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Home My WebLink About180-087( ( Memorandum To.' Re: State of Alaska Well File: ~ ~.~ -- (~?~c-~ DATE Cancelled or Expired Permit Action EXAMPLE- Point Mclntyre P2-36AXX APl # 029-22801-95 Oil and Gas Conservation Commission This memo will remain at the front of the subject well rile. Our adopted conventions for assigning APl numbers, permit numbers and well names did not specifically address expired or cancelled permits. This omission has caused some inconsistencies in the treatment of these kinds of applications for permit to drill. Operators have asked us to adopt formal procedures for this class of permit application in order to prevent future database disparities. If a permit expires or is cancelled by an operator, the permit number of the subject permit will remain unchanged. The APl number and in some instances the well name reflect the number of preexisting reddlls and or multilaterals in a well. In order to prevent confusing a cancelled or expired permit with an active well or multilateral these case sensitive well identifiers will be changed for expired and cancelled applications for permits to ddll. The APl number for this cancelled or expired permit is modified so the eleven and twelfth digits is 95. The well name for a cancelled or expired permit is modified with an appended xx. These procedures are an addendum to the APl numbering methods described in AOGCC staff memorandum "Multi-lateral (weilbore segment) Ddlling Permrt Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician for timely ccmpliance with our regulations. Operator, Well Name and Number Reports and Materials to be received by: Date Completion Report Well History Samples Mud Log Core Chips Core Description Registered Survey Plat Inclination Survey Directional Survey Drill Stem Test Reports Production Test Reports Logs Run Required,i' Date Received t Remarks Yes ' Yes Yes Digitized Log Data Tenneco Oil A Tenneco Company Calms I Office Center 3201 "C" Street, Suite 201 Anchorage, Alaska 99503 (907) 277-0753 February 2, 1982 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ATTN: C. V. Chatterton RE: Block 54 #1 Cross Island - State Beaufort Sea OCS - ADL 312806 Application to Drill (Amended) Attached is the referenced amended Application to Drill, showing a revised location, corrected ADL #312806, changed procedures and time sequence. This replaces the original Application to Drill submitted August 12, 1980. If you have any questions, please call me at (713) 757-3480. '~. '~. ~.~_~ Project Manager PRE/HCN/ed Enclosure cc: A. Scouler REC£1¥EI) F E B 0 5 1352 Oil & Gas Cons. Commission Anchorage SUBMIT IN TRf ATE Form 10-401 REV 9-! -7 8 (Other Instruc~tons on reverse ~de) la T~PE OF V, ORk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL OR DEEPEN DRILL [~ DEEPEN ~-l b TYPE OF gTLL OIL GAS ~tLL ~Xl ~ELL [~ XOTHER Wildcat 2 N&ME OF OPERATOR lenneco 0il - Exploration and Production M~DRESS OF OPERATOR Box 2511, 1010 tlilam Street, Houston, TX 77001 LOC&I Id\ OF '~TLL "'""~" Lat. 70© ~9' 38.58" 8700' FEL & 6000' FSL Long. 147v 58' 28.77" A:pr°p°sedg~dd;ne-- Straiqht Hole 5 ADL-312806 6 LEASE DESIGNATION AND SERIALNO ? IF INDI&N, ALLOTTEE OR TRIBE NAME $ UNIT FARM OR LEASE NAME Cross Island--State 9 WELL NO Block #54, Well #1 10 FIELD AND POOL, OR WILDCAT tli l dcat 11 SEC, T, R., M, (BOTTOM HOLE OBJECTIVE) Block 54 13 DISTANCE IN MILES AND DIRECTION FROM NEAREST TOW~ OR POST OFFICE' 12 15 miles Northeast of Arco Dock Beaufort Sea OCS 14 BOND INFORMATION State-Wide Oil & Gas Bond A!a_s_ka~.. TwE Blanket S,re,y,nd/orNo #61-S-33248-3-81 ,=o,.t $20C~,000, Div. of Lands 17 NO ACRES ASSIGNED ", 15 DISTANCE FROM PROPOSLD * I l0 No OF ACRES IN LEASE 5693.29 19 PROPOSED DEPTH 14,200' K.B. LOCATION TO NEAREST PROPERTY OR LEASE LINE. FI 6000' FSL (A~o to n~al'e~t ting, umt dam) DISTANCE FROM PROPOSED LOCATION TO NEAREST g~LL DRILLING COMPLETED, OR APPLIED FOR, FT None 21 ELEVATIONS (Sho~ whether DF, RT. CR, etc ) 23 PROPOSED CASING AND CEMENTING PROGRAM TgTHIS WELL " Wi ldcat 20 ROTARY OR CABLE TOOLS Rotary 22 APPROX DATE WORK WILL START iloven~b~r 1, 1982 SIZE OF HOLE SIZE OF CASING WFIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement .... 26" 20" 94# H-40 80' K.B. 300 Sacks - P'ermafrost 17-~'' 13 ')/8" 72# L-80 , 2700' K.B. 3300 Sacks - Permafrost 12¼" 9 5/8" 53.5# S0095 11000' D.B. 1st Staqe' 14.50 Sx Class ~.. 2.nd Staqe: 200 Sx Permafros~ 3rd Stage' 300 BBLS Artic P~ 8 3/8" 7" 32# S0095 14,200' Cement 7" liner as required by logs and evaluations or by hole conditions (if needed) IICII ck See attached BOP data, plat, diverte'r information, and other attachments. RECEIVED FEB 0 5 1982 IN ABOXrE SPACE DESCRIBE PROPOSED PROGRAM If proposal Is to deepen pve data on present productive zone and. l~r_o_pp.s~_~lI new productive zone If proposal Is to drdl or deepen dLrecUonalb, g;ve pertinent data on subsurface locaUonsand measur~lf~l. & Gas O0ns. 00mmisai0n depths Owe blowout preventer program Anchorage vertical (Th~s space for State office use) CONDITIONS OF &PPROVAL IF ANY SA',PLES AND CORE C.I~S REOUIRED ] .UD LOG OT.ER REOUREMENTS ,~ YES [] NO I ~YES [] NO DIRECTIONAL SURVEY REQUIRE~ ~,P I ,~U,~ERIC^L CODE [] YES ~I ~o 5~O - O Z ? - 2 O 5-0 o TITLE Prnj~ct Manaqo_r _~ PERMIT NO. ~" 5~ 7 APPROVAL DATE 53 -- '2. '7 - g ,J APPROVED BY TITLE DATE *See Instruction On Reverse Side BOP and Pressure Data The diagrams following are schematics of the divertor system and the BOP hook-ups. These eiagrams are rig type only. We have not contracted a rig yet and a specific BOP hook-up will be submitted when the rig is selected. The maximum downhole pressure expected is 7,000 PSI. Using USGS approved criteria the maximum pressure that the BOPE will be subjected to is 80% of BHP or 5,600 PSI. The maximum BHP as arrived at by using data from the R.I.S.T. well, Amoco Foggy Island Bay State, Mobil Milkel Sea Bay State, and Exxon #l Alaska State A. All of these wells, with the exception of the Exxon well, had normal type gradients. The Exxon well had a .77 PSI/foot at 13,000. This well is over 38 miles away and the closer wells are considered more representative. The other wells had formation gradients of .48 - .49/foot which would give a BHP at 14,200 of 7,000-PSI. Based on these offset wells and interpretations from seismic data, we feel this gradient should be representative of the pressure we should encounter in the Cross Island Well. RECEIVED FEB 0 5 ].982 ~daska Oil & Gas Cons. Commission Anchorage ( ( B.O.P. STACK CONFIGURATIOH 1 3-5~8" TRIPLE RAM STACK 10,000 PSI WP ANNULAR PREVENTER PIPE RAMS BLIND RAMS 2" KILL CHECK GATE GATE DRILLING SPOOL 4" CHOKE GATE H.C.R. PIPE~~RAMS ,,',,, ] RECEIVED FEB 0 5 1982 Riaska Oil & Gas Cons. Commission A~chorage j DIVERTER PROCEDURE ¢ 1. Rig up diverter system consisting of 20" 2000 psi Hydril annular preventer with auxiliary equipment as shown on attached drawing. Connect electric control switch for 10-3/4" butterfly to electric control switch for 20" annular for simultaneous operation. 2. Lay out lines on opposite sides of the rig taking into account prevailing winds. 3. In the event of well flow: A. Lift Kelly above 20" Hydril. B. ClosJ 20" Hydril C. Watch wind direction and switch diverter lines if required. D. After need for diverter has passed, purge line with steam or air. Note: The 10-3/4" electric controlled butterfly valve, attached to the diverter spool, opens by an electric switch connected to the 20" annular control switch, as the 20" annular closes. RECEIVED FEB 0 5 1982 ~aska Oil & Gas Cons. Commissior~ ~chorage 10-314" ELECTRIC CONTROL BUTTERFLYF- 6" MINIMUM DIVERTER LINE DRILLING RISER 20" 2000 PSI ANNULAR PREVENTOR DRILLING SPOOL 20~ CONDUCTOR PIPE DIVERTER LINES HAVE OPPOSITE DIRECTION DISCHARGE CAPABILITY RECEIVED F E B 0 5 1982 Oil & Gas Cons. Commissipr~ ~cho_rag~ ~ 'ON QNV'ISI SS01:13 ,OOZ'VI ItJ. d::iCi JV.LO.L O~lSOdOl:Jd tlld~ld "1S:1,000'9 ~' l:q:J ,00/.'8 A,"I :::I.LV IN I )(0 I::1 ddV LZ:9 'N"I9 t,~i-0£3 ,,L/'6Z ,8§oLIH. :3i]II.LI~)NO'I .86'8£ ,GZo0Z :](]iIll/Vl NOI.LV30'I · ' ' I I I I e £9 + Z:;9 StJ31 ~INC~*'II)I 0 000'9~ I -t- + NOIIV301 ll]M (]EISOJOtlJ (]NV-ISI SS0113 ,6~oOL PRIMARY LOCATION (CROSS ISLAND) (17§' +--) (ADD 8,200 CU. YDS.) ~ 1.00ACRE ~ TO E LEV. 08.00 NOTE: ADD 10% FOR COMPACTION FIGURE A-B-1 TENNECO OIL EXPLORATION AND PRODUCTION CROSS ISLAND EXPLORATORY WELL ACTIVITY 1982 1983 BEC JAN FEB MAR ApR MAY JUN JUL AUG SEPT OCT NOV DEC JAN FEB MAR APR PETITION 120 VARIANCE RECIEVE VARIANCE AND PERMIT BUILD DRILLING PAD ' MOVE RIG & EQUIP.& SUPPLIES DRILL EVALUATE AND TEST DEMOBILIZE Figure A-B-2 BEAUFORT SEA WELLBORE SKETCH CROSS iSLAND STATE NO. ARCTIC PACK 1 500'-SURFACE CEMENT 2700' TO 2100' ISLAND GROUND LEVEL 20" 94# ~ 80' CMTD. TO SURFACE 1 7-112" HOLE APP. 3300 SX PERMAFROST CEMENT. 13-318" 72~ L-80 BUTTRESS CASING SET AT 2700' 12-114" HOLE CEMENT 9-518" CASING UP TO APPROXIMATELY 6000' 7" LINER TOP 200' INSIDE g-518" F!GURE A-B- 3 9-518" 53.5# SOO-95 BUTTRESS CASING SET AT 1 ¶ ,000' CROSS ISLAND NO. I 2000 LOG AND RUN 13-3/8" CASING TO 2700' 4000 6000 FEET 8000 10,000 LOG AND RUN 9-5/8" CASING TO 11,000' 12,000 14,000 7" LINER TO 14,200' IF REQUIRED LOG TEST AND ABANDON 16,000, 20 "'40 60 "80 100 .... 120 DAYS Fi gure A-B-4 140 160 RECEIVED 18o FEB05] 8 ,Rl~.ska 0il & Gas Cons. CommJssiori Anchorage f ( ~rocno5is to D~~l~ Lease: Block 52l/Tract C3u-54 Weìl 1,0.: Cross Island No.1 District: Frontier Projects Projected Depth: 14,200. Area: Beaufort Sea Est. Elevation: 381 KB Location: Beaufort Sea Offshore tract Rig: Arctic Type Rig C30-54, Elock ~52i approximate~y 8700. FEL & 6000' FSL Operational Procedure: 1. As soon as the permit is received in early March of 1982, stake ~hé well location and extend the No Name ice roaå in preparation of moving gravel for the arilling pad. 2. Construct the drilling pad approximately as in the following Figure A- 6-1. Tne precise configuration of the crilling pac will "be oetermined by the drilling contractor as a function of his cnosen oeployIT,ent ,f the !Ai; ~nc ~ts supporting ~nits. 3. After August i5, 198£ move tne rig, supporting equipment ana consumac1es to tne island by Darge or ~CV. Erect ;ne. rig ana camp, dig well head cellar and set conCiuctor pipe in preparation for RECEIVED FES 0 51982 Âl!W1ca 011 & Gas Cons Ca . Äncbolage mllJlBslon 4. As soon as practical clear rignt of way for ice road to be used for supply, emergency and rig removal at tne conclusion of the we11 commencement of drilling on NovemDer i, 1982. program. ( ( ::: .,¡. install 2011 diverter system as direct::: ;r¡ 20 AAC 25.035 (0)(1). 6. Dr; 11 17 1/211 no 1 e to ¿, ìOO. and 109. 7. Run 13-3/811 casing and cement to surfa:e. Install 13-5/811 starting head anü BOP. Test per 20 AAC 25.035 (cj(l). Install wear bushing. 6. Drii1 50' of formation and test to lee~ off. 9. Dri 11 12 1/411 hole to 11,000' and log. Note: the 12 1/41. hole may be terminated at points above or belo~ 11,000' as dictated by formations encountered and hole condi:ions. 10. Run 9-5/8u casing and cement in two s:ages. Protect permafrost with Arctic pack. 11. instaii lO,OOOf BOPE ana test per 20 ;AC 25.030 (d){l). Install wear bushing. 12. Drili 50' of 8-3/811 hole and run leak ~f7 test. 13. Drill 6-3/8" hole to 14,200' and log. 14. Run liner if required RECEIVED 15. Test well if required FEB D 5 1Q'}~. WaøJëa OU & Gas Cons. Commission Anchorage ( (' . ,.. I W. Piüg and aûandon I ; . Dè~:JûiiiZE: 1£. ~inorow gravel pad and seed as per instructions from the Fish and Gar.le Department. Nü-:.es: 1. Directional surveys will be run as per 20 AAC 25.050 (a) 2. It is anticipated the drilling and evaluation can be done in one season. However, an unanticipated oelay would necessitate a carryover to the following year. Such eventualities will be planned for and acandonment procedures will be aesigneo to allow re-entry the following season if necessary. 3. ine fci]ow1ng Figure A-B-2 shows an idealizea time scnedule. ~. Figure ~-6-3 is a well diagram showing casing points, etc. 5. Figure A-5-4 is tne anticipated drilling ana testing time curve. RECEIVED FEB 051982 PJa3ka on & Gæì Cons. CommissiuD Anchorage AUgust 27, ~980 Mr. Rob R. Rainbolt Division Landman Tenneco Oil Exploration and Production Box 2511, 1010 Milam Street Houston, Texas 77001 Re: Cross Island-State No, $4-1 Tenneco Oil - Exploration and Production Permit ~o. 80-87 '~" y'~ Sur. LOC. z Lat. 70° 29* 3~, Long. 147° 57e 45". Bottomhole Loc.: SAaB Dear Mr. Rainbolt: Enclosed is the approved application for permit to drill the above re£erenced well. Well samples, sore chips and a mud log are required. A directional survey is not required. Xf available, a tape containing the digitized log information shall be su~itted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as ~mportant £or the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title Alaska Administrative Code). Prior to cGmmencing operations you may be contacted by the Habitat Coordinator's office, DopaL~cment of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and ~he regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. Rob R. Rainbolt Cross Island St. No. 54-1 -2- August 27, ~980 cmmencing operations you ~&y be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under .State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to dril 1. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so ~hat a repre- sentative of the commission may be present to witness testing of blowout preventer equip~ent before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that we stay have a witness present. Very truly yours, Hoyle H. Hamil ton Alaska 0il ~ ~s Conse~ation Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/encl. Department of Labort Supervisor, Labor Law Compliance Division w/o encl. · H~a~be Tenneco Oil Exploration and Production A Tenneco Company Tenneco Building PO Box 2511 Houston Texas 77001 (713) 757-2131 August 13, 1980 State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention- Mr. Hoyle H. Hamilton RE- Applicationz/for Permit to Drill ADL-~-Block 54 Beaufort Sea OCS, Alaska Gentlemen- Attached for you review and approval, please find in triplicate, Form 10-401. Also attached is Tenneco Oil Company's check #0074 in the amount of $100.00. Thank you for your cooperation and should you have any questions, please advise. Very truly yours, TENNECO OIL COMPANY Rob R. Rainbolt Di vi si on Landman International & Frontier Division RRR/ps Attachments LTOEP 104A 3/79 Form 10-401 REV. 9-1-78 la. TYPE OF WORK SUBMIT IN TRIPL~' (Other mstruclion~ revere rode) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMtSSION, PERMIT TO DRILL OR DEEPEN SINGLE ZONE [] DRILL I'~ DEEPEN l'-'] b TYPE OF WELL OIL WELL Z GAS WELL FT~ ~,ER Wildcat 2 NAME OF OPERATOR Tenneco 0il - Exploration and Production 3 ADDRESS OF OPERATOR Box 2511, 1010 Milam Street, Houston, TX 77001 FEL & 6400' FSL 4. LOCATION OF WELL Atsur£ace Lat. 70° 29' 37" 7400' At proposed ~nz~fl~ 1470 57' 45" Same - Straight Hole MULTIPLE f--'l AP1 #50-029-20500 ADL-~%~)6' 6 LEASE DESIGNATION AND SERIAL NO 13. DISTANCE IN MILES AND DIllON FROM NEAREST TOWN OR POST OFFICE* 15 miles Northeast of A~co Dock Beaufort Sea OCS ! 7 IF INDIAN, ALLO'FFEE OR TRIBE NAME 8 UNIT FARM OR LEASE NAME Cross Island--State 9 WELL NO Block #54, Well #1 10 FIELD AND POOL, OR WILDCAT Wildcat 11 SEC,, T , R., M , (BOTTOM HOLE OBJECTIVE) B1 ack 54 Alaska Lands in BONDINFOPd~TION State-Wide Oil & Gas Bond ~Blanket S=ety,nd/o, No 61-S-33248-39-79 (Expires 1/1/81) A~ount $100,000 Div. of 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. 6400' FSL (Also to nearest dng, umt, ff any) DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED. OR APPLIED FOR, FT None 16 No OF ACRES IN LEASE 5693.29 19 PROPOSED DEPTH 14,200' K.B. NO ACRES ASSIGNED TO THIS WELL Wi 1 dcat 20 ROTARY OR CABLE TOOLS Rotary 21 ELEVATIONS (Show whether DF, RT, CR, etc) 22 APPROX DATE WORK WILL START December 1, 1980 23 PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quant,ty of cement 26" 20" 94# H-40 80' K.B. 300 Sacks - Permafrost 17½",, 13 3/8" 72# L-80 2700' K.B. 3300 Sacks - Permafrost {to surfa 12% 9 5/8" 53.5# S0095 11000' 'D.B. 1st Stage' [450 Sx Class ~ ....... 2nd Stage' zuU 5x vermafrost "C:~ ... 3rd stage.. 300 BBls Artic Pack 8 3/8" 7" 32# S0095 14,200' Cement 7" liner as required by logs and evaluations or by hole conditions (if needed) See Attached BOP data certified plat, diverter information, $100 check, and other attachments. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM If proposal ts to deepen give data on present producUve zone and proposed new productive zone. If proposal is to drill or deepen chrecuonally, gave pertment data on subsurface locations and measured and true verUcal depths. Gtve blowout preventer program 24. I hereby ;qrttfy that theY~oregou)~ Tru%and Correct 90h R- .D..:. i nh.-. ! .+ Cllus space for State office use) SAMPLES AND CORE CHIPS REQUIRED ~s [] NO DIRECTIONAL SURVEY REQUIRED YES ~ NO PERMIT NO. OA~ August ~.Z~ ]980 CONDITIONS OF APPROVAL, IF ANY IMUD LOG .,~ YES TITLE F)ivi~inn i aqdma~ [] NO August 27, 1980 OTHER REQUIREMENTS A.P I NUMERICAL CODE 50-029-20500 APPROVED BY ~~~'~ TITLE Chai:rman t/ / - ~-,. - t/,~- e Instructmon On BY ORD~F TH: CO~J~M:SS{~ ' Reverse Side APPROVAL DATE DATE 08/27/80 ':2 x. 1o -T'v,/) , ., .70030, 70029· -I- + + ..I- CROSS ISLAND PROPOSED W 1: 25,000 1 0 1 KILOMETERS LOCATION LATITUDE: 700 29' 37" LONGITUDE: 147o 57'45" FROM THE S. E. CORNER OF BLK, 54 7400' F E L & 6400 FS L STATE/FED. LEASE SALE ! ~ BOUNDARY [ , " '~ ISLAND MILES INDEX MAP 54 55 62 63 DEPTH PROPOSED TOTAL DEPTH 14,200' CROSS ISLAND NO. I CROSS ISLAND STATE NO. 1 BLOCK #54 PROPOSED DRILLING PLAN ADL-312806 1. Prior to rig move, install cellar, drill 26" hole with dry hole digger, install 80' of 20" conductor and cement to surface. 2. Move in and rig up drill rig. Install 20" diverter systemmd test as described in 20 AAC 25.035 (b) (1). Drill 17 1/2" vertical hole to 2,700'. Run logs as per logging program. 3. Run 13 3/8" casing and cement to surface. Install 13 5/8" head, and 13 5/8" 10,000 # B.O.P.E. Test as per 20 ACC 25.035. (d) (1) 4. Drill 50' of formation and test shoe to leak off. 5. Drill 12 1/4" hole to ll,O00' unless hole conditions require prior setting of the 9 5/8" casing. Run logs as per logging program. 