situation. The attached plans are designed as minimum actions to take in the event of this emergency. ~mergency_ Plan The potential for island movement or shearing exists primarily during the period preceding freeze-up. During this period, high winds could direct the sea ice pack against the location, in which case the ice pack is anticipated to be structurally stronger than the island itself causing the island to be dis- placed laterally. In this situation the integrity of the well~ would be in question due to shearing above mud line level. We anticipate that sufficient time (8-12 hours or more) will be available to complete actions to seal the well and evacuate the location, insuring prevention of pollution to the environment · and safety of personnel. In %he event of this emerge~ncy the following steps will be followed: With sufficient time available (8-12 hours) ahd annulus injection capability established, all fuel (with the ex- ception of a 1 day supply) shall be injected subsurface to restrict the quantity which could be spilled to the environment. Contents of the sewer plant and other miscellaneous liquids should be injected and all unnec- cessary fuel lines should be drained. Upon completion of injection, a permafrost cement slurry (300 sx) should be mixed, displaced to the annulus and bullheaded with sufficient displacement fluid'to place the top of cement below 300'. Demobilize and secure the camp and evacuate all personnel with the exception of a skeleton crew to complete operations listed below. Trip out of the hole and set Johl on Hurricane or similar type packers w/back pressure valves installed at the lower- most casing shoe and 300'. (Note: Two Hurricane type packers shall be maintained on location for the 13-3/8" and 20" casing strings throughout the period before and during freeze-up.) Pull out of the hole and lay down the drill string and packer running tools. Close and manually lock the blind ram preventor and drain the BOP stack and lines. Secure %he rig and evacuate all remaining personnel. APPENDIX A FUEL TRANSFER PROCEDURES · U.S.A. · I>OUCII &~)l , ANCI, IORAG£, A. ..~KA D9502 October 17, 1977 : (See Attached Distribution List) · . . · Full compliance with all Federal, State and Local laws, rule% and regulations is of highest priority for each of us in carrying out our various duties and responsibilities. The prevention of a spill or discharge of oil, oil mixture~or any potential contaminent is probably our greatest concern in this regard and commands our utmost effort. However, we continue.to have sRills and accidental dis- charges which we believe could be avoided through greater awareness, .planning and surveillance. · Opt total effort in this regard ib expected and ordered by company -management at all levels. We each have the implied authority to do %~atever is necessary to avoid spills, discharges and contamination of any kind. Although each of us is charged with, understands and desires to fulfill this responsibility, %~e are not getting the 'results ~e seek and we must develop batter ways to prevent every possible spill or unauthorized discharge. . · We request that you analyze the Potential for ~pills.or discharges ~n the areas of your work responsibility and give us your co~ents and recommendations for avoidance as quickly as possible. One area in which we are experiencing a real difficulty is ~he trans~ far of fuels. We believe we can eliminate fuel spills by, 1) increas- ing our inspection and testing of fuel handling systems and equipment, ~) increasing the supervision and surveillance by Exxon personnel of all fuel transfers and 3) assuring that contract personnel receive explicit procedures, instructions and supervision on our fuel handling and transfer operations. To assure that we do not overlook any actions needed to prevent spills you are requested to adhere to the attached guidelines' for all trans- fers or movements of fuel, produced oil, mud or any. contaminants · conducted within your area of responsibility. The attached ct~cck lists covering transfer activities should also be carefully used and acknowledged prior to and during each transfer operation. Feel free to add to these guidelines and check lists as necessary. October 17, 19' - w Page 2 · · .. ' I';e each have many critical and important duties and responsibilities, however, the avoidance of spills and the compliance with all other regulations must be our number one priority even to the point of sacrificing other objectives and deadlines. We will appreciate your giving this maL~er whatever time and effort is necessary and we look. forward to.receiving~ your com~e.nt.__ s.~~and sug estions. - J.F. Homer JFH: cl Attachments · bce: R. L. Boane · .B. Elkin }{. J. Flatt W. M. Taylor GUIDELI]~ES 1. Awareness Be sure that you are notified and are involved before transfer of any type takes place. The most effective preventive effort occurs in proper planning before the operation is initiated. 2. Plan- Plan should include complete equipment list, detailed procedure, personnel list with duties and responsi- bilities, and contingency plans for all recognized - malfunctions and upsets. 3. Test and Inspection- Ail pipe, hoses, pumps and other equip- ment must be tested to at least 1-1/2 times tl~e ' maximum (50 psi minimum) pressure required to com- plete the job. Complete a walk around inspection of all tanks, piping and equipment to locate potential problems or possible leaks, unsupported lines, fire hazards, freeze up hazards, nozzles at lines not secured to tanks, cross threads or short make up, · g°od pressure gauges installed, damaged lines, tanks, etc. ' use check' list· -.' · 4: Supervision a~d Surveillance During Operation - Monitor pressure and volumes to assure within safe limits. Make sure contractor personnel are at stations and understand procedures. 'Keep in mind emergency procedure in-case of upset. Log volumes, pressures, time, etc. on supplied surveillance form. Shut down operation at occurrence of any anomaly. Investigate and correct before proceeding. . . · % · . · Check P~,Io or Put Applicable il~ ~d~_~r..~e. ~ .~.~_oe..l.,vJ~j ~_ank,s both gauged ~b '$~ ~:~:te~ ~r any existing leaks ~,~ ,$~ :l~C'!~ ,a~ve existing level ..~v~ $,~X h~ .ov~:~lo~ line tied back ~ke ~a:p!e !~ ~o~ce ~ank, con~irn ~, ~{~ ~g P~n {p~n.enclosed) area . ~, ~{~ pp~ ~n~e from both t~nks ~ ~ ~ f~f~ {p ~V~n~ line Vibratfon !~ ~s to prevent bending __ _ ~ained to one of tanks; flushed threaded or flanged to receivln9 sec.~ely tied down in:o receiving th.~e~Scd ~onnections for proper have calibrated gauge installed Gau$~ng connection~ hold test pressure ~.~, · ~ . Check F~q o Put · Applicabl~ ~. ~rotectlve clothing, if nece~sary~ Yom by operating personnel _._._ 4. Energency personnel ~h~er flush facilities, ~f necessary, nea£by and ready Spill Contatn=~n: and Clean Up r~uip~w, nt 1o ~erms or drains set ~o ~pilI from any pein: Jn transfer area viii drain to arcs ~here spill viii bc confined and easily recovered ------- 2.. Clean cp p~r.p and ~anifold ready near Containc~nt area 3. ~gequate sorbent ~2terial in po~ition at rental n;an~ area · · Personnel -~o Detailed procedure ~or transfer outlined supervisor 2. Exact metho~ outlined for fhutdown and purging in case of an upset ~. ~11 operating personnel know dutie~ and ~eslx>nsibilities ------ 4. All non-operating personnel inform, ed of: &. ~o smoking within 50 feet of any point ~n system bo ilo welding or open flaras within 50 fee:______ ¢o~0 equipment is to pass over 'system ~uring transfer 5. Contingency plan personnel assi~raents r~de: · a° Fire-transfer ter~,.ination and fire fighting equipment manning .__._- ~o J~eak-transfer ter~%ination and leak clean up m~nnin9 - ~. S~dden system anomly-transfer termin- &tioll anomoly detection and leak · investigation 6, Exxon 5u~rvlsor -- Contractor Supervisor O~e~ating personnel assignments: Duty and ]~esponsib{lity · 1. Initials of Persons [Inking Check: Exxon Representative Contractor Representative of During Transfer · A. ~ressures 1° ~umi~.~'~ischar9e pressure monitored · continuously &. I~lntni~cd at less th~n one half test · · %'eludes. 3, Both t&nks $3u~ed every 30 ~{nu,.es . 2, Caugin9 recorded and balance check mmde {Record on attached for--.! Potcntl~l Leaks lo Line walked every 10 miflutcs to check ~ * 2o ~eceivln9 tank checke~ for leaks · ~nutes 3. O~ration shu~ dc~ and line flushed ~tely upon deter:iCh el ~n? leak. C[can up operation commenced as soon as transfer operation secure~. Cle~a up co=pleted and leak corrected prior to resu=in~ ope:a:ions Drilling raRa~e---ent notified el leak ~s soon as possible D. ~lzes 1. Operation shut ~n and line flushea · l~mediately in even~ of fire 2. Fire ftghtin~ prccegures initiata~ &~ operation secured · ' ~. Fire extinguished and cause corrected prior · to festering o~era~ions · fire extinguished . .. · ., .. ~. Personnel %. Operating p~ksonnel tn position throughout '2. Op~rating personnel respond to system ~psets or sp!ll~ CO,V~ENTS: Ao · · T~nks Source and receiving t~nks both 9auge~ __._._ ~pth %~ks ink,coted for any tx[sting leaks~ ~ank valves clo~ed after transfer Lines drained, flushed, or bloun dr~ u~om ~Ob termination I~on pcrumuenC lines disnantlcd and properly gtowcd · Pvmp~ ' p~ps drained ~nd ~eeur~ or st~ed a(te~ transfer and conditioned for next usc Valves ' Valves c~ecked for sealing Naives stowed in designated place A~ll~a~ Equipment Firef~ghting equipment stowed properly Llne flushing eq~pment stowed p~operly Conta~nnent and Cleanup Equipment Clean ~p pump and rmnifo!d stowed properly_____ ;bsorbent material stowed in safe dry place Used absorbent ~terlal disposed of accor~- ~ tO applicable regulations . -. · O. personnel '. ~. lion operating personnel alerte~ transfer ~v Complete . · ~o Operating personnel responded to system '' ' Upsets properly and stayed in positio~ . throughout job · ~nttials of persons Waking check , · '. 1· EXXOn ~epresentative ! o- . ~. Contractor Reoresentative ._..____of should be sent to operation~ superintendent imr, ediately following transfer operations.. ~. . Transfer-hose test pressure(maximum-pump pressure): Beginning: psi Ending: psi. · .. tece ivinq Tar~k .* A~t. Added ~T~.~e~ pP..r~..s~.s X~_r~e :Trr~_~.p~e:d Gauge Fluid Since Start Source Tank G~uqe rlutd (rt-lnl (Ga~} Stnce Start (Ga~) .o · · · · __ Volu.-es Balace APPENDIX B GOVERNMENTAL AGENCY NOTIFICATION Type 4~sBarge or sheen Discharge or sheen entering navigable waters (including but not limited to seas, oceans, bays, lakes, inlets, sounds, canals, streams, rivers, creeks, ditches including wetlands and intermittant rivers, streams and lakes even if dry at time of the spill). ~':hen transportation over tundra is re- quired. ~A, ge. pc~ Contacted Region ~0, U.S. Environmental Protection Agency Alaska Department of Environmental Conservation, Northern Regional Office Alaska Divison of Oil and Gas Conservation Address (Telephone ) 1200 Sixth Avenue Seattle, WA 98101 (206)442-1213 P.O. Box 1601 Fairbanks, AK 99707 (907)452-1714 /"." 3001 Porcupine Dr. . Anchorage, AK 99504 (907)279-1433 United States Coast Guard 632 W. 6th Ave. Anchorage, AK 99501 (907)272-1531 Alaska Department of Natural Resources, Division of Minerals and Energy Manage- ment. 323 East 4th Ave. Anchorage, AK 99501 (907) 274-8542 Jim Wil lman ) Doug Lowery Bob Tsigonis Joe Green Commander in Charge Mrs. Ethei Nelsor APPENDIX C POLLUTION CONTROL EQUIPMENT OPERATING ~ANUALS · · · Th~ KO,V, ARA ~,~INISKI,,u, MER (Hydraulic Operating arid Maintenance Instructions Distributor 14r. Steve Blackbourn 206/'285-3200 · ~arco Pollution Control . 2300 W. Commodore Way, Seattle, Wash. 98199 KOMARA MINISKIM,~{ER is a Irademark of The British Petroleum Company Limited. KOMARA MINISKIMMER is manufactured by Vickers - Slingsby, a division'of Vickers Limited. Offshore Engineering Group. Address:- Vickers-SI ingsby. Kirbymoorside. York YO6 6EZ. England. Telephone:- 0751 31751. Telex:- 57911. Contents SECTION 1 Operating the. KOMARA MINISKIMMER equipment SECTION 2 Maintenance of the KOMARA MINISKIMMER equipment SECTION 3 General data and schedule of KOMARA MINISKIMMER major parts page 13 o . · · , SECTION 1 ' ' ..Operating the KO,V, ARA ,~,~INISKI2AER equipment __Combined Pump Dr',d Powerpack Unit Pump $~c Flotation ~draulic Fe ed Hosa 13uo,/ end Return Lines Figure 1. .o 'l'he hydraulIc KOMARA MINISKIMMER consists of a skimming head, a Combined pump. and power pack unit, two hydraulic lings, oil suction hose complet9 with its float, and 'an oil discharge hose. HANDLING 'l'he KOMARA MINISKIMMER is designed for ease of handling with each parl o! the equipment capable o! being manoeuvred by two men. II can be Iransported quickly to the spill site for deployment. It only remains for the MINISKIMMER to be connected to a suitable oil receiving facility. PERFORMAN CE . 'l'he KOMARA MINISKIMMER will recover any oil lhat will flow. The o. late of pick-up will be goverr~ed by Ihe d~sc speed. Ihe viscosity Ihe oil. ils deplh al~d also lhe degree ol emuls~l~callo~. 'Typical pick-up tales are as Iollows~- Diesel or Gas O,I '/.~" lhlck ' 2.5 Ionnes/hr al 130 d~sc r.p.m. Kuwail Crude '1~" Ihlck 8.0 lotuseS/lit al 60 disc r.p.m. The MINISKIM,~,~ER has a draught o! 6'/~ inches (approx. 165mm) but will operale In waler 5 inches (approx. 130mm) deep il required. The 32 pick-up discs are rotated as semi-circular banks by two hydraulic molors connecled In set,es. SETTING UP THE KOMARA h~INISKIM,~,,IER In the normal operating mode. the hydraulic feed lines ere connecled So lha! lhe outer edges ol the pick-up d~scs are moving downwards. Reversal of the hydraulic lines and hence direclion ol d~sc rotation may be used lo lacilitate clearance oi debris Irom the vicinity of the discs. The pump unit relies on suction Io draw oil f~om the MINISKIMMER. It is therefore essential that the suction hose clamps are properly lightened loensure air-tighl seals al both. ends of the pipe. With highly viscous oils losses also occur in lhe suction line so lhal lhe length of suction hose should be kept to a minimum if viscous oils are being'rnet. With fresh Kuwai£ crude oil 20ft. of 3 ins. suction hose is satisfactory but, if lhe crude oil has been emulsified and Ihickened by wave action, it may be necessary to reduce Ih~s length Io 15ll. or even 1011. When operaling from a river bank, ship deck or'jetty, the power pack Should be sited as near to the water level as possible. This applies parlicularly to highly viscous oils. A two man rowing boat is sufficienl for floating the power pack. providing that the pipes are led over the bow o! the boat. if necessary, the power pack wheels can be quickly detached from the lifting cradle Io assist with stowage. Using a boat in this manner also allows continuous operalion off a beach without conslantly adjusting the position o! the power pack with lhe movement of the tide. The oil delivery hose from lhe pump unit should also be as shorl as possible when pumping viscous oils. In the case ol an emulsified crude oil, 1001t. ol 3ins. delivery hose or a delivery lill ol 'JSlt. and, with fresh crude oil. 200 ft. of hose or a delivery lift ol 30lt. would be acceptable. HYDRAULIC CIRCUIT P~'essure in the hydraulic circuit is supplied by e variable displace- .-ner~t axial piston pump which is driven Irorn the engine crankshalt by means of a toothed-belt drive. Hydraulic oil is drawn through a "3 suction strainer in the bottom of the hydraulic oil tank !o the CO,,,'nbin.~'J pump and Ilow control valve and is routed back through the tank lo the pressure gauge and quick release 'suppl~' cou,~'~,'~Q, which is mounted on the top of the tank. The o~1 ~s relurned to a~ a01acenl quiCk r~lease coupling after passing through the twin MINISKIMMER hydraulic motors via the motor hoses. The hydraulIc oil is passed through a disposable liller as it enters the tank. Access to the disposable filler eJement is gained by removing the Ihree 3/15" AF studs which secure the return Coupling and filter top assembly to the filter body· PO /ER PACK SPATE PU, P- PETTER DIESEL ENGINE - HYDRAULIC OIL PUNtP o -. FCter/Pr~s~r~ H~n~Ik: Coni Fit)er H Tank Towir~3 Run/Stet -- Fuel L~Y~r Oil Filler/Dip LevelGauge Air Cleaner . Diesel Shut- down Valve Diesel Fuel Tank g Plug pression Lever ~rk Arrester Fhrot t~e - Setting L~v9r DLsc Spe ed Control Hydraulic Pump · . . Figure 2. ; '- STARTING THE PUMP UNIT (See Fig. 2). Check engine sump oil level' top-up if necessary. Check fuel (diesel) tank. 3 Check hydraulic oil level and top up if necessary. 4 Check tightness of hose clamps, paying particular attention to . Ihe suction hose. 5 Set the hydraulic oil pump conlrol :e~er lully anl,-clockw~se 6 Turn luel lever to RUN position. ? Adjust Ihrottle selling lever for FAST RUN. 8 Lill the boss on the starling chuck and engage lhe craJlklng handle. ' ' ¢j Lill lully lhe decompression lever and rolale Ihe engine wllh lhe cranking handle. 'JO Afler lout or five rotations with the cranking handle, release Ihe decompression lever and continue Io turn ll~e handle tora Jew levolutions whilst the engine Is Iirlng - remove tile Cranking handle when lhe engine is runnIng. `j'J Reduce lhro!tle setting lo giye adequale pump speed. `j2 It lhe engine does not start, remove the priming plug and inlroduce a small quantity of lubricating oil ~nto the priming hole - replace the priming plug. F{epeal f~om 8. `j3 The MINISKIMMER discs are now rotated by moving the large hydraulic pump control lever in a clockwise dJrecl~on. - Note:--No damage will resull lo the pump it it is lell running and pumping air alone. · .. .. CONTROL. .. For maximum efliciency, the speed of rotat~on of the KOL,IARA MINISKIMMER discs is controlled by adiusting the position of the pump control lever for various oil viscosities and f~lm thIcknesses. The aim is to keep a constant film of oil around the discs and to run the MINISKIMMER so that fresh oil llows towards it ~n an unbroken film. This will ensure a maximum rate of oil pick-up coupled with minimum water content. - ' .; . ROUTINE I~/IAINTENAN CE During oil pick-up, debris, if present, will lend lo collecl around the MINISKIMMER. This may be removed al intervals by a rake.., or allernatively, the MINISKIMMER periodically moved away from the debris wh!ch will be preventing an even liow o! oil Io lh~ MINi- SKIMMFR. Il may also be necessary lo remove debris lrom lhe coarse mesh above ll~e oil bowl. Nole:-- I! disc rotation is at any lime reslricled by lodgement ol debris or lhick emulsified oil. lhe hydraulic lines may be le~T~po~ar, ly inl. erchanged Io provide reverse rotation which will lacilitale the removal el the blockage. After removal from the ,,'cater, the MINtSKIMMER head should be washed down with fresh water, the hoses emptied and the pump drained lhrough the two brass drai~ cocks. Tl~is will enable the pump lO be started more easily when required. No damage will be caused to the pump when pumping air alone. .°. STORAGE Afler use. Ihe MINISKIMMER and power pack shnuld hP -~ade ready JOt immediate use and long storage by hosing do;'., ,~,,~'~ i,~,k water. Il Ihick oil deposits are to be removed, lhe h~iNISKIMMEH u~a:x' be · sprayed with Kerosene or white sp~r~t prior lo hosing with fresh waler. Oil dispersm'~ts or other Sur[actants should not be used because these malerials may adversely ellect the oil collection characteristics O! lhediscs. Discs and wipers should be inspected lot crack~ng and other damage and replaced when convenient. -The barrels of lhe Spate pump should be dismanlled and inspected and any debris, that has become trapped in the pump diaphragms. removed. Diaphragms should be inspecled and replaced il damaged or swollen. 'l'he Petter diesel engine should be generally cleaned and inspected before storage. Oil and filter changes should be carried out in accordance with the manufacturers' instructions. Replace the disposable element of the hydraulic oil filler after the lirsl ,50 hours of running and, thereafter at intervals of 200 hours. Inspect Ihe nylon gauze filter in the tank filler assembly aad the metal gauze suction strainer (in the bo[tom of the hydraulic tank) al similar intervals, and clean if necessary. Remove the metal guard Irom the hydraulic pump and examine the condition of the toothed-- bell driva. Note:- To prevent damage to the Spate pump in freezing conditions -- "ensure that all water is expelled from the pump alter use. This may be achieved by removin9 the oil suction and delivery hoses, opening Ihe drain taps and running the pump. PERIODIC MAINTENANCE SCHEDULE · · Daily . . Check engine oil level. Check hydraulic oil level. Ensure engine cooling ducts free from obstruction Every 50 hours Clean the air filter. Every 250 hours .. Check tightness of all nuts. boils, etc. (Cylinder head nuts musl NOT De tightensd ,,,/hen the engine is hot). Ensure that the fuel tank filler vent hole is clear. Clean the air filter. Clean out deposit from exhaust system. Drain sump. flush out and refill. · Examine fuel system for leaks. · Check the valve clearance, adjust if necessary. Fit new lubricating oil filter element and joint ring. Lubricate speed control linkage. Lubricate starting chuck. Check conditions and tension of hydraulic pump drive belt. Drain hydraulic oil tank. Change hydraulic oil filter element. Clean tank suction strainer and filler filter. Refill tank with clean hydraulic oil. " Dismantle Spa~e pump, remove debris and examine condition of d i aphrag ms. -. Every 500 hours Fit new air filter element. Every 1000 hours Clean out the fuel tank thoroughly. Fit new fuel filter element. Every 2000 hours Decarbonise. Clean out piston oil return holes. Check cylinder bore wear. Examine the crankshaft bearings and renew if clearance is excessive. Clean the engine oil pump strainer. Remove the fuel injector and test spray. w il:x~:! fully ~},L s p.orr $.