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Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. lq '~ '~0~ File Number of Well History File PAGES TO DELETE Complete RESCAN Color items- Pages: ¢1, Grayscale, halftones, pictures, graphs, charts Pages: Poor Quality Original - Pages: Other- Pages: DIGITAL DATA OVERSIZED Diskettes, No. Other, No/Type Logs of various kinds Other COMMENTS: Scanned by; Beverty ~a Vincent Nathan Lowell Date: ~-~'2 Isl TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent©n Lowell UNSCANNED, OVERSIZED MATERIALS AVAILABLE: 0E FILE # Pd 001 0 ffti 0-041' ij � r 1`J vn(„; cZ° Pr , ;oh R:es s- 4-lv(4- LcL C S(st -( (‘ Oh 5F L� Se (Is /Ki ( Sec:GOA qa A /6S— I To request any /all of the above information, please contact: Alaska Oil & Gas Conservation Commission } 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Voice (907) 279 -1433 , Fax (907) 276 -7542 RMERFIDFI HESS CnlRPnRFITION R.A. SAMONTE, Offshore Drilling Engineering Supervisor P.O. BOX 2040 HOUSTON, TEXAS 77252-2040 PHONE 713-609-5965 FAX 713-609-5669 November 1, 1995 ALASKA OIL & GAS COMMISSION 3001 Porcupine Drive Anchorage, AK 99501 Regarding' North Star No. 3 Geologic Information Dear Mr. Okland As per our telephone conversation, I am sending you one (1) copy of the handwritten descriptions of the sidewall cores obtained from the North Star No. 3 well. I have also contacted Mr. Bernie Leas with Epoch Well Logging, Inc. and instructed him to send you two (2) blueline copies of the composite mud Icg. Mr. Leas is headquartered in Anchorage and can be reached at (907) 561-2465. Please feel free to contact me if you need any additional information. RAS/jr Attachments Sincerely, AMERADA HESS CORPORATION R.A. Samonte ',lOV O9 1995 0il & Gas Cons. 60mmissior~ Anchorage ORIGINAL tlOV 09 1995 Alaska Oil & Gas Cons. Commission Anchorage LFF~ ~ 70 ~. £~, ~LE A~ PALEd ORIGiiqAL ~LEo ¥~OV 09 i935 Ai. asV, a. IJii & Gas Cons. Commission AncRorage L/, Tf/ / gas Cons. Commission Anc1~orage PALEO HOV 09 i995 Alaska Uil & Gas Cons. Oommission Ancl~orage PERMIT DATA AOGCC Individual ,},!el-~ Geolog±ca! Mater±als Inventory T DATA_PLUS Page' Da'he' RUN i l o /13 /95 DATE_RECVD 93-203 .... ~03 93-203 93-203 93-203 93~203 93 2 93-203 93~203 93-203 o3 ~0~ 93~203 .c)3~203 93~20 '~ 93~203 }, ~ 203 9~ 203 93-203 93-203 93~203 93--203 6095 610'7 _.(pT' 38~4-I0000, OH/MWD~DPR/OR ~4~I0000, OH-DiTE/AIT DRY DITCH WE'T SAMPLES ~'~100- I0000 ~5~BOXES SS~909 407 ~MP DATE 0 ~/26/94 o B!OSTRAT~rmY~, ~00 10000 n~RE ANALYSI~' DAILY SURVEY / 9436-9595 01/,3'1/94-03/22/94 -~/:-o-ioooo 132-9952 ~i32-995~ ~.RR~Y / ~uBn~./SDT ARRAY /DDBHC / SDT CB T CET CST DPR/GR ~P~./~R .~/GR D-' FHi ~/GR LDT/NP MDT MUD &I~5~00-8862 '~9634-9863 ~'3920-9982, TVD 3920-9982, TVD ~L'~ 3920--9982, MD ,.~3920-9982, MD ~230~9846 ~'996-7784 ~96-7784 ~ ~9001-9774 ~05-10000~. COLOR (2) 4-9 1-4 1-4 3.5 3.5 4 1-8 1-8 1-8 1-8 4 4 2-3 2-3 4 4 04/29/94 06/21/94 o4/2o/94 04/20/94 04/26/94 05/31/94 04/29/94 04/26/94 04/26/94 04/21/94 04/21/94 04/21/94 04/21/94 04/21/9~ 04/29/94 04/29~94 04/29/94 04/29/94 04/21/94 04/21/94 0~/21/94 04/21/94 04/21/94 04/21/94 04/29/94 DATA AO~C~ individual Well ' ~ Geological Materials Inventory T DATA_PLUS Page: 2 Date: 10./13/95 RUN DATE_RECVD 93 - 203 NGT 93-203 93-203 PIL/SFL/AIT/GR PIL/SFL/AIT/GR ~500 9981 ~z~.