6. Run 9 5/8" casing and cement in two stages. Protect permafrost with Artic-Pack. 7. Drill 50' of 8 3/8" hole below 9 5/8" shoe and run leak off test. 8. Drill 8 3/8" hole to 14,200'. Run logs as per logging program. 9. Test and/or P & A in accordance with existing requirements. Note' A 7" 32# SO0 95 liner may be run below the 9 5/8" casing and prior to reaching total depth if hole conditions dictate and/or casing off of potential pay zones is necessary. If it is run, drilling will continue, time permitting, to 14,200' with a 5 7/8" bit. BOP and Pressure Data The diagrams following are schematics of the divertor system and the BOP hook-ups. These diagrams are rig type only. We have not contracted a rig yet and a specific BOP hook-up will be submitted when the rig is selected. The maximum downhole pressure expected is 7,000 PSI. Using USGS approved criteria the maximum pressure that the BOPS will be subjected to is 80% of BHP or 5,600 PSI. The maximum BHP was arrived at by using data from the R.I.S.T. well, Amoco Foggy Island Bay State, Mobil Milkel Sea Bay State, and Exxon #1 Alaska State A. All of these wells, with the exception of the Exxon well, had normal type gradients. The Exxon well had a .77 PSI/foot at 13,000'. This well is over 38 miles away and the closer wells are considered more representative. The other wells had formation gradients of .48 - .49/foot which would give a BHD at 14,200 of 7,000-PSI. Based on these offset wells and inter- pretations from seismic data, we feel this gradient should be representative of the pressure we should encounter in the Cross Island Well. B.O.P. STACK CONFIGURATION 1 3-5~8" TRIPLE RAM STACK 10,000 PSI WP DRILLING \ I' I ANNULAR PREVENTER I I ~ PIPE RAMS~ ~ ,I I BLIND RAMS 2" KILL CHECK GATE GATE DRILLING SPOOL PIPE RAMS I I 4" CHOKE GATE H.C.R. DIVERTER PROCEDURE 1. Rig up diverter system consisting of 20" 2000 psi Hydril annular preventer with auxiliary equipment as shown on attached drawing. Connect electric control switch for 10-3/4" butterfly to electric control switch for 20" annular for simultaneous operation. 2. Lay out lines on opposite sides of the rig taking into account prevailing winds. 3. In the event of well flow: A. Lift Kelly above 20" Hydril. B. C1 ose 20" Hydri 1 C. Watch wind direction and switch diverter lines if required. D. After need for diverter has passed, purge line with steam or air. Note: The 10-3/4" electric controlled butterfly valve, attached to the diverter spool, opens by an electric switch connected to the 20" annular control switch, as the 20" annular closes. FLOWLINE DRILLING RISER 20" 2000 PSI ~ ANNULAR PREVENTOR 10-314" ELECTRIC CONTROL BUTTERFLY 6" MINIMUM DIVERTER LINE DRILLING SPOOL 20~ CONDUCTOR PiPE ' ( , DIVERTER LINES HAVE OPPOSITE DIRECTION DISCHARGE CAPABILITY .70030, 70029, -I- I . I ~ ~ o + + + CROSS ISLAND PROPOSED + 1: 25,000 I [ I[ iii MILES 0 1 · · i i I Illl I KILOMETERS 54 62 I LOCATION LATITUDE: 700 29'37" LONGITUDE: 147o 57' 45" FROM THE S. E. CORNER OF BLK. 54. 7400' F EL & 6400 FSL BOUNDARY ~=~%. ~ cross ~' ~ ISLAND "! MILES INDEX MAP '1' 55 63 DEPTH PROPOSED TOTAL DEPTH 14,200' CROSS ISLAND NO. I PLAN OF OPERATIONS CROSS ISLAND NO. I INDEX PLAN OF OPERATIONS page 2 Page 1. Purpose of Well 2. Proposed Site 3. Site Description 4. Proposed Operational Time Schedule 5. Name and Address of Operator 6. Site Drainage 7. Area Wildlife and Fish 8. Native Settlements 9. Biological Monitoring 10. Environmental Training 11. Access Roads 12. Materials Required 13. Fuel Storage 14. Blowout Prevention Program and Equipment 15. Casing and Cementing Plan 16. Food Service 17. Drilling Rig Camp 18. Fresh Water Treatment 19. Waste Disposal 20. Site Restoration 21. H2S 4 4 4 6 7 7 7 7 8 8 8 9 9 10 12 13 13 13 14 14 14 ATTACHMENTS page 3 A. Geological Prognosis and Program Recommendation to Drill Prospect Summary Well Evaluation B. Drilling Prognosis and Detailed Operational Data Well Procedure Rig Specifications Blowout Prevention Program and Equipment Mud Program 13-3/8" Casing and Cementing Program 9-5/8" Casing and Cementing Program 7" Liner and Cementing Program Testing Program Plug and Abandonment Program Effluent Control Personnel Requirements and Organization C. Spill Prevention, Control and Countermeasure Plan D. Environmental Conditions in the Vicinity of Cross Island CROSS ISLAND page 4 1. Purpose of Well The Cross Island well will be drilled to investigate a potential pinchout trap of cretaceous age sands on the north flank of the Barrow Arch. A complete testing program will be conducted if necessary to assist in evaluating potential accumulations. 2. Proposed Site The proposed site of the well is to be on Cross Island. 3. Site Description Cross Island is an offshore barrier island located about 15 miles northeast of Prudhoe Bay. It is semi-circular, about 3 miles long, and 500' at its widest point. The island is composed of silt, sand and coarse gravel, and has a maximum elevation of 7-8 feet. The water depths are very shallow around the island. During the proposed operating season, the area inside the island and slightly to the north is covered by landfast ice 5-6' thick. This landfast ice should remain essentially static throughout the winter and we anticipate no ice override of the island. However, we plan to install a suitable ice monitoring system and the rig will be positioned as much to the lee side of the island as practical so as to provide the most protection against override by the island itself. page 5 If override becomes a significant concern several optional procedures may be employed to minimize the danger to personnel and equipment. These decisions will be made based on the existing conditions and could include the following: ae Put minimum equipment and personnel on the island until protection from override is obtained by natural offshore ridging. bo Induce early offshore ridging by slotting the ice on the seaward side of the is land. Ce Provide barrier berms of snow and ice to the seaward side of the rig. d. Possibly remove encroaching override with dozers. e® As a last resort secure the well, remove personnel and as much equipment as possible. The following Figure I shows the island in respect to the surrounding area and Figure 2 show the island in more detail. Additional data on the island and surrounding area is provided in Attachment 3, "Environmental Conditions in the Vicinity of Cross Island" by Oceanographic Services, Inc. LEASE SALE BOUNDARY i j_____ BEAUFORT SEA _ L_ MIOWAY ISLANDS ' I ~ ~ '~ L J~ ~ CROSS ISLAND ' '" , % MCCLURE '~ C. -- ISLANDS ~PRUDHOE '---'--'] ~'~ L -- L. ' /~~ i STOC.ON.,S~ANOS l ~ ~ '~ ~ ~AG,mE m~OS / ~ I · FLAXMAN IS. 0 10 I I MILES FIGURE I .70°30, 70o29, 0 Il 0 0 0 p' t- + + CROSS ISLAND PROPOSED + 1,25,000 ,1 I I MILES 0 1 I I I I I I KILOMETERS I LOCATION LATITUDE: 70o 29' 37" LONGITUDE: 147o 57'45" FROM THE S. E. CORNER OF BLK. 54 70,00' FEL & 64.00 FSL FIGURE 2 54 62 I I ro~,' STATE/FED. LEASESAi. E' I °,~ ! / BOUNDARY I I ~.=,%. ~c,..~s,,,.LI MILES INDEX MAP -I- -I- 55 63 DEPTH PROPOSED TOTAL DEPTH 14,200' CROSS ISLAND NO. 1 4. Proposed Operational Time Schedule page 6 The timing sequence of the operation is shown in the following Figure 3 and is designed to be compatible with all lease stipulations and attendant ordinances concerning the ecology of the area. Survey work, the transporting of some equipment and supplies will begin after Aug. 15. Such work and supplies will be in preparation of building the Hercules Strip and doing preliminary work such as preparing the rig pad and well cellar. It is anticipated that the strip can be built, the rig moved in by barge and/or Hercules aircraft, erected, and drilling started by sometime in December. It is hoped the well can be completed and tested and the rig moved out before deterioration of the ice strip in April. If such is not the case the well would be temporarily plugged and abandoned, then completed and tested the following year. In the event a two year program is required to complete the well, the rig could be moved off of the island, then back to the island the following winter or stacked on the island, pending approval of the agencies concerned. SUMMARY PRELIMINARY SCHEDULE PREPARED FOR TENNECO OIL EXPLORATION & PRODUCTION CROSS ISLAND EXPLORATORY TEST ii i i 198_ 198_ DESCRIPTI-ON JUN JUL AUG SEP OCT NOV DEC JAN FEB MAR APR BATHYMETRIC AND SITE SURVEYS --- ,, ADVANCE LOGISTICS ,, MOVE EOUIP. TO ISLAND , PREPARE SITE, RUNWAY AND ICE ROAD MOBILIZE AND TRANSPORT RIG ......... ~---- , ERECT RIG -" ,, DRILL - -- -- EVALUATE --' -- COMPLETE -- TEST - -- DEMOBILIZE - -~ -- FIGURE 3 5. Name and Address of Operator page 7 This well will be operated by: Tenneco Oil Co. P.O. Box 2511 Houston, TX 77001 6. Site Drainage The area around the rig will be constructed to slope towards the rig cellar, which will contain any minor spills or leaks. The cellar can then be emptied and the materials can be disposed of at an onshore site. 7. Area Wildlife and Fish Local observations and area studies indicate the proposed winter operation will not hinder the habits of the area wildlife. Note Attachment "D" page 5. 8. Native Settlements No villages are in the vicinity of the proposed location so the drilling operations should not directly affect any of the local population. page 8 9. Biolo~)ical,. Monitoring, Biological populations or habitats that require additional protection, will be monitored and surveyed as directed by the Director of the Division of Minerals & Energy Management. In addition if any area of biological significance should be discovered it will be reported immediately and protected until advice is received from the Director. 10. Environment Traininl~) A series of video tapes are being developed and these, when approved, will form the basis of the program for environmental training. ll. Access Roads Vehicle access to the drilling location will be from the Prudhoe Bay field road system and a sea ice road. The ice road will comprise a cleared route approximately 15 miles long over the shore fast ice. This road will be approximately 30' wide in grounded ice areas, but will be maintained wider to facilitate snow clearing. No additional ice thickness, through'flooding, will be necessary for this road as it will only be used for light loads until the natural ice buildup allows for increased loading. The rig and all heavy components will be transported page 9 by Hercules transport or landing craft to the island. If the ice is competent enough, the rig and/or some components may be moved from the island, utilizing the ice road. Utilization of the ice is a proven aspect of Arctic drilling technology. Grounded and ungrounded ice has been utilized for ice roads to supply drilling rigs with great success. Prior to movement of any material, snow will be cleared from along the road route. This should begin in November and will be a continuous operation. The removal of the snow insulation helps the ice sheet to thicken more rapidly. A 5,000 foot ice airstrip will be made by clearing the snow off sea ice in the shallow water adjacent to the island and flooding as required. During the rig mobilization, drilling, and demob phases, the airstrip, complete with a full flight aviation station, will be utilized to support the rig and drilling operation. 12. Materials Required_ No gravel or gravel movement will be required for the drilling of this location. Therefore an Army Corps of Engineers permit will not be needed. 13. Fuel Storage Fuel will be stored in double walled steel tanks, or single wall with a containment dike of snow and ice. These dikes, based on prior Arctic page 10 experience, should be competent during the operating period. Safety precautions, procedures, flow diagrams, etc., will be developed for fuel facilities and spills. Leaks should be non-existent or minimal. All personnel will be trained in safety and procedures to avoid possible mishaps. 14. Blowout Prevention Prooram and Equipment All operating procedures at the location, whether automated or directly controlled by Company or Contractor personnel, are specifically designed and organized to prevent accidental oil spills. Continued emphasis is placed on the prevention of spills, but at the same time, contingency, emergency clean-up equipment and procedures are kept in a state of readiness. The primary method of blowout prevention utilizes hydrostatic pressures exerted by sufficient density drilling mud to prevent undesired flow into the wellbore. In the unlikely event primary well control is lost, the following surface equipment would be utilized for secondary containment of any formation fluid influx into the wellbore. The rig will be equipped with a 20" 2000 psi working pressure (wp) annular diverter system installed on 80 ft. of 20" H-40 94# conductor pipe while drilling the 17-1/2" surface hole to 2700'. The diverter lines will be vented in different directions to provide downwind diversion. After running and cementing 13-3/8" 72# L-80 surface casing at 2700', a blowout preventer (BOPE) consisting of three 13-5/8" 10,000 psi wp rams, a 13-5/8" 10,000 psi. wp annular preventer, and a page 11 two-choke manifold will be installed. After installation of the BOPE, it will be thoroughly tested for leaks using diesel fuel. It will be pressured tested and function tested as required in 20 AAC 25.035. This same procedure will also be followed after setting 9-5/8" casing. Automatic and manual monitoring equipment will be installed to detect any abnormal variation in the mud system and drilling parameters. A mud logging unit, manned by experienced personnel, will be in continuous use while drilling, and it will monitor formation pressure, hydrocarbon shows, loss or gain in the mud pits, rate of penetration, etc. In the event that the well "kicks," the BOPE will be used to shut in the well immediately and confine the pressure within a closed system. The casing program is designed so that any anticipated formation pressures can be shut in at the surface without breaking down the casing seat. The Company representatives assigned to the drill site will have extensive training, together with actual experience in controlling and killing kicks. These personnel will be further supported by well-trained drilling crews approved by the Company. Pressure resulting from a kick will be circulated out using the balanced bottom hole pressure method, and the well will be restored to its normal operating condition. Tenneco Oil Company is a member of the Alaska Beaufort Sea Oilspill Response Body (ABSORB) so in the unlikely event that secondary control of the well is lost and premature well flow occurs, the full scope of the ABSORB organization and equipment is provided for control and clean up purposes. Our Spill Contingency Plan is provided as Attachment 2. page 12 In addition to the ABSORB response to a blowout, well kill procedures will be initiated. These are highly specialized and designed to the conditions of the blowout. Capping and killing procedures are usually successful but directional relief wells are frequently started as soon as possible as an additional assurance of successfully regaining well control. A number of other drilling rigs on the North Slope would be available for such and emergency well if this were necessary. Adequate area exists on the island for an emergency well location thus shortening the response time for relief well drilling. 15. CasinO Prooram The casing and cementing program is briefly shown below. More detail is provided in the Detailed Operational Plan, Attachment 1. HOLE SIZE SHOE AT SIZE WT. (LBS.) GRADE RANGE THREAD 26" 80' G.L. 20" 17-1/2" 2,700' K.B. 13-3/8" 12-1/4" 11,000' K.B. 9-5/8" 8-3/8" 14,200' K.B. 7" 94 H 40 3 Welded 72 L 80 3 Buttress 53.5 SO0 95 3 Buttress 32 SOO 95 3 Buttress If liner is run, it should have a minimum overlap, of 200'. The hanger should be run with tie back sleeve. CEMENTING PROGRAM 1. 20 Casing ® e 13-3/8" Casing F1 oat Shoe Tag in Float Collar 12 Centralizers 9-5/8" Casing Float Shoe Float Collar Estimate 300 SX Permafrost Cement. Estimate 3300 SX Permafrost Cement (to Surface) Use 5" drill pipe stinger or Interstring Method. 37 Central izers D.V. at 2,700' F.O.C. at 1,500' page 13 First Staoe 50 bbls. water preflush and 1,454 sks. Class G. Seco. nd Stage Permafrost C. mixed at 15.7 ppg. {200 SX) Third Staoe Circulate through F.O.C. with 300 bbls. Artic Pack. {To Surface ) Cement 7" liner as required by logs and evaluations, or by hole conditions. 16. Food Service The drilling contractor will be responsible for insuring that the food and potable water is adequate, handled and prepared properly. Cleanliness will be maintained in kitchen and dining facilities in compliance with all rules of "Good Housekeeping". 17. Drilling Rig Camp The camp area wil 1 be composed of steel modular structures and will be sufficient to provide safety, comfort and convenience for all personnel. 18. Location of Fresh Water and Treatment The water necessary for the camp, approximately 300 barrels/day, will be hauled to the rig location using all-terrain vehicles. This water will be obtained from permitted land sources. A back-up system, consisting of a snow melt machine or a distillation system will be used as necessary to supplement water hauling. This lake water, supplemented as required by other facilities, will be treated to remove the contaminants by using a water treatment plant page 14 enclosed in a skid mounted insulated building. Chlorine will be injected to control algae and bacteria, then the water will be filtered and softened and then stored in camp storage tanks. 19. Waste Disposal Burnable wastes will be disposed of in an incinerator at location, and other waste material will be transported to an approved location on land for disposal. 20. Site Restoration The well may have to be suspended and reentered later if problems force rig removal prior to adequate evaluation or testing. However, upon final completion of all operations, the well will be plugged and abandoned in compliance with all appropriate regulations in force at that time. All casing and/or wellhead material will be removed to below ground level, and the ground restored to its original condition. All debris will be removed from the drillsite. 