&n,~ or,, 1' Scraper broken 2 Debris lodged between disc and scraper Poor pump suction Hydraulic motors stopplng Hose connections leaking . Pipe p~rliaily blocked Pump h,"ts debris lodged reside Pump priming dtttphragm ." S,,vo I len Suction hose !o0 long Suction lift too great .. ~ech~ntcal seizure of the bear!ngs or drive Broken disc . ., Discs jammed with debris Insufficient circuit pressure ~d, he, s~e o,i,t doto~g~on,~ m~xtu~e on the ~i,!. Movm~ MIN, I:SKI:MMER arou, nG i~ the att w~l:t improve pi, Cg-Up. Repl~ce scraper when convenient. Check ~or cracked diSC bolero replacing scraper. Using a thin blade, scrape towards the centre Of the MINI-' SKIMMER starting behind the Scrapers. Or reverse tho direclion el the motor by changing over lhe Ijow ~nd return pipes. Tighten hose cl~mps and inspocl hose ends. inspect hoses. ' Following tho pump h~ndbook, strip tho ~ump and remove debris. Reverse or replace diaphragms. Shorten hose. bnng pump nearer to water level, Check bearings and drive. Cut ~way remainder o! broken disc and tepla~ Whet. convenient, Iqcvorso disc rol~tion and clear debris. Check hydraulic oil level and pressure relief' valve sett,ng, SECTIO;I 2 Maintenance ol the KO, ARA MI[tlSKI, , ER equipmgnt · REMOVAL OF COVER AND GATE/SCRAPER ASS-,,~IBLY To remove the cover from lhe KO;,IARA i',1INISK!!,I;,{ER, it is necessary Io remove lhe eighl bolts atlaching the cover 1o the outer buoyancy' lanks. The cover can then be lifted oil. The gate/scraper assembly can now be-lifted off the centre oil bowl. This will leave the coarse filter free lor removal. REMOVAL OF HYDRAULIC MOTORS Wilh lhe MINISKI~,4MER stripped as above, the hydraulic motors can be removed by first disconnecting the pipework and then undoing the Iour bolts securing the two hydraulic motors and drawing the shall from lhe first disc assembly. .. REMOVAL AND REPLACEMENT OF DISCS - After removing ihe cover and gate/scraper assembly, undo the four bolls securing the stainless steel bearing housing to the outer buoyancy tank. This will release half of lhe dJscs if a screwdr.ver is used to lever the drive adaptor from the hydraulic motor. Securely mount each bank of discs on a bench to facilitate removal o! lhe individual discs. Each plastic driving dog;disc assembly is clamped Io the mounting bar by Iv,'o grub screws. Access to lhese grub screws may be obtained by carefully levering back the rubber boot. The grub screws may then be removed using a long handled 3/32" AF Allen key. leaving the driving dog/disc assembly free to slide along the mounting bar. . . To replace the discs, first assemble all the discs and boots on the mounting bar v,,ithout the grub screw, taking care lo position all the lapped holes for the grub screws at the top. The assembly is then lifted to the MINIS.K. IMMER and the gate/scraper moulding used to position each disc whilst the grub screws sre replaced. The rubber boots may then be refitted with the aid of a pair of pliers and a screwdriver. REMOVAL AND REPLACEMENT OF OUTER BUOYANCY TANKS To remove Ihe outer buoyancy tank it is necessary to remove all or part of the glass fibre base of the buoyancy tank. This is best carried out with a knife and hacksaw blade alter the four securing boils and nylon feet have been removed. %Vithlhebase of a tank lemoved, access is gained to the lout attachment bolts by removing a portion ol foam adjacent to lhe centre lank. the bolls c'~,~ -I~¢,n be l'emoved. To replace the outer buoyancy tanks, apply ~,,.:.,~.,.~ .om- pound PR 1221 BT to the joint bet,.,,'een the centre tank and outer tank and on the four attachment bolts and fix the four attachment bolts. Fill the area where the foam ',vas removed w~lh a rigid polyuretha~}e foam {eilher preformed or self foaming) to give a smooth surlace. Two rnelhod~ can be used to reseal lhe base:- · - l'Aelhod I - A new glass fibre base, part No. t,;R148-6/4, is filled along with Ihe nylon feet. ~'¢hen lhe base and feet have been attached Ihejoint requires filling with PR 1221 BT sealing compound. Tl~is is easily accomplished with the !,',INISKI,',I,~J, ER upside down. The lank should not be put in the waler until 24 hours have elapsed from Ihe rubber sealing being mixed. ~ethod 2 - The existing base can be repaired using 4 layers of 921~5 cloth and BP A2785CV r~sin, overia.;:)ping the hole by 25mm all round. Care should be taken to see that all surlaces are degreased and abraded. · . 'SPATE PUMP BARREL DISMANTLING Firsl slacken the jubilee clip over lhe rubber joint which connects lhe cylinder head to the induction manifold. Secondly. remove the three cylinder head nuts. The cylinder head can now be removed together with the rUbber priming annulus and delivery port plate' at all stages hole the positions o[ the various parts. By r. emoving the split pin and unscrewing the actuator valve, the cylinder body ring. second priming annulus, suction port plate and cylinder seal can ali be removed. Re-ass~.mbly is carried out in the reverse order and must include new split pins. I0 Cutaway of 3"SPATE Induced Flow Pump Delivery Spigot..~ Actuator Seal ' Cylinder Body Ring Connecting Rod Bear~n¢ Suct~n Sp~9ot I~mp Bod Connecting g Annulus Port Plate Seel ,Cyhndor Stud Port Plate · Cytinde~' Heed . Cylinder Head Nut Priming Annulus Dram Act u,3tor Valve , , KOMARA MIN]SKIi~;~MER Twin Hyc~ul~ Motors Cc~rse Filter ,.. · Gate/Scraper Assembly 3'O/13 Outlet Support t~uoyancy Tank (Foam Fil~d) ,Protective Rubbing Str,~ C~tre Buoyancy_ Chamber (Foam Filled) Ddve/Suppor t Bearing Self. Lubrice ,rig · P:ostic Dry,,': Bearings PVC Disc .A SECTION 3 General Data aad Schedule o! KO,!ARA },~INISKI~,I~IER parts SPECIFICATION OF KOMARA MINISKIMMER Minimum width 42 ins 1.06 m Maximum width 46 ins 1.16 m Overall height 18 ins 457 mm Draught 6 ins 150 mm t/eight 120 lbs 54.5 kg No. of discs 32 Disc diameter 11 ins 280 mm Disc draught {nominal) 2Y~ ins 63.5 mm 13 MAJOR SPAR~S -MAJOR SPARES Ilem 1 :3' 4 $ 7 $ 11 12 1:3 14 15 17 18 Description Part No; Centre Buoyancy, Tank MR i55-02 Buoyancy Tank (Motor Mtg) MR 155-05/1 Buoyancy Tank ' (Spacer Brg. Mtg) MR 155-05/2 Buoyancy Tank (Motor/Inlet Pipe Mtg) '' MR 155-05/3 Gate Quadrant MR 148-2 Cover MR 155-17 Disc Mounting Bar MR 148-7 Disc 'MR 1,~8-1G Driving Dog/Bearing MR 148-4 & 5 Driving Dog Cover MR 155-01/20 Adaptor MR 155-07 · Scraper MR 'i48-13 Filter Mesh MR 148-2G Motor Mounting Bracket' MR 155~05 '' 'End Bracket MR 155-10 Feet MR 148-30 Plug . MR 129-66 Spacer Bearing MR 155-13. e · o Qty. 1 1 1 4 1 2 32 66 32 2 36 1 2 8 6 2 15 HYDRAULIC SYSTEM · o ti¥1 RAUL'I C SYSTEM Item Description I Hydraulic Motor 2 Inlet Pipe 3 Link Pipe 4 Outlet Pipe 5 Male Stud Coupling 6 Male Stud Coupling 7 Bonded Washer 8 Ouick Release Coupling 9 Dust Cap i0 Dust Cap. Part No. MR 155-0 MR 155-0 I/IR 155-0 MR 155-0 MR 155-0 MR 155-0 MR 155-0 MR 155-0 MR 155-0 MR 155-0 1/22 1/23 1/24 1/25 1/26 1/27 1/28 1/30 1/31 1/32 Qty. 2 1 1 1 2 4 2 ..o 17 FASTENERS i FASTENERS · Item Description 1 Setscrew M6 x 15 Washer 2 Setscrew M6 x 15 Washer M6 3 Setscrew M6 x 15 Washer M5 4 Socket Head Cap Screw ¥~" UNF x N¥1oc Nut '/2" UNF Washer - Flat ¥~" I/D 5 Setscrew M6 x 15 Washer 6 Setscrew M6 x 25 Washer M5 7''" Pop Rive~ 8 POP Rivet 1/8" 9 Setscrew M6 x 15 Nut M6 Washer M6 I0 Bolt M6 x 25 ' Nut M6 Washer MS . . Part No. MR 155-01/35 MR 155-01/35 MR 155-01/36 MR 155-01/35 MR 155-01/35 MR 155-01/35 MR 155-01/39 MR 155-01/38 MR 155-01/37 I,~R355-01/35 MR 155-01/35 MR 155-01/42 MR 155-0t/41 MR 155-01/34 MR 155-0t/33 MR 155-01/36 MR 155-01/40 MR 155-01/35 MR 148-6/8 MR 148-1/55 MR 148-1/56 Qty. 8 8 4 ,4 16 16 144 72 16 16 32 16 16 32 .® 19 · .o · · · OI~EILA TING/MAINTENANCE lViANUA L %Vhitiaker ]Vlodel 4300 Exoandi Ol! Boom 1000 ]Ft. Transporter/Pa!let Svsterr, Designed for Offshore Drilling Rig and Platform Oil Spill Control o . . .. -o Distributor Mr. Warren Bacher 714/469-0171 Whittaker Corporation ' 5159 Baltimore Dr., La Mesa, Ca. 92D41 i · i · Manual No. EOB 4300.1076 WI{ITTANEI~ CORPORA TION Survival Systems Division. · ~CT!ON 'TABLE OF CONTENTS PREFA CE SPE CIFICA TION, DRAWING/PARTS LIST . . . . . GENERAL DESCRIPTION/PURPOSE OF THE 1000 FOOT EXPAND! OIL BOOM TRANSPORTER/PALLET SYSTEM o . DEPLOYMENT PROCEDURES ¥I RECOVERY PROCEDURES CA-RE AND MAINTENAN CE TRANSPORTER/PALLET SYSTEM REPACKING AND ASSEMBLY SEQUENCE INSTRUCTIONS FOR JOINING AND FOLDING THE EXPAtNDI OIL ]~OOM Survival S¥$~"as Division . Pa. ge I SECTION I · . . " PREFIX CE This Manual of the Expandl Oil Boom deployment, recovery and maintenance procedures is available to purchasers oitF, e Transporter/pallet.System to supplement the on-site training that is necessary to assure proper overall use of Expandi Oil Boom products. It should not be used in lieu of such training, as ¥,'hittaker Corporation's Survival SYstems Division strongly i-ecommends that on-site training of all personnel involved in a potential oil spill situation take place at the earliest practical date since there can be no substitute for on-site training. Training can be-accomplished by means of contractor service or Company supplied schools. It is most ~mportant that supervSsory level p~rsonnel be the first to be trained so that dissemination of all operation procedures will be properly transmitted to the working crew when the emergency occurs. A continued periodic training program is necessary to assure an efficient and quick response when an oil spill occurs. " " Deployments where only one boat is used for "setting" the boom containment configuration, followed by release of the second end of the boom from the boat to set it in a drifting mode will differ greatly according to the' existing wind and water conditions: In single boat deployments to a drifting mode, underwater drogues are normally utilized at both ends of the boom to establish and hold the catenary shape. Each deployment utilizing drogues must be carefully considered. to take maximum advantage of all existing conditions. The purpose of the first drogue is to provide sufficient drag t'o allow the one boat to "set" the catenary. · The purpose of the second drogue set is to relieve the boat entirely, for other oil spill operations after containment is achieved. .. Tl~e instructions: contained herein are intended to be guideline inforrnat, ion only, and each user must be' prepared to vary procedures to suit individual circumstances with regard to environmental conditions, available auxiliary equipment and type of deployment vessel. · ~ .. S~CTION II TRANSPORTER/PALLET SYSTEM . . SPECIFICATION. DRAWING/PARTS LIST · . *. - o MODEL 4300 ]~reaking strength of ballast chain (approx:.) Dimensions ¥olume of boom element Buoyancy Weight per section Boom resistance in tearing Boom material weight Freeboard D raft .A cces sor-~ es · . Metric English 7500 kgf 16,500 lbf 15, Z meters 50 feet long in long in a a package package 33.46" x 41.34" 850mm x x 11.81" · '1050mm x 300mm 0, Z7m3 9, 5 cu. ft. IZ0 kg/linear 83 lbs. /linear meter foot 80 kg 176.4 lbs. '4'10 kp/Scm, 915 lbs. /Z" width' 800 gm/mZ . 164 lbs, /ft. g · . 450mm 18, 0Z" 650mm 25. 50" Patch kits of adhesive and fabric; towing adapters for Model 4300/1100mm (43") Boom; and magnet ~dapters L VACt,"JM VALVES ." PATCH KIT . .. SECTION III ~- ~-- , , _ GENERAL DESCRIPTION/PURPOSE OF TIlE 1000 FOOT EXPANDI OIL BOOM TtLANSPORTER/PALLET SYSTEM The 1000 foot Transporter/Pallet System provides the most compact/lightweight large-size oil containment boom available to the industry at this time. Each 50~foot boom section with its 20" flotation member containing .14 individually . compartmented waterti'ght cells, and a 23" skirt, provides exceptional water stability characteristics which makes possible its ability to contain oil under adverse conditions. The 20 sections (50-foot length - each section) are pre- connected and loaded on the Transporter/Pallet together with a towing adapter attached to each end of the boom. '' .. The boom, because of its compactness and relative light~vei'ght (4000 pour. ds total) can be located almost anywhere-- on a drillship, platform, oil tanker, above or'below deck, 0r on a' supply or'crew boat - So that it can be at the oil spill site in the sho'rtest period of time. The boom can be deployed from this Transporter'/P'ali'e~ in a matter of minutes D, E. F. G. Two boats - without drogues Boat with one drogue only ' Boat with Z drogues (second drogue deployed after set configuration is achieved). · . Boat with deck crane ...... Two deck cranes with man overboard boat or supply boat One drogue with tie-off to rig leg or anchor buoy Other s '{see Section 4'for Deployment details). Several methods of deployment are: Survival Sy~..ms Division Pa. ge ~ SECTION IV DEPLOYMENT PROCEDURES 'Following are the suggested outline procedures for deployment of the · 1000 foot Transporter/Pallet System. The procedures are designed for the use of at least one boat for deployment with the boom pallet transferred from the drillship or platform deck to the crew or supply boat by means of the deck crane, or permanently located on the supply or .crew boat, etc.: Step 1. · . Before transferring the Transporter/Pallet by crane from an-offshore structure to a deployment vessel, remove the orange color plastic protective storage cover by untying the 1/8" line located above the top base of the pallet. Dis- engage this line by lifting it away from the open loop metal .. eyelets~{6 on each side of pallet base). . o . 'P0sition'Pallet center/aft/)os'i~ion cio'se'{6 Stern bf 9essel." ' To prevent slippage, lash pallet to deck if deployment is to take ph/ce in'roUgh'water conditions.' .... .'~ 'i. .. '~' (Note: .The pallet must be placed on vessel deck with forward · ' and aft - port and starboard markings in the same orientation as those positions of the boat. ) .. Step B. Igyebolts are located at forward and aft sides of the pallet stiffener beams for purpose of securing deck lines to the. pallet. - . Remove the lifting harness by unbolting Z shackles on starboard side only. It is not necessary to unbolt 4 shackles, however, care should be taken to store harness ends in storage compart- ments located on port side of pallet in order to prevent personnel from becoming entangled in harness ends during deployment. Step 4. Release the two ratchet type release (yellow color) outer restraining straps. Then release the 1" wide tie-down straps located approximately at the 600 ft., 800 ft., and 1000 ft. levels of the boom pack build-up on the pallet. These straps should be released from both sides of the pallet so that they may be removed by the-person designated to be responsible for this task as the boom leaves the pallet. Step S. °o Step 6. Step 7. o 3ustbefore deployment of the boom, it is necessary to remove the plug in each of the two tow adapters, located at each end of the boom, to permit air entry into the air compartment. After the air inflates these compartments, the plugs are to be replaced into the nipples to eliminate the possibility of water entering into 'the chambers during towing. The 1000 foot long main body of the boom consists of Z0 connected sections. Each section of the boom has 14 white colored injestion valves with an orange colored protective spray cover or cap fastened to the valve. These valves do not require attention while deploying and inflation - occurs ~utomaticatly as the boom is laid out on the water. · . If the Expandi Oil Boom Transporter/Pallet System is equipped with the optional drogue deployment system, each 75 feet of 3'/4" line (attached to the drogue harness rings and tow adapters) should be uncoiled and made ready to deploy. The towing line attached to the bottom layer of the boom pack on the pallet should be tied to a center location of the boat. 2% heavy duty line ru'.~nin§ across the deck secured somewhere aft of the pallet is a conve- nient'method of locating a place for securing the tow line at a center line position. A safety line should be located about three feet from the stem to protect personnel from beino~ washed over- board in rough water conditions ........ · . . · The lead line with the drogue attached' should be set into the water (or handed to the Znd deployment boat) if no drogue is utilized. If a drogu.e system is used, sufficient "drag" will be obtained as the boom is laid out to "set" the boom catenary. Although high speed deployments have been successfully performed, a speed cf two kruts'is the recommended deployment speed until the proper containment configuration has been acconaplished. If the two-drogue system is used, it is possible after the boom has been let out - and pro%al'ding undercurrents and Surface wind condi'tions are proper, to release the second drogue and marker buoy. In this drifting mode the two drogues will hold the catenary configuration. This will permit use of the boat for other emergency situations related to recovery of the spilled oil. }-or detailed procedures with illus- trations showing the methods of drogue system deployment, see Step ! 5. Step 8. Returning to boom deployment from the boat deck. as it unfolds. it will inflate automatically (see page 3 of Instructions for Joining and Folding pamphlet for details) as more boom is let out. When ~o ww -® .. o Step 9. the 1000 feet of boom is in the water, the second drogue and two marker buoys should be released from the pallet. Care should be exercised in preventing entanglement of the attachment lines. In the event that the drogues do not take a set and it becomes impossible to maintain the boom in a containment configuration, ~he drogues and buoys should be remov'ed and conventional tow- ing by two boats to guide the boom into position for oil contain- ment should be considered. · Two persons are required to attend the boom during deployment. Their responsibility is to (1) coordinate removal of the loose or disconnected inner toggle tie-down straps, (2) check to make -certain that all injestion valves are secure in the blue color nipples, (3) coordinate with the boat operator the speed and -direction of the boom deployment, and (4) to control folds of -. boom as they are released from the boom deck. The man on the chain side of the boom ('starboard side) is responsible for control- ting the boom to prevent it from falling sideways if the boat should roll in heavy sea conditions. ~afet-y- Note: This man must be careful t° stand near the forward end of the pallet to prevent the possibilify of becOming entangled 'in the boom while'it is being deployed. ' ........ The man positioned on the opposite side of the boom pallet is responsible for checking that valves are in place and removal of the loose tie-down straps located at approximately the 600 ft., 750 ft., and 1000 ft. boom pack locations as .it is' deployed. Step 10. General Considerations: A. lthough it is possible to deploy the boom in a very short period of time - under 3 minutes - it will require several training sessions to do so. Therefore, until skills are obtained, the previously mentioned two knots deployment speed is recommended. Depending on the overali situation, the boat captain should control the deployment operation and coordinate varying conditions with the crew. He should be ready to stop the boat momentarily or reverse engine direction in the event of emergencies.. The method of deployment and/or configuration should be left to the discretion of the supervisor in charge of a spill emergency. It is most important that the boat crew, as well as the drillship crew, be familiar with deployment procedures in the event tlxat either of the other crews are not available - or if excessively rough seas are encountered whereby circumstances may require the assistance of additional personnel. · Step 11.. If, after the 1000 ft. of boom is deployed into a catenary configuration, it becomes feasible to close each end of the boom into a continuous' circle, the tow adapters with drogues and/or tow line can be removed, and the male/female ends · of the boom can be connected by simply following procedures · as outlined in Section 8 - page 2, thus completing the encirclement of the contained oil. Th~ boom can then be permitted to drift with the current or be anchored in place by means of anchor lines attached to the metal hoops (attached to the 3/8" bottom towing 'tension ballast chain located at the bottom of the Z3" skirt). Alter- naltely, the blue straps located at the top and bottom location on each end of the boom can be tied together with line or rope to accomplish an encirclement. st p The towing adiiP~/ers should not be removed While towing in the water unless encirclement is completed as previously' described in Step K. The proper tow line connection through the towing adapters is to loop the 3/4" line through the bottom tension chain r~.ng and the second and third blue plastic and secure a bowliiae knot for towing purposes. The top blue loop is not '" intended to be used for towing. Its purpose is to provide a 1.o. cation when positioning the boom at a fixed location to act as an ending fence. "' .. Step 13. If it becomes necessary to straightline tow the boom at a higher than one knot tow speed while expanded, the entire tow adapter section (:4, 5 feet) together with the drogue and marker buoy is to be positioned on deck and out of the water to prevent any possible submergence of the boom. This end 'of the boom on the boat shduld be fastened in a position so that the injestion valves are in the vertical or upright position. Step.14. After the pJeceding Steps 1 through 6 have b~en completed, the /;1 buoy (see Diagram(~) located on the starboard side of the vessel is placed on the water. Next, the attached drogue and //Z buoy are deployed. The vessel then proceeds'in a downwind direction, and as the drogue follows it will inflate. The resulting drag will cause the boom to unfold from the pallet. The vessel speed during deplosn'nent of the boom should be urrter two knots. The two persons assigned to the deployment task should then proceed ~tith the instructions outlined in Step 9. When the boom has been completely deployed in a straight line gownwind configuration, the vessel will turn in a port or starboard r~ght angle direction (depending upon the location of the oil spill lio, be contained) and proceed in this direction for approximately ~e-third ·of. this total length of the boom under tow before he.ading wp~[n.d' (see DiagramQ), Before the vessel comes abreast of the tfi~r'atdrogue set, it is to stop its forward motion until the #3 buoy ~n:ct' drogue on the port side of the vessel are placed on the water. "iThe-buoy line should be held by one of the crew members until ih.e drift speed of the vessel causes the drogue to unfold. Once this occurs, the line may be released and the drogues willtake ~- ~et in the water thus tightening the catenary configuration of tt~,~ i~oom. ~l~e boom deplbYed with the two drogues set in'this manner will remai, n in a catenary configuration for a period of time - usually ..~[~'om 30 minutes to severa,1._~ours./_x _,CT'xdepe,n, ding on wind and/or current · . ~:ct~ti'ons (see Diagrams ~C~)and~D~)). '~hile in this stationary ~,~i~on, the deployment v~-~sel m~y proceed 'with other ¢~e-~up' ope ra tion s. " ' ...... " "' · . BUOY BUOY #1 . . Step 15. EXPANDI-BOOM DROGUE ,~'~ ',,"~ ,,;i-,"!-i i~1 ~ / ON 12'x5' SIZE TRANSPORTER PALLET BUOY #4 DROGUE BUOY #2 . . (~ To~'-V~W o. :.'. I:..XNANDI-MUDM" .. · .. · · · . o TRANSPORTER PALLET .. ........ -. .. . SID E VIEW. BDOM & PALLET .] DROGUE~ 4 SEWN IN LEAD WEIGHT - : '' . · ~ DROGUE POSITION IN WATER . ' " ~~ ~-DROGUE D DIRECTION .' ~ ~ -~--~ =:~ ; ' ......... ~ ' .~ ~ ~-~- _~_~-~ .... . ooo . .... ~ - ~/~~- ~-~. ~ . .. ... . . . . ~ ~ J-~ ~~ ~ ~ ~~ .......... . _. ~~~~_~ - . . . . .'. . _ ~ ~-~ . . ~.5'~ ~..'~ ~ ' ~ ~J ~ ~ ~ ~ . ..... ...... ........ . . - . ~ .~ * ~ ~ ~--~ ~. ~z ........ ~.~~~~~ ..... ~ .............. -- ~~~~~~--:~ .~ . ...... .,_ . . . .. ~~~~~~-~~ - . · . .. . . . · . . .~ ~/~- ~ ._ ~~ -- ~ J~~~ ~ ~ . ~ ..... ~. .. . . ~~~ ~ _ . . . · ~t-t~"~ ' ' ~ ~~~~~' ~- ~--' (~ MAJOR STAGES OF ---,- · .- (~ EXPANDI-BOOM/DROGUF_ DEPLOYMENT rmvai ~y.~' ~s Division SECTION V l~age 1 3 · BOOM RECOVERY PROCEDURES Following are the suggested outline procedures for recovery of the Transporter/Pallet System. The outline is general and should be changed or modified as necessary to meet the specific conditions of the spill; i.e., weather conditions, location, vessels~ and other avail- able equipment. Without the use of power winch equipment on the recovery vessel, a minimum of five persons i$ required to recover 'the ~reconnected bodm from the water. In situations when the boom has not come in contact w. ithoil, it can be repacked on the pallet while still located on the deploy- ment vessel, The procedure for accomplishing this follows: · -. Step l. Retrieve the buoy/drogue or tow line end of the boom which. was last released or attached to the vessel first. As the boom is brought on board, place it on the pallet with t. he side marked "up" on the 23" skirt in the up position laying o on the Transporter/Pallet. Be sure that the towing adapter is laid down on the pallet full length with the.two blue tow gtraps extending over the forward end of the pallet,' as shown in Diagram Q. Two persons are r~equired on each side of the boom with the fifth person working the dual roll of assisting tO pull the boom from the water and assisting the four other persons in folding the boom. Note~ When power equipment is available, onty four persons are required for t'he overall operation. Step 2. · . As the boom is brought on deck, the fifth person is responsible for removing the orange colored cap injestion valves that are .permanently attached to the boom and coordinate insertion of the separate vacuum valves {off-white color with blue tab) located in the second and third compartments under the inclined plane or wedge at the boom chain side (see illustration}. .® Step 3. .~ . OW ADAPTER _ . . The pallet is 12 ft. x 5 R. x 5 ft., with the inclined plane of g4~ on a 30° angle. The purpose of the incline~ plane is to accommodate the appro~mately 84 layers of boom (1000 ..... folded ih 1Z ft. lehgths) where the thicker frame'or Gotation chamber builds up higher than the skirt or chain'slde of the Boom package .relative to th.e B~t surface of the pallet. .. By use of a wet/dry ]10 volt industrial canister-type vacuum cleaner, the boom can be quickly de~qated, by inserting the flexible tube end of the vacuum c;eaner over' the individual vacuum valves and sequentially evacuating the air from each of the chambers. Note that each section Of boom is 50 ft. in length with 14 separate chambers in each section, Twenty of these sections are connected to complete the 1000 feet of boom on the pallet. The vacuum operation procedures are shown in Section 8. page 4. _At approximately the 50th layer of boom, the vacuum valves should be removed from the bottom layers and replaced with the [niestion valves. The replacement of the remaining injestion valves should be sequenced approximately every 20 layers thereafter, When the package of deflated boom is laid up in the 12 foot folded lengths, the drogue and marker buoy attached to the trailing towing adapter marked (Z) should be laid on top of the package and secured with a toggle tie-down strap. . o. .Step 4. Another method of recovering the boom for short term storage if it is contaminated with oil can be used. This procedure is to roll the boom into individual sections. This is accomplished by removal of the injestion valves and disconnecting each of the individual sections of boom while depressing back or flattening the boom frames. Two persons are usually required to roll the boom sections. Care must be taken to completely depress the frames and keep the boom as wrinkle free as possible wh:.le rolling the boom (see page 5 of Section 8). The disconnect procedure can easily be accomplished by untying the single knot of the locking iron and separating the chain (see photograph below). After the locking iron is removed, the boom can' be separated by sliding the interlocking male and female ends apart {see page 2 of Section 8). A locking rivet feature permits a third ..... method 'of folding the boom. It is described on page 3 of Section 8. After cleanup of the boom is completed, the indi- vidual sections can be reconnected as illustrated or, page Z of Section 8 and reloaded onto the Transporter/Pallet in accordance with the folding procedures as shown on page 4 of Section 8, except that the boom is laid on the Transporter/ Pallet in continuously joined 1Z-foot lengths instead of the shorter S0 ft ~ection lllustrated. ~u~dvM S~'~-'~m s SECTION VI CARE AND MAINTENANCE AI~ %vith any fabric material oil boom, care should be taken to avoid lacraping the boom against sharp objects when in the water, or during ¢l'~;~ning or repackaging. Remember the Expandi Oil Boom's primary &dvalliage 15 it~o compactness and light weight features which permit {'1 1o be transported to areas where larger bulkier booms cannot be cl~rr{ed or in some cases even deployed. Therefore, thc more carefully the boom sections and related equipment are cleaned and repacked, %he longer they will last and properly function. ]Following are more ~pecific procedures for care and maintenance of the boom: Step 1. The usuttl cleaning equipment, chemicals and detergents can be used in removing o[1 from the soiled surfaces of 'the boom, as with any boom. · 8%e15 :~, If %he boom has been separated ~nto individual sections or l~eturned in the rolled up 50 ft. section condition, s{mply , ~nroll or unfold /he boom and it will again inflate. A suit- able area should' be made available for this purpose. It laeettbe no larger an area than 6 ft. x 25 ft. with a relatively ~ ~mooth surface to prevent unnecessary abrasuve wear of , ~' the Boom fabric material. ~%ep g, The easiest method of cleaning the boom - either'with detergent or wet steam procedures - is to flatten the frames l~y followlng the vacuum.procedures outlined on page 4 of Settion 8. Even though the boom is not coated with oil, it should be washed down with fresh water when pos sible. Step 4. Step 5. After cleaning is accomplished, the boom - still in its :[lat'tened configuration - should be inspected for worn or to~n places to determine if repairs are necessary. If it is determined that a patch repair is required, the area to be patched should be recleanedwith a suitable solvent such.as alcohol. A prope'r size patch to cover the darna~;ed area should be cut out of the repair kit material (located in the lhird compartment of the pallet) making sure tl~at the lpl~tch'is rut with well rounded corners or is cut in an oval ~hape, The t'ube of adhesive is to be applied sparingly to th~ over¢ll surfaces of the damaged area as xvt:Il as to the -® Step 6. Step 7. Step 8' Step Step 10. patch to be applied. Waiting unt{1 both surfaces are tacky, the patch is to be depressed to the damaged area and pressure applied to work out remaining air bubbles or wrinkles in the materials. Allow to dry or cure for at least 30 minutes (preferably 24 hours) before reusing in the water. In the possible event that a boom frame ~ecomes damaged (or appears to be damaged) consult the distributor in the appropriate area for instructions before cutting info the fabric. Repair or replacement of the frames is possible but must be made under the specific instructions of the manufacturer. The frames are very' durable and therefore most of the time, though the frames may appear to be damaged, they will return to the proper configuration given time to reform .... -.~ Before joining the 50-ft. individual sections, it is suggested ~that a suitable lubricant such as silicone grease or even vaseline be wiped onto the fabric (male) e~id co~mector t0.' facilif~te joining of the metal (female) end connector of the . . ~ext section. After completion of the above tasks, the boom may be repacked onto the Transporter/Pallet as described in Section 5, and recover with the protective cover securely to the pallet for storage until needed again. .. Secure the lifting harness 'in position by re-bolting the two starboard shackles. The boom Transporter/Pallet can then be stored, o~: the deployment vessel or lifted on board the drillship or platform by'use of deck cranes.. In the event of rough water conditions where it is not possible or safe to attempt repacking the boom on the pallet, the alter- mate procedure follows: With the use of suitable deck-located winches, the inflated boom can bg retrieved bi using 3 or ~ men (without powered equipment, , 5 to 6 men are required). On supply vessels with a large open usable deck space, no more than 13 layers of continuous 80 ft. lengths of boom need to be placed in the fore and aft parallel length positions on deck. Following, or while bringing the boom on deck, one man is responsible to see that a 3/4" line is threaded through the shackle bolts ~t approxi- mately the mid-point of the 80 ft. 'lengths of the 13 lengths of boom.' It is important for him to s~e that the line is running over and not ~mder the boom flotation section so it is not crushed when lifted by the lifting device. The person's designated to pull the boom from the water should work as separate two-men teams. They should work in tandem for ease of pulling the boom from the water. The Boat Captain should coordinate his speed with the boom recovery by slowing or even reversing direction to slowly "back-up-into- the-boom" as required. DependLng on the severity of conditions, it may be necessary to secure the loop ends of the boom to prevent sliding across the deck and interferring with work in progress to recover the remaining lengths of boom. · . .:If the recovered boom-is to be lifted, to the deck of the drillship 'or platform. -t~-.e ends 'of the~threaded 3~4" line should be gath- -ered and looped over the crane hook, before lifting to the deck. Then lift the Transporter/Pallet to the same location when cleaning or repacking procedures will be carried out. If a suitable space or facility is not available on the drillship or · platform, the alt. ernates are to transport the inflated boom.. to a suitable land area where cleaning or repack[ng operations · can take place; Alternately, if the s'upply vessel can stay in position mntil weather conditions permit, repacking can wait until that time and be performed on the supply ship deck. ADDITIONAL CONSIDI~RA TIONS It is important when rep~cking the boom on the pallet to a. Utilize the full 12 ft. length of the pallet. b. Evacuate all of the air from the chambers, c. Stretch the boom as wrinkle free as possible while evacuating the air. d. Properly depress the frames. e. Maintain vertical alignment of folds at flotation frameside of boom.. The purpose of performing these operations as carefully as possible is to reduce the height of the package - under 5 feet - and maintain as low a center of gravity as possible. This is important when encountering a rough sea condition or when lifting the 4200 pound package with any l~oist equipment:. 5~ 6~ 7~ The frames should be alternated or otaggered slightly out of position when repacking to prevent stacking each frame on top of each other..By carefully attending to this detail the pack height can be maintained under the 5 ft. dimension. In the event that frames are not properly folded when vacuumed or rolled, and left in the wrong position for several days or longer, can deform the frames. to repair - simply (and "plastic creep" can occur that If this occurs, do not attempt when possible) unroll or unfold the boom in the inflated condition and store in a warm, under 130° IF. atmosphere). The deformation will grad- ually disappear within several'hours or days (depending on the temperature), thus permitting the boom frames to recover fully the original configuration. When building the boom pack above approximately the 600 ft. height, the chain (located at the bottom of the boom skirt) sho.uld_be, laid slightly ~.ne sted with each succeeding layer .. of chain on top of the lower chain in Order to secure or lock the chain, thus preventing the boom from sliding sidewise before the white color tie-down straps can be secured. Care should be taken not to attach tie-down lines or restrain- ing straps at the forklift locations. '.'. Due to the settling effect that is caused by the weight of succeeding layers of stacked boom, the straps and' tie-down lines should be checked and retightened several days after the repacking operation takes place. To assnre that thl. s inspection takes place, it is.suggested that the protective cover not be placed or secured to the pallet prior to inspec- ting these tie-down lines and straps. Remember, it is easier 'to remove the vacuum valves if the pack layers are in good vertical alignment and the' attached injestion valves are hanging by the straps outside the pack buildup. Only 1Z0 vacuum valves are furnished purposely so that it is remembered that it is necessary to remove these valves prior to completing the repacking operation. ]Be sure to replace injestion valves in the same blue color 10, nipple each valve is attached to in order to prevent entangle- ment while deploying, thus causing damage to valves. To obtain optimum vacuum pressure from the wet/dry vacuum cleaner, remove the inside tank filter. Some water will collect in the vacuum cleaner tank. This is normal and the tank should be emptied as required. Clean tank when finished with fresh water and dry. Remember that, should it not be necessary to deploy all 1000 ft. of the Expandi Oil Boom, the portion deployed can be disco~_uected within a matter of several seconds time. The remainder of the boom is then available for another, spill area. Before proceeding, attach three of. the toggle tie-down straps to the remaining Boom on the T ran sport e r / Pallet. ' ' - . . Remember that the reverse procedure to Item 10, above - it is almost as. easy to add additional sections, of boom to the 1000 feet by joining additional boom, as required. BY follow- ing the instructions in Section 8, page Z, this can be accom- plished in less than 30 seconds for each additional section. Nohand tools, such as wrenches, screw drivers, pliers, hammers, etc. are required. Remember this manual is only intended to be general in its suggested procedures for deployment and recovery of the boom. Each location, with its available equipment, etc., may require variations to the procedures outlined herein. The most i. mportant advantage of Expandi Oil Boom over other products - besides its low storage vblume - is its versatility which permits virtually an unlimited number of ~vays to use the boom in an oil spill situation. SECTIO~ VII TRANSPORTER/I~ALLET SYSTEM 1REi~ACKI1NG .AND ASSE~{BLY SE©UENCES PARTIALLY FOLDED BOOM ON THE TRAN SPO RTE 1% / PA LLE T TRANSPORTE}I/PALLET BASE OF FOLDING t:'T. LENGTHS OF BOOM OF IrOLDI. NG FT. OF CONNECTED TOWING ADAPTER SIDE VIEW OF BOOM INGESTION %~'.A LVE ., .o SIDE VIEW OF BOOM SKIRT SEA DROGUI FORK LIFTt PA LLE T 'J['RU Ct~ TRANSPORTS% BLE :FROM THE RIG o TO THE BOAT :® .: o TO THE ~V.ATt~R TWO DROGU]ES I)EPLOYED Survival Syste~-s Division SECTION VIII INSTRUCTIONS FOR JOINING AND FOLDING OF THE EXPANDI OIL BOOM ©~ land O O · . o · ,. .o . ~@ 0 0 · · After the protective covering has been removed, the bundles are placed beside each other and joining can proceed. Avoid pulling ~,,e boom over sharp objects. The boom is const, r. ucted to stand up to normal wear and tear. The weave can, nevertheless, be dama- ged if pulled over sharp stones and edges.. The rope at aha end of the boom is inset- 3 The joining can be done by I--2 persons. ted in the channel of the other boom. The ring attached to the rope end can be used for gripping purposes. When the booms have been sufficiently drawn together, the free end of rope is inserted into the intended channol of the joining end's upper side. -. Pulling together is completed by pulling tho ring on oho of th~ booma and by pulling t~e handl~ on the other. 5 Locking Is dona as shown tn fig. 5. The free end of the rope Is then placed through the hole of the locking iron. . CheCk that alt valves are connected, The Ex. pandi oli boom Is~ then ready for laying out. pump or a vacuum cleaner w~lh comp!etely enclosed motor). Connect the vacuum va!yes. Keep the boom pr'operly stretched out. Suck out afl the' air until a Vacuum is fbrmed in the boOm.-lt thus becomes flat and ~S.easy to fold up. Begin foidin9 at the tie rope end. ~,./" v J' ~'~ u R When fording of the boom is complete, a rope is tied over the top and bo~h ends are folded up. ~~ n A rope t~ed lengthwise across th~ Dundle. ~',,.~'~'..,~ ~_-'~.. _ ~ ~' Release vacuum-valves and fasten the ordl- :'~:~.:-;'~J;~~::;~.~:~' .~/...'~A ~ na~, ones F,nally pack the boom in its -t.i~.~ ~-~. , , ~' n'.- :,-'.- .... ( "-~...'~.-,, ,~ - ~ '~¢ . ....:--..-- .... ,. ...-~ .......... .,~~.. , , ....,. .~, ... ~ .... . ...... , ~~ ,, ~.~,,,,., ... .... ~ .-~,....- ,. ......... , :..: '~ ~-%~ ;.. .... :~ .... . ~t~,,. "~5~.~ ~,' ":~'~': :.~':';F;' .~ 8URVIV,~,L SYSTEMS DIVISION 5~4.~ RIVER L"OAP 'N[W O;,~LI:AN$, I. OUISIANA 70!$3 TEL[ ;'lION[::: (504) 733-7050 I'£LE×: $3.7343 paCK_ c The boom is rolled up as tightly as possible, starting at the joining end (see fig. 11). It is an edvantage if someone goes in front and holds the framing down before rolling, 1 aLternatzYe l' ,o I · .. When the rolling of the boom is completed, the intake-holes are plugged with No 6 rubber corks. : ~'~ The boom can then be rolled out and it will retain its flat form. The boom is folded as illustra. ' : ~ tion shows. .. I~ - ~ - . - - ~..~l.~.~ : .~ . . . ' . ~:~,.~.~:'. - .. ~:- ~-:-~ ,_-.'.-'. - ~.~ ,i~~. ' : .... . - ~;--'~-'--~-.~',-,~C~ '-,- ~'~~ ~::' ~,-,..-~.~x~'. .~ ..... ,~...... .... ~~:~.'~.~'~. t -'~;-~:~~~~~ :.' .'- f ,:~¢". :~:,.-, , i~-X~-:': .-.~:~' .j- :.- :-x~~ ¢~~~ ' .- ~ '¢. ' ~~~ - ......... · .,~...- . . ,:. ,-.:: . . i * Ze~," WherF-folding of the- bo'om' is- complete; a rope'- is'tied' over'the top and both· ends'are folded up.- ' : I : i "- ' ,~ ...... ~ %~-,'". ..... :'t:':.~ ~.~~~~%~ .-.'-'- ..,.~'. - · '. -' ' ' ~ · · i A rope is then tied !engthwise ac- i ._.~...,,,~.:. ~ ross the bundle. Take out the rub- ~'.,',-..:',~...,-'.'.Z~":.,:..';';.',:"~ :'":.f.:~-.,,~ \ ber corks and replace the valves. '"~.',:~'~'~.";.~::::,'..:.:,.:,;-~.'~~~.,~..'7"~,...~. . ,..-- -~_,: · ..:. ,:-- .- · , . ~ Finally pack the boOm in its protec- ~-.,..~ ..,~.-.. , -t..t . - ..... / ~ ~ ~.~/ ' . - . %_ lot,,,; ' ,.-..z~,~. ' ~ .... ~h, , : "~,'1 ; · ' ' ' ~ ' ;~ :1t';~.~' 't~ ' ;' ..,[, - -~~~ '.' ' '. / ~,'-"~'~,, ~. ,'. ."'.1 ,: ': ,STATE O -~XLASKA OIL AND GAS CONSERVATION COMMII-I'EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS I. O.L F] G,,, '~ o,.,, Wi ldc at NAME OF OPEI%ATOR Exxon Corporation 3. ADDRESS OF OPERATOR SUBMVr IN Pouch 6601, Anchor%ge:. Alaska 99502 4 ~CA~ON OF w~ Surface- 700' NSL & 800' WEL of Sec. 8, TllN-R17E, UPM, North Slope, Alaska BHL (Proposed)' 500' NSL & 800' WEL of Sec. 5, TllN-R17E, UPM, North Slope, .. Alaska ~PI NUMER1C~ CODE Not Available L2~SE DESiGNA~ON AND S~IAL NO ADL 47502 IF INDIANT. ALOi'F'EE OR TRIBE NAME L.~IT FARA! OR I,EASE NAME Duck Island g W~%LL .NO No. 1 10 FLF, I.~ A_ND POOL. OR WILDCAT = Wildcat 11 SF_,C. T.. R. .%! (B4)~FrOM HOl~ o s.rsc-m~_D Sec. 5, TllN-R17E, UPM 12. Plgl~MIT ~O Not Available 13. REPORT TOTAL DKP~H AT END OF MONTH. CHANGES IN HOLE SIZE. CA~ING AND C~,IF..I~T!NG JOBS INCLUDING DEPTH SET AN~ VOLb~ US~. P~O~TIONS. ~TS ~ ~SUL~ F~HING JO~ JL~K ~ HO~ AND SIDE-T~CKED HO~ AND ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~ITIONS '... No operations were performed during August 1978. CONFIDENTIAL '"'~"~*"=Tf-~._~=~~'~f~'~a~°~ Dist. Mgr. Ak/Pacific Div. szoN~~~ Z / ~~,~ =~Exolora~~ n~ Sept ? 1978 NOTE--Report on this fora ts required for each calendar ~ntht re0ardle~s of the Ifatu~ of ooeratie~s, and must ~ flied In dupJlcote with the otl and gOl conservation commi~ee ~ythe 15~ of the ~ucc~aing month.~le~ otherwise directed. I ]. . t:! Conservation August 31, 1978 Re: Duck Island Unit Exxon Co~oration 78-68 Mr. Cranial! D. Jones Manager Exxon Cor~ration P. O. Box 2180 Houston, Texas 77001 Dear S'ir: Enclosed is ~e approved application for permit to drill the above referenced well at a location in Section 5, Township llN, Range 17E, UM. Well samples~ core chips and a mud log are required. A direc- tional su~y is required. ~any rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadro- mous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulagted thereunder (Title 5, Alaska A~ministration Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 03, Article 7 and the regulations promulgated thereunder (Title 18, Alaska A~inistrative Code, Chapter 70) and by the' Federal Water Pollution Control Act, as amended. Prior to com- mencing operations you may be contacted by a representativeof the Department of E~ironmental Conservat~o Pursuant to AS 38.40, Local }~ire under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us in scheduling field work, we would appreciate your notifyin~ this office within 48 hours after the well is spudded. would also like to be notified so that a represan%akive of Mr. Crandall D. Jones Duck Is. Unit #1 August 31, 1978 the Division may be present to witness testing of blowout preven- ter ~ipment before surface casing shoe is drilled. In the event of suspension or abandonment please give this office adequate advance notification so that we may have a witness present. Very' truly yours, I . ~l'~.. .: ' ~nie C. ~ Smith ~e~er Alaska Oil and Gas Conservation Co~ittee ~S:be Enclosure cc: Department of Fish and Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Depart~ent of Labor, Supervisor, Labor Law Compliance Division w/o encl. STATE k ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS I. WI~LLil W~;LL SUBMIT [N BUPLICATIg ~1. NAME OF OPI~ATOlt Exxon Corporat ion ~.' ADi~RESS 6F' bi, roToR Wildcat Pouch 6601, Anchorage~.