~ ~? - 4 04/21/94 ~/ ' ~ - ')~ 04/2i/9~ · ~2 9989 124 . '~132-9989 }- 124 04/2i/94 Are dry ditch samples rec~uired?_ ~-~7_~__~.~~ no And received? ~~no Was the well cored? )no ys~s ~description received? no Well is in compliance ~ Initial COMMENT S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johns~:~ DATE: ChairmacF~ THRU: Blair Wondzell, ~ FILE NO: NSTARLOC.DOC P. I. Supervisor ~ [~'~ Lou Grimaldi,~ Petroleum Inspector FROM: SUBJECT: August 25, 1994 Location inspection Amerada Hess North Star island Thursday, August 25, 1994: I made a follow-up Location inspection on Amerada Hess' North Star island. Bob Gardener (Fair-weather rep.) Accompanied me on my inspection. This was a follow- up to Jerry Herring's recent Location Clearance Inspection in which the island was ready for clearance with the exception of the trash that was left on location. The location was neat and clean and all trash had been removed. The island had been graded as smooth as possible and has already began its erosion process. Fair-weather has the contract with Amerada Hess to conduct periodic inspections and cleanups for the next five years. I recommend North Star Island to be granted a final location clearance. SUMMARY: I made a follow-uR Location inspection on Amerada Hess' North Star Attachments: Photographs August 15, 1994 Mr. Jerry Herring Petroleum Inspector Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Final Cleanup, Amerada Hess Corporation, Northstar No. 3 location Dear Jerry: On Thursday, August 11, 1994, we completed the final cleanup and restoration of the above-referenced well location. Although the site clearance letter has already been issued by the Commission following an earlier inspection, it was with the understanding that certain minor site work would be completed as soon as nesting waterfowl were off the island. The following work was accomplished: · The depression created by subsidence following the removal of the well cellar last winter was filled with gravel and the area contoured to conform to the island surface. Three ice road delineator stakes and minor miscellaneous debris (i.e., electrical cable, small pieces of foam insulation, fragments of pit liner, etc.) were recovered and transported to Deadhorse for disposal. A diver recovered minor miscellaneous debris (road delineator stakes and rope) from the sea floor off the east and southeast side of the island which was visible from the air on a calm day. The area covered by the diver was within the footprint of the ice drilling pad. · The restored site was documented with color photographs (enclosed). Thanks for working with us on this, Jerry. If you have any questions, please give me a call. ~~Si. nce. rely, Enclosures 715 L Street Anchorage, Alaska 99501 (907) 258-3446 FAX (907) 258-5557 STATE OF ALASKA Alaska Oil Gas Conservation Commission Anchorage, Alaska 99501-3192 CONFIDENTIAL DATA RELEASE The AOGCC will release confidential well data to authorized DNR/DOG employees. Ail data is to be inventoried prior to release and a copy of the inventory given to the DNR/DOG employee. Well Name: 01) Permit to Drill (401): ~ 05) Drill Stem Tests: /~ pages /06) Core Analysis Report: ,~~pages 07) Core Description~~,,l~gey 08) Digital Data: __. reels 09) Formation Picks:~ ~6Y'~age/s 10) Bluelines: logs (list below) pages 02) Completion Report (407) ' ~es LOG TYPE INTERVAL RUN # SCALE TODAY'S DATE' ~/7~ff/~F The under-signed ])m~/]~o(~ employee hereby accepts receipt of the above listed confidential materials. Print and sign your name below. Signature'. ~~'-~-~f"~7" -- - -- ~ ~-v_~-~J AuthodZedsignature: AOGCC personnel,/~n,. ~:~,/,-~beJ°w tO/verify transference of these confidential materials. ALASKA OIL AND GAS CONSERVATION CO~I~IISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALAS .KA 99501-3192 PHONE: (gOT} 279.,1433 TELECOPY: (907) 276,7542 June 23, 1994 Robert C. Gardner, President Fairweather E&P Services, Inc. Agent, Amerada Hess P O Box 103296 Anchorage, AK 99510-3296 Re: Location Clearance, Amerada Hess North Star wells- Dear Mr. Gardner: You requested location clearance on the Amerada Hess North Star wells #1 (PTD 85-085), #2 (PTD 86-013), and #3 (PTD 93-203). On June 9, 1994 our inspector Jerry Herring accompanied you and others on an inspection of the North Star wells. Based on his observations, Mr. Herring recommends Location Clearance for North Star Well #3; he noted that there was additional work that needed to be done to the North Star #1 & #2 location before they could be cleared. (See his report "i99kfjbd" dated June 9, 1994 for additional details). Location Clearance for Amerada Hess well North Star #3 (PTD 93-203) is hereby approved. Chairman c: Blair Won~zell bew/lcahns64 ,~r prin[ed on recycled p;)l')er b y C.D RMERRDR HESS CORPORRTIEIN P. O. BOX 2040 TULSA, OKLAHOMA 74102 9! 8-599-4200 June 15, 1994 Alaska Oil & Gas Commission Bob Crandal 3001 Porcupine Ddve Anchorage, AK 99501 ~h% RE: Northstar #3, Northstar Unit, Beaufort Sea AK Dear Sir: I am sending to you a Composite Tape containing all wireline Icg and MWD data for the Northstar No. 3 well. The tape was wdtten in LIS format @ 1600 BPI. Aisc enclosed is a tape verification listing. In accordance with provisions of 11 AAC 82.810(a), Amerada Hess Corporation hereby requests that this information be kept confidential. Please acknowledge receipt of the Composite Tape by signing and returning a copy of this letter to me. Sincerely, AMERADA HESS CORPORATION R. Emerson Stine, Jr. RES:kll CC: Received: J. A. Ready C. R. Richard R. Gardner- Fairweather Date: R£CF_IVF. D Gas Cons. Commission I 8,PARATE WET.I~ FILES WITH LOG DATA WERE FOUND ON THIS TA/~[/ ~' ~>-, ~ ~<~ ~"~t~ ' *********************** t******************* ~********************************************~******************* SPECIPICATION NUMBERs LOGGING DIRECTIONs LOGGING COMPANYs DATE LOGGEDI KB RL,VATION~ LOGGING INTERVALs 1 tip *** COMMENTS *** KB RLRVI GROUND RLRVs CURVE UNITS TOP ~M MIN MAX INCREMENT 8.5000 BS 74.00 9995.50 16.0000 0.5000 F TENS CGR GAPI POTA SGR GAPI THOR PPi/ URAN PPM HTEN MRRS DRItO G/C3 RIiOB G/C3 NRRO CALI MTEM DPHI PHND NPHI NPOR HPHN HDRH HPI~F HRHO HNRH HDPH HNPO DT DTL DTLN DTLP GR GAPI SP MV AT10 AT20 AT30 AT60 AT90 CADE CPDE DCCM GRAM INC PDCM PDDC PDEN PDIM RACM RADE ROPA ROPS RPDE RPCM TCDM CIDP IDPH IDER IDVR IMER IMVR CILD I LD SFLA SFLU MCAL DTCO DTSM BHIN BHNO 662 · 