21. H2S The probability of encountering H2S in the drilling of this well is considered to be minimal. However, H2S monitoring systems will be provided and maintained by the mud logging unit so that in the unlikely event H2S is encountered, it will be detected and proper precautions can be initiated. page 15 Attachment A GEOLOGICAL PROGNOSIS AND PROGRAM June 1980 RECOMMENDATION TO DRILL TENNECO CROSS ISLAND STATE NO. 1 page 16 Operator: Tenneco Oil Company Location: Beaufort Sea Offshore Tract C30-54 Block #521 Approximately 7400' FEL & 6400' FSL Distance from Shore: 15 miles northeast of Arco East Dock 12 miles northeast of Niakuk Islands 12 miles north of Sag Delta area Adjacent Leaseholders: (see plat) Tenneco to East and West; Amoco to South and Southwest; Union to Southeast; open to North, Northeast and Northwest Proposed TD: 14,200' This should be adequate to penetrate all the prospective sedimentary section above economic basement and allow sufficient penetration of the pre-Mississippian to identify and log it. Elevation: GL 3' (+_) KB' 30'_+ page 1 7 Significant Nearby Wells The key well is the Sohio Reindeer Island Stratigraphic Test No. l, a 14,352' MD {13,645' TVD) basement test drilled ten miles to the west in 1979. Tenneco was one of the participants in this hole and we have all the well information. Sohio drilled four directional holes and one straight hole in the vicinity of the Niakuk Islands located 9 to ll miles to the southwest. Tenneco has varying amounts of information on most of these wells but knows nothing about the #3 Niakuk which was drilled from an ice pad in 1969. In addition, the Amoco Foggy Island Bay State Unit 1 in Section 19-11N-17E, an 11,202' Mississippian test, about 14 miles due south and the Exxon #1 Alaska State A, a 14,206' basement test drilled on Flaxman Island about 38 miles to the southeast, are considered important reference wells for this prospect. Rig: To be negotiated. Est. Spud Date: Dec. 15 Est. Days to Comp 1 et i on: Estimated Date of Demob and Clearing Location' 75 Mar. 31 tl,4.ooo It;,,.ooo I J.~,,...oo? I ~"~heil-Arc~ !! ...... 14 I, 505,000 ~ t 15.050.900 / ~Arco-Murphy i ..... .I ~ ~ I ~ I I ;46J.~z, I . I I i . j ' ' Am~o ' ~ , ~ ~ , ; ~ / ~ L ~ t,,,-,,,, ,~.z=~t,~l ' I I I I ~ I ~ J Arco I ~;~ ~c.~s ~ ~,;4~ it,~*oo.-t/...t,o,~.;~o ~ TET I : :o jUnicol / "~BP-~hio ~ ,, -.,-,,% ,~ -- _ ~_ ~[ ,~ =i.,.ooo ~ I t I xxon-Unic, l I I I Gulf Gulf - Cities 38.56650% · ,0o J $ i2 I,ZTO,O00 L~.xxon 74.83 % Exxon-Arco --~?--I- "~' Amerada Morolhon I ~12,22e,ooo Unicol Exxon-Arco I I tl,,;~o, ooo _~xon .~$hrogri. ! Phillips Mob-Chev 1,0o30* IS - Exxor, I / I o ,~ I I ° I. I itz~,eo, I Berglund I '. ' ;),.~oo.04e 14.100.000 I te.,4~.ooo L Arco ~~erglund · ' ~ ;8,310,101 I I 9 · · · · · I' ,", ' · · e · - , ~ Arco ;hell ,zo.ooo )~,o7o.ooo Mobil I · · Murky IMobil IMobil Phillips I O~ · · · ~ ~ . ~ · · ~ ~~ ' iPhiI i~il ~v ;tz,,z4.ez · · · · ~ ~ · · · 0 · 9 -- I iChev /Choy Ill'Mobil o~ O w lo ;e · · ee ' . ! I Id · Ieee · el ; oleo -- I I eee,, ~'ee oeo J · oo,.~o ' ,~.ooo I I J eeOe ·e -e · ee I . 'Y ~ tts,o3o,~ooJ TENNECO OIL COMPANY · · FBONI',IER PROJECTS NOBTHEflN ALASKA · BEAUFOItT SEA ;,exton- Ber(jlund BEAUFORT SEA LOCATION MAP Mobil PROSPECT SUI~ARY page 18 Dr i 11 i nO Hazards: A. Permafrost Some permafrost is anticipated. Its depth, thickness and nature is difficult to predict. In a 20 hole core drilling program conducted by the U.S.G.S. in February and March of 1979 within the lease sale area, permafrost was encountered in all but five holes. The deepest of those five only went to 140 feet. The shallowest permafrost was encountered at 46 feet and the maximum amount penetrated was 261 feet, and was still in permafrost at TD. In the R.I.S.T. well, the actual amount of permafrost was difficult to determine but its base could be picked at 1030' KB. This is approximately where it would be anticipated in the Cross Island area as well. Gas could be trapped below the permafrost zone or gas hydrates could also be present. If gas hydrates are encountered some free gas, either as pockets within the hydrate zone, or trapped beneath it would be anticipated. These have not presented any particular problems elsewhere in the area. B. Abnormal Pressures Reference to drilling histories and the plotting of the resistivities of shales encountered in area wells suggest the possibility that some higher than normal pressures can be anticipated. The most likely zones for geopressures page 19 to occur are in the deep-water shales in the basal part of the Seabee Formation and below the Neocomian unconformity. These would be expected from about 10,555' to 12,650' and below 13,150', respectively. Most wells have been successfully drilled with about l0 ppg mud. The maximum known mud weight used in the area was at the Exxon #1 Alaska State A on Flaxman Island where 15.3 ppg was employed. WELL EVALUATION A. Mud Logging Continuous mud logging should be started from below the 20" casing shoe and continued to total depth. In addition to the standard sample logging, gas detection and pore pressure services, hydrogen sulphide (H2S) and carbon dioxide (C02) detection systems should be provided as well as continuous automatic mud weighing systems. B. Coring 1. Conventional Cores Conventional cores will be taken only if hole conditions and time permit. No coring is anticipated above 12650'. Below that point it will be at the discretion of the well site geologist and only if potential reservoir rocks are encountered. 2. Si dewa 11 Cores Numerous sidewall cores are anticipated, primarily for paleontologic and reservoir information and also for geochemical purposes. Coring points will be determined by the wellsite geologist. p age 20 Wirel ine Logging: Logging Run SWC #1 Prior to 13-3/8" csg. 2700' - #2 Corre 1 ati on 7000' P #3 Prior to 9-5/8" csg. 11000' X #4 Approx. LSS FDC-CNL Depth DIL-S GR-C GR-C HDT Velocit), X X X X X X TD 14200' X X X X X X Schlumberger will do the wireline logging. Additional log runs may be made if abnormal pressure, adverse hole conditions or other circumstances warrant doing so. Formation testing: A. Wireline Testing The Schlumberger Repeat Formation Tester (RTF) may be used to determine possible hydrocarbon zones or potential reservoirs where other data is lacking or inconclusive. The wellsite geologist will determine such test points, to be based on mud log, drilling time, wireline logs or other data. B. Drillstem Testing No open hole DSTs are anticipated. If testing is warranted a 7" liner will be ( ,run for this purpose. page 21 Dri 11 in~) Cuttin~)s: A. Dry Cuttings Samples will be collected every 30' from below the 20" casing shoe to approximately 10,000'. Ten foot intervals will be sampled below 10,000'. B. Wet Cuttings Wet cuttings should be collected at the same intervals as the dry cuttings but should only be lightly rinsed and placed in plastic bags. C. Canned Geochemical Samples These samples should be collected at 100' intervals from below the 20" conductor pipe to TD. They should be placed directly in a quart container, sprayed with Bactericide "Zephrin Chloride", and sealed. Geochemical Evaluation: Tenneco will evaluate the source rock and thermal maturity of the section. Routine determination of total organic carbon, hydrocarbon solubles, vitrinite reflectance and kerogen coloration will be carried out. Canned samples will be available for head-space gas analysis or carbon isotope work. page 22 Biostrati~)raphj/: Biostratigraphic work will be contracted out. Contractor will be determined at a later date. The unwashed samples will be available for biostratigraphic information and sidewall cores will be taken for this purpose with the number and location to be decided by the wellsite geologist. Geological Supervision: The Tenneco wellsite geologist will be responsible for all geologic functions during drilling of the well. He will be responsible for daily geologic reporting to the Houston office. A coordinator for all geologic evaluation of the well will be located in Houston. Securit),: As this will probably be one of the first wells drilled on offshore tracts purchased at the December, 1979 lease sale, maximum security measures will be enforced at all times. This would include the following: (A) Only Tenneco and authorized personnel are to be admitted into the mud logging and wireline logging units at all times. All logs (original and copies) are to be secured at all times and unwanted copies are to be destroyed. page 23 (B) The radio-room is to be cleared of all non-Tenneco personnel during the times of morning reports or reporting of confidential matters to the Houston office. (C) All distribution of geologic well data is to be handled out of the Houston office. (D) Only authorized personnel will be allowed on the drillfloor when cores are pulled and laid out on the drillfloor. This will also apply when wireline formation test tools are being unloaded. Authorized personnel will be Tenneco personnel, contractors' personnel working on the drillfloor, and all other persons authorized by the Tenneco operations supervisor. Supplementary Notes: Specific procedures will be given as to the disposition of samples, shipping or transmittal of data and samples at a later date. page 24 Attachment B DRILLING PROGNOSIS AND DETAILED OPERATIONAL DATA Prognosis to Dri 11 Lease: Block 521/Tract C30-54 District: International and Frontier Prlojected Depth: 14,200' Location: Beaufort Sea Offshore tract C30-54 Block #521 approximately 7400' FEL & 6400' FSL page 25 Well No: Cross Island No. I Area: Beaufort Sea Est. Elevation: 35' KB Rig: Arctic Type Hercules Rig Wel 1 Procedure: 1) As soon after August 15 as possible conduct a bottom survey of the lee side of the island and define the optimum position for the Hercules Air Strip. 2) Perform surface surveys as required to stake our location and assure compatibility with our foundation design and location selection. 3) Move in by barge as much equipment and supplies as practical before beginning of freeze up. Additional supplies and equipment may be moved by air cushion vehicle even after freeze up has stopped barge transport, if such vehicle is available at th is time. 4) As soon as possible clear snow and start pumping for Hercules air strip, this will probably be about Nov. 1st. Herc strip should be usable by Dec. 1. 5) Clear right of way for ice road as soon as possible. p age 26 .3) Install well cellar (10'x10'x10'), drill 26" hole with dry hole digger, install 80' of 20" conductor and cement to surface. 7) Lay herculite seal, rig and camp foundation. 8) Move in balance of the rig, if necessary, by Hercules aircraft and erect on prepared site. 9) Install 20" diverter system as directed in 20AAC 25.035 (b)(1). 10) Drill 17~" hole to 2,700' and log. Drilling should start sometime in late December. 11) Run 13-3/8" casing and cement to surface. Install 13-5/8 starting head and BOP. Test per 20 AAC 25.035 {d){1}. Install wear bushing. 12) Drill 50' of formation and test to leak off. 13) Drill 12¼ inch hole to 11,000' and log. Note: the 12~" hole may be terminated at points above or below 11,000' as dictated by formations encountered and hole conditions. 14) Run 9-5/8" casing and cement in two stages. Protect permafrost with Arctic pack. 15) Install 10,000~ BOPE and test per 20 AAC 25.035 (d)(1). Install wear bushings. 16) Drill 50' of 8-3/8" hole and run leak off test. page 27 17) Drill 8-3/8" hole to 14,200' and log. 18) Run liner if required 19) Test well if required 20) P1 ug and abandon 21) Demobilize 22) Restore drilling site to its original state. Notes: 1) Directional surveys will be run as per 20 AAC 25.050 (a) 2) It is anticipated the drilling and evaluation can be done in one season. However, the time is very short to do this and only a small amount of delay will necessitate a carryover to the following year. Such eventualities will be planned for and abandonment procedures will be designed to al 1 ow re-entry the fol 1 owing season if necessary. 3) The following figure A-B-1 shows an idealized time schedule. 4) Figure A-B-2 is a well diagram showing casing points, etc. 5) Figure A-B-3 is the anticipated drilling and testing time curve. SUMMARY PRELIMINARY SCHEDULE PREPARED FOR TENNECO OIL EXPLORATION & PRODUCTION CROSS ISLAND EXPLORATORY TEST ii I 198_ 198_ DESCRIPTION ' ' JUN JUL AUG SEP OCT NOV DEC JAN FEB MAR APR BATHYMETRIC AND SITE SURVEYS ~. ADVANCE LOGISTICS , ,, , MOVE EOUIP. TO ISLAND PREPARE SITE, RUNWAY AND ICE ROAD .... MOBILIZE AND TRANSPORT RIG ............ , ERECT RIG ------ .......... DRILL -- -- -- EVALUATE -- -- COMPLETE -- --- ,,,, ,, TEST - --- . DEMOBILIZE - --- -- i FIGURE A-B-1 BEAUFORT SEA WELLBORE SKETCH CROSS ISLAND STATE NO. I ARCTIC PACK 1500'-SURFACE ISLAND GROUND LEVEL 20" 94# @ 80' CMTD. TO SURFACE CEMENT 2700' TO 2],00' 17-112" HOLE APP. 3300 SX PERMAFROST CEMENT. 13-318" 72# L-80 BUTTRESS lING SET AT 2700' 12-114" HOLE CEMENT 9-5~8" CASING UP TO APPROXIMATELY 6000' 7" LINER TOP 200' IHSIDE 9-5~8" 9-5~8" 53.5# SOO-95 BUTTRESS CASING ~ET AT 11,000' ;-318" HOLE FIGURE A-B-2 7" 32# SOO-95 T.D. 14,200' CROSS ISLAND STATE NO. 1 DRILL TIME 2OO0 · LOG AND RUN 13-318" CASING @ 2700' 4000 6O0O 8O0O 10,000 LOG AND RUN 9-5~8" @ 11,000' 12,000 14,000 EVALUATE, TEST, P&A 16,000 Ii I I I I 40 60 80 100 DAYS FI GURE A-B-3 page 28 RIG SPECIFICATIONS Although a rig for this well is not under contract at this time, it will be a rig such as AADCO rig #4, the general description of which follows: Rig options will primarily be determined by the stipulated short drilling season (1 Nov.-31 Mar.) and the vehicle options for rig transport. The availability of a 100 ton air-cushion transporter could increase the probability of completing a well in one year and could accomodate a broader selection of rigs. AADCO RIG NO. 4~ .NOW UNDER CONSTRUCTION-COMPLETION SCHEDULE DECEMBER l, 1980 Mast & Substructure: Dreco; M14225-1330; "Slingshot"; 1,300,000 # GNC; 900,000# casing capacity; 500,000# set back; 500 ton, seven 60" x 1-3/8" sheave crown block; and mast raised at six foot ground level . . . then floor raised to 29' high drilling level . . . to avoid the necessity of cranes and high rig-up ramps. There will be 25' BOPE working space x 18' horizontal space under the rotary beams after the floor is raised to drilling position. Drawworks: Oilwell; E2000, 2000 HP, Parkersburg V-200 brake, driven by two 1000 intermittent and 900 brake HP traction motors. Motors, manual and hydramatic brake cooling system totally enclosed with heat salvaged and flooded into the subsi~ructure. Drillin9 Pumps: Oilwell; two A-1700, 1700 HP, triplex single acting pumps, each driven by two 900 brake HP traction motors. Pumps are equipped with page 29 5000 psi wp discharge manifold to kill line and stand pipe system, Demco shear relief valves, TOTCO mud gauges, Hydril pulsation dampeners and suctions super charged. Travelin~) Block: Oilwell; B-500 ton, six 60" x 1-3/8" sheaves. Hook: BJ, 5500, 500 ton, dynaplex, automatic positioner hook. Swivel: Oilwell; PC-500, 500 ton, goose neck taped for 2" free point access. Rotary Table: Oilwell; B-375, 37-1/2" opening, driven from drawworks. Prime Movers: Caterpillar; diesels, five D-398, 900 HP (sea level, 1200 RPM) driving five 700 KW AC generators with a power factor of .70, resulting in a continuous total of 3375 KW or 4500 brake HP; two Caterpillar diesel 3304 "cold start" and auxiliary generators with residental spark arresting mufflers. Auxiliary is portable and equipped with six 1200 AMP flood lights. Riodrive: General Electric; AC/DC SCR system and motor control distribution center, all pressurized and atmospheric controlled with six GE 752 DC motors which are controlled from the drillers consule position. Mud Tank S~/stem: 1000 BBL active tanks, 350 BBL liquid mud (or water) storage, 80 BBL independent."trip tank" with separate pump; tank baffles, skimmers, bypass pit, arctic non-freeze bottom cleanout jets, all closed loop system, and built in mud check lab with Baroid Field mud check equipment. page 30 Mud Processing Equipment: Brandt dual double shale separators; two Demco lO00 GPM desanders; two Brandt "combination" 400 GPM mud cleaners and/or can be used as desilters; Pioneer Mark I 100 GPM centrifuge with four feed pumps; two Pioneer SIDEWINDER cyclonic mud blenders one 5 HP chemical blender with forced discharge; six Brandt 5 HP mud agitators, submerged mud guns; seven Gallagher 4"x6"x16" impaller centrifugal charging and processing pumps driven by 75HP Ac motors. Floor Tools: VARCO; iron roughneck; power slips; 5" and 3-1/2" hand slips; ~ i, Kelly spinner; Master and Kelly bushings; BJ 350 ton elevator bails; BJ 350 ton 5" & 3-1/2" elevators; three sets type DB tongs; two sets type C tongs; Drilco easy torque; Mathey 20,000' hydraulic wireline un'it; 10,000# air winch; two 5000# derrick booms with 5000# air winchs; 7500' 1-3/8" wire line with power spool; Hercules dead line anchor; two covered personnel elevators - one GL to drillers doghouse and one casing walk to DK floor; OK mud box with drain to flow-line; 4" casing fill line; casing stabbing board; automatic drain heated DP rack; snub posts and lines; facility built into rotary beams to install and service a rental automatic pipe wiper, all laid out to reduce accidents, connection and trip time and personnel fatigue. NOTE: No drilling of rat or mouse holes is required due to floor height. Water & Fuel Storag.e.; 1000 BBL total water storage (doesn't include 350 BBL with mud system that can be utilized for water storage on big cement jobs); lO00 BBL total diesel storage with double walls to avoid necessity of building and lining berms; lO00'gallon gasoline tank for pickups; 250 gallon forklift portable diesel fuel tank for fueling up machinery/trucks on rig moves. page 31 Instrumentation: One TOTCO drillers console with gauges and indicators for weight, rotary torque, RPM, tong torque, easy torque, iron roughneck, flow-show, PVT, hole-fill, SPM, gain and loss; one TOTCO eight pen record system for weight, trip time, penetration, rotary torque, pump pressure & SPM for #1 and #2 pump and PVT; one TOTCO circular record for trip tank; one TOTCO survey drift indicator barrel with one 7o and one 14o drift instrument . . can be run on wire line, dropped and retrieved on trip and/or retrieved with sinker bars and mouse trap with wire line unit. Safety & Communications: 16 AD open all station intercoms; 6 general monitor #520 gas detectors; 3 RCA closed circuit TV screens (doghouse, toolpusher and company man office) with 3 cameras (shakerroom, mud mixing room, pump room and derrick floor); MSA FIRST-AID KIT; MSA evacuation basket litters with blankets; one Ansul LT 150# all purpose wheel mounted fire extinguisher; 40 Ansul LT 30# all purpose hand fire extinguishers; Geronimo derrickman safety escape; Geronimo derrickman climber; S&S Crown-o-Matic protection device; and 6 MSA gas masks with oxygen tanks. Air Compressors & Heating: Two Sullair series 12 H-5AO single stage rotary screw air compressors driven by 50 HP AC motors, rated 200 CFM at 125 psi wp; two Keewanee 100 HP boilers, automatic diesel fired and water level control; 20 Stardozik Ruffneck steam heaters driven by 1/2 HP AC motors; two Tioga 3,500,000 BTU salvaged from the D-398 prime mover cooling system (creating 1,500,000 BTU each under 75% load) and force distributed into the rig housing with additional fans to distribute heat turbulance in large areas such as the substructure and rack house complex. ~ ~ page 32 Housin9, Windwalls, Tubular Machine & Shop: All outside perimeters of the rig (including the pipe rack house, walk and ramp) is insulated from ground level to 10' above the derrick floor with windwalls extended on up to 50' high around the derrick floor. No drilling personnel have to go outside the protected heated rig after going on tour. There is a doghouse mounted on each side of the substructure, one for spare subs and tools and one for drillers and company mens (separate) offices. An easy access material ramp from ground level to the derrick floor for handling of casing tools, bits, stabilizers and other tools. All housing is modular design with vee blocks for correct and easy alignment when setting in. After set in . . . union facing union and plug are hooked up while personnel are protected from arctic weather with plenty of lights in order to see what they are doing. The pipe rackhouse includes an automatic hydraulic pick-up and lay-down machine powered by a 75 HP motor and can handle up to 10" drill collars and 20" casing up to 50' lengths. 