~Alaska 99502 4. LOCAl6N ~ W~.LI- Surface' 700' NSL & 800' WEL of Sec. 8, TllN-R17E, UPM, North Slope, Alaska BHL (Proposed)' 500' NSL & 800' WEL of Sec. 5, TllN-R17E, UPM, North Slope, Alaska Not Available ADL 47502 IF INDIAN[. ALOT'Y~.F. OB TRIBE Duck Island Unit' ~ w~2~'xo-' ' Wildcat Sec. 5, TllN-R17E, Not Available '13. R~b~T TOTAL D~TH AT END OF MONT~I. CHA~NGF~S IN HOLE SIZE, CA~ING A~ C~ENTING 30~S INCLUDING DEPT}~ SET A~ VOL~ USED. F~O~TIONS, ~TS ~ ~SULTS FISHING JO~ JI~K ~ HOLE AND SIDE-~.ACKED HOLE ~ND ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~ITIONS No operations: were performed during July 1978. CONFIDENTIAL RECEIVED NOTE --Report on this form is required for each calendar ~nth~ regardles~ of t~ etatul ~f oDerotleas, and must ~ flied In duplicate with the oil and got CO,,ervat/on commi~ee bythe 15~ of the ~ucc~ding mon~. u.l,~ ~thetwi~a directed. STATE OF Au~SKA SUBMIT ~ DUPLICA'I"~ OIL AND GAS CONSERVATION COMMI'FrEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 0IL [] GAB ~. OTI:{ ~R ,-L,. ,,,.L Wildcat 2. NAME OF OPerATOR Exxon Corporation 3. ADDRESS OF OPERATOR Pouch 6601, Anchora.qe~ Alaska 99502 4 LOCATION OF WELL Surface' 700' NSL & 800' WEL of Sec. 8, TllN-R17E, UPM, North Slope, Alaska BHL (Proposed)- 500' NSL & 800' WEL of Sec. 5, TllN-R17E, UPM, North Slope, Alaska N o t A v a i 1 a~b~~ ~ ~,~,,. m~i~ LEASE DESiGNA'i'ION AND SEI~IAL NO. ADL 47502 '(i~ 5 1978 I~ 3, OEOLOGICAL SURVEY 8. t~,,'IT FAI~M OR LEA,.C~I~]~RAGE, ALASKA Duck Island Unit g WELEo NO No. 1 lO FIELD £~_ND POOl,, OR %%'ILDCAT Wildcat 11 SEC , T., R.. 1VI. (BO'I'I'OM HOLE Sec. 5, TllN-R17E, UPM 12 PE1R.MIT NO Not A~ailable 13. REPORT TOTAL DEPTH AT END OF MONTH. CHA, NGES IN HOLE SIZE, CA,qlNG AND CEMF.2qTIiNG JOBS INCLUDING DEPTIt SET Al~q~) VOLI_I1VIES USED. PERFORATIONS, T'ESTS ~ HF. SULTS FISHING JOB~ JIL'~IK IAI HOLE AND SIDE-TI:tACKED HOLE A~TD ANY OTHER SIGNIFICA.NT CI-t. A1NTG~;5 IN HOL~ CONDITIONS No operations were performed during June 1978. RECEIVED .!dL .51978 Bivision of Oil & 6as 6onservatiOn Anch0ra~0 14. I hereby c~ctif~[ .l~;$a.~ the foregoing is tr~e ~ ~ Dist Mgr Offs hore/AK s~a~~/~/~~~ aod L. Boane:~ExDloration Department ~,~ Julv 5 lg7a oil and gas conservation commiffee bythe 15~ of the luOcNding mon~, uflle~ ~therwila d~rected. Form No. P--4 REV. 3-1-70 STATE OF OIL AND GAS CONSERVATION COMMI'I-rEE SUBMrT IN DU!?LICAT'Ig MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. o,L J"-l o,,e ~ o,.., Wildcat Wi[LL W~.LL 2. NAME OF OPEP~TOR Exxon Corporation ADDRESS OF OPERATOR Pouch 6601, Anchorage, Alaska 99502 4 LOCATION Surface. 700' NSL & 800' WEL of Sec. 8, TllN-R17E, UPM, North Slope, Alaska BHL (Proposed). 500' NSL & 800' WEL of Sec. 5, TllN-R17E, UPM, North Slope, Alaska APl NU~iERICA. L CODE Not Available LEASE DESIGN'A'~ION AND SEI~IAL NO ADL 47502 IF INDIAR~ ALOTT-EE Ol~ TRIB ,] NAM]~ 8. L.~IT FAP,~ OR LEASE NAME! Duck Island Unit 9 WELL N'O No. 1 10 FIELD A_ND POOL OH WI'LD~AT Wildcat SEC. T.. R. M (BO'FI'OM HOLE Sec. 5, TllN-R17E~, UPM r 1:~ PER.MIT N'O Not Available 13. REPORT TOTAL DEPTH AT END OF MON'I~. CI-IA~\'GES IN HOLE SIZE, CASING AND CEMFA~qT!NG JOBS INCLUDING DEPTH SET AN-D VOLtTIVIES USED, P~O~TIONS. ~TS ~ ~SULTS FISHING JO~ JL~K LN HOL~ AND SIDE-~ACKED HOLE ~D ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~ITIONS Rig up was completed and all personnel left the island on May 14, 1978. CONFIDENTIAL RECEIVED ,J{{N 2 2 OWJ~O~ O~ 0~ & ~s Conservation 14. I hereby certify that the foregoing is true and correct ~ Dist. Mgr. O~-fshore/Ak. j~., ..Ro.d ~; Boane :~ smmm,~&£ ~-~ Exploration Department ~ June 22 lq7g '" At,,~/'~..a.,~/e.~ .............. NOTE --Report off this'form i$/r~cluired for each calendar monthI regardless of the status of o,oeratiens, and must be filed in duplicate with the oil and gas coneervation commiftee bythe 15th of the succeeding month, ufllel~ otherwila directed. .] Pouch ~601 ~age, ALaska 99502 Please be adv~ that by midnight, June 3, 1978, the us~ of ~roun~ vehicles on state ~ on t~e North Slo[~ must be terminated, pe=ament roach. Ethel H. Nelson La~ Manag~ent Offioer cc: No~cP~-en~ District Office Dept. of Fish & C~e, Fairhmks ¢ 11¥k'1 g':llJIll]']O al, IV (33HI'lSNI '(]3B3J..SIrJ31t *.Ldl3331:1 NI:II'II~IB /./.6I 'JdV 'llll~ mo..I Sd , f WILL STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS °*' [] oT., Wildcat W]~LL NAME OF OPERATOR Exxon Corporation 3. ADDRESS OF OPER. ATOR Pouch 6601, Anchorage, Alaska 99502 SUBMIT IH DUPLICATE 4 LOCATiON OF WELL Surface- 700' NSL & 800' WEL of Sec. 8, TllN-R17E, UPM, North Slope, Alaska Not Available G LF~SE DESiGN'AT'ION AN'D SEHIAL NO,i - !ADL 47502 ' '~ .' 7 IF INDiAkI', AI.XDiI-EE O~ TRIBE N~,ME 8. L~,'IT FAFiA'I OR LEASE }gAME Duck Island Unit 9 WELL NO No. 1 l0 FIELD A_NTD POOL. OR %%'ILDCAT Wi I dcat 11 SEC. T . , R. I ~i r (BO'I~/'OM HOLE O~-ECT~V~ BHL (Proposed)' 500' NSL & 800' WEL of Sec. UPM, North Slope,~ Alaska 5, TllN-R17E, Sec. 5, TllN-R17E, UF {;;' ~,~iT ~o Not Available 13. REPORT TOTAL DEI~'I'I-I AT END OF MONT'I-I, CH~.NGF, S IN HOLE SIZE, CASING AND CEMF~'qTING JOBS INCLUDING DEPTH SET A_Nq~ VOLU1VIES USED. PERFORATIONS. TESTS AN~ H.ESULTS FISHII%rG JOBS JI/'NK I.N HOLE AND SIDE-T~.ACKED ItOLE AND ~'qY o'r~,l~ SIGNIFICANT C-~GE;~ IN HOLE CON'DITIONS / Construction of the gravel island was completed April 5, 1978. A 36 inch conductor hole was spudded on April 21, 1978 and 30 inch conductor pipe was set and cemented at 102 feet. Also on April 21, 1978 a camp was moved in and set up for the rig up of Parker Rig No. 97. At the end of the month rig up is 90% complete and supplies and equipment are being hauled onto the location. CONFIDENTIAL 14. , hereb, cert/~/~ .goin~ is true anlt ¢orrect Dist.Mgr. Offshore/A'k. ' /(4r~ff-~)~~d L. Boane=~ Exp]0patipn__D¢p~pt~en._t~__~.~ _ May 5: ~qTa oil o~d gas conservation commlflee bythe 15~ of the succ~ding mon~, ufll,~ otherwila directed. ]~x~.~n ~_1~ u.S.A. - -o - - .- . April 19, 1978 / I .IA Y ~. HAMMON~I, EOY£RMOR Mr. Crandall D. Jones, Manager Exxon Company, U.S.A. · Anchorage, Alaska 99502 Dear Mr. Jones: EnclOsed is a corrected Page 6 of 8 to your waste Disposal Permit No. g~C 78-4 issued April 3, 1978. Stipulation D.4., Proper'ty Rights, was mistakenly omitted from the final permit. Please substitute the corrected page for the incomplete page in your permit and any copies. This action will not affect any other conditions or stipulations of Permit No. ICPC 78-4 or its transmittal letter dated April 3, 1978. Sincerely, _,_,_J e~j-¢ y K/_e:~ nwa n d -~r~puty L~Ommis sioner Enclosure cc:...~,,,.:-.,. .,.-~...,..~,,,~;..=.'*"; -'"* °"- Operations O~f~ .... (w!enc!.) O. K. Gilbre.t.h_~z~ Division of Oil and Gas Conservation ,,,. File: Exxon Duck Island Unit,~__/ - ,~.~ Form No. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WOR'KOVER OPERATIONS 1. o,L []] o,, J~ o~',,,~. Wildcat WI~LL NAME OF OPI!IRATOR Exxon Corporation ADDRESS OF OPEI~ATOR T~X~,i ~m{EalCAL CODE Not Available L~kSE DESIGNATION AN'D SEI~IJ ADL 47502 7 IF Ii~IDIAI4'. ALX37"I~E Ol~ TI'~IBE 8 'L,~IT FAFtIVI OR [,EASE NAME Duck Island Unit SUBMrr l~N DL~. LICA~I~ 9 WELL NO Pouch 6601~ Anchoraqe~ Alaska 99502 4 LOCATION OF WF~ Surface- 700' NSL & 800' WEL of Sec. 8, TllN-R17E, UPM North Slope, Alaska BHL (Proposed)- 500' NSL & 800' WEL of Sec. 5, TllN-R17E, UPM, North Slope, Alaska No. 1 Wi 1 dca t 11 SEC. T.. R. M (Bo'r'ToM ltOL~ Sec. 5, TllN-R17E, 1~ PER1VIIT NO Not Available 13. REPORT TOTAL DEPTH AT E,I~'D OF MON~'~I-. CHA~'¢GF~ IN HOLE SIZE, CASING A~ C~F~TING JOB~ INCLUDING DEPTH SET ~ VOLL~ USED. P~O~TIONS, ~TS ~ ~SULTS FISItlNrG JO~ JLCCK ~ HOL~ AND SIDE-~,ACKED HOLE ~D ~Y O~R SIGNIFIC~T ~G~ IN HO~ ~ITIONS Construction of an ice road from the location to the gravel source was started March 8, 1978. On March 16, 1978 ice removal was initiated at the wellsite and the hauling of gravel started on March 21, 1978. At the end of March the gravel island is 69% complete. CONFIDENTIAL ,,~.,h.,~,.,~'~,~'= t :o~.o~,..,~,,~o~-~ Dist,Mgr. Offshore/Ak. ~m~~~d L. Boane ~ Fxplnr, tinn n~p~rtment_~_ 4-19-78 NOTE --Re0ort on this farm ii required for each cal.ndar ~nth~ regardless of )~ status of o~erations, and must ~ flied In duplicate with th e oil and gas consorvotion commifee by the 15~ of the succ~ding mon~, ~le~ otb.rwisa directed. E ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION R. L. 13CANE DISTRICT MANAGER April 17, 1978 Re' Duck Island Unit No. 1 ADL 47502 LO/NS 77-162 Mr. Joseph P. Green Director, Division of Minerals and Energy Management Department of Natural Resources State of Alaska 323 East 4th Avenue Anchorage, Alaska 99501 Dear Mr. Green' APR 8 1978 Dl_v. of Minerals & Energy Mgt. Anchorage, Ak. The plan of operation for subject Duck Island Unit No. 1 well filed with you December 2, 1977 provides in paragraph 3, page 3 for the,,final ,s~e_l.e. ction_e~. ~ ~~ement of the rig to the location -~ ~'!, ,u ~' ' It now appears that selection of a drilling rig must be made at this time if we are to be assured of suitable equipment. Such being the case there would, very likely, be more than suffic~_e~.~_.tim_e~.r~o .~,~.~be~,erAi..nation ~.f.,~t~be..=. .... req~-~ei rig, o ers as are custoin-~i'ly~Asued at the termination of the winter season by the Department of Natural Resources closing the region embracing the subject operations to all surface movement and activities. . t As the sole purpose of this request is to permi and as early a completion - of the subject well with which we believe the state concurs, we earnestly hope that this requested modification of the plan of operation will receive your approval. RLB' RKR' et cc' J. Scott Grundy William Copeland Dougl as Lowery A DI¥1SION OF EXXON CORPORATION Sincerely yours, Rod L. Boane E - ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION R. L. BOANE DISTRICT MANAGER April 6, 1978 Re' LO/NS 77-162 ~'7~--~- Exxon Co., U.S.A. Duck Island Unit No. 1 North Slope Alaska Mrs. Ethel H. Nelson Land Management Officer State of Alaska Department of Natural Resources Division of Minerals and Energy Management 323 East 4th Avenue Anchorage, Alaska 99501 Dear Mrs. Nelson' In regard to the above captioned permit, stipulation No. 3 states, "Do not conduct any staging activities in the vicinity during the months of June through September 15. We request this to avoid stress to waterfowl ..." In order to expedite our exploration efforts, we may move our drilling rig in prior to breakup. However, if breakup is earlier than we anticipate, we request an option to move our drilling rig and necessary drilling equip- ment and supplies, by barge, to our gravel island drilling location whenever ice and water conditions permit. Approval of this request would allow us to commence operations as soon as conditions are favorable within the permitted drilling season. Mrs. Nelson, thank you for your time and attention in considering our request. RLB'DTR:et APR 1 0 1978 Yours very truly, ~ . · ,. ,. ~'" .~'-----.,~ . / ~. (,~..'7~.._~_ ..... Rod L. Boane Div. of Minerals & Energy. Anchorage, Mr. Crandall D. Jones, Manager Exxon Company, U.S.A. Pouch 6001 Anchorage, Alaska 99502 Dear Mr. Jones' JAY $. HA,I~O.ND, GOYER,¥OR POOCH 0 - April 3, 1978 , The Depa.¥tment of Environmental Conservation has complete~u .. its evaluation of your Waste Disposal Permit application for the discharge of treated liquid waste to the lands or waters of the State from wastewater treatment facilities associated with an exploratory drilling operation and is issuing the enclosed permit, WPC 75-4, in accordance with AS 46.03.100-110 and 18 AAC 70. Please review the conditions and stipulations in the permit and insure they are all understood. If you disagree with any portion of the permit, you may request an adjudicatory hearing by filing a statement of issues under AS 44.62.370 within' thirty (30) days of receipt of this letter. The statement of issues should be mailed to the Alaska Department of Environmental Conservation, Pouch O, Juneau, Alaska 99811, or delivered to our office at 3220 Hospital Drive, Juneau. The filing of a statement of issues entitles you to an adjudicatory hearing to contest the permit. Failure to file a statement of issues within thirty (30) days of receipt of this letter shall constitute a waiver of your right to judicial review of these permits. ~nclosure' Sincerely,.._. C.Je r~'~ ',R':e _~nwan d ]3~ p-~u t y"l~ omm i s s i on e r cc' EPA, Alaska Operations Office (w/encls) ~O.K. Gilbreth D~~n of Oil and Gas Conservation STATE OF ALASKA DEPAR~ OF ENVIR0h~ CONSERVATION POUCH 0 JUNEAU, ALASI<iK 99811 WASTE DISPOSAL PERmiT No. gTC 78- 4 Date April .3~ 1978 This waste disposal permit is issued to F~m~xon Corporation, Pouch 6001, Anchorage, Alaska 99502 for the disposal of treated liquid wast& to the lands or waters of the State from trea~nent facilities associated with an exploratory drilling operation idantified as Ik~ck Island I~i.t No. 1 located at Southeast 1/4, Section 8, Township 11 North, P~m~ge 17 East, Umiat Yeridisn, A.D.L. 47502, North Slope, Alaska, subject to the con~ ditions and stipulations of this pezTnit. 7his pe~Tnit is issued under provisions of Alaslca Statutes AS 46.02.100-110, Water, Air and Env-ironmental Conse~,ation, ti~e Alaska Actministrative Code as gnended or revised, and other applicable State laws and regulations. 7his permit is effective upon issuance and expires ~'brch 1, 1983. It may be terminated or modified in accor&nnce ~,dth AS ~6.03.120. '-' ?&rr~. Re~'~nd 'Page 2 o[ 8 A, EI:t:LI Ii!.VF L!:,IfT;-VFION5 . During the pc;tied beg.i, nni_nz~ on the ~.~..~c~.~.h,'e date off tl~i.s pe'n~tit and lasting through the e?~Fat'ion date o,.' tenai~mtion date, the penaittee is at~timrized to di scharge treated wast:c'vmtcr effluent as specified in ti~s scctio~. 1he treated 1. iqu.id wast. e discharge shall not exceed the following limi U_~tions' 'k,;~] ] uO Total Flow Biocnen:,_~cal Oxygea Demand (EO[)S) Stash.ended So!ids {SS) Fcca! Col. [fo'n~t 50 50 .:xg/1 ~00/100 mi 70[)0 gpd 60 re.g/1 60 400/100 ml . .... OL,~=I irt the efilttent after at: least: 30 minutes contact ..... time s}',..:~,]_~ not b".~ more than -2. ,-';'~/~,o , at. any t LvEo. The cl;~solved oxygen in tlu~ cfflucitL shai'l 'not be ]ess 2 nig/1. . Ihe p~I of thc effluent slm].l be bet:wen 0.0 and or w~th'in_.. 0.5 unit o£ the -a.v[~ of the raw water . ,nere snal. 1 be ho dzs,.n.:~zs~ or floati[tg solids or iToam i~'~ ~1 ~ ' 1 ociter c~tan trace mc, ~-t-- oily was'~-' ~,.om~b or t.t;b wh;t. cr~ prodt, tce a sheen on thc SLtr[ace O[ the z'ece~v].n~ waters. , Sludge £rom the wastewater treatment facility shall not be dzscnargea to the waters o-f ~te state. 7he met]~o,:! o~ d;spos~-~l o'f s].udge shall- be by incineration unless a~t altc, r'~mtivo disposal method is approved in ;,,Tiring by 't}te dei~;t:'tment. . iOX I q-O[:~. I' x .,~, 2&l) REPORTING 1. ~.bni. torin~ of Efftue~:t The pennittee sh~.ll monitor the wastewat:er s treoz:t in the fei. low.trig n,a~,:.~r and freqt~cncy, · c3ofS ~,';[t S ~e2W3 tO I.' C}lJ..'aic LC I'± :5 t J C Stream E F.'.[luen t Biocitemica~ Oxyge:.i Demaud (S-Day) r.:o;l t:hl v · coirtmosite oF at Ieast 4 grabs pe r.i od Total_ Flow ca ]. ] y N/A Suspended Sol. ids mon lilly con,:posi_te of at lea.st 4 grabs du F.i n~; ! 2 hour per :] od Total Chlorine da Resi ' ' D i ~ sol~ ut_ Oxygen Fecal Co]. i. ? o na mort L~lly g F~,J~ · . Representative Se.,:,?] ins Samples and moasuFomoats taken as reqti: :_~ representative of the voh~ne and natu~-e og the mo~Jtored discharge. The pen'~tittee shal. 1 subrf!J.t a brief descr.ipt~ou of composi~ing me,hods including, but not lk:d ~ed to, 1eta. ti.on of sampling and mc, asuuement points. 3. Additional bbni toting_ the pe~T,,,i~tee monitors an),' influent o'u ef[lue,:~t cha_,'~,.ctcrJ, stic identifSed in this penn_Lt more ft'eqtlently than requi_red, the results o.f such monitoring shall be reoo~'tcd to ti~e Pei)aFtment. the monthly moni. torin$ repoF-t ..... ~,i~--,~, tire. cica' pacagr',rd, B.4 this , ~--' '; FUni_touipg r'es~dts obtained during '~--~ pFevi " sIm'l. 1 be stmmmrizcd and rcpoz'tcd ~o the Dcpart~:?;tt [u;.:l !)c.)stm~rked la'ret tha~ thc ].4th day of thc mouth Col ]owi. n~ i:[tc repoFt_ing period, blon.[toring shall b%ia at the oFct'].scn.~t' ~ -,-~os~.. Signed copi. es of t}mse, a~c! ..... ~,]~ oc~ter' reports rec?~ired herein sIm].l be ' . , Sth)~:~.:_tted to the [)cpart'mcnt' at tho following address: Alaska Depat-tment of }!rlv i~-o~.;.:i~.~r'..ta].. '" ' ~ ].Oll P.O. Box 1601 FaJrl):,r~;~ Alaska~:,~q"°~,-,.~, Phone' (.9~q7) 452-171.4 , , C. Pa~e. 4 o f 8 Peri,tit' No. WI'(: 78~4 :~ .... ,.,,~ ,ol): n,~ k.~ng a bx.- the Derrait. tec, the ope~ aLor oF othcF emr)!ovCcs, ' -- -~: - may result in the imposit[oi~ oF criminal oe~ml, tics as provided for under AS 46.05.790. · 5. Test Procedu Fes , Test procedures for the a~m!ys.ls off poll. uta.;tts shall con[o'uu to methods cited in 18 ~L~XC 70.020(c), or as such r%u!atj, ons ntay be ~ne~tded. ~e penaittee may subst.ttute al ter'~tative me,hods of 7 mon.Ltocing or anal),'sis upon receipt of prior wr.ktten approual -Croi;t tlte ])epar~nent. Recur c~s Rc-tention Ail recoFds and inFozmtatie:t resulting fro:.'; the mo~titor:i, ng activities requiued by ~is permit, inc:luding al!.. re:or'ds of ana!.ysc~s perfon,ed and calibrat:lon and ntaintcna~t,ae of irtstz-Lznentatiott and recordi~gs from continuous monitorinS ittsttxn?~tttat~e::, sh:-~lI be ?.'ctai~tcd .i.[~ ' ..- ~ _~ ~.- ~1 A!~{ska for obse=wa,~on by the Depart-merit foF [~'ee years. Upon 'request from the Deparbuet~t, the pe:7~dttee shi~'!.i submit certified cop.les of SI~C~ reco~-ds. Pd:Qt t J_I-u',,i,...N ~ I o Change in I')isch_~_'..f~2<e All discharges atttnor~zed he'rein shall, he. co.u:4istertt: with tac 'terms apd_ conditious o._F t}~is pe',~:,[ ........ ~ ~,- d~s' ch:-,~;e~, of any pol h~t'ant - _ ~- ~. - ,~ ~';~'~'~ or solvents~ more frequently than oF at a concentration or l:imit authorized shall constitute ttoncempl.tance with the pe'nrti, t. 'Arty anticipated faci.!itf expansion, production in,::rcase, or process modification. ._ which will resu].t in ..~..r,,~,,, c!i~ferent, or increased. of pollutants must be reported by sub,:tission of a new waste d i. sposal pe~Tait appl~c~.c, zon, or 5f suca chrmges w511 not'. 'afFect the abilit:v of the pennittce to comply with the effFlue,~ ].Smi. tations spcG'i '" in ~uhz_'s permit, by ~Tittert noticc to [nc !)ep':~rtmer~z. a'[: thc ac~d~:,s-"- . specified in paz-'agrapn B.=~ at ]east 50 da)'s pFiOr to Cl~e :im21e-- mentation o.f such changes. Toxic Pollutants If a toxic polluta~.~_t, including oil, grexse, o'r so'lveats, com'cntration standaFd is cstab!ishcd :ia accordaucc wi. th iS :L:!C 70 f-of a pol'l.utant present in this df -'' .... ~ ...... scna~ge, aud if suc~t sr~:",'~ard :is more st:r.i, rtgcnt than the lim_Ltation in tills per:ui.t, tlxJ_$ pen:ti.t: may be mod-iF-i ed :i~t acco:dance , . . Acc idental Discharges Th~ pennit£ee sha].l provide protec~]o~ £ro;n acc[de;-:tn!, discharges not ].n compliar~ce w_[th tlie ,.n.~:ovisio,:!s oF t!~.]s pe~n:i.[t. F~c.i]J'tic's ~o ?revent such discharges sha'l.l be ~ta]ntai,:le~l in good work.]~:S condition at M1 ~ime$ by 'the peN:'..it~ee. Nonuomo]. l.a[tuc No ui r.t.cat lop. If for any reason the pe~7~:i, ttec does r~ot co~q')!.y w[t!l o'r wi. ti be tmable to comp]_y with any ef[-l, tmnt !im[t:at.:ions specif:[ed in this penait, the peNnit, tee shall renoi't the i~oncomPl, iance to the Department wi. thin ~4 ko~r~ o~. b~t,,:~nS a~,-n of condition by tel. epl~one, te!esr:?l~, or i.~ d~o. absence by mai1. b. v,Tittcn [ol[ow-t~p ro;',.?Yt wit. bin seven da/s of the eyelet re~:~t'lel. ...... contain [.~t. not be l];:,;'~c.,' to' (1) tSrles and d:~t:c:s on w!t,ci'~ t..'-':e eve:~t occ'ur:c,~ ~0 ~- CO~'~'OCtOc~ *~ is expected to cont i_~ue; (_2) a detai_'led deqcr~t',t-ion of the and 'types of mater [als invo!veJ; (5) deta]].s ol any da:~n<<c to the rece]v;p,; (4) details of a,-ctjon~ ~.~_~..~,: o~' ~u ~e t'~i~d~ t~ cor~'oc.t the causes o[ tho event; (S) details of actions tax,~: or to damage resulting from thc evc~tt. . Co It is recognized that "c-, .... u!ons ~ or ~lcontro].tat)! ~' C'li'ct~p. st'~-{[lc~ ~'t:~',,' SOHIO[: resu].t in effluent conce~trations excct'ckling the [)eniti. t ]imi-- rations, despite the exercise o~ all poss[b]e care and maintenance measures and cor~:ec'tivc mea.su~cs b>' the pe~'mlttee. The pele:[ttee may demonstrate to the inep:n'tnte~t that circumstances exist in any case whe~'o e f.[!.uen[ exceed ctto~e set fordt ~n ~. q ~..,:;:,~tit 7he Co~[~5lnper s}m.ll consider such showing J_n de~'' ~--u~::,. i-im~o pe~.,~,',~ i.'-~ vi. ol'-,t ions., and for enforcei;tent pLiI~}OqCS_.. . The De[)art~,.ent doe~. not w;~ive ar'~-.., of its legal rights ' ' ' Tiie pemlitt:ee sb. all. take a]I neces.4c~rv im_-:a~.s to roi. n itemize any ad,.'tn'se i~uoact to tn~ receiving wat,",r-~ or i;-~nds rc<t~l, t ing (rcr:t nonc:o~i~p] ~.a,tcc with any l:imi, tations spec:i, fled in this Pe't7~ti t, incl~.td'ing additional monitoring as necess,2vv to determine t. ltc natt~re of the nonco~nplyino discha~'~c~ ~J~e ~" -- . 'o .:,.~. ~tmLtt:ec J.$ restful, r-ed to under- take cloanu[) activities J.n tho ct-ent of am.- adverse impact resu'Iti, n~, from noncon~)], iance. th'Jot to coi~,,i~""-iug_,,,~.., a di. sc~:',vqe.., to the' wa~ter5 or lands off the State, etd~. 5. n the f.lrst locat'Lon after t~.s pcv~ai.t is ],ssucd or in any subscc[t~c~t re!ocat-io~s cC thc dri. ll rig, the pe'nx~Ltteo shall submit a pl.a~ for approval, to the Super- v~so~' of the Department's ~ug~o~at O[~ice in v,'h~c~t thc oper'at~on ~s located. The pe[~nitLco Mia'l] obt:a'J.~ pt'ior approval froa the Regiomd ., ~.~c.e before d]scn:ttgtn?; any wastes at the new sSte. If the Rcgtona~ Of Eice docs not apl~'ovc the site for operation under this per;nit, the pe~;uit, tee must obtain an appropriatc amendment to tt~'is . t)~.,.z~t~e shall, allow tiTe Co~:~;.~i. ss-~_o,:'u:; or his author[zed representatives, upon pre-sc~;t:a t ion of credc,~'~t i al s, to enter upon the pe~7nit_Lcc's prec.;ti, scs where waste collect;ion or trea .... ~ .... requ'['cc, a nd ' bo at .rcaso~tab]c times, to have acce:;s 't.o a~d to be ;~'1 lowed to copy any records -~--,, and conditi, o[ts of this ectuip~nent or mo~[tori~<4,'- met]tod_ ~'ec[t~ired J_r~ t. Iti. s per'lull;, a~td to take any sami)-les ilOCOSS;It'? [01.' t.]lC onl-,-',rccmcitt eL th_is pena;t t. Trans.Ser o£ ©,,.r, ership o-r Control In the event of any change in control or o'~,t~ersh.i.p of facJlitkes from wl~ich the authorized discha, rges e~nz~tat, e, the peak,ri, tree shall notify the succeeding owner oF contro~'Ler oF Lite exi_steitce off this permit by letter, a cop)' of M~-i. ch shall be f"orwarded to the Con,mis~-' -e . 