00 7438.00 7438 · 00 7438.00 7438.00 7438 · 00 662.00 662 · O0 842.50 842.50 842.50 842.50 842.50 662 · 00 842.50 7438.00 74.00 74 · 00 8853.00 8853.00 8853 · 00 8853.00 8853.00 8853.00 8853.00 74.00 74.00 74.00 74 · 00 74 · 00 74.00 662 · 00 662 · 00 662.00 662.00 662 · O0 662.00 3824.00 3919.50 3919.50 3919.50 3024.00 3824.00 3919.50 3919.50 3825.00 3919 50 3824 50 3919 50 3824 00 3824 00 3919 50 3824 50 3824 00 3824 00 74 00 74 00 74 00 74 00 74 00 74 00 74 00 74 00 74 00 74 00 74 00 74 · 00 74 · 00 74.00 74 · 00 74.50 74.50 10000.00 1005.0000 4330.0000 0.5000 9995.50 -29.8270 150.0049 0.5000 9995.50 0.0001 0.0372 0.5000 9995 50 22.6911 222.7353 0.5000 9995.50 -7.5751 28.6330 0.5000 9995.50 -0.1074 16.4347 0.5000 10000.00 372.8688 1280.7957 0.5000 10000.00 0.2925 1.3057 0.5000 9995.50 -1.1961 0.3527 0.5000 9995.50 -1663.7307 476.7389 0.5000 9995.50 1.1662 3.3748 0.5000 9995.50 1.0114 3.7562 0.5000 9995.50 2.7220 30.3963 0.5000 10000.00 57.8189 174.0296 0.5000 9995.50 -38.8765 90.2814 0.5000 9995.50 -58.1147 99.3088 0.5000 9995.50 -180.8452 143.8148 0.5000 9995.50 -99925.0000 639.1401 0.5000 9995.50 -0.3512 0.9055 0.5000 9995.50 -1.5475 0.2023 0.5000 9995.50 -207.5164 986.1769 0.5000 9995.50 1.4433 3.2608 0.5000 9995.50 1.1559 3.2295 0.5000 9995.50 -37.0198 73.1354 0.5000 9995.50 14.8158 101.3443 0.5000 10000.00 -57.4000 330.8000 0.5000 10000.00 -68.1000 358.8000 0.5000 10000.00 -325.0500 483.4000 0.5000 10000.00 -532.2000 616.0000 0.5000 7784.00 15.8617 117.5625 0.5000 10000.00 -128.0000 66.7500 0.5000 10000.00 17.5544 124.4287 0.5000 3918.00 0.0874 1950.0000 0.5000 3918.00 0.0374 1950.0000 0.5000 3918.00 0.0291 1950.0000 0.5000 3918.00 0.0065 1950.0000 0.5000 3918.00 0.0045 1950.0000 0.5000 10000.00 119.2000 232.0000 0.5000 9987.50 11.4520 1473.5110 0.5000 9987.50 3.4075 1576.4417 0.5000 9987.50 20.7799 279.9747 0.5000 9981.50 2.2913 361.4253 0.5000 10000.00 0.4000 25.9000 0.5000 9987.50 0.4261 131.7890 0.5000 9987.50 0.3759 89.1526 0.5000 9987.00 3.8833 8589.5000 0.5000 9987.50 1.0000 40518.5000 0.5000 9987.50 0.0552 1475.7065 0.5000 9987.50 0.6787 87.3208 0.5000 10000.00 5.0298 605.4254 0.5000 10000.00 4.3734 679.0762 0.5000 9987.50 0.6343 293.4692 0.5000 9987.50 0.0687 2192.9707 0.5000 9999.50 55.3719 155.4125 0.5000 10000.00 3823.9048 9559.8555 0.5000 10000.00 -671.4803 2893.1113 0.5000 10000.00 0.3456 1950.0000 0.5000 10000.00 0.3237 1950.0000 0.5000 10000.00 0.2537 1950.0000 0.5000 10000.00 0.7142 1950.0000 0.5000 10000.00 0.5485 1950.0000 0.5000 10000.00 0.3497 1950.0000 0.5000 10000.00 -561.4956 2320.4067 0.5000 10000.00 0.4310 1950.0000 0.5000 10000.00 0.5008 1950.0000 0.5000 10000.00 0.0985 9700.0000 0.5000 10000.00 0.0930 9700.0000 0.5000 997.00 11.7347 20.1242 0.5000 10000.00 47 9044 183.3526 0.5000 9959.50 97.8795 226.1223 0.5000 997.00 0.2491 5.6796 0.5000 997.00 0.1600 5.5263 0.5000 D te, - RECEIVED JUN 211994 A!ask~ Oit & G25 Oons. Commission Anchomge Facsimile Cover Sheet . I To-' Company: Phone: Fax: LARRY GRANT Oil & Gas Conservation Comm. 907-279,1'433 907-276-7542 From: Timothy J. Ryherd Company: Alaska D,N,R., Division of Oil & Gas Phone: Fax: (907)7(~2-2140 (go7)s62-3852 Pages Including this JUN l cover page: I 4t~k~ 0ii & Gas ~ons. Lam/. .Alqchorage I ~qUeSt the