12,000' of 9-5/8" casing can be racked in this house and still lay down (or stand back in mast) the 5" drill string when ready to run casing. Included with the rig is an insulated heated shop building for a combination, but separate, mechanic, electrician and welder areas. Overall size is 36' wide x 48' long x 17' high with four man doors and 16' wide x 16' high vehicle door. The shop is equipped with work benches, storage, drill press, anvils, vises, grinders, 600 AMP electric welder, cutting torch and 5 ton overhead electric crane. Also.included with the shop is a portable 400 AMP diesel welding machine and cutting assembly that will reach the crown of the mast. Drill Pipe,' page 33 Main strin9 consists of 20,000' of 5" Oilwell IEU grade "E" tube, with HTCO 5" extra hole tool joints, 6-1/2" OD with smooth x hard facing and AMF TK-34 internal plastic coat. 10,000' is 19.50# rated 396,000 tensile and 10,000' is 25.60# rated 530,000 tensile, all equipped with stamped steel thread protectors. Auxiliary string consists of 12,000' of 3-1/2" Oilwell IEU grade "E" tube, 15.50# rated 323,000# tensile strength with HTCO 3-1/2" IF tool joints, 4-3/4" OD with stamped steel thread protectors. Down Hole Tools: "All drill collars are spiraled and grooved for elevators and slips, recessed fine particular hard bands, all tool joints on all tools are stress relieved and equipped with cast steel thread protectors." 18 - Drilco 8" OD DC with 6-5/8" H-90 box to pin 18 - Drilco 6-1/2" OD DC with 4-1/2" X-hole box to pin 12 - Drilco 6-1/2" OD DC with 3-1/2" IF box to pin 35 - Drilco 5" 5 - Drilco 5" HWDP with 5" extra hole tool joints HWDP pup joints 5', 10', 15', 20' & 25' lengths 1 - Drilco 5-1/4" Hex Kelly 4-1/2" IF pin down 1 - Drilco 4-1/4" Hex Kelly 3-1/2" IF pin down 6- Drilco 8" DC pick-up subs 6- Drilco 6-1/2" DC pick-up subs 4- Drilco 3-1/2" DC pick-up subs Plus BJ Zip-Handling bails and elevators i - 8" DC to bit junk basket i - 6-1/2" DC to bit junk basket i - 4-3/4" DC to bit junk basket page 34 i - lot of subs for above contractor equipment Blow-Out Prevention Equipment: Diverter~ one Hydril 20" - 2000 psi wp annular BOP with flanged bottom and studded top with 10-3/4" diverter system, diverter opens to reserve pit when 20" annu 1 ar is closed. Main stack~ 1 - Hydril 13-5/8" - 5000 psi wp annular BOP with studded top and hub-clamp bottom connections, fast change locking bonnet. 3 - Hydril 13-5/8" - 10,000 psi wp single gate BOPs with top and bottom hub-clamp connections, each with one 3" flanged side outlet. Ram sizes with rig; I set of 2-7/8", 3-1/2", 4-1/2" 2 sets of 5"; i set of 7", 9-5/8"; blinds and shears. NOTE: Shear rams can be used with either of the above three gates. All gates equipped with automatic-ram-locks. page 35 1 - Shaffer drilling spool, 13-5/8" - lO,O00 psi wp, top and bottom hub-clamp connections with one 3" flanged side outlet equipped with two 3" lO,O00 psi wp flanged valves {one hydraulic} for kill line and one 4" flanged side outlet with two 4" - lO,O00 psi wp valves {one Hydraulic} for line to choke assembly. 1 - Unitized lO,O00 psi wp choke assembly consisting of 4" straight through, two 3" Cameron automatic adjustable chokes, one 3" Cameron manual adjustable choke with two 10,000 psi wp valves up stream of each above function with drillers remote control console (located just inside driller doghouse) and proper gauges and sensors at the manifold with 5000 psi wp valves with 3" outlet to DRECO primary degasser-shaker box and Drilco seaflow degasser, or 3" outlet to flare pit and/or test tanks, or 4" straight through to reserve pit. Covered mud tanks are equipped with six 1200 CFM fans which can exhaust all mud tank house air in two minutes or less. 1 - NL Kooney seven station, 3000 psi wp BOP accumulator control system, with 20-11 gallon accumlator bottles (220 gal. capacity), 280 gallon fluid reservoir, 20 HP electric triplex pump at 8.7 GPM at 3000 psi, two air pumps 3.5 GPM each at 3000 psi as first back-up, 6-275 CF nitrogen bottles as second back-up with remote electric control console behind driller on derrick floor. 1 - National liquid blast lO,O00 psi wp single acting triplex test pump driven by 50 HP AC motor complete with tank, gauges, by-pass valves, manifold, hoses and controls. page 36 ( I - Hydril 10,000 psi upper Kelly cock. I - each Hydril 10,000 psi 3-1/2" & 5" lower Kelly cock. 1 - each Hydril 10,000 psi 3-1/2" & 5" floor valves. 1 - each Flocon 10,000 psi 3-1/2" & 5" inside BOP. 1- lot Baker floats for DC float subs. 1 - Substructure 50 ton overhead BOP handling system. Rolling Stock & Miscellaneous:_ 1 - Caterpillar 966 front-end loader, arctic equipped, double heaters, with snow bucket, fork extensions and personnel basket. 2 - Crewcab pickups, arctic equipped, double heaters, equipped with 4 doors and 4 wheel dr ive. 1 - Caterpillar 3304 auxiliary generator, 90 KW, installed in insulated house and equipped with six 12 AMP flood lights for use during rig-up-down. 1 - Lot of slings, spreader bars, racks for nippling-up, rigging-up and down and moving. i - Complete set of unitized 6" thick steel rimmed wooden rig mats both for rig and camp. page 37 Camp - Sixtj/ Bed.-, The camp is totally self-sufficient with systems and facilities such as beds, kitchen, dining room; walk-in dry food, cooler, freezer storage; baths, laundry, portable water storage, water purification, waste disposal, incineration, locker change room, recreation and coffee day-room which are designed for sixty inhabitants. All sleeping quarters and most of the halls and recreation rooms are carpeted for warmth, quietness and house slipper comfort throughout. The outside shell and main structure is manufactured of steel for strength and fire proofing. All of the camp is heavily insulated (similar to walk-in freezer) for comfort in the coldest seasons and to reduce heating fuel costs. The entire camp is totally electric with power supplied by two Caterpillar D353 300 KW Ac generators with residental mufflers for quietness. The camp is equipped with automatic fire extinguishers over the kitchen stove, 10 Ansul LT 30~ hand fire extinguishers, on Ansul LT 150# wheel mounted fire extinguisher, fire hoses/reels and heat/smoke detectors with alarms and manual fire alarms. The company representative, toolpusher and head cook have private baths in their quarters. Straight across the hall from the company representative and toolpusher are private offices over looking the yard or camp parking area. The geologist quarters is equipped with a laboratory (sink, two burner electric plate, exhaust fans and desk) and private bath. The camp meets or exceeds all Federal and State codes, rules and regulations. BLOWOUT PREVENTION PROGRAM AND EQUIPMENT page 38 All operating procedures at the location, whether automated or directly controlled by Company or Contractor personnel, are specifically designed and organized to prevent a loss of well control. Continued emphasis is placed on well control, but at the same time, contingency and emergency clean-up equipment and procedures are kept in a state of readiness. The primary method of blowout prevention utilizes hydrostatic pressures exerted by sufficient density drilling mud to prevent undesired flow into the wellbore. In the unlikely event primary well control is lost, the following surface equipment would be utilized for secondary, containment of formation fluid influx into the wellbore. The rig will be equipped with a .2~'~ ~000 psi wp annular diverter system installed on 80 ft. of 20" H-40 94# conductor pipe while drilling the 17-1/2" surface hole to 2700' (see Figure A-B-4). The 10-3/4" diverter line will be connected to storage tanks or bermed areas capable of holding the surface hole volume. After running and cementing 13-3/8" 72# L-80 surface casing at 2700', a blowout preventer (BOPE) consisting of three 13-5/8"~]~,~0~Q psi wp rams, a 13-5/8" 10,000 psi. wp annular preventer, and a two-choke manifold will be installed (see Figure A-B-5). After installation of the BOPE, it will be thoroughly tested for leaks using diesel fuel. It will be tested at least weekly thereafter, as well as prior to drilling out casing shoes. Operational tests and crew drills-will be conducted daily. This same procedure will also be followed after setting 9-5/8" casing. F BELL NIPPLE 10-314" ELECTRIC CONTROL BUTTERFLY DIVERTER LINE 20" 2000 PSI ANNULAR PREVENTOR DRILLING SPOOL 20" CONDUCTOR PIPE DIVERTER LINES HAVE OPPOSITE DIRECTION DISCHARGE CAPABILITY B.O.P. STACK CONFIGURATION 1 3-5~8" TRIPLE RAM STACK 10,000 PSI WP DRILLING ! ANNULAR PREVENTER PIPE RAMS BLIND RAMS 2" KILL CHECK GATE GATE DRILLING SPOOL 4" CHOKE GATE H.C.R. PIPE RAMS ,,, FIGURE A-B-5 page 39 Primary well control will be maintained by over-balancing formation pressure with a column of drilling fluid. Automatic and manual monitoring equipment will be installed to detect any abnormal variation in the mud system and drilling parameters. A mud logging unit, manned by experienced personnel, will be in continuous use while drilling, and it will monitor formation pressure, hydrocarbon shows, and loss or gain in the mud pits as well as other downhole conditions. In the event that the well "kicks," the BOPE will be used to shut in the well and confine the pressure within a closed system. The casing program is designed so any anticipated formation pressures can be shut in at the surface without breaking down the casing shoe. The Company representatives assigned to the drill site will have extensive training, together with actual experience in controlling and killing kicks. These personnel will be further supported by well-trained drilling crews approved by the Company. Pressure resulting from a kick will be circulated out using the balanced bottom hole pressure method, and the well will be restored to its normal operating condition. Following are hydraulic installation instructions and diverter procedures. page 40 · ® Be HYDRAULIC EQUIPMENT SPECIFICATIONS AND INSTALLATION INSTRUCTIONS All connections shall be flanged or Cameron clamp of comparable rating. All flanges to be API 6B or 6BX and ring gaskets shall be API steel RX or BX. BOP stack shall be braced to sub-base or suitable support by turnbuckled lines or rods. (No rigid connections.) All gate valves must be equipped with handwheels. Rams shall have manually-operated screw locking extensions with handwheels ready for use. The remote station is to be located near the driller's position. The operating unit master control and BOP's shall be connected with steel lines and swing joints with 5000 psi working pressure rating. Inoperative condition of remote unit is not to interfere with operation of the master control unit. ® Housing and heating should be provided for accumulator, blowout preventors, and choke manifold. Contractor to make no connection to casing head side outlets, except as advised. 8. Keep on rig one spare set of ram blocks for the drillpipe in use. 9. Any misalignment of rig must be corrected to avoid undue wear of casing. DIVERTER PROCEDURE 1. Rig up diverter system consisting of 20" 2000 psi Hydril annular preventer with auxiliary equipment. Connect electric control switch for 10-3/4" butterfly to electric control switch for 20" annular for simultaneous operation. 2. Lay out lines on opposite sides of the rig taking into account prevailing winds. page 41 3. In the event of well flow: A. Lift Kelly above 20" Hydril. B. Close 20" Hydril C. Watch wind direction and switch diverter lines if required. D. After need for diverter has passed, purge line with steam or air. Note: The 10-3/4" electric controlled butterfly valve, attached to the diverter spool, opens by an electric switch connected to the 20" annular control switch, as the 20" annular closes. MUD PROGRAM 26" hole to 80' - Drill with dry hole digger to 80' prior to rig move. No mud will be used. e 17-1/2" hole to 2,700' - Drill with XC polymer, and gel. Funnel viscosity to be 200 SEC + through gravels and thinned back accordingly bel ow 1,500'. o 12-1/4" hole to ll,O00 + or - - Drill with non dispersed gel mud, XC polymer, and 10.5 - 11 PH. May be lightly dispersed to control gels. Maximum anticipated mud weight is 10.2 ppg. ( 4. p age 42 8-3/8 hole to 14~200' + or - - Drill with Lignosulfinate mud system. W.L. to be maintained 5-10. Maintain other properties as hole may dictate. Maximum anticipated mud weight is 11.0 ppg. 13-3/8" CASING PROGRAM The 13-3/8" casing will be run from surface to 2,700'. Data from area wells indicate this should give a good casing seat and shut off the perma frost that exists from surface to approximately 1,000'. Because this permafrost might act as a caprock, small accumulations of gas could be present in the surface hole. It is anticipated that gas would be at normal pressures. (The surface hole should be carefully monitored while drilling and tripping.} Also, mud should be kept as cool as possible to prevent thawing of the permafrost. PROGRAM ® Install diverter system on 20" conductor. Using sufficent collars and drilling jars, drill 17-1/2" hole vertically to 2700, surveying every 500'. Note: a. Maintain mud temperature between 40-45°F. Monitor and report accurately suction pit and flowline mud temperature. b. Clean and inspect casing. Make up and thread lock float shoe, insert float collar and duplex latch in collar on pipe rack. Ensure duplex stab-in sub will fit latch-in collar. Ce page 43 Thickening time tests should be carried out by cementing company on each of the two batches of cement mixed, using the water which will be used for the job. TT to equal 4 hours at 50°F. 3. Run 2700' of 13-3/8" 72# L-80 Buttress casing as follows: F1 oat shoe One joint casing Insert fl oat Latch-in baffle collar (equipped 'for latch-down plug) Have 13-3/8" Buttress swage with 2" valve and cementers hook-up available on floor. Rig to fill casing each joint while running. Centralize 10' and 20' on shoe joint, then one per joint on bottom l0 joints. Thread lock bottom 2 joints. ® Land casing with landing joint spaced to place top of casing head flange 6' below ground level. Hook up circulating swage and break circulation to ensure floats are not plugged. 5, RIH with stab-in sub, on drill pipe and stab into latch-in collar. Circulate and cement with: Permafrost II: slurry weight 14.9 ppg., yield 0.93 cu.ft./sk., water 3.5 gal/sk, until cement returns to surface. page 44 Drop plug, displace with mud to latch-in collar checking displacement. Bump plug with 2000 psi. In float holds, POH and back out landing joint. Ensure landing joint is breaking out of top joint of casing leaving thread up. Check T.O.C. Perform top cement job through tubing, if necessary. e Install 13-5/8" screw-on casing head. Nipple up on this head as required by head design. ® Install and test BOP stack as per requirements. Have state representative present. The 13-3/8" casing should be tested to 3000 psi before drilling out the shoe. 9, Install wear ring. Run 12-1/4" drilling assembly. Drill out shoe and approx. 