3 Availabi. lity of Records Except for infonuati, on relating to secret p'.rc,,:'ess(:s or re'ct'hod:; o~ mantt~actt~ro, ~7.1 recordq fi4td reports pro[x:tt't:.(1 '.in accordance ,,, >n .... available [or pttt)li.,c w:i. th the teiqils 0.[ t. lti. s pct'-,tt '-' .,',s 10e ' 1. [1!~ insi)~.ut5o~ at the o~ficcs o[ the 78-4 . Sere rah ilitv ]~e provisiorts oF this peFilti, t are scver~-d'~lo ap,J, iF any pro'c1.:.; o.C thi. s per'mit or the app]:icat ion of anv [~rovi:;ior~ of this to any ci. rcun~st'ance~ Js held immlid, tlle m'~')l icat'i,~n oc such provision to other ci. vcumsta;~ce5 and tim reu[a.~n,~.F of th permit event that such invalidati, on mater_i.::dty alters the scepe or -"~ th,-l~elmrtu'.cnt s}ml'l, have the riqht. conditions of this pozutrc, ,~. ~ , at its so.lc option, to terminate the ,,x.~ ~ ~-,i,, t'. . State Noth:iT,~g in thi_s per'nii, t shall, l~c const'm.:eJ to pt'cclt:.J-: tim of ar~y legal act.i, nu~. or rtl_lc'cc pen:ilttc, c fro~:t :t~v, uc::i.)onsii~il, it:,..~-s.., 'iiab i.].ities, or poitalti.cs cstabl, i_shcd F,,_tvs[i:~t. tn a.'~v u!)P] icab State law or reg~tlation. o POStipo O[ PelT:lit. ]]~e pe?.:,-uitt, cc slml. 1 post tlLi. s [)elsili. t co.,'~.spic.-:_vqusl, y ;~_~ the works loc~ti.o.:~ and maintain a copy of it 5n thoi. rc-'-',,.~.~;_.l. o De [ln i. t i ohs ~'~ ntlt )ns ~ th1 't. the [:OI_' u. ll~_..... 7t.__O O.L S DO'rTl! hOt'tOm''D:' ~... ii~i/ period of time. For coli[orla clcteuuined lov the rm~]t tube procech~re thc ', metr.i.c meem; -for co1 i Cona de tezqlttrt5~.'l t)y thc liiOli% filter procedure the,~,verao'o. . o ...... shall [)c coF'ix,Led, as. 'the aritNne tic mean. Comau i. s s i one r Con~aiss tone F o £ Env [ ronmen tal Censer-va t i o~ Co! npo s i t e A combination off_LnU" "[v.i.d~,:tl >tuar:~>~" ' o ~.r wat.c,F o,- wau. t.c.'..::),teF"' taken at selected in[eFva~s, generally specJ[ied period to mLni~n:Lzc the , . .kc..u of the variabi.'lJty of ' ' 1 i~to the conti~sS_-te 5~t propo-rtio~t to fi. ow. Dei)a~ ....... ]'he Departiuent of Ertvi-ron:;,o;~ L:-xl Consct"~ :-.ti ion L[.~; W~!Rt otc'[[ OF S+' '~"' ' ' ,. , ' thc fire"rtl, sr~-cup wa .............>~,~,. is di~ct~=t xL.,~, tn the receiv.iny., eitv.i'ronriie~t. A single individtml santp'!e oi:'- t,:astcw::r, ur- ~' taken at n'c.~;., t'!'~er- scl time nor' gl. ow. P(.) Flit [ t NC). 1¢;['~C 7 ~ - 4 That. segment-o-F the was tew:tteF stre;',.:'~, which 2. is witlti[~ or i~imtediately Following a surge or equat, ization t~ml<, providi, n,.j tlmt: raw wastcwatcr or raw wastew:tt, cr' jnmtediate] alter pr'etreat~,ent cheer:.; thc ta~tks, or if no pretFeatment: or cq~.~allza't ion faci].it exist. The value of arty glvcr~ p~tt'amcter' ttt:-lt ..ks nevcF to beexc~e~l~:~- l b}: an,.-, sa~::p'~_ e . ..' ' The removal o£ laFg,? so! ids F~'om n,w s~u,:;.:L,,c, by solids by ~-,,'~-'; Rat.,.- l','a Let Rote Wing Envi t-o nr:t c n t Thirt>~ Day Average The location at which ......... 5cn:',~gc~: t.o the onvironi~¢,R'r bo 5 t'. 1 - , The a,/erage of a!1 sa;~tt)le_~ taken clt~Fii~,~jI a t}~i~'ty consecutive a..).- per S Ul CELL4 The flow o[ wastcw:ttct' [:ro{u its co1 1 oct_ion a~<t t Fcatmcrtt faci l i t Les 'to the F,o:i.nt of final discharge to the recei, v'ing envirol~ment. S LI Oct[. Segment A porkioa o£ the wast. ewateF stFca:,. _ rFI , Includes lakes, bays, sounds, ponds, :[~itt';,.;u,::d:i.r~g rc'qer'voi rs, Bering Sea, am. Arctic Ocean :in the 'r-" ' ;'t.s of the S~tas'~e, and a1.1 oil,e:. Dc, die< oF sttr-'/acc or urtder'- ground ,'~*',','.,.~.= ~:. , natta'al or ~.*t't] [Jc[a] , .r)'-fi'>l ic or pci.':a'tc, inland or coastal, [rcsh o: salt:, v.-hi, ctt arc ~c}to'I.tF or par~i;tl]y in or border_inS the StaLe of tmdor juF.isd.i, c2ion of the St:~te. Mm'. Cranda!! D. Jones Exxon Corporation Pouch 6001 ,~nchorage, Alaska 99502 Dear Mr. Jones: ! i · POUCH March 17, 1978 f I Eu, closed for your review is a draft waste disposal permit for discharge of treated liquid waste from treatmant facilities associated vith the exploratory drilling operation Duck Island Unit No. 1. ..~efw~uld ap~ciate receiving your cormrants on this draft permit by C'~,~arch 31, 1978~ Shortly afterward we plan to prepare the final per~it ar~'-send ~.~-~-~---tO y..ou. · .. . Enclosure cc' OoK. Gilbreth Div~ of Oil and Gas Conservation DRAFT STATE OF ALAo~<A · DEPA;RT~r~ OF ENVIROh%'~2q2~L CONSERVMEION POUCH 0 JUNEAU, ALASKA 99811 WAS%E DISPOS~,~L PERMIT No. ~TC 78- Date 2%._is waste disposal permit, is issued to E~xon Corporation, Pouch 600]., Anchorage, Alaska 99502 for the disposal of treated liquid wasta, to the 'lands or x~aters of the State from treah._-~ent facilities associated rtl.th ~ exploratory drilling operation identified as Duck Island I~i~t No. 1 located at Southeast 1/4, Section 8, To~,mship 11 North, Range 17 East, L~iat ~ridi~, A.D.L. 47502, North Slope, Alasl.'~., s~ject to the con- ditions and stipulations of this pea_mit. II, is permit is issued under provisions of Al. as~e~ Statutes AS 46.02.100-110. Water, Air and Environmental Conservation~ ~e Alas.~m. Admix~ist~;ative Code as amended or revised, and other applicable State la~,~s ~and regulations. This Peunnit is effective upon issuance and expires March 1, 1983. It may be terminated or modified in accordance with AS 46.03.120. Jerry Re inwan-ld' Deputy Con,hiss ioner Page 2 of 8 Penni. t No. WIC 78- A~ EFFLUENT LIr,II2:4TIONS . During the period beginning on the effective date of this permit and lasting through the expiration date or tet~nination date, the pe~mittee is authorized to discharge treated was tew-ater effluent as specified in this section. . 2he treated liquid waste discharge shall not exceed the following limitations' E~. flt ~,n c Thir fy- day ~ h×imum Characteristic Ave rage Value ca~ Flow Bi ochemical Oxygen Demand (BOD5) Suspended Solids (SS) Fecal_ Coliform Bacteria 30 mg,/t 30 rog/1 200/100 ml· 7000 gpd 60 rog/1. 60 rog/1 400/100 ~ The total ch].orine residual in the effluent after at least 30 minutes contact time shall not be more than 2 rog/1 at any t~ne. . The dissolved oxygen in d~e e~flu~n~ shall not be less ttian 2 rog/1. , The pH of the effluent shall be be17ven 6.0 and 9.0 pH un.i. ts or within 0.5'unit of the pt{ of the raw water supply. ]l~ere shall be no discharge of floating solids or foam in other than trace remounts or oily wastes which produce a sheen on the surface of the receiving waters. , S]_udge from d~e wastewater treatment facility shall not be discharged to the waters of the state. ~he method of disposal of sludge shall be by incineration unless ~m alternative disposal method is approved in wTiting by the depar~nent. o No untreated domestic was~c,~a~er shall be di. scharged to the lands or watc~'s of the state unless othcn¢ise app,'or-ed. bIONITORING ANT) REPOP~TING ! ': ' 1. kbnitoring of Effluent The pennittee shall monitor the wastewater stream ~in the fo].l, owing - maimer and frequency, while discharge is occurrzng. Page 3 of 8 Permit No. b]~C 78- Wa s tewa ter Stremm Segment Effluent Characteristic Biochemical Oxygen Demand (5-Day) Total Flow Min.imtm~ S~up ] e F~ equine.. Ty_yj~e. monthly daily compos.[te of at least 4 grabs during 12 hour period N/A Suspended Solids monthly conposi, te of' at least 4 grabs duriuo' 11_2 hour period pH daily grab To tal ChIorine dail.y grab Re s idu a I Dissolved Oxygen weekly grab Fecal Coliform mondt_ly grab 2. R_~nresenta tire S~mupl. lng Samples and measurements taken as required herein shall be representative of the voltme and nature of the monitored discharge. The pet~ittee shall submit a brief description of compositing methods including, but not limited to lo:aclon of smnpling and measurement points. 5. Additional ~bni tof.i_F_g_n~ if the permitee monitors any influent or e:[-.[].uent characteristic identified in this permit more frequently than required, the results of such mo~itoring shall be reported to the Dei:,ar'tnter~t in the monthly monitoring report required under paragraph B.4. of this permit. 4. Reporting Monitoring results obtained duri~g the previous month shall, be smmmarized and reported to the I)epar~nent and ost~utrked no later than the 14th day of the mon~n folio:al, rig the completed reporting period. Monitoring shall begin at the commence,tent of discharge. Signed copies of these, and al! other reports required herein, shall be submitted to the Deoar'attent at the following address- ~ : Alaska Depar~mnt of Environmental Consetw'ation P.O. Box 1601 Fairbanks, Alaska 99707 Phone.' (90,7] 452-]714 Page 4 of 8 Permit No. WPC 78- S~ . Knowingly making a false statement, by the permittee, the operato'r or other enrployees, including contractors, on any such report may 'result in the imposition oi7 crkninal penalties as; provided for under AS 46.03. 790. Test Procedures Test procedures for the ana].ysis of pollutants shall, conform to methods cited in 18 /LAC 70.020(c), or as such re~!ations may be anended. The pen~.ittee may substitute alternative methods of monitoring or analysis upon receipt of prior ~,,~r~tten_ approval from the Department. Records Retention .~U ..... records and ].m:'omation resulting from il're moni_tor:ing activiti, es required by this per,nit, including allt records of analyses per£onned and calibration and maintenance of instrtalentati, on and recordings from continuous monitoring instrtateatation, shall be fora.[ned in At'aska for observation by the Department for three years. Ui)on request from the Depar~nen't, the pet~ittee stroll submit certi, fied copies of such records. C. 1.. Change in Discharge All discharges authorized herein shall be comsistent with d~e terms and conditions of this permit. The dischage of arty pollutant identified in this De,roi. t,_ or toxic material, incIuatng" oil, grease, or solvents, more frequently than or at a concentration or lJmi. t not authorized shall constitute noncompliance with the permit. ~y anticipated facility expansion, production increase, or process modification which will result in new, diffferent, or increased discharge of pollutants mttst be reported by submission o.[ a new waste disposal permit application, or if such ch~ges will not a'ggect the ability of the pe'nttittee to comply with the effluent 15mitat.i. ons specified in this permit, by ~,Titten notice to the Departme~th at tire address . . days specified in paragraph B 4 at least 50 - prior to the -bnple--. mentatJon of such changes. 2. Toxic Pollutants If a toxic pollutant, including oil, grease, or solvcuts, concentration standard is established in accordance with 1.8 ~%\C 70 for a pol. lutant present in tltis discharge, and if such standard is more stringent than the l~nitati, on in dxis permit, this penutt may be modified in accordance with the toxic pollutant concentration standar'd. of 8 No. I~>C e · . Accidental Discharges The penr, ittee shall provide protection from accidental discharges not in compliance with the provisions of this per-mit. Facilities to prevent such discharges shall be maintained -1~ good working condition at all times by the pe~ittee. Noncompliance Notification If for any reason the pe~mtittee does not co~ttply with or wil'l. be tmable to comply with any ef~uent limitations specified in this per, tit, the peri,tit, tee sha].l report the noncomp].iance to the Department within 24 hours of becomi..ng aware of condition by telephone tele=rapn, or i.n the absence of both, by mail. b. A ~'itten follow-up report shall be sent to the Department within seven days of the event ret~rted. The ~.~a-itten report shall contain but not be limited to: (t) times and dates on ~dtich the event occurred and, if not corrected, the anticipated time the no~com?li_ance is expected to continue; (2) a detailed description of the event inc]~ding quanti~ties and tF%aes of materials involved; (S) 'details of any d~mnage to the receiving em;iro:~aent; (4) details of actions taken or to be taken to correct the causes of the event; and (5) details of actions taken or to be taken to correct any damage resulting from the event. C. It is recognized that influent quality changes, equipment malfunctions, or mqcontrollable circtm~stances may sometimes result in effluent concentratioms exceeding the 'pe~:~tit limi- tations, despite the exercise of all possible care and ~intenance measures and corrective measures by the permi, ttee. ~e petmittee may demonstrate to the Department that such circL~ast~mces exist in any case where et:fluent con. cen[.rati, ons exceed those set forth in this pe~-mit. The Co~;~'~.issi. orter shall consicter such sho~¢ing in detet~tining pen~ti_t violati, ons and for enforcement puq)oses. ~te Department does not ~'aive any of its legal rights during such consideration. Adverse Impact ?'he per~-,nJttee shall take all necessary/ means to minimize arty adverse impact to the receiving waters or lands resulting from noncomt-~liance with an)' limitations specified in this pei~,~tit, including such additional monitoring as necessary to dete~ttine the nature and impact of -the noncomplying discharge. ~1~e permittee is required to under- take cleanup activities irt the event of any adverse impact resulting from nonco~.pliance. :,e 6 of 8 ~ ' Pem~i.t No. WPC 7 . Chr:mge of tocat[on Prior to co~uencing a discltarge to the waters or ].mtds of the State, either in the first location affter thi_s permit is issued or irt any subsequent relocations of the duill rig, the pe'nnittee shall submit a plan for approval to the Super- visor o£ the Depar~tent's Regional Orifice irt which the operation is located. The pennittee shall obtain prior approval from the Regional O-F.~ice before dischauging arty wastes at the new site. If the Regional O.[-ffice does not approve the site for operation under thi. s' permit, the peNnittee must obta'in an appropriate amendment to this pennit pursuant to 18 AAC ]5.100(d). D. G.F:~iRAL 1. Right of The petmi'ttee shall allow-the Co,m~issioner or~ his authorized representatives, upon presentation of credentials, to enter upon the peNaittee's premises where waste collection or treatment works are located at such times and upon such temps as the Department ma/ r'easonal)ly rectu'~re, and ' bo at reasonable times, to have access to and to be allowed to copy any records required to be kept uader the ten.:~s and conditions of- this pem~it, to inspect a.n/ monitoring equipment or monitoring method required in th_is pcmdt, and to take any samples necessauy for the en'Forccmcnt oF this permit. Tr~msfer of (~,mership or Control In the event of any change in control or ow~ershi,t) o£ .[acilJ. tles £rom which the authorized discharges emanate, the pe'nuittee shall notify the succeeding o~cr or controller of the existence . s~m[ be ~orwarded of ~'~n.~s ~ ~'~--'~,~,,:~t 'Dy letter, a cop' of which "'-l to the Con~tissiorter. 3. Availability of Records F~xcep%: for inComtation relating to secret precesses or methods of manufacture, all. records and reports prepared in accordance with the teNns of this. permit shall be available for pub'l i.c inspection at the offices of the Deparbuent. ..... e.' 6 of 8 mit No. M~C 78-4 6. Change of location Prior to conm~encing a discharge to' the waters or l~mds of the State, either in the first location after this pe~nit is issued or in any subsequent relocations of the drill rig, the permittee shall submit a plan for approva! to the Super- visor of the Department's Regional Office in which the operation is located. The pe~vnittee shall obtain prior approval from the Regional Office before discharging any wastes at the new site. If the Regional Office does not approve the site for operation under this permit, the pe~nnittee must obtain an appropriate amendment to this permit pursuant to 18 A,&C 15.100(d). 1. Right of Entry The pennittee shall allow the Connnissioner or his authorized representatives, upon presentation of credentials, a. to enter upon the permittee's premises where waste collection or treatment works are located at such times and upon such terms as the Department may reasonably require, and b. at reasonable times, to have access to and to be allowed to copy any records required to be kept under the re,mm and conditions of this pe~nit, to i~m~pect any monitoring equipment or monitoring method required in this permit, and to take any samples necessary for the enforcement of this permit. 2. Transfer of {~mership or Control In the event of any change in control or o~,7~ership of facilities from which the authorized discharges emanate, the pe~w~ittee shall notify the succeeding o~,mer or controller of the existence of this pe~vnit by letter, a copy of which to the Con~nissioner. Availability· of Records ~, ~.~', ~',. ~ ~" !'~ "~,. ~" F_xcept for info~xnation relating to secret ~roces~e~ or methods of manufacture, all records and reports prepared in accordance wi-th the te~ms of this pe~mdt shall be ava[.!able ~for pub].ic. inspection at the offices of the Department. 4. Pr___ope_ rty Rights The issuance of this permit does not convey an)' property rights in either real or pez'sonal property, or any o~er p~-i'~,~ileges, nor does it authorize any injury to private property or any invasion of personal rights, nor any infrin~emei~ts of £ederal, State or local laws and regulations. ~ .ge 7 of_- 8 5~ Sere rah il i tw The provisions of this pe~uit are severable and, if any provision of this permit or the application of an? provision of: this pe~m~t to any circumstances is held invalSd, the application of such provision to other ci~ct~nstances and the remainder of th~s pe~mdt shall not be a£fected thereby. Noh~ithstandin~ the above, i.n the event that such ~nvalidation materially alters the scope or conditions of this pe~it, the De?a~tm~ent shall have 'the right, at its so~e option, to terminate the pe~uit. . State Laws Nothing in this permit shall be construed to preclude the ins'titut.J, oa of any. legal action or relieve pe~m~ttee from any liabilities, or penalties established pursuant to any applicable State law or regu!ation. 7. Posting of Pe~md.t 7~e pe~mittee shall post this permit conspicuously at the treatment' 0 . 2~ I. Cc., works location and maintain a copy of it itu their contra] f-:" ~ 8 Definitions , For the purpose of this pe~mfi, t the following de[ini, tions shall, apply. Ave ra ~e The aritb~netic mean o£ values obtai~ed over a spec_'i, fl. ed period of time. For coliform de'te~nined by the multiple tube procedure the average shall be computed as theo~eo-.~ metric me~; for colifo~ dete~ined by the membra~e filter procedure the average shall be computed as the arit~.et ic mean. Conmissioner Coimnis'sioner of Enviromuental Conservation Composite S~mp I e A combination of individual samples of water or wastewater taken at selected intervals, generally hour'l.? for some specified period, to min~ize the effect of the vat.lability of individual samples. Individual samples are comb]~md into the composite, in proportion to flow. Depar~ueut The Department of ~vironmental Conse~x.'ation Erflu~nt Grab Sample That segment of the wa~ cewate~ stream i~uuedi, a. tely following the final step in the treatment process but before 'thc wastewater stream is discharged to the receiving environment. A single individual smmpie of wastewater taken at neither set time nor flow. ~ ~oe 8 o-t7 8 PoriuJt No. NPC 78- Influent ~ximLm~ Value Raw Water Receiving Environment Thirty. Day AY eI aoe Was tewater Stre&m Was tewat e r Stream Segment kate rs That segment of the wastewater stream which 1. irap, ediately :follows pretrcatmcnt, or 2. is ~dthin or ~mediatcl_v fo]lowing a s~a'ge or equalization t~k, providing that only raw wastewater or raw wastexater i~imediately after pretreatment enters the tanks, or 5. enters the first step of the treameat process if no pretreatment or equa].J_zatfon facilities exist. ~%e va].ue of any given parameter' 'that is never to be exceeded by any sample. The removal_ of large solid~, fro~., raw ~.,,,,~.~.~"- by coarse filtration, or the shredding of large solids by co~r~tinution. l'acer as it exists in its natural statc at. thc point of taking for domestic use or other puqx)scs. The location at tdxich waste is discharged to 'thc be it lands or waters enviro~nent, . , The average of all samples taken during a thirty consecutive day period. The flow of waste'water from its source(s) th:rough the collection and treah.qent facilities to the point of final discharge to the receiving ent.~ironment. A portion of the wastewater stre~un. Includes lakes, bays, sounds, ponds, 5n.~ounding rc'scrvoirs, springs, creek, estuaries, marshes, in] ets, strai, ts, passages, canals, the Pacific ~ea-n, Gtfl[: of Al.a>~'"~-', , A~cu~.c Ocean, in the territorial ].imi_ts Bering Sea sKI -' ~' of the State, and all other bodies of surface or under-- ground water, natural or artificial, publ:ic or private, ~l~d or coastal, fresh or salt, which arc wholly or partially in or bordcrins the State or under jurisdiction of the State. · . . Pouch Anchorage. AK 99502 Attn: ..... Cranda11 D, ,1ones, ~naga~' - '--~-- - Exploration 0Iq'shore/AK DiviSion" Duck ]:sland Untt #1 ~' ~:' The referenced lease operat!o,n* ts approved sub,lect to the follokrlng stipulations = 1o The well must be abandoned be1°w the sea-' floor bey~d any potentlal depth of Scour and all structures ,(Including the gravel ft11) must be removed :p~p.r_ to !~ 15. 1979 or spr4ng.'breakup, ~htchevar occurs ftrst~.. ':"~ .'-'--' ~. Drt111ng and testtng actjvfties should 'be: completed no later than t4arch::31, - . .... __ : . - - .. 3. Do not conduct any stagt~g actsvtLcS~-~Jn 'the vtctntty durSng the months' of aune through September-l'5. He request thts to avot4 stress to water~owl ~hlCh uttltze thts area for feedtng, r~sttng, molting and/or nesttng purposes' :. 4. The bank(S) ot' tim water~ourSe shall not be altered. ::' ......,.:,?~_~ ....... -6. Matertal sha11 be remove~t only from.unvegetated and exposed (de-watered)' bars of the watercourse to the exlsttngJ,ce or'water levelo - .~-''? 6. Removal shall occur 'tn Sgch a manner that the water tqo~ o~ the watercOUrse .. ,.....-.~ _'. To the gceatest extant p~Sstbla"?emoval: shall occur tn such a manner'i;hat~ be~mso potholes, and/or d. epresstons are not created, '~-:~ '~ :,' .... S. UPon' complot!°n;:~r mater~al removal' or bet~°re ,xpjratJon of tht$ auth°rlzatton the mJntng stte(s) shall be graded smooth wtth all berms and potholes removed. and all'depressions ftlle:d to prevent entrapment ot' ftsh. ~ .. :-~.i~:...~!~:~, ~ aa : ' ' "': -- ' ' · . :~'.-~ . :..,. -- ; ,- . i:..~ . . .- ~ ..... . ....~. :,,:~' ~, ~ Exxon Company LISA danua~ 11, I g78 Page O. £qUtpment sba11 n°t~enter Or'~croSs an actsve (open flowtng) Channel of the 10. 11. 