following well data t~ p~'epared for me to pickup aa ~oon as possible. I=lease cell when you I~ave thLs data put together or if you have any questions. Thanks for your tteip. ARCO ~uth Co~k Inlet ~2 (=onfldentlal well statu~)--all well logs, well h~ory, completion rel~rt, ha'izon pic~, dlm~on.l surveys, ~om clesc~ons & analyses, & production tests. ARCO ~outh Cook Inlet ~ (confidential well status)--all well logs, well history, comple/Jon rel3(3rt, horizon picks, directional surveys, ~re descrii~or~ & analyses, & production tests, Phllllm Sunfish #2 (confidential well status)-mucl Icg. Stewart West McArthur River a~2 (confl~ntlal well status)--all well logs, well histo~j, completion mpofl, he.on Fflr. k.l, climc~lonal surveys, cere clesc~ptic)n$ & anmyses, & BP Yul~on Gold ~ (c~3nfidenflal well statu~)--all well logs, well histo~, completion rel~rt, horizon picks, clltectlonal aurveys, ~ore desorlpUons & analy~es, & production tests. ARCO Fio~ d2 (conflde~al well stalus)-.all well logs, wail history, ~Om~etion report, hodzon I:dCkS, dimctiormi sur~ey~, core desmlpfJon$ & analyse~, & pm<luctlon tests, Ameracla No.star ~ (~3rrfldentl.i vmll statu$)-a(I well logs, well hi~tory, ~omptetlon I1orlzon plc~m, cllrectiormt surveys, ~re clesmt~ons & analym~, & production ARCO E~unfish-~ (~~ai well status)-all well logs, well I'dsto~, completion report, hmizon pt~<s, cli~l surveys, ~o~e clesmtptlo~ & analymas, & producUon tests. BP Soun:lough ~ (confidential well status) all well logs, well history, completion report, horizon picks, direc~lonal surveys, ~o~e descriptions & analyses, & .m'o~uctJon teg. s. ARCO Be~sctlmrld ~1 (confidential well statua}-ail well logs, well' history, ~ompletion report, hmizon pic~<a, dlrecUonal surveys, ~ore desml~ons & analyses, & I:~'oduction tests. UNOCAL Amethyst~State ~1 (~nf'~ential well status)--all well logs, welt historT, completion report, horizon pi~, (llrm~lonal surveys, m3m ~lescrlptlons & analyses, & I:mXluctlorl tests. MEMORANDb, State Alaska Alaska Oil and Gas Conservation Commission TO: David Johns~, ' Chairmar~ DATE: June 9, 1994 THRU: Blair Wondzell, ~ P. I. Supervisor FROM: Jerry Herring,~ SUBJECT: Petroleum Inspector FILE NO: i99kt]bd.doc Location Clearance Amerada Hess, North Star #3 North Star Unit Thursday, June 9, 1994: I traveled to Seal Island, North Star Island and the temporary ice island for the North Star #3 well to review the condition of the islands. Travel was completed with Craig Edel, Amerada Hess and Robert Gardner, Fairweather on an ERA Bell 206L. Do to low ceiling conditions which prevailed most of the day, two attempts were made before we could actually make it to the islands. A helicopter flight was made over the ice island for North Star #3 well which was plugged and abandoned in March of this year. Pictures were taken from the air. All debris has been removed from the ice island. The location clearance for North Star #3 is recommended to be approved for final well abandonment. The Location Clearance Report for North Star #3 is attached. This trip was primarily made by Amerada Hess to finalize the scope of work for a bid package to be released in the near future for island abandonment work remaining for both Seal and North Star