50'. Pressure test to leak-off. 9-5/8" CASING AND CEMENTATION PROGRAM page 45 9-5/8" .Casin~) Properties and Dimensions Weight Grade Thread I.D. Drift Tension {Pipe Body} Co 11 ap se Internal Yield Make Up Torque 53.5 lb./ft Soo-95 Buttress 8.535 in. 8.379 in. 1,477,000 lbs. 7330 psi 9410 psi Make up to base of Triangle on Buttress Pin Annulus and Pipe Volumes 12-1/4" Ho le 9-5/8" Casing 12-1/4" x 9-5/8" Annulus 13-3/8" 72# x 9-5/8" Annulus 5" Heavy Wt. Drill Pipe 5" Drill Pipe ft. 3/ft. bbl./ft. 0.8185 O. 1458 0.404 0.072 O. 3132 O. 0558 0.3262 0.0581 O. 0499 O. 0089 0.0999 0.0178 Di, i sp1 acements 9-5/8" Casing 5" Heavy Wt. Drill Pipe (w/TJ) 5" Drill Pipe (w/TJ) f_t. 3/ft. bbl./ft. 0.0965 0.0172 0.1015 0.0181 0.0376 0.0067 The 9-5/8" casing will be run from surface to 11,000'+. This will case off the unconsolidated or weakly consolidated shallow sands, and the majority of the hydratable shales. page 46 Potential hydrocarbon bearing sands can occur in the Cretaceous sediments. Extreme caution should be exercised on trips through these sections. The 12-1/4" hole should not encounter severe abnormal pressure gradients, but all indicators must be closely monitored as this is an exploratory well. SUMMARY 1. Run 9-5/8" 53.5#/S00-95 CASING TO T.D. ® The first stage cement is designed to fill 60% of open hole volume from the 9-5/8" shoe to the 13-3/8" shoe with the estimated top of cement at 6,000' MD. ® Second stage cement wil 1 be circulated through the DV collar at 2,700 to tie the 9-5/8" and 13-3/8" casing strings together. · e A third stage will place Artic Pack, a non-freezable and non-polluting fluid, through the potential permafrost areas from 1500 to surface in the.9-5/8" x 13-3/8" annulus. PROGRAM page 47 1. Drill 12-1/4" to 11,000. . Run open hole logs as listed in the logging program. Make wiper trip to T.D. POH. Pull wear ring. Install 9-5/8" rams. 3. Rig up and run 9-5/8" 53.5 Soo-95 Buttress casing as follows: Float shoe Ijt g-5~8" Soo-95 casing F1 oat co 11 ar 1 it. 9-5/8" Soo-95 casing Shut-off baffle plate 8300 g-5/8 casing Howco DV col 1 ar 1200' + 9-5/8" casing Howco F.O. Cementer 1500 + 9-5/8" casing CASING RUNNING NOTES page 48 a. Make up float shoe and float collar on casing prior to running casing. b. Threadlock all connections on bottom 4 casing joints and also on DV collar. c. Centralize 10' and 20' above shoe and one centralizer every/other joint for 15 joints. Centralize every joint 10 joints below DV collar and on every joint other joint for 12 joints above D.V. d. Space out so casing slips can be dropped through rotary (depends on casing head type.) e. Have circulating swages with valve and cementers hook up available on floor while running casing. f. When running casing, fill every three joints. ® After running last joint, install cement plug holding head, break circulation and circulate bottoms up. Hook up cement lines and test to 3500 psi. Note: Attempt to space out such that casing collar is below slip placement area with casing set on bottom. Pump 50 _+ bbls. fresh water pre-wash ahead of cement. page 49 Mix and pump first stage. Top of cement to be at 6000'. Slurr._..___~y- 1715 cu.ft. (1454 sks) Class G cement with 1% CFR-2 Weight 15.8 ppg Yield 1.18 cu.ft/sk. Water 5.0 gal./sk. TT 3 hrs. at 185°F BHST ® After cement is pumped, drop 9-5/8" wiper plug. Displace with mud at a maximum pump speed with rig pump (_+ 10 bpm) to baffle plate. Bump plug with 3000 psi. Release pressure and check floats. 0 Drop DV opening bomb. Load cement head with DV closing plug. Allow time for bon~3 to drop (120'/min.), pressure up and open DV (1000 psi). Break circulation. Circular bottoms up. ® Mix and displace second stage cement as follows: Slurry- 190 cu. ft. (200 sks) Permafrost C (600' of fill) Weight 15.6 ppg. Yield 0.95 cu. ft./sk. Water 3.75 gal./sk. TT 3 hrs. @ 50°F 11. After pumping cement, drop DV closing plug. Displace with mud until plug lands. Close DV collar with 3000 psi. Lower slips and packoff down well bore through the rotary table. Pick up and pull and land slips and packoff. This should be done immediately after cementing. (This procedure may be modified, depending on casing head type.) 12 page 50 Nipple down BOPE. Install packoffs. Nipple up BOP's. Pressure 9-5/8" to 3000 psi and test packoff to 5000 psi. Test BOPE and auxiliary equipment as per requirements. Install wear ring. (Depending on head design, nipple down may be eliminated.) 13. RIH with FO(; shifting fingers and packer. Open FOC, set packer. Open annulus valve and break circulation. Close annulus valve and pressure test cement job in 9-5/8" x 13-3/8" annulus to 1000 psi. Open annulus valve, pump 150 bbls. water and 300 bbls. Artic pack. Displace with mud. Close annulus valve, unseat packer, and close FOC. Test closed FOC with annulus valve open. Close annulus valve. 14 RIH with bit. Drill out DV and test casing to 3000 psi. Drill out cement and float shoe. Drill 50' and test to leakoff. 7" LINER PROGRAM AND CEMENTATION PROGRAM A 7" liner will be run in this well only if hole conditions dictate that the liner is necessary to reach total depth, and or if necessary for testing purposes. The liner would be run where drilling is in jeopardy due to hole conditions. The depth of the well is such that running a 7" liner could prevent reaching TD at 14,200'. Slower penetration rates and shorter bit life associated with 5-7/8" bits, along with the time required to run and cement the liner will lengthen the required drilling time. No operations are planned to extend past the winter operating season. PROGRAM page 51 le Drill 8-3/8" hole to TD of 14,200' or as hole conditions dictate. Coring should be at a minimum. e Run open hole logs as per Logging Program. Install 7" rams in BOP stack if liner is to be run. 3. Rig up and run 7" 32# Soo-95 Buttress casing as follows: F1 oat shoe Two joints casing Float collar Sufficient 7", 32#, Soo-95 casing for a 200 liner lap Hanger Liner packer Tieback sleeve CASING RUNNING NOTES ,,,, a. Threadlok all connections on bottom three casing joints. b. Centralize 10' and 20' above shoe and every joint on the bottom 25 joints c. Have circulating swages with valve and cementers hook up on floor for casing drillpipe. When running casing, fill as necessary. ® Hangliner Pump + 50 bbls. water ahead of cement. p age 52 Mix and pump cement: Slurry- Class G with 18% salt, 1% friction reducer. Calculate cement volume based upon annular volume from caliper log + 25% excess. Weight 16 ppg Yield 1.2 cu.ft.sk. Water 5.0 gal/sk. 3 hrs. @ BHST from loggers (retard as required) 0 Bump plug and set packer after checking that floats hold. Pick up and reverse out excess cement. POH. Lay down 8-3/8" BHA. 8. Replace 7" rams with 3-1/2" rams in BOP stack. ® Pick up sufficient 3-1/2" drill pipe and 4-3/4" collars and RIH with 5-7/8" bit. Clean out to float collar. 10. Pressure test lap to 3000 psi surface pressure. (Do not test before 12 hours after CIP). Squeeze if necessary. 11. If liner cement job tests to 3000 psi, drill out float equipment and cement then begin drilling new 5-7/8" hole. 12. Drill 30' of new hole below the 7" shoe and run static leakoff test. Drill to TD log, test and or P&A as required. 4-1/2" Liner page 53 The possibility exists that a 4-1/2" liner may be run from the 7" liner shoe to TD. This possibility is remote, but must be provided for if hole conditions require running the 7" liner prior to T.D., and then shows are encountered below the 7" liner. The 4-1/2" liner will be run in the same manner as the 7", and a detailed procedure will be issued at a later date. TESTING PROGRAM If testing is necessary to evaluate this well, we propose to test in a fashion compatible with the production expected and the Arctic climate. All tests will be performed with tubing and packers in the hole and the tree installed. Detailed procedures will be forthcoming when and if any testing should be done. The following Figure A-B-6 is a general layout of the surface testing equipment that could be used for a production test. PROPOSED TESTING SCHEMATIC ~U-R FACE WELLHEAD $SV HEATER BURNER 1 GAS OIL WATER AIR GAS ,, OIL , WATER AIR BURNER 2 CHOKE MANIFOLD X ) V FIGURE A-B-6 PUMP IN vl GAS v TEST SEPARATOR ASME CODED OIL WATER OUT ( ( ( Plug and Abandonment Prooram page 54 Several plug and abandonment alternatives exist and will be covered in the following. Both downhole and surface abandonment procedures will be in accordance with 20 AAC 25.105 and 20 A. AC 25.120. Case #1 Well drilled to TD below 9-5/8 casing string. P&A procedure shown in Figure A-B-7 Case #2 Well drilled to TD and 7" liner set. P&A or T&A procedure shown in Figure A-B-8 Case #3 7" liner set to TD and well perforated. Procedure shown in Figure A-B-g. Case #4 Open hole below liner. Procedure shown in Figure A-B-lO. Surface abandonment will be as shown in Figure A-B-11. Effluent Control Waste material will not be permitted to accumulate at the drilling site. Burnable wastes will be disposed of in an incinerator, and other waste material will be transported away from the site on a frequent basis for disposal at an approved location on land. Garbage, noncombustible trash, ash from the incinerator, and other solid wastes will be transported to the North Slope Borough Solid Waste Disposal Utility or other appropriate sites as may be designated. Sewage will be treated by the camps physical-chemical PROPOSED DOWNHOLE DIAGRAM ABANDONMENT WITH NO SHOW NO LINER RUN TOP OF CEMENT @ -10' GL BASE OF CEMENT @ -60' GL 1:3-818" @ 2700' 50' ABOVE SHOE 9-5~8" @ 11,000' ~ 50' BELOW SHOE T.D. 14,200' CI BRIDGE PLUG ARCTIC PACK 1500' TO SURFACE PLUG CI BRIDGE PLUG IN ADDITION PLUGS WILL BE SET ACROSS AND ABOVE SANDS AS PER REGULATION FIGURE A-B-7 PROPOSED DOWNHOLE DIAGRAM TEMPORARY ABANDONMENT (LINER RUN) ZONE NOT PRODUCTION TESTED SURFACE PLUG 50' CEMENT PLUG 13-318" @ 2700' BRIDGE PLUG ARCTIC PACK FROM 1500' --TO SURFACE PLUG CI BRIDGE PLUG LINER LAP PLUG 100' CEMENT PLUG 9-5~8" @ 11,000' CASING SHOE PLUG 100' CEMENT PLUG 7" @ T.D. 14,200' FIGURE A-B-8 PROPOSED DOWNHOLE DIAGRAM TEMPORARY ABANDONMENT WITH SHOW ZONE PRODUCTION TESTED SURFACE PLUG 50' CEMENT PLUG 13-318" @ 2700' LINER LAP PLUG 100' CEMENT PLUG ~ ~CI BRIDGE PLUG ARCTIC PACK FROM 1500' TO SURFACE PLUG CI BRIDGE PLUG 9-5~8" @ 11,000' 100' CEMENT PLUG ABOVE PERF INTERVAL CASING SHOE PLUG 100' CEMENT PLUG 7" @ T.D. 14,200' FIGURE A-B-9 PROPOSED DOWNHOLE DIAGRAM PLUG AND ABANDONMENT (LINER RUN ABOVE 14,200') SURFACE PLUG 50' CEMENT PLUG 13.318" @ 2700' ~ ~Cl BRIDGE PLUG ARCTIC PACK 1500' TO SURFACE PLUG LINER LAP PLUG 100' CEMENT PLUG 9.5~8" @ 11,000' CI BRIDGE PLUG OPEN HOLE PLUGS AS REQUIRED 100' PLUG CEMENT 50' BELOW SHOE FIGURE A-B-lO ( SURFACE LOCATION ABANDONMENT ABANDONMENT MARKER WITH REQ'D. INFO. CELLAR 1 4' DIA. CELLAR FILLED 20" 1 3-318" BLIND FLANGE 10' GL FIGURE A-B-11 p age 55 treatment unit. Effluent from this unit will be chlorinated prior to discharge, sludge will be incinerated. Used drilling fluid will be processed for reuse when feasible, otherwise both mud and cuttings will be transported to land for disposal at a designated pit, or if permitted to at this time, on ice disposal may be used. The following Figure A-B-12 shows the general flow of all rig effluents. Personnel Requirements and Organization The drilling of the Cross Island well will be conducted by the International and Frontier Division of Tenneco in Houston, Texas. Adequate staffing of qualified personnel will be provided in Anchorage and on the North Slope to provide on site supervision and control of all phases. This staff will be supported by the contract rig personnel and their management, service personnel and consultants when needed. Some of the contracted services and consultants that may be used are as follows: 1) Logging companies 2) Cementing companies 3) Casing crews 4} Wellhead services 5} Mud loggers 6} Mud engineers 7} Ice engineers RIG AND CAMP EFFLUENT SYSTEM COMBUSTIBLE WASTE m mm mmm mm mm m m mm mm m m m mm m mm mm mm mm mm m m mm m l INCINERATOR SLUDGE SEWAGE SEWAGE PLANT GARBAGE, NONCOMBUSTIBLE WASTE CAMP DRILLING RIG L DRILLING FLUID AND CUTTINGS WASTE OIL I I I I I I I '1 I I I L mm mm m mm mm m mm m m mm mm mm m mm mm mm mm mm m mm mm mm J ASH EFFLUENT I NORTH SLOPE I I BOROUGH I I SOLID WASTE I I FACILITY I I I I I I I I I I I I I I WASTE PIT I I I I I I I I I I I , ! I..._ WASTE OIL ROAD OILING~ I ii I "- STORAGE '"- I I I I I I VARIOUS SITES INLAND I I- .............. .I FIGURE A-B-12 OPERATIONAL MANAGEMENT SYSTEM FOR CROSS ISLAND NO. I I CONSULTANTS & SERVICES SECRETARY & DISPATCHER ANCHORAGE 1 PRODUCTION HOUSTON DRILLING SUPT. ANCHORAGE .I I ASST. DRLG. SUPT. ANCHORAGE INTERNATIONAL AND FRONTIER PROJECTS HOUSTON ! MATERIAL SUPER. & EXPEDITOR ANCHORAGE DRLG. ENG. NORTH SLOPE 3-ROTATE EXPLORATION HOUSTON , I CONSULTANTS & SERVICES GEOL. ENG. NORTH SLOPE 3-ROTATE MATERIAL MEN ANCHORAGE 3 F I GURE A-B- 13 8) Weather services 9) Communications specialists 10) Environmental engineers 11) Others page 56 A general plan of the operating organization is shown in Figure A-B-13. page 57 ENGINEERS CERTIFICATION I hereby certify I have reviewed the following SPCC plan and being familiar with the provisions of 40 CFR, Part 112 and 18 AAC 75.310, attest that it was prepared in accordance with good engineer practices. P. R. Edling Professional Engineer Texas Registration No. 34740 page 58 Attachment C TENNECO OIL COMPANY OIL SPILL CONTINGENCY PLAN CROSS ISLAND NO. 1 WELL INDEX Preface Introduction General Information 1.1 Facility Name 1.2 Type of Facility 1.3 Location of Facility 1.4 Site Description 1.5 Proposed Operational Time Schedule 1.6 Name and Address of Operator Details as Specified in 18 AAC 75.310 2.1 Response Cooperative Unit 2.2 Containment and Response 2.3 Key Personnel 2.4 Communications 2.5 Spill Probability 2.6 Detection and Monitoring 2.7 Notifications 2.8 Inventories 2.9 Chemical Control of Spills 2.10 Response Times 2.11 Disposal 2.12 Training and Manuals page 59 60 61 62 62 62 62 62 63 64 64 64 65 68 68 68 69 72 72 72 72 73 73 PREFACE page 60 The following document is designed to serve as a guide for dealing with oil spill emergencies, should they occur in our Cross Island No. 1 well. The purpose of this offshore contingency plan is fourfold: l) To provide a list of jobs that must be done when oil is spilled, with identification of their priority and importance. 2) To provide for the assignment of such jobs prior to an oil spill, with appropriate designation of authority. 3) To provide communication patterns to assure coordination of efforts. 4) To provide reference materials to those responsible for the various duties that occur as the result of a spill. This plan is considered supplementary to the ABSORB Contingency Plan and contains only elements of contingency planning pertaining to Tenneco Oil Company's philosophy and organization. The bulk of the above listed preparation, training, equipment lists, organization and response actions will be defined and controlled by the ABSORB Contingency Plan and organization. It is through such cooperative efforts by the operating companies that the greatest efficiencies can be obtained in the unlikely event that an oil spill does occur during our planned exploratory operation. INTRODUCTION page 61 Oil spills have generated complex technical, legal, and public relations problems for the companies involved. Prior planning can help avoid or minimize such difficulties. It cannot be emphasized too strongly that the best way to handle oil spills is to prevent their occurrence. Good housekeeping, adequate equipment maintenance, and adherence to proper operational procedures are the best insurance against oil spills. If, in spite of the best care, accidental spills do occur, they will require the immediate coordination and efforts of many company departments, and perhaps, contractors and/or outside agencies. This offshore contingency plan is designed to guide Tenneco Oil Company personnel in the quick and effective response to the problems presented by accidental spills. Its primary goal is to limit, as far as practicable, damage to property, wildlife, or the ecology from such a spill. Within this offshore Contingency Plan and primarily in the referenced ABSORB Plan, you will find descriptions of the duties that are to be discharged when oil is spilled. It provides affected personnel with procedures for handling such spills effectively. Some of the procedures are mandatory, and they are so identified, others are merely suggested, as their application might be dependent on the conditions of the spill. 1. GENERAL INFORMATION page 62 1.1 Facility Name_ Cross Island No. l, State Block 54 Alaska Beaufort Sea 1.2 Tj/pe of Facility/ Exploratory Wel 1 1.3 Location of Facilitj/ The location will be on Cross Island. Cross Island is located about 15 miles from the Prudhoe Bay East Docks on a heading of 35o. Figure 1.1 is a map showing its location. 1.4 Site Description Cross Island is a member of the Midway Islands group. The island is semi-circular in plan, about three miles long and 150 yards at its widest point. Maximum elevations on the island are seven to eight feet. The island is primarily composed of silt and sand with coarse gravels being found at the higher elevations. This island is one of the chain of islands which form a barrier protecting the sea area adjacent to the Arctic coast in this region. LEASE SALE BOUNDARY MIDWAY ISLANDS CROSS ISLAND PRUDHOE MCCLURE ISLANDS BEAUFORT SEA I *--I STOCKTON. ISLANDS MAGUIRE ISLANDS FLA~(MAN IS. MILES lO FIGURE 1.1 page 63 Freezeup in this area takes place in late September or early October. By the middle of October the ice is usually continuous between the island and shore and by early November the ice extends from the island to the polar pack. In early freezeup the ice may be susceptible to large movements but stabilizes as the ice thickens. These movements will not affect the Cross Island well as all equipment will be located on the island with the exception of the access ice road, the Hercules airstrip, temporary ice berms for secondary spill containment, and possibly some vehicle parking areas. 1.5 Proposed Operational Time Schedule Survey work and the transporting of some equipment and supplies will begin after August 15. Such work and movement of supplies will be in preparation of building the Hercules strip and doing preliminary work such as preparing the rig pad and well cellar. It is anticipated that the strip can be built, rig moved in by Hercules aircraft or barge, erected, and drilling started by sometime in December. It is hoped the well can be completed and tested and the rig moved out before deterioration of the ice strip in late April. If such is not the case the well would be temporarily plugged and abandoned, then completed and tested the following year. In the event a two year program is required to complete the well, the rig could be moved off the island then back to the island the following winter or stacked on SUMMARY PRELIMINARY SCHEDULE PREPARED FOR TENNECO OIL EXPLORATION & PRODUCTION CROSS ISLAND EXPLORATORY TEST 198_ 198_ DESCRIPTION ' ' JUN JUL AUG SEP OCT NOV DEC JAN FEB MAR APR BATHYMETRIC AND SITE SURVEYS ---- , ADVANCE LOGISTICS MOVE EOUIP. TO ISLAND PREPARE SITE, RUNWAY AND ICE ROAD ..... MOBILIZE AND TRANSPORT RIG ............ ERECT RIG --'-'" DRILL -- -- "- EVALUATE · - '-- COMPLETE --' '-' TEST - -- ' DEMOBILIZE - -- -- FIGURE 1.2 page 64 the island pending approval of the agencies concerned. Note Figure 1.2 for time schedule. It is noted that by State Stipulation No. 9, downhole activities are limited to the time period of Nov. 1 to Mar. 31 unless special permission is granted by the DMEM. 1.6 Name and Address of Operator This well will be operated by Tenneco Oil Company P. O. Box 2511 Houston, TX 77001 2. DETAILS AS SPECIFIED IN 18 AAC 75.310 2.1 Tenneco Oil Company is a member of the Alaska Beaufort Sea Oil Spill Response Body (ABSORB) and as such the Oil Spill Contingency Plan for Cross Island No. 1 well will be the ABSORB Contingency Plan supplemented with specific information relative to our company and this well. References will be made to the ABSORB Plan but its pertinent sections will not be duplicated and included here as the plan in its entirety will be in all agency files along with sample participation contracts in fullfillment of 18 AAC 75.310 (a) (1). 2.2 A detailed description of the proposed manner of oil discharge containment and clean up operations, including operating manuals, personnel, organization, logistics, and communications is as follows: 2.2.1 Containment page 65 In the extremely unlikely event of a very large spill, containment will be provided in the form of a large containment area to one side of the island. This system involves an ice sealed containment berm approximately two to three feet above the sea ice and about 200 feet square. The containment area will provide sufficient volume for a large spill from the rig (20,000 barrels). Adjacent areas can be quickly bermed in the same manner with on-site bulldozers and earth moving equipment should a larger area be needed. Fuel will be stored in double walled steel tanks or in tanks which will be surrounded by snow and ice berms constructed for secondary containment. Once the snow berm is constructed, the area will be lined with herculite and the berms will be sprayed with water which, when frozen will form a complete ice/herculite containment area. Any fuel from a spill coming in contact with the berm would be at ambient temperatures. Inasmuch as the drilling program calls for completion prior to breakup, these dikes will be competent during the period of operations. The use of snow berms and herculite eliminates the need for additional gravel and site restoration after the equipment has been removed. 2.2.2 Response page 66 An alert and response procedure will become effective immediately upon the observance of any oil spill. 2.2.2.1 Any employee observing an oil spill of any quantity must immediately notify his supervisor (Mandatory) 2.2.2.2 The supervisor will confirm the spill, its cause and basic nature, and notify the Drilling Supervisor. (Mandatory) 2.2.2.3 The Drilling Supervisor will make a preliminary determination of the seriousness of the spill and initiate corrective and clean up measures. (Mandatory) 2.2.2.4 The Drilling Supervisor will notify the onshore Drilling Superintendent. If assistance is needed the Drilling Superintendent will provide personnel and equipment as needed up to and including the full scope response team as specified in ABSORB Plan Section 2. (Mandatory) 2.2.3 Clean Up Equipment page 67 A portable spill countermeasure building containing sorbent materials and clean up tools will be located near the wellsite. This equipment is designed to clean up minor spills. In the event a larger spill does occur additonal equipment and materials are available through the ABSORB Organization as specified in the Logistics and Equipment Section 6 and 7 of the ABSORB Plan. 2.2.4 Clean Up Operations Clean up operations will be conducted in accordance with Section 3 "Response Action Outline" of the ABSORB manual using the techniques of cleanup as described in Section 8. Operating manuals on spill response and equipment operation will be provided by ABSORB as will the basic organization for logistics and communications. These functions are covered in the ABSORB Manual Sections 2, 5, and 6. Personnel requirements for a Spill Response will be provided as much as possible with Tenneco employees and supplemented with qualified contract people and other company response te~ms as provided for in Section 2.2.1 of the ABSORB Manual. 2.3 page 68 The name, title, business address, telex number, and business and after hours telephone or contact for key personnel who are assigned to elements of the Cross Island No. 1 Well operation and who will constitute the response team organization in case of a spill event cannot be provided at this time. As we assemble our personnel for this well a complete response team organization will be provided as in the following Figure 2-1 and in accordance with ABSORB Manual Section 2. These assignments will be updated during the progress of the well so that current availability and accountability is known by all concerned. 2.4 A communications plan to direct and coordinate clean up personnel is covered in Section 5 of the ABSORB Manual and will provide the basics of such emergency communications requirements. In the case of minor spills, and to initiate mobilization of the more complex ABSORB System, existing communication equipment on the rig and in mobile units will be used. 2.5 An estimate of the size, frequency, and location of the maximum probable and median oil discharge is difficult to predict with any precision. Table 2.1 shows quantities that should be considered as estimates of spill events which might be reasonably conceived. In addition to this table, spill scenarios are provided in much more detail in Section 4 of the ABSORB Contingency Plan. This data includes maximum possible and "worst case" estimates from two different sources. ItAHA(;EN£HT { (spin.r) , OPE~TIOHS I { , [ }~AGER ~AGER I.OGISTIC8 , T~C~IC~ 8~PORT SERVICES CLE~UP [ SUPERVISOR~ SUPERVISOR. ~: SUPERVKSOR SUPERVISOR { ii i ii i i i ii i ~n~TII SLOPE'' ~OR~C~ { NOR~i 8LOP~ ~CliO~Cg [ NORTH SLOPE ANOIORACE OFFSIIO~E SIIORE~.I~ Coordlnatore~ ~ordinators: ' ~ordlnators: Coordfnator~: Coordl~toro~ = ~ordi~tor8: Coordinntorn~ Coordlnutoru: *Comttntcations *Co,narrations *Envlromental *Enviromental °Documentation ' *Docmentation *Contain,at °Hanpowe~ *Nanpower *Safety *Safety '~ovecnm~nt *~over~ent i, 'Recovery 'Recovery : Liaison Liaison {'Equipment/ 'Equipment/ { *Ensineetln8 'Englneett,8 'Storm{e/ 'Storage/ { ~tetlal ~terial 'Security ' 'Security Transfer ~ Transfer 'TraneporLatton 'Transportation 'Aecountlt~ ~ °Accounttn8 'Disposal 'Disposal ', ' Food/Il, using 'Food/Il,using 'Legal/ , 'Legal/ 'Diepereal I 'Dispersal Insurance Xnsurance 'Public 'Public I FIGURE 2- 1 ABSORB RESPO~S~ TE~ ORGA~IZATIO~ i i i iiii ~trolled flow of c=%=lm oil or wall- bore fluid 200 75 595 75 100 200,000 2,000 page 69 The estimated frequency of such events is historically very low. As an indication of this low probability, note the following quotes: "No oil spill in excess of 50 barrels has been recorded during exploratory drilling, to our knowledge, in any offshore area throughout the world," Elmer P. Danenberger, 1976, U.S.G.S. Circular 741 page 9. Further more, "A study for Environment Canada indicated the probability of having a large blowout during exploration in the Beaufort Sea was in the range of 1 in 100,000 to 1 in 1,000,000," S. L Ross, Oilweek, May 19, 1980, page 52. We thus assume the probability of a maximum to median oil discharge on this well to be extremely small. The most probable occurrance would be a minor spill associated with fuel transfer or maintenance and would occur in the fuel storage or power plant areas. These areas are provided with containment facilities and would be easily cleaned up. 2.6 Means of oil discharge detection, including surveillance schedules, leak detection, monitoring systems, spill detection systems and spill detection instrumentation: 2.6.1 Fuel and Lube _ The total operation of the Cross Island well will be under the constant surveillance of both operator and rig supervisors, and daily inspections will be made to assure no oil leaks or minor spills have occured. All personnel page 70 working in the fuel handling area or other areas where spills could occur will be thoroughly trained in handling procedures and how to respond in the event an accidental spill does occur. 2.6.2 Blowout Prevention The source of a major spill would be from a well blowout and all operating procedures at the location, whether automated or directly controlled by Company or Contractor personnel, are specifically designed and organized to prevent such blowouts. The primary method of blowout prevention utilizes hydrostatic pressures exerted by sufficient density drilling mud to prevent undesired flow into the wellbore. In the unlikely event primary well control is lost, the following surface equipment would be utilized for secondary containment of influx into the wellbore. The rig will be equipped with a 20" 2000 psi W.P. annular diverter system installed on 80 ft. of 20" H-40 94# conductor pipe while drilling the 17-1/2" surface hole to 2700'. The diverter lines will be vented in two different directions to provide downwind diversion. After running and cementing 13-3/8" 72# L-80 surface casing at 2700', a page 71 blowout preventer {BOPE} consisting of three 13-5/8" 10,O00 psi W.P. rams, a 13-5/8" lO,000 psi. W.P. annular preventer, and a two-choke manifold will be installed, After installation of the BOPE, it will be thoroughly tested for leaks using diesel fuel. It will be pressured tested and function tested as required in 20 AAC 25.035. This same procedure will also be followed after setting 9-5/8" casing. Automatic and manual monitoring equipment will be installed to detect any abnormal variation in the mud system and drill)ng parameters. A mud logging unit, manned by experienced personnel, will be in continuous use while drilling, and it will monitor formation pressure, hydrocarbon shows, and loss or gain in the mud pits as well as other downhole conditions. In the event that the well "kicks", the BOPE will be used to shut in the well immediately and confine the pressure within a closed system. The casing program is designed so any anticipated formation pressures can be shut in at the surface without a casing failure. The Company representatives assigned to the drill site will have extensive training, together with actual experience in controlling and killing kicks. These personnel will be further supported by well-trained drilling crews approved by the Company. Pressure resulting from a kick will be circulated out using the balanced bottomhole pressure method, and the well will be restored to its nQrmal operating condition. page 72 In the unlikely event that control procedures are unsuccessful and a blowout does occur, emergency steps must be initiated. This usually involves people, equipment and methods dictated by the circumstances. Very often directional wells are drilled for the purpose of killing or controlling the blowout. In the event of such an emergency one of the many rigs in the North Slope area would be made available for drilling the directional well. Adequate area exists on the island for a relief well location, thus response time would be much less than if a gravel island would have to be constructed. 2.7 Procedures for notifying operating personnel, response personnel, and appropriate state and federal agencies are covered in Section 3 and Appendix D of the ABSORB Manual. A copy of the form and reporting guidelines from ABSORB are included here as Figure 2.2 and 2.3. 2.8 A complete inventory of clean up equipment is provided in Section 7 of the ABSORB Manual. 2.9 The use of chemical collectants and chemical dispersants for the use of oil discharge control is thoroughly covered in Section 8 of the ABSORB Manual. 2.10 Response times to a spill will depend on the source and severity of the spill and many other conditions that may exist at the time of the spill. Small spills can be reacted to immediately, then contained and cleaned up with personnel and equipment at the well site. Other spills may require the obtaining of additional personnel and equipment. The I. SPILL DATA TIME OF CALL PERSON I~EPORTING SPILL AFFILIATION SPILL LOCATION (Specify) DATE EST. GRAVITY Yes Member Company Non-Member Company Government Agency TYPE OF OIL [_--] No SPILL SOURCE (Blowout, Tank rupture, etc.) VOLUME/FLOWRATE FLOW STOPPED? · SPILL DESCRIPTION (Into Water? Ignited? Areal Extent? Etc.) ACTIONS TAKEN (Briefly}- EQUIPMENT DEPLOYED (Major Pieces); i,. , AGENCIES NOTIFIED II. ENVIRONMENTAL CONDITIONS AT SITE WIND (Speed ~ Direction) TEMPERATURE VI S I B I L I TY ICE CONDITIONS SEA STATE ( ]NVIRONAfENTAL DAMAGE (Real or Potential) 5-10 - i ~ i i i! ~ll i iii I I I I I II I I f I I II II II III I I I i~1 AGENCY SPILL LOCATION U.S. COAST U.S. ENVIROI~ENTAL U.S. GEOLOGICAL ~ DEPT. OF AK OIL & GAS GUARD PROTECTION AGENCY SURVEY ENVIRONMENTAL CONSERVATION CON S ERVAT ION COMlq I S S ION i_ L L J I I II I I L I ON LAND ONLY ~ 1/ ~,~ ~ 2/ ON LAND BUT THREATENING OR IN INLAND sURFACE WATER ~ ~ 1/ ~,~ ~ 2/.~ i , i ON WATER (Within 3- nautical-mile limit} ~ ~ ~ 2/ ON WATER (Between 3- and 200-nautical-mile ~ ~ 1/ limit} ~- NOTIFICATION REQUIRED ~ I/If oil ts from a well on a federal oil lease 2/If otl is from a well on a state~oil lease II Jlllll "" I" ' I ' I] '1 ' '1'1' I I 'i I il I I I ! III I'~ I II I I ,~ tl , FIGURE 2.3 THEGOVERNMENTBEAUFoRTNOTIFICATIONLEASE SALE AREAREQUIRE~{ENTS FOR SPILLS IN Page 1 of 2 ~ I I I I III I J I I £ I I I I I I I I I I I~lll ~ ll~ ii m i i i i i ii ii i 31 i~1~ J il ~ i i i i i i ii i i , SPILL VERBAL i PHONE 14RITTEN ' AGENCY SIZE REPORT NU}IBER REPORT i U.S. COAST GUARD All Spills Immediately (211) ZENITH 5555 Recommended but or 271-5137 not required U.S. ENVIROI{HENTAL All Spills Immediately (211) ZENITH 5555 For facility PROTECTION AGENCY or 271-5083 (Days) requiring SPCC Plan { 344-9]27 (Nights) if spill is · 1000, : i gallons or if spill {{ i is second spill in , ' i I 12 months ~.S. GEOLOGICAL >_ 1 cu. meter (6.3bbl) Immediately 271-4348 (Days) All spills (Form SURVEY ~ 271-4303 (Nights) 9-1880) < 1 cu. meter (6.3bbl) 14tthin 12 hours Ali OIL & GAS Water : ' CONSERVATION , CO~IlSSION )55 gal or 1000 sq. ft. sheen Immediately (211) ZENITH 9300 i 14ithtn 15 days of or 452-1714 (Fair- I end of cleanup Hazardous material banks) operation other than oil Immediately < .5 pt or < 100 sq. ft. 7 days { All other water spills 24 hours i Land i , >55 gal 5 hours (211) ZENITH 9300 t~ithin 15 days or 452-1714 (Fair- of end o! 10 to 55 gal 24 hours banks) cleanup operation <10 8al 7 days Any other hazardous ma ce r iai Immed ia lely AK DIV. OF ~11 Spills Immediately 279-1433 Within 5 days of I OIL & GAS spill report I CONSERVATION { ,. , , , , , *See Section 2.3.3 for details of report requirements. Il i~1 Ill II[, ...... !l I' i I I ! Il] ....... ' Il ' " I I I I I , Ill ill , · I '' I~I I I .... I 'l '"[' ~' I ' , FIUURE 2.3 gOYERNMENT NOTIFICATIU~ REQUIREUENTS FOR SPILLS IN Page 2 of 2 (Cont' d) THE BEAUFORT LEASE SALE AREA i i ii ii i · I III III I ]1 I I I I I Il iii i I I I IIII i I SPILL VERBAL PHONE 14RITTEN AGENCY SIZE REPORT NU}IBER REPORT U.S. COAST GUARD All Spills Immediately (211) ZENITH 5555 Recommended but or 271-5137 not required U.S. ENVIROI{HENTAL Ali Spills Immediately (211) ZENITH 5555 For facility PROTECTION AGENCY or 271-5083 (Days) requiting SPCC Plan 344-9327 (Nights) if spill is · 1000 gallons or if spill: is second spill in 12 months b.a. GEOLOGICAL ~ I cu. meter (6.3bbl) Immediately 271-4348 (Days) All spills (Form SURVEY 271-4303 (Nights) 9-1880) < 1 cu. meter (6.3bbl) Within 12 hours . , , · AK OIL & GAS Water CONSERVATION COt~tI$SlON )55 gal or 1000 sq. ft. sheen Immediately (211) ZENITH 9300 14ithin 15 days of or 452-1714 (Fair- end of cleanup Hazardous material banks) operation other than oil Immediately < .5 pt or < 100 sq. ft. 7 days All other water spills 2~ hours Lan4 >55 gal 5 hours (211) ZENITH 9300 Within 15 days or 452-1714 (Fair- of end o! 10 to 55 gal 24 hours banks) cleanup operation <10 8al 7 days Any other hazardous material Immediately AK DIV. OF ~ll Spills Immediately 279-1433 Within 5 days of OIL & GAS spill report CONSERVATION , ,, , page 73 response to several scenarios of spill occurrances is covered in great detail in Section 4 of the ABSORB Manual. 2.11 Section 8.4 of the ABSORB Manual discusses in detail disposal alternatives. This data will be used as a guide line in the event a spill does occur and disposal of oil and clean up materials is required. 2.12 Tenneco as a member of ABSORB will participate in the training prescribed in Appendix C of the ABSORB Manual. Through this organization training, field exercises, workshops, seminars, and operating manuals will be available to assure our response personnel are properly prepared in the event of a spill. OSI ~5289 Santa Barbara California May 1980 ATTACHMENT D Prepared for: TENNECO OIL COMPANY Prepared by: OCEANOGRAPHIC SERVICES, INC. · ENVIRONMENTAL CONDITIONS IN THE VICINITY OF CROSS ISLAND INTRODUCTION Table of Contents Pa~e SITE DESCRIPTION General Geotechnical Considerations Summer Conditions Winter Conditions Area Wildlife Area Fish 1 1 3 3 4 11 13 ICE LOADS AND RIDE-UP 14 ICE RUNWAY 15 ICE ROAD 17 REFERENCES Attachment ~1 - ADDITIONAL COMMENTS ON ICE RIDE-UP Attachment #2 - ADDITIONAL COMMENTS ON THE ICE ROAD List of Tables Table Page FREQUENCY OF EASTERLY AND WESTERLY STORMS ALONG THE NORTH SLOPE OCEANOGRAPHIC DESIGN CRITERIA FOR A 30-FOOT WATER DEPTH SITE IN STEFANSSON SOUND SIGNIFICANT SEASONAL FAST ICE EVENTS WINTER ICE MOVEMENT STATISTICS FOR STEFANSSON SOUND SUMMARY OF BIOLOGICAL EVENTS IN THE BEAUFORT SEA 10 List of Figures Figure 1 LOCATOR CHART BEAUFORT SEA ICE THICKNESS CURVE 18 ENVIRONMENTAL CONDITIONS IN THE VICINITY OF CROSS ISLAND INTRODUCTION The report presents an overview of the environmental conditions in the vicinity of Cross Island. Attention has been focused on those environmental conditions that will have an impact on the drilling of an exploratory well from Cross Island next winter. Consideration has been given to site description; ice, oceanographic, and meteorological conditions affecting site preparation, mobiliza- tion, drilling, and demobilization; and the biological impact of drilling activities on wildlife and fish in the area. An attempt has been made to present the discussion in a format that can be directly used in Tenneco's operational plan. SITE DESCRIPTION ,, General Cross Island is a member of the Midway Islands group located about 18 miles north of Prudhoe Bay (Figure 1). The island is semi- ~ circular in plan, about 3 miles long, and 150 yards at its widest point. Maximum elevations on the island are 7 to 8 feet. The island is primarily composed of silt and sand, and coarse gravels may be found at higher elevations. There are a few patches of sparse vegetation on the island (Gavin, 1976). During the summer the island may be subjected to waves and surge caused by severe summer storms (Reimnitz and Maurer, 1979). In winter large ice pile-ups have been observed on the island's northern beaches (Kovacs and Sodhi, 1979). It should also be noted that Cross Island has been identified as an important bird breeding and molting site during the summer (Divocky, 1978; and Gavin, 1976). 