12. Fuel: or intor oti Storage areas shall ret be located on a floodplain or i00 feet of a ~aterbOdy~.. Fuel storage areas should be located where spilled fuel COuld be east!~ contained and retrieved. ReCuellng of equipment should not-o~cur on an active (g~coured-unvegetated) floodplain or wlthtn 100 feet The Hah?tat Protection ~?on, 1300 College Road, FaSrbanks, Alaska 99701 shall be notified tn writing' or b7 phone {452-1531) prior and subsequent, to removal of material' An ~uthortzed representative of thts department nuLy wlsb to vtew the operation to 'ensureprotectton of fish and wtldltfe valueso. The area around and belo~ the t~el storage facilities shall have a dtke surrounding It utth Impermeable membranes beneath Or the fuel storage facilities shall be of double wall construction. · 13.. If the well does not have producttofl capabf1'tty, ue recoenefld the gravel tsland be removed and used fn another pro;leer. ' 14. 15. 16.. 17. Zce/sno~ roads should be 'used when vehlcles travel on the vegetated uplands. . . The extsttng wtnter trails should not be utilized; an 1ce/snow road paralleling tbe wtnter tra11 may be utilized. ' 'In travellt~j fron the ~ell slte to tim ~ater sourc~ the beds~d channels should be used rather than crossing the vegetated uplands. See Exhtbft B for 'a posslble route (out11~ tn red). _ . A completion rePOrt shall' be submitted ~thla 15 days upon termination of permtt acttvttteso Thts report ,shall contatn the following Information: A. Actual routes bf travel and actual location of all camps dtptcted on a 'USGS topo raP* -- All addlttofls I~o orlgtnal application. Statement of cleanup activities. Do Time spent fa each campsite. E. Methods Of dfspo~l of garbage and other camp debris. E ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION R. L. BOANE DISTRICT MANAGERr December 19, 1977 Exxon No. 1 Duck Island Unit Sec. 5, TllN, R17E, UM A.D.L. 47502 North Slope, Alaska Mr. O. K. Gilbreth, Jr. Director, Division of Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Gilbreth: We wish to amend the Permit to Drill or Deepen for the above captioned well by adding the attached diverter installation plan and well control procedures. This information is being forwarded as discussed in a telephone conversation between Mr. Lonnie Smith of the Division of Conservation and Mr. John Glaeser of this office on December 16. Very truly yours, R. L. Boane JLG:jrh A DIVISION OF EXXON CORPORATION DoC~_ T. SL..A~dD Mo. I . FLO~O D~gE~,T6R Ildg"'1'ALLA'TI0t~ VALVe__ f ANNULAR. ~oP 2.0" 20o0P&l W,R 0 T~i> T'At,J.14, ,J LIME- sLOPE ' ,.T~ARG E'F AMD 6L6At~'OL,q"" 3LG Well Control procedures Before setting 13-3/8" Casing - Do Not Shut in Well: 1. Close 20" Hydril. Diverter valves to be open. 2. Direct flow to downwind side of rig. 3. Pump mud or water at high rate as availability permits. After Setting 13 3/8" Casing: 1. Follow Exxon well control procedure. · · Hydril hydraulic regulator should be set at 1500 psi to minimize closing time. After bag is closed, closing pressure should be reduced to minimum required to maintain seal which will permit slight leakage while working the pipe. If well flow cannot be controlled initiate contin- gency plan. JLG:jrh 12-22-77 1 20'x 30' Standby Effluent Pit PLAN _ I"= 200' 20'x 60' Standby Reserve Pit 18 w I B EA UFOR T T. II N. /, VICINITY . 1"=5000' SEA 800' ,9 , SURFACE LOCATION Drilling Rig I _.. 400' ~""'--Approx. 165' High '- Purpose: Drill Site For Exploratory Well Duck Island Unit Exxon No.! Locotion SECTION '~'- '~' -_ VERT. SCALE' I"=lO'" HORIZ. SCALE' i": IO0' EXHIBIT "C" PROPOSED GRAVEL ]SI_AND IN BEAUFORT sEA AT MOUTH OF SAGAVANIRKTOK RIVER. NORTH SLOPE BOROUGH., 'ALASKA. _A.P..P. L~ ! ,C A~T.]O N,, ~.Y y '76o ~ 't v 0 /r_). ?~o ,'T v'!3 E) ON COMPANY, U.S.A. POST OFFICE BOX 2180. HOUSTON, TEXAS 77001 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION CRANDALL D. JONES MANAGER Re: December 2, 1977 Duck Island Unit No. 1 Sec. 5, TllN, R17E, UM A.D.L. 47502 North Slope, Alaska Mr. O. K. Gilbreth, Jr. Director, Division of Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Gilbreth: Exxon Corporation submits the following in regard to the captioned well: (1) State of Alaska Oil and Gas Conservation Committee Permit to Drill, Form 10-401, in triplicate with triplicate copies of the location plat and contingency plan. (2) Exxon Check No. FC16339 dated October 25, 1977 in the amount of $100.00 in payment of the required permit fee. Concurrently with this application, we have also filed with the State Division of Energy and Minerals Management the following: (1) A plan of operations describing the drilling island construction, rig move and resupply, waste and sewage disposal, pollution pre- vention and measures which will be taken to mitigate erosion. (2) Plats showing the routes to mobilize the construction equipment using rubber tired loaders and hauling units and to move the rig over the winter road routes and Beaufort Sea ice as well as possible gravel and water sources. It is our plan to commence location work during February 1978; the drilling rig will probably be moved on location in early December 1978 and operations completed by May 1, 1979. An application was submitted to the U.S. Army Corps of Engineers on September 14, 1977 to conduct this operation in the navigable waters of the Beaufort Sea. OCR:mm Enc lo s ur es xc: EPA Region X w/encl. DMEM - Mr. Joe Green A DIVISION OF EXXON CORPORATION Sincerely, · WELLBORE SCHEMATIC 30" DRIVEN TO ~ 100' PERMAFROST CEMENT TO SURFACE 9-5/8" FO @ 2000' 9-5/8" FO @ 2200' 13-3/8" SURFACE @ 2700' TOC @ APPROX. 7000' 9-5/8" PROTECTIVE @ APPROX. ~ 11,000' CEMENT INTO 9-5/8" 7" PRODUCTION LINER @ APPROX. 12,800' CONTINGENCY PLAN DUCK ISLAND UNIT NO. t The objective of this plan is to outline major operating, and contingency requirements to ensure a safe and efficient operation throughout the drilling activity. The 400 foot diameter gravel island surface area is designed to accommodate the drilling rig, camp, and necessary supplies for a winter drilling operation. The island freeboard of 6-1/2 feet is designed to withstand the maximum anticipated ice forces at the designated location. The elevation of the island surface is above the maximum indicated tide based on observations along the surrounding coast; however, it is planned -to remove all drilling equipment and supplies from the island before breakup. The 1:7 island beach slope design is based on gravel size to provide acceptable erosion charac.- teristics. The location and operating plan is designed to provide containment of all drilling operation effluents that could be considered as pollutants. All drilling cuttings, drilling mud, other effluents, and waste materials will be transported over established winter road routes to upland disposal sites approved by the State of Alaska. An impermeable sheet will be placed under the drilling rig to collect and divert any liquid waste to a ten-foot diameter metal cellar for proper disposal. Fuel will be stored in welded steel tanks located within a~ impermeably lined area. Reserve mud and sewage effluent pits will be utilized for emergency use. Additional precautions will be taken to prevent drainage of hydro- carbons into the sea. The island surface will be sealed with ice by spraying with water before moving the rig on location. The ice 'should prevent liquids spilled on the surface from draining downward into the ~ravel fill. Also, any spills will be cleaned up as soon as possible. Contaminated snow will be incinerated on site or hauled 'to a disposal site on shore. The island surface will be thoroughly cleaned after clearing the island of all drilling equipment. The selected drilling contractor will be required to develop a comprehensive SPCC plan to prevent' po!lutio~ as a result of any drilling rig operation. In addition to the impermeable sheet under the rig mats, drip pans or other containment measures will be provided under the engines and rig machinery. Good housekeepin~ will be stressed on all parts of the location with emphasis on minimizing contamination of the peripheral drainage from the island. Any minor oil spil].s will be collected using sorbent material for disposal in the incinerator. Personnel safety, protection of environment and well control are the uppermost factors in well design and operational planning. Sufficient data are available to plan the well for evaluation of the geologic objectives and conduct a safe drilling operation. Although this well is planned to penetrate normal formation pressure zones, advanced abnormal pressure technology will be used to detect changes in formation pressure to permit ad. j usting the casing and drilling fluid program as required to control the well. Emphasis will be placed on well control equipment and procedures to permJ.t circulating out a formation "kick" in an orderly manner if it should be necessary; any hydrocarbons in the influx will be diverted to the flare pit and disposed of at an approved upland site. In the event .. of an unplanned upset resulting in uncontrolled well flow, the fol- lowing basic procedures will be followed: 1. Divert well flow to the flare pit as the first defense against a spill. When the safe working level of the flare pit is reached, switch the flow to a containment area on the ice constructed with snow and ice retaining walls. After the well is under control, produced we].]. fluids will be transported to an approved onshore area for disposal. The contaminated ice and snow will be cleaned up and burned. 2. Prepare plans for drilling a relief well from an alternate location. The well will be ignited, if the situation warrants, only after approval from the proper governmental agencies. A Catastrophe Organization consisting of specifically designated personnel ~ill be activated to cope with an emergency such as an out- of-control drilling well. The Drilling Section of the Catastrophe Organization is responsible for performing the well control function which includes all surface well control procedures as well as plans for a relief well. Immediate action will be taken to minimize en- vironmental damage and institute cleanup operations. The basic relief well plan involves construction of another gravel island approximately S,000 feet northwest of the original we]_l's surface location. The most likely time for a severe well control problem to develop would be ].ate February, which would allow sufficient time to construct the gravel island and spud the relief well before breakup; the rig could be resupplied by barge after breakup. The planned relief well location would permit the relief wellbore to penetrate zhe £iowing zone near the out-of-control well with a 3,000 foot horizontal displacement. In the event insufficient time is available to f_nitiate the gravel island relief well, a barge rig operation could be mobilized after breakup to drill a relief well. Both relief well plans are predicated on emergency approval of ail phases of the operation by all state and federal regulatory agencies. RMIt ' k c 10/]_8/77 -2- E: ON COMPANY, U.S.A. POST OFFICE BOX 2180 ° HOUSTON. TEXAS 77001 EXPLORATION DEPARTMENT OFFSHORE/ALASKA DIVISION CRANDALL D JONES MANAGER Re- December 2, 1 977 Duck Island Unit No. 1 Sec. 5, TllN, R'17E, UM A.D.L. 47502 North Slope, Alaska Mr. Joseph Green Director, Division of Minerals and Energy Management Department of Natural Resources State of Alaska 323 East 4th Avenue Anchorage, Alaska 99501 Dear Mr. Green- Exxon Corporation filed an ap'plication with the State Division of Conservation for a permit to drill the subject well together with our check in the amount of $100.00 in payment of the required permit fee. Additionally, and in accordance with the requirements of the subject oil and ..gas lease and applicable regulations, we submit the following' (1) A plan of operations describing the drilling island con- struction, rig move and resupply, potable water supply, waste and sewage disposal, pollution prevention and . measures which will be taken to mitigate erosion. (2) Plats showing the routes to mobilize the construction equipment using rubber tired loaders and hauling units and to move the rig over the winter road routes and Beaufort Sea ice as well as possible gravel and water sources. Exhibit A - Location Plat, Exxon No. 1 Duck Island Unit Exhibit B Area map showing gravel sources and haul roads Exhibit C- Gravel island layout · Exhibit D - Gravel source locations & DIVISION CF EXXON CORPORATION Mr. Green -2- October 26, 1977 As stated herein, it is our plan, State approval permitting, to commence location work during February 1978; actual drilling operations are to be commenced during December 1978 and conclude and rig removed by May l, 1979 prior to breakup. OCR:lj Enclosures Si ncerely, cc:. EPA Region X PLAN OF OPERATIONS Duck Island Unit NO. 1 This plan covers the preparation of a location and other operations related to the drilling of an exploratory well to be designated as Duck Island Unit, Exxon No. 1. This well will be drilled direction- ally from a gravel island to be constructed in approximately three feet of water offshore from the Sagavanirktok-River Delta east of Prudhoe Bay, Alaska. If oil and gas are discovered in commercial quantities, the island may also be enlarged and used for the subse- quent installation of production facilities. The surface location for this well will be 800'WEL and 700'NSL, Section 8, TllN, R17E. The approximate bottom hole location of the well will be 800'WEL and 500'NSL, Section 5, TllN, R17E. Natural Environment The proposed drilling' island will be located approximately 2200 feet seaward from the coastline of the Beaufort Sea as shown on Exhibit "A". Nearshore waters within a one mile radius of the location range upward to 11 feet in depth. ~'~¥-'~ · The southern Beaufort Sea has a slow westward circulatiOn with near- shore currents stronger and more variable. Sea ice, which forms in September or October and breaks up in June or July, freezes to the sea bottom within the ~ix foot depth contour in this area. The onshore terrain in the vicinity of the drill Site is a low lying coastal plain with mud flats and scattered small lakes. Surface vegetation, where present, is typical tundra type with mosses, lichens, grasses, and sedges being most dominant. Removal or damage to the ground cover, particularly in areas of any appreciable slope, is a major factor in causing erosion. Consequently, every possibl.e effort will be made to preserve the ground cover and protect the surface from unnecessary damage. There are no established roads, airstrips, housing, or other facilities in the area. Heavy vehicular traffic can operate only during the winter season while the ground, streams, and lakes are frozen because of the fragile nature of the terrain. Prudhoe-D~adhorse, located approximately 15 miles west of the location, is the nearest staging area and airstrip with facilities for handling cargo and housing personnel. Construct ion and Operating Plan Construction of the drilling island is planned during February through April 1978, consistent wigh State approval, after freeze-up is suff-i- cient to facilitate movement of heavy equipment. Construction equipment will be moved in from Prudhoe Bay over an existing winter trail and along the Sag River Delta to the shoreline near the location site as shown by Exhibit "B". I~uring construction, it is anticipated that a temporary self-contained camp will'be provided at the island con- struction site. The sequence of location preparation should be as follows' Move in construction equipment to establish a road route from Prudhoe Bay to the shoreline near the location utilizing existing winter trails where possible. Establish a road from existing winter trails to sources of gravel. This road will be routed over river ice and unvegetated river bars where feasible. Ice roads will be constructed wherever natural vegetation is crossed. Activate the temporary construction camp to be located at the location. Move in bulldozers, loaders, hauling units, and other equipment re'quired for mining gravel and construction of the drilling island. ®' Prepare ice road from the shoreline to the island site. · Remove existing ice at the location. Stockpile gravel as necessary using bulldozers. Load and haul the gravel to the locat'ion over the prepared road routes, as shown on Exhibit "B", using rubber tired loaders and hauling units. Water trucks will be utilized during construction to maintain haul roads. Approximately 65 men will be required to staff an operation of this magnitude on a 24-hour basis. The drilling island will be constructed at a water depth of approxi- mately three feet as shown by Exhibit "C" It will be circular in shape with a diameter of 400 feet at the top and 1:7 slope on the perimeter. This island will be constructed to an elevation of 6'6" above MLW and will require approximately 61,000 cubic yards of com- pacted native gravel. Existing ice will be removed to the bottom prior to placement of the gravel. Gravel will be obtained from the bars along 'a non-active channel of the Sagavanirktok River as shown on Exhibit "D". The gravel removal and hauling will be accomplished using rubber tired loaders and hauling units over the road from the mining area to the location. Only the exposed gravel deposits above the water line will be removed to ensure that no holes remain at the borrow area 'which could cause fish or animal entrapment' after spring flooding. -2- The proposed gravel sources f6r the island construction are identified as sites 1, 2, 4, and 5 in the detail portion of Exhibit "D". These sites are located in Sections 28 and 33, T10N, R16E, UM. Final selection of the material will be based'on analysis of gravel samples obtained from each of the sites to provide the most suitable island slope design. The proposed layout of the drill site, as shown on Exhibit "C", is planned for The accommodation of the drilling rig, camp, and necessary support facilities. Wooden matting will be u~ed under the drilling rig and mud pumps for stability. An impermeable sheet will be placed under the drilling rig to collect and divert any liquid wastes into a ten foot diameter metal cellar for proper disposal. Approximately 50,000 gallons of fuel storage capacity will be provided using welded steel tanks.located 'within an impermeably lined area capable of re- taining 115 percent of the fuel storage volume. The reserve and effluent pits shown on Exhibit "C" will be utilized for emergency use only. Ail drilling cuttings, drilling mud, other effluents, and waste materials will be transported over the established winter road routes, shown by Exhibit "B", to the mainland for disposal at sites approved by the State. of Alaska. The final selection of the rig for the' proposed location has not been made. The rig selected will be moved to the location over the winter road, shown by Exhibit "B", as early as possible in December 1978. It is planned that the well will be spudded in late December 1978 and that drilling and evaluation operations will be completed in time to permit removal of the rig from the islsnd by May 1, 1979. Major supplies of mud, cement, casing, fuel, and miscellaneous supplies will be hauled to the location over the winter.road routes. A sea ice road will probably be used to transport supplies later in the winter. Camp Facilities A camp for rig personnel will be located on the gravel island during drilling operations. Water supply and the disposal of sewage, garbage, and trash for this facility will be provided as follows. 1. Water Supply Potable water for the camp facilities will be hauled from lakes located in the south half of Sections 33 and 34, TllN, R16E. A snow melter will be used as necessary to supplement the rig water requirement. The water will be processed through a water treating unit, which meets State of Alaska Department'of Conservation requirements, before use in the camp. Gray water discharged from the camp will be used for mud and rig wash water. -~ -3- 2. Sewage Disposal Sewage and gray water discharged from the camp will be collected separately and the sewage will be processed through a waste disposal unit which complies with State of Alaska requirements. Effluent from the sewage treating unit will be discharged to a heated tank for temporary storage and subsequently' hauled in vacuum trucks to a site onshore approved by the State of Alaska for final disposal. 20' x 30' x 4' holding pit is planned. To allow temporary diversion of the waste disposal unit discharge in the event of a treating plant upset. 3. Garbage and Waste Disposal Burnable garbage and wastes will be disposed Of in a trash incinerator unit on the drilling island. ~ome of the more readily combustible products, such as paper, wood, and cardboard, may also be open burned on the island. Non- combustible wastes, such as scrap metal, tires, batteries, and drums, ~ill be hauled to Deadhorse and final disposal will be in accordance with State Waste Management requirements. Development Plans The gravel island is favorably located for development of potential reservoirs, based on current structural interpretation, and can be enlarged to provide a multi-well pad. Slope protection and other de- sign considerations will be inCorporated into development planning. If oil is discovered in sufficient quantities to warrant future development, the Prudhoe Bay to Valdez oil pipeline will be the probable Marketing outlet from the area. oil and casinghead gas would be pro- cessed, through central oil gathering facilities with oil being pipe- lined to the Alyeska line passing approximately 20 miles to the west. If commercial quantities of gas are discovered, development of a gas market outlet will be related to studies to market gas from the Prudhoe area. Surface Protection and ReStoration Plan As previously mentioned, precautions will be taken to protect the surface by not beginning operations until after ~reeze-up and by using existing roads and winter trails where possible. Upon completion of construction of the gravel island, the gravel mining area will be graded to remove all berms and potholes. At the completion of the well, the location and adjoining area will be cleared of all waste materials. All pits will be backfilled and · leveled in accordance with governmental regulations~ ..... -4- Special procedures for drilling and subsurface equipment are required. by the unique characteristics .of the. permafrost area. Casing cement used through the permafrost zones is of special composition to reduce possibility of freezing and other casing problems. Casing is run and cemented through the permafrost, and in the event of production or interruption of operation, the casing must be protected by non-freezing fluid. RMH/AVL :kc 10,/18/77 -5- COMPANY. U.S:A. POST OFFICE BOX 2180- HOUSTON, TEXAS 77001 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION August 28, 1978 Re' Duck Island Unit North Slope, Alaska Mr. W. M. Selvidge Houston As telephoned to you August 25 the APPROVAL - CERTIFICATION - DETERMINATION executed August 21, 1978 by Frederick H. Boness, Deputy Commissioner of Natural Resources was delivered to us prior to the closing of that business day. The three executed copies of the Certification are enclosed along with the Division of Minerals and Energy Management letter of transmittal. You will note that the approval certification and determination is.made expressly subject to the condition that a unit operating agreement be filed with the Division of Minerals and Energy Management within 90 days from the effective date of the unit agreement, i.e. August 21, 1978. Ro' - bert ~: '~. Rzddle RKR'et attachments cc' Mr. Robert Anderson w/attach. Union Oil Co. of California P. O. Box 6247, 909 ~Vest Ninth Avenue, Anchorage, Alaska 99502 Mr. James Saviers w/attach. Amoco Production Co. P. O. Box 779, 425 G Street - 3rd Floor, Anchorage, Alaska 99510 A DIVISION OF E×XO,'~ CO~[PORATION 'MINERALS AND ENERGY MANAGEMENT August 24, 1978 Re: Duck Island Unit Agreement Exxon Company, U.S.Ao P.O. Box 2180 Houston; Texas 77001 Attn: W. J. Whaley Gentlemen: The subject unit agreement was approved August 21, 1978, with the condition that an appropriate uni~ operating agreement would be filed within 90 days. Enclosed are several approval pages for your files. Sincerely, Ethel H. Nelson Acting Leasing Manager cc: Exxon Company, U.S.A. (Anchorage) / t' r-~T~- r-r- ~ ~*, .