Islands, for the North Star Unit. There are (2) plug and abandoned wells on North Star Island and (4) wellheads remaining on Seal Island. Work will consist of bringing crew and heavy equipment by barge to North Star Island to remove all of the remaining debris, and to Seal Island for surface P&A of the (4) wells and to remove all of the remaining debris. Currently, there is too much debris still on North Star Island to recommend approval of final abandonment of the (2) wells there. The attached Location Clearance Reports for the (2) North Star Island wells are attached and reflect this recommendation. Final location clearance inspections for the (2) North Star Island wells and the (4) Seal Islands wells should be completed this August when the remaining clean-up work of the islands are completed. Summa..ry: I completed a location clearance inspection of the North Star #3 well and recommend approval of final abandonment of this well. Attachment: i99kfjbd.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Surface Abandonment / Location Clearance Report ( T'Cde 20 AAC 25, Article 2 ) Operator: Amerada Hess Corp. Address: 1201 Louisiana, Suite 700 Houston, Texas 77002-5681 Surface Location: F L, F L Section 32 ,T 14N ,R ,13E, ,, ,M ,Urn Well Name: North Star #1 PTD No.: 85-085 APl No. 50- 02g-213;1~"~0 ....... Unit or Lease Name: North Star Unit Field and Pool: Downhole P&A Date: ~'~:[::"~:~'~::~:: ~.~::;:::::::~::.~:.:.~::..:.~.~.~:~:~:;~;:~..~:.~:~:::.~:.~::::~;~;~;~;:~;:.:::~;..:.~:~;:~::.:~:.::~:::.::~:.~::::::~:::;~.:.[~:~:~:::.:~:.;~;::~::::~::.~;~::..:::~:~:~:::~:~::~:::: ~:;~:'~'~'::'~'~::"~::::;~:::~;:~:';':':::: ~:~;:~'~::;~:~:':~:~'~:~':' ::::':~:::;;:';:'~: ;~ ::~'~:::'~:~'~:Ma~.:Pta. eD~me~ ============================== ~¥:.-~:-.~¥~::.::::::::::::::::::::::::: mE ne~,::::%~::~:::~.::¥%-~..:.: D~~.-Bet;' ::'::;::::~:;':;' :%:':"~ Fma!:":":Grade' "' "Level.'; ' ~. . . ::':::-.':::"_'.-:-.':'""::':::~:_::.::.; ~'":.~;';":':':::':::::"'"~ ' '"::'::"~-"-:-~"i"~ '.~: ;::-:r:'"~ -"~"'--';~.:"::-":"-"?'" '--'"'"-':'i'-"' "'r'"'~"';" ;~'-'""rr ~:':'~"'.'L'~'-'~:"r, '.~:"' '"' ." (' '"','" ','" ,: ~.. ~ . , ,, ~ . _ ~. ,~.~ , t ,. ~ . : - - : . '" ea:te : ::.( Note ~en-different from file info~ati°n) ~ We~:~&~:.:~:..~:~?~?::~::.:~::~:~:~:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~:~:::~:::::~:~:~:~:~::.~::~:?.~::::~:.::~:~::~::.~:::~:::~:~::~::Rem:a~?..::~::~.~:?:::.::?~:::::.:.~:~:~:~::.~:. ::.:..~.~.. - '::.--:-'. :::.': ..... :.: ....... ".':...'.'.'.'..'.'."-'..'..:.':'.'..'.'.: ......... :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .?.??~::~?.:?::::~.~:~:::?~?~?.?~:~::.~::::~:~M:~::::::~:~:~:::::~::~:.~ ::::::::::::::::::::: :.':::~:-: ::~ .~. :. PITS: Filled In: N/A Liners Removed or Buried: /V/A Debris Removed: No SURFACE CONDITION OF PAD AND / OR LOCATION · North Star Island is ero.d, ing away. ( Rough, Smooth, Contoured, Flat, Compacted ) Clean: No Type &Quan. of Debris'if any '~emaining on pad and / or location: Much man made materials. · TYPE AND CONDITION OF SOR~6UNDING AREA' Ar., ~ic Qcean .s, ~, ounds North Star Island. (Wooded,Tundra,Grass,Brush,Dirt,Gravel,Sand) Clean: Yes , Type &Quan. of Debris if any remaining on surrounding area · . .... TYPE AND