71°00' 70°30~ 70°00' II ii I 1,3 ' I ~2 ~s ,~ 0 10 20 ' '-' ~ 22 Depths in Fathoms 16 t ' I t ~ 0 17 ~ 7 ~ 12 22 22 20 ~ 15 13 26 28 il 15 . 13 '""~"-~~ ....~ ...... ' 'i " .... - ". / ' ' ' '~ '~ ~ ~' '"' ,,' ' .. .... ~'" ~ '-. '. -'-- --' ",.~ .-o,~_ ~ ~ 'J ~9 - / ~~ )_ . . % . '.. , ~ .......... ~- ~- .. /~ / ( ' .~- ~ ~ -~ I~"%, ' ~ - - ~ -'~ ~ - ~0 tIL~ ~-7~e"~/'~~. ,-.,,,, ',..~ '~.,¢ ' .' .,,*; - -,,,'.~ '; /t : .,.: I/// ', Figure 1 Nautical Miles LOCATOR CHART (Cross Island indicated by arrow) ! I I 150° 149 o 14 8° 16 7 o Ih 6 ° Geotechnical Considerations Cross Island is a recent constructional accumulation (lag deposit) of sand and gravel entirely derived from the Pleistocene Flaxman Formation (consolidated marine sandy silt containing dropstones of Canadian origin). The island appears to be migrating southward en masse at rates of 12 to 24 feet per year. The older parts of the island, covered by vegetation, are underlain by ice-bonded permafrost at depths of about 6 feet. Most of the island does not have permafrost near the surface, that is, within 30 feet (Rogers and Morack, 1978). Based on a borehole obtained just northeast of Cross Island by Harding-Lawson Associates (1979), relict permafrost is expected about 60 to 70 feet below the island surface. Numerous mounds, up to 5 feet high, extend as much as 100 feet inland from the northern beach. These mounds were formed during previous ice pile-up and ride-up events (Kovacs and Sodhi, 1979). Problems may be encountered with gas hydrates during drilling. Katz (1971) has indicated that gas hydrates may be present at depths between 1900 and 3400 feet in the Prudhoe Bay area. The sediment source for Cross Island is no longer evident. The ~ island is a lag deposit and is regarded as being irreplaceable by arctic geologists. Removal of gravel from the island would perturb the local oceanographic and biological regime. Summer Conditions During August and September the area around Cross Island is usually ice free and the island may be subjected to waves and surge caused by easterly and westerly storms. Easterly storms (winds greater than 25 knots) typically last for 3 to 5 days. They result in offshore ice movement and negative surge. The low water levels often ground boats and barges in shallow water areas. Westerly storms are usually accompanied by strong west to northwest winds (greater than 25 knots) and usually last 2 to 3 days. These storms result in positive surge and must be considered in the design height of drilling platforms to be used in the summer. The average frequency of easterly and westerly storms by month is given in Table 1. Waves during the summer are generally less than 2 feet high and rarely greater than 8 feet in height (Brower and others, 1977). Extreme statistics on oceanographic conditions have been reported by Heideman (1979). Some results from two hindcast studies performed for a 30-foot water depth site in Stefansson Sound are given in Table 2. The Splash II model was used to hindcast storm surges and Bretschneider's shallow-water wave generation theory was used to calculate the height of storm wages. It is expected that the storm surge levels would be slightly less for Cross Island and that the storm waves would be slightly higher. The estimated 100-year storm surge level agrees favorably with observed results of the 1970 North Slope storm reported by Reimnitz and Maurer (1979). Wood carvings from a cross erected on Cross Island in 1889 were washed away during that storm. Winter Conditions Freezeup along the North Slope takes place in late September or early October. By the middle of October the ice is usually continuous inside the barrier islands and by early November the ice extends seaward of the barrier island to the pack. During freezeup the thin ice may be susceptible to large movements, however, as the ice thickens it becomes more stable. Over ice transport inside the barrier islands is generally safe by late December when the sheet ice is about 3 feet thick. The ice remains safe for travel in Stefansson Sound until the rivers overflow the sea ice in late May. Immediately north of Cross Island the ice may remain dynamic throughout the winter and is usually Table 1 FREQUENCY OF EASTERLY AND WESTERLY STORMS ALONG THE NORTH SLOPE (after Selkregg, 1976) Month August September October Easterly 3.3 2.8 1.5 Westerly 1.0 1.3 1.0 Table 2 OCEANOGRAPHIC DESIGN CRITERIA FOR A 30-FOOT WATER DEPTH SITE IN STEFANSSON SOUND (after Heideman, 1979) Return Period (Years) Storm Significant Wave Maximum Wave Surge Height Height (Feet) (Feet) (Feet) 25 4.4 12 22 100 6.3 14 27 highly deformed. Breakup takes place in July and by the end of July the area of interest in usually surrounded by open water. Average dates of significant seasonal fast ice events are given in Table 3. These data were compiled by Barry (1977) from four years (1973-76) of Landsat satellite imagery. In a subsequent study, Barry (1978) reported that river overflooding of the sea ice was first preceded by darkening of the river channels (average date of 22 April). Stringer (1979) has characterized the ice inside the barrier islands as being generally smooth, often formed in place with little or no deformation. Occasionally, the ice is broken while it is still thin and forms a cover of floes surrounded by a matrix of younger broken ice. These small ridges are typically less than 2 feet high (Cox, personal communication) and present little difficulty to surface travel. Even though the ice inside the barrier islands is generally smooth from year to year, it can exhibit significant surface roughness. During 4-9 November 1978 storm ridges up to 13 feet high were formed inside the barrier islands. This storm was then followed by another event which resulted in the formation of some minor pile-ups on the south side of the barrier islands~ (Kovacs and Weeks, 1979). Larger ridges, such as these, are typically isolated and may be avoided through route selection by ice reconnaissance flights. Ice movement inside the barrier islands after November is certainly limited. Ice movements statistics for a site in the middle of Stefansson Sound have been presented by ~Fneeler (1979) and are given in Table 4. The data were compiled from three winters of ice movement measurements obtained in the area by petroleum operators. The maximum observed ice movement or excursion in Stefansson Sound was 14 feet. The maximum measured rate of movement was 5 feet per hour. Estimates of the 25 and 100-year ice movement rate and excursion were also given. Table 3 SIGNIFICANT SEASONAL FAST ICE EVENTS Average date (+-10 days) of significant seasonal fast ice events from Landsat imagery (after Barry, 1977) Event New ice formation, freezeup First continuous ice River overflooding of sea ice Appearance of melt pools on ice First 6penings in ice End of stable period, breakup Coastal zone ice free Average Date 3 October 15 October 25 May 10 June 29 June 7 July 31 July Table WINTER ICE MOVEMENT STATISTICS FOR STEFANSSON SOUND (after Wheeler, 1979) Return Period 25-Year 100-Year Maximum Observed Rate (Feet/Hour) 6 8 5 Excursion (Feet) 50 87 14 The ice conditions immediately north of Cross Island are signifi- cantly different from those observed in Stefansson Sound (Stringer, 1979). The ice just offshore is usually highly deformed consisting of large shear ridges and dynamic flaw leads. These ridges have sail heights of several tens of feet and are up to 10 miles long (Kovacs and others, 1976). During March-May 1976, a large multi-year shear ridge was investigated in 45 feet of water just north of Cross Island. Maximum ridge heights were up to 40 feet. This ridge had formed in the fall of 1974 and remained in the area through August 1976 (Kovacs and Weeks, 1976). Similar large features have also been observed off Narwhal Island in 60 feet of water. During a 16-18 March 1979 storm, a grounded ridge 70 feet high and over 1000 feet long was formed. Half a mile of ice movement was observed to have taken place about 5 miles to the west of this site (displaced seismic lines) . Ice movements in water depths less than 60 feet just north of Cross Island have been described by Agerton and Kreider (1979). During the 1976-77 winter, movements in excess of 150 feet were · measured during January and April storms. Movements measured farther offshore by OCSEAP investigators were even greater (Tucker and others, 1978). Large ice motions can occur any time during the winter north of the barrier islands if the ice sheet is not suitably pinned by large grounded ridges or multi-year ice. Large ice pile-ups also have been observed on the northern beach of Cross Island. In 1974 a large pile-up having a mean height in excess of 20 feet was studied by Kovacs (Kovacs and Sodhi, 1979). The ice blocks in the pile-up were 20 inches thick. Ice just offshore was 21 inches thick indicating'that the pile-up had recently formed. 10- Area Wildlife A summary of annual biological events in the Beaufort Sea is presented in Table 5 (from Broad, 1980). Available information indicates that little wildlife will be present on or around Cross Island during the anticipated operations period (15 October through 15 May). The primary residents in the area during winter are polar bears and ringed seals. Occasional visitors are arctic foxes and a few bird species (willow ptarmigan, snowy owl and common raven). Polar bears and ringed seals reproduce during the winter. Major land denning areas of the polar bear are along the banks of rivers, especially in Cambden Bay. Denning areas in landfast ice are believed to be distributed widely along the Beaufort coast from Jones Island eastward beyond Flaxman Island. Polar bear tracks have been sighted on Cross Island during winter (Gavin, 1976). Ringed seals are present in the landfast ice zone during winter. They are known to be in the area from historical hunting records. The depth beneath the ice adjacent to Cross Island is limited during winter, so it is doubtful that any seals will be present near the drilling site during drilling operations. Several other organisms are present on and around Cross Island during the summer or "non-drilling" season only, and therefore, should pose no restrictions to winter drilling operations. Benthic forms retreat to greater depths with the onset of freezeup to escape crushing by encroaching ice. Plankton is plentiful during the brief open water period. ~{ost of these organisms are eaten by fish and seals while those that survive overwinter under the ice bear young the following year (Carey, 1978). Birds, primarily common eiders, glaucus and sabine gulls, and arctic terns, nest on Cross Island from June through August. However, they do not occupy the island until the onset of breakup 11 MICROB. ACTIVITY MICRO ALGAE ZOO- PLANKTON BENTHOS EPI- BENTHIC CRUSTACEA MACRO ALGAE FISH BIRDS MAMMALS EVENTS OCTI , Table 5 SUMMARY OF BIOLOGICAL EVENTS IN THE BEAUFORT SEA (from Broad, 1980) · Declining iM sedimenl and woler ~o'lumn N- Fixo lion ~ dawn winler Lows · ~-,-Increotied aclivity in sedirnenl, Slight decline .............. : .............. ~ Increase ......... ~ Zncreose - -Peak - - Decrease Only smoll~~r,Become flogelloles frozen tn ice Maximum nulrienl concentrations Ice ol~loe Bloom in H20 Blooms- Maximum - Sloughs off Copepods p!'~dominonl Polychoete larvae ~ound Copepods w/egg sacs polychoele I~ born(~¢le larv(~e common Cyclopoids predominole under ice Reduced feeding Increased activity filter feeders .................. ]'ce ossocioled polych~3eles --- Decreases . Nematodes incr. under ice Spawning Crusloceo leave nearshore ~ Increased inciden(~e oceanic spp. Amphip, ods, mysids · ovlgerous Onislmus halches · oclive in sell ice Abundanl · High aclivily Saduria Mysids move offshore - still ovig~rous ];ce fauna disappears Crusloceo relurn Io neorshore and lagoons Rapid growth of Lominctria , Kelp release metospores Red algae reprod~Jce Pholosynlhesis high .: Arctic cod "Green"- ~p(~wn- eggs floal(under ice)-- hatch Anodromous ~.J~.J~ Predominonlly marine ~_p.~_. Marina ~pp...: enler slreams in neorshore/inshore exit Simpson Lagoon Boreal smell" remain Myoxocepholus spown~ - Eggs sink Ltporids spawn : - No birds sing -- Anodromous spp in leads along 'shOre ~ IOG-IO7 IE]lrds IO4 Birds in Only slragglers Jeff enter Beoufor! neorshore Wesl migroti0n Ringed seals feed of Bowheads on cod Polar bear · denning Ringed seals Pupping East-offshore migration establish lalr~ Nursing of Bowheods ~Poldr bears Seals artier emerge tram S I~ W Shore- fosl .. ice forming~ -' FULL WINTER CONDITIONS - High sedi- ]~ncreosing solinily on'd inereOSiAg oil ,sensiliViy menlolion ';:. t :: ^ Maximum' ice thi(~kness · ' . ~ Maxima ~ Turbidlty Increases · (after 15 May) when a moat forms around the island to protect them from predation by arctic foxes (Schamel, 1978). Many birds-- old squaws, red and northern phalaropes, sabine's gulls, snow geese and eiders--use many of the barrier islands, including Cross Island, for molting and staging prior to their southward migration. All birds, except a few stragglers, are gone from the North Slope by 15 October. Bowhead whales migrate during the proposed non-drilling season. Their north-northeastward movement takes place from May to June primarily in leads offshore in the flaw zone. They migrate west- ward during September and October, generally seaward of the barrier islands (Braham and others, 1978). There is some concern that young bowhead whales, because of their relatively small size, will be able to come near or even inside the barrier islands. However, it is unlikely that they will remain in the area later than October. Area Fish Over 30 species of fish inhabit the nearshore waters along the Alaskan North Slope. Areas of greatest species diversity are the deltas of the large rivers. The species can be classified into~ three broad categories: (1) freshwater species which reside in rivers; (2) anadromous species, those that tolerate both salt and fresh water and migrate from one to the other during their life cycle; and (3) marine species, those that remain in brackish or marine waters throughout their lives. Three anadromous and two marine species account for most of the fish present in near- shore waters of the Alaskan Beaufort Sea. These are: · Anadramous Arctic cisco Least cisco Arctic char 13 Marine Fourhorn sculpin Arctic cod During the summer the anadromous species migrate from the rivers to the nearshore deltaic regions to feed extensively. In general these fish do not migrate far offshore and most are found along the mainland coast or around the island perimeters. The reason for this is not known entirely, but the shoreline waters tend to be slightly warmer and less saline than other areas. Little is known about fish overwintering habits. In general, anadromous fish leave the coastal waters and return to overwinter in deep or spring-fed channels in the deltas of major river mouths. Presumably marine species migrate to deeper water offshore, though the fourhorn sculpin is known to use the Colville Delta. Arctic cod are known to be present during winter, but their under-ice distribution is unknown (Carey, 1978). Ice surrounding Cross Island undoubtedly will be grounded, and therefore, it is unlikely that any fish will be present in the vicinity of the proposed drill site. ICE LOADS AND RIDE-UP During the course of the drilling operation the island'may be susceptible to large lateral ice loads and ice ride-up caused by movement of the surrounding ice sheet. However, as it is planned to locate the well near the widest portion of the island and begin drilling after 1 January, the integrity of the well should not be threatened by ice movement. Drilling operations will commence in early January. By this time the surrounding ice has stablized and the island is frozen both near the surface and at depth. As the bonded sediment is stronger 14 than the surrounding ice, and the shearing resistance of the island is greater than the anticipated ice loads, the ice will fail should it move against the island. Ice ride-up is not considered to be a problem after December. Typically, ice ride-up and pile-up occur during freezeup and breakup when the ice is highly mobile (Kovacs and Sodhi, 1979). After December, the ice around Cross Island has stabilized. Immediately around the island the ice will have frozen to the sea floor to the 3-foot depth contour. Grounded shear ridges north of Cross Island also will pin the ice sheet and protect the island from the pack. The southern and central portions of the island may be protected from ride-up by pile-ups which had formed on the island perimeter during freezeup. An advancing ice sheet would either join against the pile-up or ride up to the top of the pile and fail. Existing ice push mounds on the beach will increase the sliding resistance of an advancing ice sheet and induce failure. Even though ice push mounds and pile-ups have been observed on the perimeter of Cross Island, the island has not been over-ridden .o by ice in the recent past. The USGS survey tower and the 30-year old cabin on the island have never been encroached upon by ice. Drilling operations have also been safely conducted on'other natural islands near Prudhoe Bay (Gull, Niakuk, and Flaxman Islands). Consideration is being given to installing an ice movement station north of Cross Island to warn personnel of any ice motion during the drilling program. The ice movement monitoring system causes an alarm to sound at the drill site should the ice move greater than a preset amount. ICE RUNWAY An ice runway will be constructed on the south side of Cross Island in November and early December to allow mobilization of the well 15 by C-130 aircraft. The ice runway will be 5000 feet long, 100 feet wide, and grounded on the sea floor. The natural ice sheet will be artificially thickened by flooding the ice surface with thin layers of sea water. Artificial sea ice, constructed by the controlled flooding of sea water on the ice surface, has been used to build a number of ice structures. These included: ice roads and bridges (Kivisild and others, 1975); ice runways and aircraft parking aprons (Dykins and others, 1962; Dykins and Funai, 1962; and Kingery and others, 1962); ice wharves (Barthelemy, 1975; and Kirkpatrick, 1974); floating ice drilling platforms (Baudais and others, 1974; and Masterson and Kivisild, 1978); and grounded drilling ice islands (Utt, 1978; and Cox, 1979). During the 1978-79 winter Sohio constructed an artifically thickened ice road to Reindeer Island and Exxon built an ice island using various construction techniques. Considerable expertise and technology are available to construct the ice runway. The runway will be constructed by either confined or free flooding. In confined flooding, snow berms are used to retain the flood water which is pumped from under the ice surface. This techniqu% reduces the amount of water required for construction and allows the operator to 'produce a pad of a desired geometry. In general, berms are compacted to reduce seepage and are placed to minimize deflection and cracking of the surrounding ice sheet. In free flooding, the flood water is allowed to seek its own distribution pattern. The extent of the flood is primarily controlled by the rate and direction of flow, wind and air temperature, and the deflection of the ice sheet. Even though more water is used for construction, time is saved by not having to construct dikes or berms. Relative to confined flooding, deflection and cracking of the surrounding ice sheet is reduced. 