~,:~-~qOVAL - C,:kT!FiCATION -- Ur'FE_F~.Mi!~/~,TION Pursuant to ~':'~ authority vested in ~.n~ Cor,..,~issioner of the D~par~m~nt of N~tural R~.,ources of the State of Alaska under -l-ill~ 38 .~. of the Alaska Statutes, as am~n~d, and the Al , ,Jn~r asKa Oil and Gas [easing Regulations pursuant thereto, I do hereby' (a) Approve the attached Unit Agreement for the Developme~t and Operation of t~3e Duck Island Unit Area, State of Alaska. (b) Certify and determine that the unit plan of develo;]ment and .......... ~'~ is necesssary and operation, contemplated in ~ne a~ched ag, e~,n~nt, advisable in the public inte r~s~ for the purpose of more properly conserving nauural resources. (c) Certify and d e~rmine that the drillinm pro~ucinm rental minimum royalty and royalty requirements of all State of Alaska leases committed to said a§reement are hereby established, altered, changed, or revoked to conform with the terms and conditions of this agreement. Provided, however, this approval, certification and determination is made expressly subject to the condition that, regardless of any provision of the Unit Agreement, the ?arties to said Unit Agreement shall enter into an aDpropriafe Unit O,)~a,~ing Agreement for said uni~ area, and if such Unit Operating Agreement shall not have been filed with the office of the Division of Minerals and Energy Anchorage, Alaska, within 90 days from the effective date of this. Onit Agreement, this approval, certification and determination and Unit Agreement shall become null and void as of its original dat'e. Time is of the essence for this a?proval. Deparu:~ent of Hatural Resources , 1978. SUBMIT IN (Other instru~tio-~, on S;ATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE' PERMIT TO DRILL OR DEEPEN DRILL [] DEEPEN [-] b, ?~r~ or W~:LL 50-029-20280 [~SE DI~iilGNA'rlON A.N'D ~ NO. ADL 47502 7. IF INDIAN. AJ, J.,OTTEE OR T~i~3E NA.M~ 8. UNIT, FARM OR LEASE NA.ME DUC_K Island Unit 9, WELL NO. . No. 1 10. FIELD AND POOL. Ot{ WILDCAT Wildcat Z NAME OF ()P~JLATOR 5xxon Corporation 2. ADDRIkSS (DF OP'LtCATOR P. O. Box 2180, Houston, Texas 77001 4. LOCATION OF WELL At surface 700' NSL and 800' WEL of Sec. 8, TllN, R17E,'UM At proposed prod. zone 500' NSL and 800' WEL of Sec. 5, TllN, R17E, UM 13. IDISTANCE IN MILES AND DiRECTiON FROM NEAREST TOWN OR POST OFFICE* 12. 15 miles northeast of Deadhorse il. SEC.. T.. R.. M.. tBO"lq'o.%l HOLE OBJECTIVE) -Sec. 5, IllN, R17E 14. BOND INFOkMA'I'ION Oil & Gas Conservation Bond 5134049 'State Bond B-l-4 TYPE St, retv and'or No t 16. NO. OF ACR~--k% IN LEASE l& DISTANCE f'H.C.M PROPOSED LOCA~ON' 1N. PROPOSD D~ 12,800' 15. DISTANCE F!kO?,I PROPuSED* LOCATION TO NE.xREST PROPERTY OR lEASE LINE. FT. . . IAL;o to nea~¢'-~t drip: unit, ff a~y) TO NEARESI' WELL DEiLLING, COMPLETe, OR APPLIED FOR. ~r. 2 m~. N of lwoco-Fo99y Is. Bay St.-] 21. ELEVATIONS ¢Shc~ whethcr DF. RT. CH. etc.} 3 ft. ~ater depth at surface location ,~o=t ILIO0,000 , _~ TO 'l'FiiS WELL 20. ROTARY OP. CABLE TOOLS Re ta ry 99. APPROX. DATE WORK WILL STAH'I" February l, 1978 PROPOSED CASING AND CEMENTING PEOGRAaM IZE OF HOLE SIZE OF CASING WEIGHT PIER FOOT G~ADE SL"'i'TING DEPTH quantify of cement - 3~" 310' 13 :t:1 O0 Driven ~onductor ..... ]7-,1/2.' 13-318" .72 N-80 2700 1o Surface 17-1/4" q-fi/R" . 43.5 i.Soo-95 llO.O.O ,Approx. TOC @ 7000' ,8-1~/2" ...... ¢" 29 iSoo.--95 1,0~.500-12~800 .,To top of liner ,, ...... 9-5/8" casing designed for production and 7" liner will be set to test .well. Blowout Preventers' A 20" annular blowout preventer with a diverter line will. be installed on the 30" conductor w[~ile drilling the ]7-1/2" hole A 13-5/8" '5,000 psi WP BOP stack consisting of an annular BOP-and. three 'ram type preventers~ will. be~ instal'l'ed on the'13-3/8" and. 9-5/8" casing. BOP installation and testing will be in accordance with Exxon standards which require pressure testing on.initial installation; when' any component .is changed, and at least once weekly thereafter; All BOP's Will..be.~fuuction tested each trip. Drilling proficiency tests of well' shut-in procedures will ~e conducted at' least once each week with each crew. o . l~r ABOV]~ SPACE DI~-qC"PJBE PROPOSI~D PR~R.~: If ~l Is to dee~n 'give ~ on present p~u~ive zone ~d pro~ new pro'~lPF zone. fit. p~,$ts ~ drill, or a~n d~ec~ionaliy, give p~r%tnen~ ~' on sdbsu~'a~ ~t~ ~d meas~d ~d ~ue ~,~.~~,~6~~~~/ UA~ October 26, 1977 Of~sho~e/Alask ~a~age~ ~ , ,,,, , ............ ,- , , , space for ,~&~te oC~:.~ ~<, // CONDITIONS OF APPROVAL, IF ANY: -./ ' DI~E~IONAL SURVEY E~L'~ A.P.L N~C~ COD~ ~ 7<.i'-}-~ ; August 31, 1978 P~M~ N~ ~OV~ DA~ CONTINGENCY PLAN DUCK ISLAND UNIT NO. 1 The objective of this pi. an is to outline major operating and contingency requirements to ensure a safe and efficient operation throughout the drilling activity. The 400 foot diameter gravel island surface area is designed 'to accommodate the drilling rig, camp, and necessary supplies for a winter drilling operation. The island freeboard of 6-1/2 feet is designed to withstand the maximum anticipated ice forces at the designated location. The elevation of the island surface is; above the maximum indicated tide based on observations a!on~f, the surrounding coast; however, it is planned to remove all drilling equipment and supplies from the island before breakup. The 1:7 island beach slope design is based on gravel size to provide acceptable erosion charac- teristics. The location and operating plan is designed to provide containment of all drilling operation effluents that could be considered as pollu~tanZs. Ali. drilling cuttings, drilling mud, other effluents, and waste materials will be transported over established winter road routes to upland disposal sites approved by the State of Alaska. impermeable sheet will be placed under the drilling rig to and diverZ any liquid waste to a ten-foot diameter metal cellar for proper disposal. Fuel will be stored in welded steel tanks located within an impermeably lined area. Reserve mud and sewage effluent pits will be utilized for emergency use. Additional precautions will be -taken to prevent drainage o£ hydro-- carbons into the sea. The island surface will be sea]ed with ice by spraying with water before moving the rig on location. The ice should prevent liquids spilled on the surface from drainin~ downward into the gravel fill. Also, any spills will be cleaned up as soon as possible. Contaminated snow will be incinerated on site or hauled to a disposal site on shore. The island surface will be thoroughly cleaned after clearing the island of all drillin~ equipment. The selected drilling contractor will be required to deve]_op a comprehensive SPCC plan to prevent pollution as a result of any drilling rig' operation. In addition to the impermeable sheet uniter the rig mats, drip pans or other containment measures will bo provided under.~ the engines and rig machinery. Good housekeeping will be stressed on all parts of the location with emphasis on minimizin~ contami~ation of the peripheral drainage from the island. Any minor oil spil].s will be collected using sorbent material for dispo,'sal in tho incinerator. Personnel safety, protection of environment and well control are the uppermost fact~ors in well design and operational planning. Sufficient data are available to plan the well for evaluation of the geologic objectives and conduct a safe 'drilling operation. Although this well is planned to penetrate normal formation pressure zones, advanced abnormal pressure technology will be used to detect changes in formation pressure to permit adjusting the casing and drilling fluid program as required to control the well. Emphasis will be placed on well control equipment and procedures to permit circulating out a formation "kick" in an orderly manner if it should be necessary; any hydrocarbons in the influx will be diverted to the flare pit and disposed of at an approved upland site. In the event of an unplammed upset resulting in uncontrolled well flow, the fol- lowing basic procedures will be followed: 1. Divert well flow to the flare pit as the first defense against a spill. When the safe working' level of the flare pit is reached, switch -the flow to a containment area on the ice constructed with snow and ice retaining walls. After 'the well is under control, produced fluids will be transported to an approved onshore area for disposal. The contaminated ice and snow will be cleaned up and burned. 2. Prepare plans for drilling a relJ. ef well from an alternate location. The well will be ignited, if the situation warrants, only after approval from the proper governmental agencies. A Catastrophe Organization consisting of specifically designated personnel ~ill be activated to cope with an emergency such as an out-- of-control drilli~g well. The Drilling Section of the Catastrophe Organization is responsible for performing the well control function which includes all surface well control procedures as we].], as plans for a relief well. I~mnediate action will be taken to minimize en- vironmental damage and institute cleanup operations. The basic relief well plan involves construction of another gravel island approximately 3,000 feet northwest of the orig'inal well's surface location. The most likely time for a severe well control problem to develop would be late February, which would ali. ow sufficient time to construct the gravel island and spud the relief well before breakup; the rig could be resupplied by barge after breakup. The planned relief well location would permit the relief wellbore to penetrate the flowing zone near the out-of-control we_Il w~th a 3~000 foot horizontal displacement. In the event insufficient time is available to initiate the gravel island relief well, a barge r.i~' operation could be mobilized after breakup to drill a relief well. Both relief well plans are predicated on emergency approval of all phases of the operation by all state and federal, regulatory agencies. RMH :kc lO/lS/ --2-- WELLBORE SCHEMATIC 30" DRIVEN TO _+ 100' PERMAFROST CEMENT TO SURFACE 9-5/8" FO @ 2000' 9-5/8" FO @ 2200' 13-3/8" SURFACE @'2700' TOC @ APPROX. 7000' 9-5/8" PROTECTIVE @ APPROX. :~ ll,O00' CEMENT INTO 9-5/8" 7" PRODUCTION LINER @ APPROX. 12,800' OIL SPILL CONTINGENCY PLAN For GEORGE FERRIS EXPLORATORY DRILL BARGE 'At PHILLIPS PETROLEUM COMPANY' S T~N 'A' No. 1 LOCATION COOK INLET, ALASKA OIL SPILL CONTINGENCY PLAN SPCC Plant Attachment #6 Phillips Petroleum Company George F. Ferris Exploratory Drill Barge TABLE OF CONTENTS Introduction . ......... DeFinition of an Oil' Spill ........ 2 Requirements & Responsibilities for Reporting Oil Spills . 2 Notification of Government Agencies ...... 2 Control, Containment~ Cleanup& Disposal Procedures . · 3 Training Program ........... ~ Governmental & Public Relations ....... g Page No. APPENDIX I. PhilliPs Oil Spill Report Form II. Spill Behavior Report III. Containment & Cleanup Equipment Available " A. Onboard the Ferris B. Onboard the Norma Ann C. Cook Inlet Oil Spill Coop D. Coop Members Eo Commercial Sources IV. Training Workbooks~ Cassettes & Slides V. Phillips Oil Spill Committee Organization Chart INTRODUCTION An ounce of prevention is worth more than a pound of cure. Prevention of oil Spills is the ultimate answer to everyone's concerns about 'the environment. At the exploratory well site~ the barge and the drilling rig will be operated in a manner that will prevent the accidental discharge of fuel, lubricating, or crude oil. The operator of the George F. Ferris has also prepared a Spill Prevention Control and Countermeasure Plan for the barge in compliance with requirements of the Environmental Protection Agency. (See Attachment #8 to Phillips SPCC Plan). The barge operator has also prepared a fuel transfer plan to satisf~ the requirements of the U. S. Coast Guard. Phillips Petroleum Company will require the d~illing contractor to adhere to the SPCC Plans and also to follow all applicable regulations pertaining to drilling established by the Alaska Department of Natural Resources and all regulations established for this operation by other Alaska State agencies and by all Federal agencies having jurisdiction over the operation. The purpose of this Contingency Plan is to provide guidelines for an effective and coordinated response to any oil spill that might occur at this operation. This plan defines responsibilities and provides a gemaral plan of action for responding to an oil spill. Main elements of the plan are as follows: A. A list of agencies to be notified if a spill occurs. B. A list of Company and contract personnel who will respond to a spill and a description of their duties. C. A predictive document which describes and predicts the most likely path of a spill under different conditions of wind and current. D. The location of approved onshore disposal sites. E. A description of the emergency containment and pickup equipment on board the barge and procedures for prompt and effective use of this ~quipment. F. A list of all available oil spill containment and cleanup equipment in the area. G. Procedures that will be followed to train key personnel in oil spill containment~ and cleanup techniques. This plan is designed to supplement the SPCC and fuel transfer plans. This plan will be modified and supplemented as necessary to keep it up to date with changes in technology~ in personnel~ and in inventories of equipment. -1- Oil Spil! Definition An oil spill is any discharge of oil into the waters of the United StaLes! Re ortin 1. Requirements Ail oil spills must be immediately reported to the U. S. CoasL Guard. Several State agencies must be notified immediately following the USCG report. Failure to report can result in personal fine and imprisonment. 2. Responsibility It is the responsibility of all persons on board the Ferris and the Norma Ann, to be on-the alert for oil spills. Any person~ who is aware of an oil spill, shall inform the Phillips on-site supervisor or the Contractor on-site supervisor, depending on which can be reached first. The Phillips on-site supervisor or the Contractor on-site supervisor will initiate action to stop or minimize the spill and ~modiately noti~k the Federal and State agencies and the Phillips office. These verbal reports shall fo~low the format contained in Phillips Oil Spill Report (Appendix I). The verbal report must be confirmed in writing within three days following the incident. This confirmation should be sent via "Registered Mail". Reporting U. S. Coast Guard Call Anchorage 265-5571 between 0800 & 1630' hours, Monday - I~iday. Call Anchorage 272-8812 after hours~ weekends & holidays. This is FAA Duty Officer and will relay your report on to USCG. Call Juneau ~86-73~0 if no contact established above within 5 minutes. Ala. sk, a .,D..epartment of Environmental Conservation Call Anchorage 27g-5~27 during office homrs. Call Anchorage 658-2~88 after hours (Mr. Kyle Cherry). Call Juneau 586-6721 if no contact established above. Alaska Division of Oil & Gas (If a blowout occurs) ~all Anchorage 279-1933 during office hours Call Anchorage 279-~705 after hours (Mr. T. R. Marshall) or Call Anchorage 555-8000 after hours (Mr. O. K. Gilbreth) Phillips Petroleum Company CalI Ke~a~ ~76-'8166~ ~ hours every day. On duty personnel will alert Phillips Oil Spill Co~nittee Members. -2- Cont. r. ql.., Containment~ Cleanup & Disposal Procedures The Phillips on-site supervisor will take charge of the control, containment, cleanup and disposal operation. The Contractor on-site supervisor will assume this charge if the Phillips on-site supervisor is absent and will act in 'this capacity until a Phillips representative arrives. Rapid response in the spill incident is necessary to min~-nize -the enviroD3~ental impact. This response capability is provided by having trained personnel and experience proven containment and cleanup equipment and materials onboard Ferris to contain and clean up credible spill volumes. The six man barge crew wi~ ~orm the trained nucleus 'of the 'Ferris' Oil Spill Task Force. The con- tainment and clean up activities of the Task Force will be directed by the Phillips 'or Contractor on-site supervisor. The Phillips Oil Spill Committee Chairman~ Mr. H. J. Stein. er, upon receiving notice of a spill, will activate the Committee (Appendix V) if assistance is required. If the USCG's National Response Team is activated, Mr. Steiner will be the Industry Representative on that team. . Control~ containment, cleanup and disposal actions Will depend on the situation existing at the time of the incident. The on-site supervisor must assess the situation and specify a prudent course of action to be 'taken. Some general pro- cedures that can be followed are as follows: Co.n.t, r01~ Prqce~dures~ to stop or reduce further spillage. 1. Close block valves. Shut down transfer pumps. ~rain lines to storage containers. Catch drips in buckets, etc. 5. Close blowout preventors. Containment & Cleanup Procedures 1. Activate Ferris Oil Spill Task Force. 2. Deploy the sorbent boom or the "Aqua-Fence" boom to enc~mcle the spill using the onboard power skiff and/or the MV Norma Ann. 5. After containing the spitl~ proceed to pick up the oil with sorbent pads or the Komara skimmer coupled to the Kepner storage bladder. g. If assessment indicates assistance will be required, mobilize the Cook Inlet Oil Spill' Cooperative via the Phillips Oil Spill Committee. - 5. Predict the probable course of the spill by reviewing the '~pill Behavior Report" (Appendix II). 6. Direct the deployment of the Coop's Vikoma Sea Pak boom to augment the Aqua fence boom containment or diversionary capability. 7. Utilize the Coop's ~ark II Skin, her to pick up oil contaC]ed by the deployed booms. 8. Utilize sorbent materials to pick up small isolated patches of oil 'on the water and/or beaches. 9. Do not use any sinking, collecting, dispersing, or wicki~g a~ents unless directed by the Federal or State On-Scene Coordinator. ~Disposal Proc edures 1. Crude or diesel oil recovered during cleanup operations will be offered to the refineries located at Nikiski. Their agreement to ~accept recovered oil has been solicited. This is thc preferred disposal method because it conserves an energy resource. However, if salvaged oil cannot be disposed of in this manner~ it will be stored at the Phillips It~G Plant until such time as an Alaska Department of Environmental Conservation (ADEC) approved land dis- posal site is developed by the Kenai Peninsula Borough. 2. Oily solid wastes reCovered during cleanup will be stored in suitable containers at the Phillips LNG Plant until it can be disposed of at an approved land site on the Nenai Peninsula. Training ..P~.ogr am Ail barge and drilling personnel on the Ferris and the crew of the workboat, Norma Ann~~' will be given training stressing' prevention and control measures the requirements for reporting oil spills. The training material in the Section 1 workbook "Oil Spill Prevention" (Appendix IV) provides a learning technique for imparting~his information to these crews. Ail barge and ship crews will be given additional training in prevention and control measures utilizing the Section 3 "Shipboard Oil Spill Prevention" slide and lecture series (Appendix IV). Ail barge and ship crews will receive training in containment and cleanup procedures through the presentation of Section 2 workbook "Inland Water Clea~up Procedure" (Appendix IV). After completion of this phase of the~ training, they will receive separate instruction in the use and deployment of the contai~ent and cleanup equipment and materials onboard their respectiVe facility. Drills will be conducted in the deployment and use of the onboard equipment to attain and maintain a' fast~ ef. fective response capability to credible spills. Selected Phillips and Contractor personnel will also attend the '76 sea trials of the Cook Inlet Oil Spill Coop's equipment to receive instruction in its de~ ployment and use. Key drilling personnel have already been trained in blowout prevention and control procedures. During the weekly BOP equipment tests~ all drilling personnel will be assigned a work station and instructed in the basic actions required of them to retain control of the well. Following the initial training session with each drilling crew~ weekly drills will be conducted prior to the BOP equipment tests. Public and Government Relations If a spill occurs~ the Phillips on-site Superintenden~t will act as Company spokesman until such time as this duty is assumed by Mr. H. J. Steiner~ Area Superintendents. or his designated agent. Other Phillips and Contract perso~mel should refer all inquiries to the Company spokesman for an answer to thei~ questions. The Company spokesman has the responsibility for issuing all press statements. The guidelines set forth below should be followed. Initial press statements should: 1. Give the name of the installation involved, the time of the accident, and ar4v other facts that are not in dispute (such as the steps the Company has taken to contain, control, or handle the spill). 2. State explicitly that it is t.he Compar4v's policy to prevent pollution ~mad to minimize damage to property or the ecology. As the following information becomes available, press statements should: 1. Not'e that containment and cleanup experts are (on) (being called the scene to supervise the operation. 2. Give the type of product spilled. 3. Report whether the spill has been controlled. Give the size of the spill- quantity and area affected. 5. Tell how spill is moving, such as wind, current, and tides. 6. Describe cleanup measures that have been taken and planned - types and quantities of equipment being used and manpower involved. 7. Describe special efforts taken to protect property and wildlife. No statements shall be made containing any of the following unless cleared by Public Relations Department in Bartlesville, Oklahoma. 1. Speculations concerning liability for the spill or its legal consequences. 2. Speculations regarding the cause of the spill.. An extended inquiry may be needed to determine the actual cause, and legal liability could be affected by what is said. 3. Estimates of damage expressed in dollars. Estimates of how long cleanup will take or of cleanup costs. · 5. Promises that property, ecology, or anything else will be restored to normal. 6. Opinions concerning the appropriateness of government response to the oil spill. PHILLIPS PETROL~M COMPANY OIL SPILL REPORT Date/Time Report Made ~me of Person Reported to (USCG) ( PA) Reported By (Signature) (FAA),_ ( AS~ ~ Time Spill St~%ed or Sighted Ended Location of Spill ........................... ......... . .... What Spilled Description of Slick Wind Direct ion Velocity Tide EBB FLOOD SEAS ~' · Visibility Miles Snow Rain Clear Apparent Hazard to Life or Property Damage Done i ,~ · ~l ! ; ~ ~ J,, i Personnel, Injured W~y Spill Occurred · Action Already Taken to Stop and/or Clean Up Spill Future Action Plans Operator :: _ .............. _ ~ ~ _ ~llow %his format in Pepox~ing oil' spills %o Governmental agencies. Submit compleLed £orm %0 office wi%bin 2~ hours for transmittal of writ%eh report Lo same agencies. OIL SPILL CONTINGENCY PLAN Oil Spill Behavior Report For Phillips Petroleum Company Tern 'A' No. 1 Cook Inlet~ Alaska ,OIL SPZLL BEHAVIOR REPORT ~ or PHII,I,IPS P~OLEUM COi~ Tt~N 'A' No. 1 A Summary Prediction o.f Spilled Oil Distribution In Cook Inlet, Alaska Many factors must be considered in predicting the rate of sprend and the an oil spill on water will take. Five of 'l;he more imporLan'L f'acLors ar,~ velocity~ w~d direction, wave activity, w~ter current v'eloc:LLy am~ waLnr dJmection. Wind is usually the controlling factor and the drLft rate spill can be est~ated to be about 5./~ of the wind w:~locif, y. Wm~s by the w~d c~ ~crease the speed of a spill to a velocfl, y ~ppro>::]~aLe]v '~ '~'~ , . ,, ., · .. ~/'~) of the w~d velocity (1). ~ the absence o~ w~d, oi~ on 'bh~ surf'ac~ will move at the velocity of the current. When the wind and ~.~.iud driven waw~s ~e gong the s~e d~ection ss the curr~no, be the summation, of the current veloci{,y and 5[~ of the wir~,t w~loeit,y. when these~ forces are directly opposins each oLher, the oil s[,i].] ~,:.loc.Lkv ~.~[']'1 be the difference between the current velocity and,,~,~. of f, ho w]~[ 'vnl~'~,~ ~I,,,. W~,~ ~ "~"~ forces ~e at ~ angle to each other, vector analysis w:L]]. 3~rov'.~]e an of the speed and course of an oil spill on water 2attl.la[,:~ ., :: s, , of the speeds and courses of an oil spill based upon a 'voc'[~r ~:~,'~'Ly:'~i:';. No. 2 illustrates the general porbions of Cook in]et 'Lh~,L t,~:~" vector ~alysis indicates could be afFnc'Led ol~ the f'JrsL t-[de by- at~ o.~] at the proposed ~ocaLion of the exp]..ora~,~rv weX1 ). Tho ci the ~c of each.pie-like segment represent the increasJ~,~l: df.,~,,t.,~ ~ from 10 to ~OK. The speed 'and course of an oil spill after thc' firsL tide coul,~t determined. However, a comN~tcr would be required to of cases necess~ to define the behavior. Definition by the lack of reliable input on current courses ~nd vcg.ocif, ies the Inlet. At this point in time, previous oil spi.]] behavior ~ predict~g the extent of the coas[,al area thab mi_ghL b~ 8f'~'ected. In the final EIS for Cook Inlet, the distribution behavi.or of only one .];'~r/~,o :::,,il is presented by the Corps. Figure 5 il]ustra'bes the d:ir~f, rit~uLion b~;a,:i.e.v ,~'F ,'~ 1700 b~rel crude oil sp.i].l. The dis'bribu'bion beh,nvior through .several tides has been af,-bribuLed 'Lo 'Lhe 'L.'~drO_ ~;~,:~-~,t~, ~f,[,t'.~:r~, ',',~"~, , xJ;'.~. ~ the ~ea (2). The Inlet current pattern is char~c:torJzed ment of salve oceanic water up the eastern shore fresher water do~m the western shore (2). At the Forola~,:is, there ~::; ~ r"ir,.:~.-]:~l,'.~'.v pattern evident. If a spill occurred at our proposed location the ti~a]. would tend to take it up the e .... Lern s tow.:~rd /mc~or,:~;~ and do~ 'the western side from ~c}~oragc 'bo abou'h Page 2- At the Forelands a portion of the spill oil could swing arourld and up,.£he eastern side on the next f].ood tide. The es-tim~t~-d d~:tance spill would go from our location has been based upon ¢}~,: ~.,:.:~r~'~r~es during the ~ift River spill. The circles on ];'i~mes 2 an~] '~ l"ef]:cc't distances. ~owledge of these distances and 'the g~rmra]_ c~rror~l~ indicates the coastal ~eas that might be affected by an ~j.'l -extend from the ~st Forelands to Anchorage on the esstem~ s:-i.,l,:~ and from about H~riett PoinL to Point. MacKenzie on 'h, be w.'.::r:[,r:rn the strong tid~ currents ~d the~ geomet~r generally tc~,J ~,o keep has been spilled out in the Inlet away from the beaches, w:[hh the [azg~ ZsZ~d (~). -- _.' =c-~ ;5 Wind D~~ '~ ion (Feb.~ 2.1~~.~ OSV at OSV at E,~'ection Wired Direct ion S (Ma~ ~Tune~ JU~/- A--?'~ 101f Aug. ) ' 20K 3. 30K W4~nd D~ec%ion Co4~.ciden% WiZh Tidal C~ren% At ~OK 3.5 N64E ~0.~ 4.0 % t.O ' 5.0 PPemises: C~n~ lr,~loci+ ...... "-' "~ ~Y = 3.0 Kph in Direction !ndicaved Above ;find &. Wave ~fect = 5;q% of W~nd Velocity ~om +he D~ections Lndicated at V~ious zmmes of the .~ev~m~g W~nd D~ection Taken ~om l',lO~_ CiLmatica! Data 2am. m~/ (1973) REFERENCES 1. Mil.lard Smith & Peter Lane, "Pla~ning, ~.tuipment and 'l~a:hning for :'" Oil Pollution Control"~ Slickbar Inc. (1973) 2. U. S. COrps of ~gineers, Final EnvJ~orzmental Impact Statement, Offshore Oil & Gas Development, Cook Inlet, Alaska (197~). 3. P' Jj Kinney, D. K. Button, a~d D. M. Schell "Kinet,~_cs oi' DissipaLion and Biodegradation o£ Czmdc Oil in Alaska's Co~k ][~].c-~, Institute o£ Ma~ine Science, University of Ala,,~ka (1')(~9)o /, / PE~II~$LILA III[IIOIIA~ II~11 ~ I:O01l i#t,,(! DRIFT RIVER ./ 5o. of K;tlgJu Island itt EL:~-T'~ - extent of oil spill l-l-oS (wc,.:.t side of i~tf.t not cllecked) ~ff~ - extent of oil spill 1-5-68 at. 1100 9'?x/~:...,', PHILLIPS PETROLEUM COMPA~ff Oil, SPILL CO~fI~]ENC~ PLAN GEORGE FERRIS JACK-UP DRILL BARGE .... . Cont~ainment an__~d C~lean~p _Equipment an__~d M~a.t_e. rial_ iya~3a~b,i!it Ao Onboard the Ferris 1. 1 23' Boston. Whaler w/twin 70 HP OB engines 2.. 1 SO0' Type 48-C Aqua Fence boom 3. 1 Komara Mini skimmer · 4- 1 Kepner Sea Container (2500 Gal. cap) 5. 1 100' Type G-50 Astroturf Sweep '6. 5 100' 3M Type 126 Sorbent Sweeps 7.' 12 40' 3M Type 70 Sorbent Booms Or 480,2total 8. 1800 5M Type 156 Sorbent Pads (4050 ft.2) 9. 1000 3M Type 151 Sorbent Pads (2250 ft. ? 10. 5-150' 3M Type 100 Sorbent Rolls (2250 fo.2) 11. i 55 gal drum Shell Oil Herder collecting agent 12. 1 55 gal. drum Exxon 7664 dispersing agent B. 0nboard the Norma Ann 1. 10 24': Conwed Sorbent booms or 22+0' total 2. 550 Conwed Sorbent Pads (1238 ft. ~) Co Cook Inlet 0il Spill Co-op 1° 1 1000' Vikoma Seapak boom 2. 1 Mark II Skimmer D. Coop Members Stock Co~p~ Amoco Telephone 0ffice Hours After IJours 283-7147 or 283--78.59 CIPL 272-9568 or 31j~-72].6 KPL (Sec al Re finery) 776-8711 or 776-8204 Marathon 776-$1~1 or 283-1+283 Mobil Phillips 776-8722 or 277-4235 · 776-8166 or 283-4339 Shell (Production) Shell (Marketing) 776-~73 or 277-25Z~7 279-4024 or .333-1753 Socal (Marke-[, ing) 279-9666 or 274-2.373 Tesoro (Refinery) Tesoro (Market lng) 776-8191 or 283-lj-,.93 279-5ZA6 or 344-?36? Union (Production) Union (Market ing ) 283-7505 or 283-494.1 277-]Z~74 or Amoco Arc o 2 drums Polyc omplex A-ii 1 Lot Hand Tools 2 6OO' reels 1/2" Nylon Rope 32 Bales- Type 150 Oil Sorbent Pads 32 Bales- Type 151 Oil Sorbent Pads 36 Bales- Type 270 Sorbent Booms (5 booms to ea. bale) ~ 150' Roils TyPe 100 Sorbent Material lOCATION Platforms Kenai Cook Inlet Pipeline Co. Drums Polycomplex A-Ii 800' Boom Centrifugal Pump, 2,000 bph @ 50 psi powered by Caterpillar diesel engine skid mounted Oil ~Mop~ Inc. surface ski~m~g unit Small centrifugal pumps rated ~ 50 - 70 gpm each Vacuum tank with pump, trailer mounted 50 kw generators, engine powered~ skid mounted Air pump Joy 125 air compressor Case front end loader and backhoe Fork lift Caterpiller D-6 dozer Caterpiller D-$ dozer 2-ton dump truck 2-ton boom truck ~.,~sce!!aneous Hand Tools 26' Boat "Kenai Scout"- 170 hp GM Diesel Inboard 16' Boat "~ss California"- ~0 hp Job_nson Outboard Drift River Term~.nal Kenai Pipeline Compar~~ Collecting Agents ! Bale (300) burlap sacks 1,200 Bales Straw 2 Bal~s of 3M Sorbent Pads ~ Boxes of 2" Thick Sorbent Strips 2OO' of Grafco Absorbent boom Front end loader, 1 I/2yd., on Ford Tractor ~scel!aneous H~nd Tools Stsm_dard Oil RefLne~y -, i co . 2 Marat non Mobil ITEM Conwed Sorbent Boom ,, ,! ,! Bundles Sorbent s Lot mi~scellaneous hand tools Motor grader Bac kho e AwwJ+ Pickup LOCATION Dolly Platform Trading Bay Prod. Granite Point Prod. 'Phillips Sorbents 3'x150' Roils of 3M Type 100 Rolls Bales 3M Type 126 Sweeps Bales 3M Type 151 Sweeps Bales 5M Type 270 Boom Chemic als 2 Drums ShelI Oil Herder collecting agent 2 Drums Exxon Corexit 766~ dispersing agent Equipment 1 Hough 90 Front end loader 1 John Deere 550 dozer 1 Case 580 Backhoe and front end loader 1 Lot miscellaneous hand tools Kenai LNG Plant Warehouse Shell (Production) 1000 lbs. "Sea Beads"- a-wicking agent for combustion 1 0il Skimmer boom Nikiski Onshore Platform A Shell ( M~rket ing) 300 ft. T-T boom (Jointly owned by marketing companies) 16 ft. Boston Whaler w/33 H.P. motor S;.~iss OELA Iii oil skimmer 10 gal. Shell 0il Herder 1 roll 5M sorbent Anchorage Soc al 5-M Sbrbent material 21 ~pe i00 36" x 50 yd. roils 9 Type 150 15" squares- 100 sheets 2 Cases - 9 sheets per case - 1' ~ide~ 6' long~ 1 1/2" Amc ho r ag e Tesoro (Production) Refinery 5 Bales of 3M Type 150,36" x 56" Sorbent 1 Lot miscellane°us Tesoro (Market irg) Bales, 5M Type 100, 50 yds. x 3~" Sorbent Bales, 5M Type 150, 56" x 36" Sorbent Mop up kit s, SS Sorbent case~ 9 sheets 6' x 1' x 2" SS Sorbent LOCATION Kenai Anchorage · Union (Production) Union (Market i~g) NOne Boxes of Conwed absorbent rugs Boxes of Conwed absorbent pads Kenai Anchorage E. Commercial Sources 1. Sinking Agents A. Cement Barite. Sand 2. Collecting Chemicals A. Oil Herder B. Corexit 0C-5 Kaiser Cement Mud Companies Peninsula Ready Mix Northern Light s Gas & Oil~ Inc. Exxon Chemic als Nikiski Doc k 776-8322 Nikis ki Dock Nikiski 776-8]-75 Anchorage 277-5533 Anchorage 277-162~+ Dispersing Chemic als A. Corexit 7664 B. Polycomplex A-ii Exxon Chemicals Colletta Corp. Anchorage 277-162~. Anchorage 279-1536 4. Sorbent ~,~terials A. Type 100 Rolls Type 126 Sweeps Type 151 & 156 Pads Type 270 Boom 3M Company Anchorage 276-2363 B. Blankets Pads Boom Conwed Products order by calling 213-327-9800 Stocked ab North Star Bonded Warehouse, Anchorage 277-8323 5 · Skimmers A. Komara Mini Skimmer B. Slikskim Booms A. Vikoma SeaPak B. Slikbar C. Aqua-Fenc e Marco Pollution Control Slikbar, Inc. Marco Pollution Control Slikbar, Inc. 203-226-6~4~ Pacific Pollution Control Emeryville, CA Seattle 206-285-3200 A~chorage agent, 279-1923 Seattle 206-285-3200 Anchorage agent, 279-1925 415-956-1662 Tanks A, 2 500 bbl B. 1 500 bbl C. 1 500 bbl D, Kepner Sea Container Various Sizes Kenai Industrial Park Dowell~ Inc. Peninsula Tanking & Equip. Rental Eepner Plastics Torrence~ CA Kenai 283-7975 Kenai 285-7165 Soldotna 262-4798 - 213-772-3;~6 8. Vacuum Truc ks A. 1 80 & 1 60 bbl B. 1 90 .& 1 70 bbl C. 1 80 & 1 60 bbl D. 2 80 bbt 9. Ground Transportation A. Ail kinds AAA Delivery "Mukluk Town & Country Pumping Peninsula Truc king AAA Trucking KAPS Mukluk Weaver Bros. Kenai 28~-4393 Kenai 283-75]-3 Kenai 283-74.36 Soldotna 262-4798 10. Air Transportation A.~ Rotary & Fixed Wing B. Rotary & Fixed Wing C. Rotary Wing D. Rotary Wing E. Fixed Wing Kenai Air Service E~A Helicopters Anchorage Helicopters Evergreen Helicopters Winship Air Service Kenai 283-7561 Nikiski 776-9581 Anc borage 272-5~+22 Nikiski 776-8l~.37 ~c borage 277-1671 Anc hot age 274-0561 114 Marine Transportation A. Boats 1. MV Alaska Husky- Call Amoco, 776-8993 office hours or Call Don Wycoff, 285-4234 nights & weekends 2. MV Rig Engineer,- Call Marathon, 776-81~1 office hours or Call Jim Lawerence, 283-4283 nights & weekends 3. Mv Krystal - Call Arnt Bros., Homer, 235-8581+ 4. MV Moss Harbor - Call 283-4728 or 776-8459 or 235-8697 B. Fuel Barge 1.~ UT17 (45,000 gal cap.) Call Tesoro, 776-8191 ~ .... · -- 0~ ~,_ ~C e hollr s or 776-8333 nights & weekends C. Cargo Barge 1. KCB-1 (600 Ton cap.) - Call Arnt Bros., Homer 235-858~ APPENDIX IV is in envelope attached to Alaska. Division of Lands' copy of Oil Spill Contingency Plan OIL SPILL CONTINGENCY PLAN PHILLIPS PE~['ROLEUM COMPANY G~ORGE F. FERRIS EXPLORATORY DRILL BARGE Phillips Oil Spill Committee (POSC) Organization Chart Coop Coordinator N. E. Porter : _ssv. Coordinator I J.A. Woods Coop Members POSC CHAIRMAN H. J. Steiner Vic e-C hairm an Coordinator I Coordinat or J. D. Remir~tlo_~' ..... ] ...... Asst. Coordinator Expedit er C. E. Allen D' J. Yelton Contract Transport- ation~ Supplies~ Ste.~d.~Company i ' Contract .......................... : ....................... ~ Labor & I ~ Labor & R_F2t/U!Pm~ent._. Governmel~t al Public Re] ation: F. W. Ball 46 0703 ~ADE IN U.S.A. CHECK LIST ~I)R ~-~4 %'~7.1, PERMITS 1. Is the pelTnit fee attached ..................... %, 2.c Is well tO'. b~ located in a defined po~l .............. 3. Is a registered-'survey plat attached ................ 4. Is well ]©cated proper distance from property line ......... 5. Is well located proper distance from., other wells .......... 6. Is sufficient undedicated acreage available in this pool 7. Is well to be deviated .............. ~,- . . ~'~.~ . 8. Is operator the only affected party ....... ~ .... 9. Can permit be approved before ten-day ~,ait .... [... 10. Does operator have a bond in force ........ ~ ..... 11. Is a conservation order needed ..... ~.- 12. Is administrative approval n~ded ........ ~.. 13. Is conductor strin~ provided .................... 14. Is enough omment used to circulate on conductor and surface .... 15. Will cement tie in surface and intermediate or production strings . 16. Will cement cover all known productive horizons .......... 17. Will surface casing protect fresh water zones ........... 18. Will all casing give adequate safety in collapse, tension & burst . 19. Does BOPE have sufficient pressure rating - Test to ~'~ psig . Item. Approve Date -(1) Fee (4) sg. - (5) P~DPE J c~.c~; ~00 ~- ~~. ~-~( . ~tpproval Recommended: Cmo!ogy: Engineering: _TP~_ M HHH JCM t9~ LCS RAD 20. Has D~ ,4EM approved Plan of Operation ................ Additional Re92ir,-~Jnents: Yes No Remarks /2/9 t'. .; Revised 4/14/78 NEW WELL PERi,11-I'S Yes No' Remarks' ' 1...~ Is the permit-.,~'ee attaChed .... 2. Is well to be located in.a defined ·pool .... . .......... ~. Is a registered survey plat attached 4. Is well located proper distance from property line 5. Is we.ll located pFoper distance 'from other :-..'ells 6 Is sufficient undedicated acreage available in this pool ...... lO. Does operator have a bond in force . · . l l. Is a conservation order needed i2. -s ~.2::'.inistrative approval needed . 7o Is well tO be deviated ................. · L~.-,,.,~,~.~., ..... ::: ...... 8. Is operator ~he only affected party . . . ~:.'.~.i' ~::'~ .-~ ....... 9. Can permit..,b~ approved before ten-day wait [..:,~, ~ ~. .'~ , ~.. . z.~.~..~ ."_ '13. Is conductor strin~ provided . ~~-::'.:.i.~ ·~~ ......... 14. Is enouah cement used to circulate on conductor and 'surface 15. Will cement tie in surface and intermediate or. production strings 16. Will cement cover a.ll known productive horizons -.. . .... 17. ~" ............. .',~11 surface casing protect fresh water zones "q ..... '-'i~l all ca~ing give adequate safety in collapse, tension & burst i9. Does BOPE have sufficient pressure rating - Test to S~u~ psig 20. Has DHEH approved Plan of Operation ..... :.. ...... : Approval Recommended- ?~dditional Requirements' ~ ~ ~ ~s ~~~ C~ ~3b,w~ % ~ ~: ....... ~ ~ed~.~.],-w -:~/~ ..... ~-~ ~..~ Geoloey' Enoineerin9' . -~~ ~'. ~ ~- ~ LCS RAD Revised 11/lY/7~ ..... Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi No special'effort has been made to chronologically organize this category of information. !' I J l I 1 1111I. I JI 1.i Il ! I 1 ] 11 I ] ! ] ! I iii. l!! fl' Y¥ ¥'~ YY YY YY YY Y~ ~'y YY Y¥ YY q. AIJ33 M{tf, iI'r(}~ SWS FI.,InR.~I 21-J'~fiV'-78 /t,!g i)A"i'h 26-,JAN-79 ii0:40:24 79/ '! 125 G 1 F ! I,F, H l;. A [)i~., R I, S 1 ('Ii,b Ci,l.,~ C h [,, i G H C GP F P: [':" Df:PT SHIF- 68 () 0 6 8 0 0 68. 0 0 t) 8 0 0 68 O 0 6 8 0 0 a8 0 0 68 0 0 68 ~i 0 6 a 0 c: 200.0 00 1 <':! (). 00 7 0.0 00 G [: ('A [~ ] C A l: .1 (:; P. C i': 1, J ~3 P G 5.0 () 4~.19 17.35 : .q.75 ! ). 35 Be. 50 2.25 a8.1 q ! 2. ,():, t ']. () O 26.3O 2 ?6.75 :2~. 70 ] 0. (} 0 45. () 0 t :.~. 70 47.00 22.3 q I 3.75 -6. '? 0.03 :17.20 '2.75 12.20 .') T CAI: I. 0 T Ci t,h C AI,.I. [; T C 1: ]., {1: C A .[, I r) T C :1 !., i') (' A ! :1 () T C I I., i ) [) T C I [~ i) C .., i. i LI C I h D C a L: t. D T C A I, I D T C 1 L, [) D T I:) T V ~ h7 1 ! ] 7 i ~.. q. 1"; (,: ('j 6.749 }_. n () ) .779 4. 11 2.720 l ?. 250 I r~7 .~50 61 t2 76 1'2 3 12 559 !7 q~7 i .1 00 .5 E, 0 550 65{) .756 .550 .8 O0 . q :30 .55O 45 c) .560 .55O .050 .600 .95O .758 .550 .200 . q 30 .20r~ C I!,F: (.) 'I C :1 [, .,'-i [., I' i) T C ! I, H C Il L, d [:) T 0 T l) T 5~6. I 38 - 99 9.00 1 4.454 10 (). c :} 0 ,~3.170 I 0 7.5i)<) ! 27.05 'l t 15P,.777 153.450 105.1 O0 81.659 I O0. '4.50 ? 29.087 1 O5.95O I 00. g 25 I 20. b 50 I O2.75O t 000.000 6O. 450 272. 898 e, () . ,::i.: 50 Cbb8 CbT: q G~ Cl_;b8 C t. I, 8 G ~ C L b 8,' C b L 8 GR C il.,t h 8 C l,l'~ 8 G R C b h 8 (; .R, C b b 8 G R G R v .a i_, U & 440.555 999.000 1 ~.seo 54 .~72 45.512 1 :l 1 .686 5:49.511 4.9.~26 54.450 25...~6 · 46.1 3'.).. 24.512 316 407 100.925 30.2 09 :29.92 ] 23. 291 1318. 257 4oOgl 4,081 T'AFF; T?A]LFi:~i f) 1 7 9 ,/ VV Vv VV VV v'~, VV V V VV VV VV Vv /1. [ iL I. l .il ]I lI J'l I 1 1. I [i I i ]|I. ] ]I]L I i ! YY YY YY YY ¥.~ YY YY YY PR1NTE, P: 26-,].~,~-'7q 16:32:C)4 a 6 4 t') ^ I'~2 2 6 -d A r,.i .-, 7 9 16:31,:29 nl i)~I;E,.; '7. 9/ 1/26 ! 024 B ~ T E 8 :i 2 7 6 7. (i (10 $i> CAt, t C Al, .1 (; F' CAt,J. CAf, [ C A t.~ J. C CAi~ 1 G P C A I, 1 SP G F~ C A L .[ C A I~ ] CAI,I CALl V a L t.! F 'I 2.5 C, I 1 . ] I . 850 3~. 25o 26.51 37.7 '~ ! I. 70 { 2.0 n I 1.. 550 q2.43~ 1 I. 7 0 1~.50n 55. I I. e 5 I 6.50 67.5 ~ ! 1.75 2 2.00 2 8.5 2 1 I. 60 15.25 6 2.2 l %,. ~ (;' . 5 I P, 65 C 1.. L C' ! C,gl, [ C I i.: [.) ~)~ C .[ I., i) CAb ] CAbi. 0 T C I b Cnbl C 1 L D C A L I [) T C ] CALl' D q' C A t, I O'P C i b i) C b. 1., I C 1 L, t) C .A b I 0 T C I b 1) CALl C I L D C~h! C I '[., C A :L 1 0 T :ti. 7. I I . ) '~ ~. 4 ~'~ 0 O56. ~ I 7 ~ 1.7 ' '~ {'} q J ~ - . 24 't . 1 I . 16~. ~00 3 4 2.7 65 I !. a 772. ~ 91 ! '2. 142. q2~.q66 I t. 500 1 5g. ~4'7.227 1 ! . ann 105 ,)0 ~ 1.650 t :1.60 I 4 6. g 0 () 5 s 4. '~ 37 I !. 650 1, 47 . ~ 00 759 I !. 65O i.~.200 I t. 400 164. ~ 37 i 6 ?. 50 L; I' t> 'r C I [':,, 'r C 1. L, [:' T C I l., ~,.,.i C 1: L i) q? C I. J, M C I )', ~q D 0 q? C I L D T ~50 5{i)0 1213. ~ 8 I ql .~,00 I 116.8o3 t 41. 000 1224.616 1 35. 1342 · 705 I 5 3. 300 751 .~2 ~ 169. 700 g63.829 166.800 855.06 '1 154.000 704,6g ] ! 4 R. ! 00 6 ] 0. g 57 ~ 47.000 602.560 146. 900 71 7.794 ~ 43. 200 337. 287 152.200 2 0 8. g 30 t 35' ]00 C L, b 8 G J~ C L,L, 8 (.-; R CL, L~ CLI,8 (; R G R C P L, 8 GP C h L, 8 G R C' L,t., 8 G R C :l, [, 8 G R C,~ bL GF',t: V A L V ~'. 52.481 -999. ()00 9¢6.2] ? I .('}al ,..y 't 72 . h g I 801 .~478 .'tl. 459 937.562 32.966 515.229 2a.la9 6 'l 9.2 (:) 4 3 7.49 3 642.688 ]7. 744 5 ~ 6.1. 38 44.1 i4 519.996 59. 537 5 () 1.187 62.052 524. 807 27.4 3.4 325.08 7 70 . 350 192.3 'g :3 6.99 0 1 t::)O.OmC! 1 nO0. ~ 00.000 790. () 0 o C Zt !, i CA)~ I C .~ !: I (; p (.;, C' A ,b 1 (; P S, (:; R CAI, I. '7.52 9 o 0 () n 1 '2.2 $ :! ?. 5 n o ,~. S On 5. 120 C J I. th I.) T C ~.L I i)T C1Li.) C'AI,~ C I L D . C l i.; 1) 0 T C ].bi: C A b i D T C I [_, D [) T C I: L, t, C A L T. [) T I a7 .F, g7 1 q,). s 46 t 1 . fl. 5 () 1 '? .t. '~ () 0 ] ,') 4.7 n 0 1 ! q..t ()0 159..757 ! 4.7 q0 1 e, ~4,. O00 152.757 45.7 i')0 1 ~ 0.617 45.700 C C [> ]' I) T C l T., F! .~5.505 600 2:2 .'9. C) ~ '7 1 3~.773 1 ! 7. i ()0 5'~, 954 :106.40 ,') 71 .779 gT. 1 nO 242. 103 1 C)9. ~Oc~ 267.91 '1 167. 400 '2 4: b. 6, 0 ~ I 67.4, 00 Gk C bL,~ C. lb b 8 G~ C I, L 8 G R C L, b 8 v Al,LIE, 235.505 5~. % t 9 2. 3 0 9 54.6'76 119.124 4, 5 . ] 7 2 ~1.. ]'/6 4 '7. , r) ) '70.¢~9 1 38.0 31 216. '7 '70 46. 195.884 46. :]78 D A T ~; ~ 1 /20 [ .} .! ii 1 1!]11! ] I it t i Ii I ! .I I IJtiff Et" '~rY ¥~ YY ~Y ¥¥ YY ¥¥ YY ~Y !.2~4 i)ATL 127 -' J A !',! - ? 9 () 4: 09: 1 3 04:55:45 I-: A C 1 P J C 1o'?n6,51%5'~ DAfb.: 791 I) ATE.: 79/ 1./21 * , * , * , ii, $ ~,~ -, t. 0 5 P A C !i ~:,t G S fi [,,i I C * * :*: ¢ ("' I [: !'~ !3 j. i. r., Cb..J.,8 i~.l. [, 7 (; ? C ;.~ [. 2 .r, P .R l" C i'v I~ :~ i,, C ::,'I ,! fC!vL, 7 J) 7 !.!! h C ~ (;P, 't 7 42 42 42 ~0 t> 0 t; 0 E, !'1 X. i) E, P T ,S' ~! ! F' T t 1%'"'0 FC 1~ L (; P F (' ~'.: G F: S P t.! 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O0 O0 09 O0 1 l 11 O0 O0 O0 O0 1 ] ~ 1 O0 0000 O0 0000 11 O0 0000 O0 0000 11 O0 O0 O0 O0 O0 O0 Il O0 Oa O0 O0 O0 O0 11 0000 O0 0000 O0 I1 0000 O0 0000 O0 11 O0 O0 O0 O0 11 O0 O0 O0 O0 11 000000 O00000 111111 000000 000000 llllll *START* USER PCCC [1070b,55237J J(.JB HONITLJH 8W8 KL]0833 22-~'~b-79 *STARTS. FI6E;: DS~,.H:VER1F~.O01<057>[1.0706 55237J CREA'I~.,;D: PRINTED: 05-APR-79 0013~118 (IUELJE SNi'TCHES: /~'i6E, IEtJ~T /COPIES: 1, ISPACI. N(;: l. /bINI'I': I 1. 3 /FOPMS: NDRMAL 1.5 ..43 .D 05- APR- 05-APR-79 00:33:15 UO: ]7: 35 LENGIH: 1.712 RELL J,~/41',1L; P.C.I).C. 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