16 Average buildup rates of 1.5 inches per day can be achieved easily in November and December using lightweight, portable pumping equipment. As the natural ice sheet will be about 1 foot thick early in November, an ice runway up to 6.6 feet thick can be constructed by 15 December. Greater thicknesses can be achieved under favorable conditions (2 inches per day) or by using larger submersible pumps (2 to 4 inches per day). A bathymetric survey will be conducted at possible runway sites this summer to determine the required ice thickness for the runway and the most suitable construction technique. ICE ROAD Once the sea ice in Stefansson Sound has reached a safe thickness, the drilling operation will be supplied via an ice road from Prudhoe Bay to Cross Island. The ice road will also be used to demobilize the well in late March and April. An analysis of the "safe ice thickness" is academic for most ice road traffic. North Slope construction firms and contractors have indicated that the ice must be about 3.5 to 4 feet thick before they will operate heavy equipment (25-50 tons) on the ice. Based on..the ice thickness data compiled by Schell (1974), this thickness is usually attained by early to late January (Figure 2). Ice stress calculations will be performed for heavy loads (rig and substructure). A safety factor of 3 in these calculations has proved to provide a realistic margin of safety. The ice is regarded as being safe for travel until late May when the ice near the coast is flooded by river overflow. Other factors besides the flexural strength and ice thickness affect the bearing capacity of the ice sheet. Consideration will be given to vehicle speeds, fatigue, and cracks. Vehicle speeds will be maintained below the critical velocity that results in the formation 17 Figure 2 BEAUFORT SEA ICE THICKNESS CURVE (after Schell, 1974) 0.0 0.5 ~ LO 1,5 2,0 OCr. NOV. DEC. dAN. FEB. MA R. APR. I I I I I MA Y 1CE THICKNESS- ARCTIC COAST (CompoJI/m do/o 19;'0 o HARRISON BAY - SIM'SON LAGOON · ELSON LAGOON- DEASE INLET 0o · o · o °o'~ ~ *·' · o 0 0o o O0 ,o of a hydronamic wave in the underlying water. Velocities in excess of the critical velocity can result in increased stresses in the ice sheet and failure. Fatigue due to repeated loading may produce unwanted cracks in the ice. Consideration is being made to make the ice road of sufficient width so that the traveled path can be changed periodically to allow for the recovery of fatigued areas. Wet cracks will be avoided as the bearing capacity of the ice sheet is one-half that of a continuous ice sheet. Factors affecting the bearing capacity of an ice sheet and the use of ice roads have been described adequately by Assur (1961), Gold and others (1958), Gold (1971) Michel (1978), and Nevel (1970). Ice roughness should not present a problem for over-ice transport in Stefansson Sound. Generally, the ice is smooth with low relief. Larger ice features or deformed areas can be avoided by flying an ice reconnaissance prior to route selection. 19 REFERENCES Agerton, D. J. and Kreider, J. R. (1979) Correlation of storms and major ice movements in the nearshore Alaskan Beaufort Sea, POAC '79 Proceedings, Vol. 1, p. 177-189. Assur, A. (1961) Traffic Over Frozen or Crusted Surfaces, Proceedings of the 1st International Conference on the Mechanics of Soil-Vehicle Systems, Torino, Italy, pp. 913-923. B~rry, R. G. (1977) Study of climatic effects on fast ice extent and its seasonal decay along the Beaufort-Chukchi Coasts, OCSEAP 1977 Annual Report, Vol. XIV, Transport, p. 574-632. Barry, R. G. (1978) Study of climatic effects on fast ice extent and its seasonal decay along the Beaufort-Chukchi Coasts, OCSEAP 1978 Annual Report, Vol. IX, Transport, p. 604-680. Barthelemy, J. L. (1975) The man-made ice wharf, CEL Technical Note TN-1376, p. 18. Baudais, D. J.; Masterson, D. M.; and Watts, J. S. (1974) A system for offshore drilling in the arctic islands, Journal of Canadian Petroleum Technology, July - September 1974, p. 1-12. Braham, Howard; Kingman, Bruce; Leatherwood, Stephen; Marguette, William; Rugle, David; Tillman, Michael; Johnson, James; and Carrol, Geoff (1978) Preliminary report of the 1978 spring bowhead whale research program results, Marine Mammal Division, NMFS, NOAA, Seattle, 98115. Broad, A. Carter (1980) Biological events - October through June - Beaufort Sea, In OCSEAP Special Bulletin #29, pp. 36-39. Brower, W. A., Jr., and others (1977) Climatic Atlas of the Outer Continental Shelf Waters and Coastal Regions of Alaska: Volume III, Chukchi - Beaufort Sea," NOAA/BLM, AEIDC Publications B-77. Bureau of Land Management (1979) Beaufort Sea: Final Environmental Impact Statement, VI (pp. 59-90) and VIII (Graphics 2-9). Carey, Andrew G., Jr., (ed.) (1978) Environmental Assessment of the Alaskan Continental Shelf, Interim Synthesis: Beaufort/Chukchi Seas, Part 6 (Marine Biota), (P 1 ankton/Ben thos/Fish ) . Cox, G. F. N. (1979) Artificial ice islands for exploratory drilling, in POAC '79 Proceedings, Vol. 1, pp. 147-162, Trondheim, Norway, 13-18 August 1979, Norwegian Institute of Technology. Cox, G. F. N., Personal co~~ication Research Geophysicist, Divocky, G. J. (1978) Breeding Bird Use of Barrier Islands in the Northern Chukchi and Beaufort Seas. In Environmental Assessment of the Alaskan Continental Shelf, Annual · Reports of Principal Investigators for the year ending March 1978, Vol. I, pp. 482-569. Dykins, J. E. and Funai, A. J. (1962) Point Barrow Trials - FY 1959; Investigations on thickened sea ice, NCEL Technical Report R185, p. 142. Dykins, J. E.; Stehle, N. A.; and Gray, K. O. (1962) Point Barrow Trials - FY 1960, Free-flooded and ice-aggregate-fill sea ice, NCEL Technical Report R218, p. 77. Eley, T. and L. Lowry (ed.) (1978) Environmental Assessment of the Alaskan Continental Shelf, Interim Synthesis: Beaufort/Chukchi Seas, Part 4, Marine Mammals, pp. 134-151. Gavin, A. (1976) Wildlife of the North Slope: The Islands Offshore Prudhoe Bay, the Snow Geese of Howe Island, the Seventh Year of Study, Atlantic Richfield Company, pp. 71. Gold, L. W. (1971) Use of Ice Covers for Transportation, Canadian Geotechnical Journal, Vol. 8, pp. 170-181. Gold, L. W. and others (1958) Deflection of Plates on Elastic Foundations, Transactions of the Engineering Institute of Canada, Vol. 2, pp. 123-130. Harding-Lawson Associates (1979) USGS Geotechnical Investigation Beaufort Sea - 1979. Heideman, J. C. (1979) Oceanographic Design Criteria, Technical Seminar on Alaskan Beaufort Sea Gravel Island Design, Exxon Company U.S.A. Katz, D. L. (1971) Depths to which frozen gas fields (gas hydrates) may be expected, Journal of Petroleum Technology, Vol. 23, No. 4, p. 419-423. Kingery, W. D.; Klick, D. M.; and Dykins, J. E. (1962) Sea ice engineering, summary report, Project Ice Way, NCEL Technical Report R159, p. 223. Kirkpatrick, T. W. (1974) Ship operations, Deepfreeze '74, Antarctic Journal of the United States, Vol. 9, No. 4, p. 180-183. Kivisild, H. R.; Rose, G. D.; and Masterson, D. M. (1978) Salvage of heavy construction equipment by a floating ice bridge, Canadian Geotechnical Journal, Vol. 12, No. 1, p. 58-69. Kovacs, A. and Weeks, W. F. (1978) Dynamics of nearshore ice, OCSEAP 1978 Annual Report, Vol. IX, Hazards, p. 11-22. Kovacs, A. and Sodhi, D. S. (1979) Shore ice pile-up and ride-up, Paper presented at the Workshop on Problems of the Seasonal Sea Ice Zone, Naval Postgraduate School, Monterey, California, 26 February - 1 March 1979. Kovacs, A. and Weeks, W. F. (1979) Dynamics of nearshore ice, OCSEAP 1979 Annual Report, Vol. VII, Transport, p. 181-207. Masterson, D. M. and Kivisild, H. R. (1978) Floating ice platform: offshore oil exploration, Paper presented at the ASCE Annual Convention, Chicago, Illinois, 16-20' October 1978. McKay, A. R. (1970) Man-made ice structures for arctic marine use, in IAHR Symposium, Ice and its action oX hydraulic structures, Reykjavik, Iceland, 7-10 September 1970, Section 2.9, p. 11. Michel, B. (1978) Ice Mechanics, Les Presses de l'Universite, Laval, Quebec. Nevel, D. E. (1970) Moving Loads on a Floating Ice Sheet, CRREL Research Report 265. Reimnitz, E. and D. K. Maurer (1979) Effects of Storm Surges on the Beaufort Sea Coast, Northern Alaska, Arctic, Vol. 32, pp. 329-344. Rogers, J. C. and Morack, J. L. ~1978) Beaufort seacoast perma- frost studies, OCSEAP 1978 Annual Report, Vol. XI, Hazards, p. 651-688. Schamel, D. (ed.) (1978) Environmental Assessment of the Alaskan Continental Shelf, Interim Synthesis: Beaufort/ Chukchi Seas, Part 5, Birds, pp. 152-173. Schell, D. (1974) Seasonal variation in the nutrient chemistry and conservative constituents in coastal Alaskan Beaufort Sea waters, In Environmental Studies of an Arctic Estuarine System, University of Alaska, Institute of Marine Sciences, Report No. R-74-1, p. 233. Selkregg, L. L. (1976) Alaskan Regional Profiles, Arctic Region, AEIDC. Tucker, W. B.; Weeks, W. F.; Kovacs, A.; and Gow, A. J. (1978) Nearshore ice motion at Prudhoe Bay, Alaska, In A Symposium on Sea Ice Processes and Models, 6-9 September 1977, University of Washington, Seattle, Washington, p. 23-31. Utt, M. E. (1978) Grounded ice islands, Paper presented at the Beaufort Sea OCSEAP Synthesis Meeting, Barrow, Alaska, 24 January 1978. Wheeler, J. D. (1979) Sea Ice Statistics, Technical Seminar on Alaskan Beaufort Sea Gravel Island Design, Exxon Company U.S.A. Attachment #1 ADDITIONAL COMMENTS ON ICE RIDE-UP Ice ride-up is of great concern to North Slope natives and will certainly be an issue during presentations in Barrow. Ride-up or "Ivu" has been observed by the Inupiat on many occasions in the Barrow area. The advancing ice sheet has damaged structures and taken lives. Natives have reported that even the top of barrier islands have been sheared off by ice. The most comprehensive work on the nature and occurrance of ride-up is that of Kovac$ and Sodhi (1979). As the distribution of this report is limited, a copy is attached for your information and files. The report has been described as "bad news" by Exxon personnel during the Gravel Island Technical Seminar. Kovacs and Sodhi show that ride-up is a common event and that it can take place during the winter even when the ice is in excess of 4 feet thick. A summary of observed ride-up events along the north coast of Alaska is included in Table lA. Ice has also been observed to have ridden- up and on top of 30-foot high bluffs near Barrow. As ride-up events usually last less than one-half hour, little time is available f~r evasive action. Fortunately, the ice stresses associated with ride-up are low, less than 50 psi, and defensive measures may be taken to minimize the risk of ride-up. These include placing sandbags on the beach to resist sliding of the ice sheet; a berm may be constructed around the perimeter of the island to cause jamming of the ice and initiate pile-ups, and a buffer zone may be maintained around the well and camp to accommodate~any ride-up. We may also be warned of such events with a suitable ice monitoring system. Table IA SUMMARY OF OBSERVED RIDE-UP EVENTS ALONG THE NORTH COAST OF ALASKA (Compiled from Kcvacs and Sodhi, 1979) Location Barrow Barrow Barrow ~ Flaxman Is. Camden Bay Barrow Barrow Lease Area Janette Is. Barrow Barrow Stump Is. Egg Is. Long Is. Barrow Bodfish Is. Barrow Tapkaluk Is. Martin Is. Igalik Is. Advance Dar e Wid:h Length 7/1892 11/1895 220 200-300 ft. many feet 7/1914 1937 1961 39.0 ft. 150 ft. 9/1975 160 ft. 9/1975 completely over-ridden 7/1975 25 ft. 6/1975 $ mi. 80 ft. 7/1977 1011978 11/1977 1/1978 290 ft. 80 ft. 130 ft. 2300 ft. 110 ft. completely over-ridden 700 ft. 180 ft. 1 mi. 315 ft. Ice Thickness 12-15 ia. 8 in. 39 60 in. 7 in. 20 in. 50 in. 36 in. 36 in. 36 in. Attachment %2 ADDITIONAL COMMENTS ON THE ICE ROAD TO insure safe utilization of the ice road the following should be considered: 1. Placement of stakes at 300-foot intervals along the road and several emergency warm-up huts. This will allow travel along the road during poor visibility periods and shelter during white-out conditions. 2. Determine critical velocity for vehicles as a function of ice thickness and water depth. Place speed limit signs along ice road. 3. Snow removal and control should receive adequate attention. Snow banks along the sides of an ice road may overload the ice and cause the formation of longitudinal cracks. It is standard practice to clear the snow to a width of at least 150 feet and keep the snow bank height less than two-thirds the ice thickness. It is also recommended to keep a few inches of compacted snow on the ice for better traction. The thin snow layer will reduce thermal cracking and internal deterioration due to the absorbtion of solar radiation. 4. Advantage should be taken of the experience gained during the use of the Reindeer Island ice road (RIST well). 5. Safety procedures should be defined and given to personnel using the ice road. CHECK LIST EOR NEW WELL PERMITS Company Lease & Well No. IT~ APPROVE DATE (1) Fee (2) Loc YES NO 1. Is the permit fee attached ............................... 2. Is well to be located in a defined pool ................ 3. Is well located proper distance from property line ........ 4. Is well located proper distance from other wells ......... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is well bore plat included ..... ~ ~ 7. Is operator the only affected party .................... 8. Can permit be approved before ten-day wait .............. (3) Admin'~(/ct~- l. g' ~'v 9. (9z thru 11) 10. 11. (4) Casg 2~thru 20) -- '%21 thru 24) 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Add: Does operator have a bond in force. ....,,.........,............... . . ~ Is a conservation order needed .... ......---..-------------,---.---.-, ,, Is administrative approval needed ................................... Is conductor string provided ....................................... Is enough cement used to circulate on conductor and surface.,.... .. Will cement tie in surface and intermediate or production strings '' Will cement cover all known productive horizons ....... ,. , . ,........ Will surface casing protect fresh water zones ..''..'.'.''.''.'''.'' Will all casing give adequate safety in collapse, tension and burst. Is this well to be kicked off from an existing wellbore ............ Is old wellbore abandonment procedure included on 10-403 ........... Is adequate well bore separation proposed .......................... Is a diverter system required ...................................... Are necessary diagrams of diverter and BOP equipment attache~ ...... ~:~ -/_~ Does BOPE have sufficient pressure rating -Test to/~=~-~ psig . ( 8) Does the choke manifold comply w I RP-53 Feb,7 ................. REMARKS Additional requirements Additional Remarks: ~m~ 0 Geology: Engineering: HWK L C S BEW WVA JKT RAD JAL ~ MTM rev: 01/13/82 INITIAL GEO. UNIT ON'/DFF POOL CLASS STATUS AREA NO. SHORE Item Apurove Date Yes No (1) Fee ,~o~ Foz/-Fo ~, 1. Is the permit fee attached .......................................... ~ 2. Is w~ll to be located in a defined pool ............................. w~ 3. Is a registered survey plat attached ................................ 4. Is well located proper distance frcm property line .................. f~m_~ 5. Is well located proper distance frcm other wells .................... ~ 6. Is sufficient undedicated acreage available in this pool ............ //,of 7. Is well to be deviated .............................................. 8. Is operator the only affected party ................................. ~ 9. Can permit be approved before ten-day wait .......................... /6o~ (3) klmin. ~' 10. Does operator have a bond in force .................................. ~ 11. Is a conservation order needed ...................................... ~ 12. Is administrative approval needed ................................... ~ (4) Cas9~ (5) BOPE ~ 13. Is conductor string provided ........................................ cement used to circulate on conductor and surface ........ .,~ 14. Is enough ~.zz-~O, 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 and burst.. 19. Does BOPE have sufficient pressure rating - Test to /~_! Oo O psig . Approval Reccmmended: Additional Requirements: Geology: Engineering: HWK ;~0/~ LCS BEW__ JAL~-- rev: 03/05/80