CONDITION OF ACCESS ROAD AND SURROUNDING AREA: Ice road melting away.. ( Dirt, Gravel, Ice, Other) Clean: Yes Type & Quam of Debris if any remaining on access road or surrounding area · CLEANUP WORK REMAINING TO BE DONE' Removal of all man made materials required for abandonment ~ island. ' ' RECOMMENDED FOR APPROVAL OF ABANDONMENT: Yes No X ( If "No" See Reason ) Distd~n: odg - Welt fi~ Ope~or Database Inspector Reason: FI-g00 (Rev. 3/93) Location Clearance should be completed in Augu. s.t. /s/and aban. don. ment e. fforts, a. re. u,n,d, ervvay. , FINAL INSPECTION: Yes No X ,, . INSPECTED BY: Jerry, P. Herring DATE: 6/9/94 199KFLBD.XLS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Surface Abandonment / Location Clearance Report ( Title 20 AAC 25, Article 2 ) North Star #2 86-013 029-21511-00 Operator:. Amerada Hess Corp. Address: 1201 Louisiana, Suite 700 . .. Hous, ton,, Texas 77002-5681 Surface Location: F L, F L Section -32 ,T 14N ,R' '13E' ,MUm Well Name: PTD No.: APl No. 50- Unit or Lease Name: Field and Pool: Downhole P&A Date: North Star Unit : :: ~ __ I ~il-- (On Wellhead, Csg, In c:mt) ' i!.:~~p:~~~::~~!:tq:i~~:ip~:::~~::~er!:P~e~:.~::~:i::.~:!~:~:~.~:~:::~::~:~:~¢~::;~:~.:::.~:~;~:~;{~;.:~::~:~;:~:::.:~:~::;:.~::~:~:.~;:{~:~:~;::~.:.~::~{~;~:::;}`~:~:;~:~.:::~{~::~::~:::~:::::::::.::.:~:::~::::~:~:::;~:::::.~.;:.::::~:~::~:;~::~:~;:~:~:~;:.;~:~:;~:~::::::.:;};:~:~::;:{:~;:::.:~::.::::~:::::.{~:.~:::~:::}:;...::.~.:::.:.~::~:::::~;~:~::~:.::.~:~::::.:; ?;:.: '-. -:. i!(:Note, vtd14~n dlfferellt'" from file iilforlllatiort) .... :.:.::::.::. . ..... :::.:::Lee i .... :.'['l'l'.'.l. l'.'l'~, l'.l I 'ii: I l.l l.l.l.' I I[ ...... ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: 'il l'll:.'.ll.~l' I .l Jlll ; I [ II I I I I1~1 I I I II I I' I ;~~i:::.~O~|~?:~).?::??).!~!~:::~::.):i;i;i;:;::~: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::: ::. :...; ::l ~ :.l:l · l i:;ii:.:l ':l'l'' ............ ' -- , ............... .l :::??:.~::::~.::~ ~.~::.:.:~ :~;.::.~..:~:.~..:.:.:s~i~:~:~?::?!::~:~:ii:?f~:.!~i~:~:iii~::~i:/:i:~ii:!~:.ii::::~i~:~i~iZ:.ii?.!:~?~;:.:~?.~~ ?:?:.l: ~- :~ :: :~ :L: .:::::x.:;~:.....~:¥~:¥.:~-~..: .::.:.~¥:.:.:;.:.:....:L.:¥-.¥::..:.:.- :;....-.~ -::li:i:~:i:::iii::i:i::i::ii~ii~ii;:i::'R: :-~i?;:~'~:iM:'::::i:i:i:i;?~':~i~:::i~f:if:~:!::f~:~?'ii::iii:?ii:~{i~i'~::':: i?:::5 i::?i:~ ~:~:::~'-: :l.: l:l:':l'::l :il:~ :' i'll:: I I ' i :l--::. lll--I t:nspectioh::D:ate:~:?~':'~:'?~:'';':''',,,, ........ ~-- .-~---: --::- :..:~: ~-....:..-........~.-~.,......~...-,:.:..:...........~....:.~...~.~.....~...,..:.:.:..,.. :.., ~ - ~J94~:'"'t'ii?'iii"!?!';'i'!i~"i!~i~i~~ii~:'[~TmN'~~UP:':' ': 'il'.' ~,pp}°va[ i:}~'te: ..... ' PITS: Filled In: N/4 Liners Removed or Buried: N/4 Debris Removed: No SURFACE CONDITION OF PAD AND / OR LOCATION · North Star Island is eroding away. ( Rough, Smooth, Contoured, Flat, Compacted ) Clean: No Type &Quan. of Debris if' any remaining on pad and / or location: Much man made materials. TYPE AND CONDITION OF SURROUNDING AREA' Arcl?'c Ocean surrounds North Star Island. ( Wooded,Tundra,GraSs, Brush,Dirt,GraveI,Sand) Clean: _ Yes Type &Quan. of DebdSif any remaining'~ri'surrounding area · TYPE AND CONDITION OF AC'CEOS 'ROAD AND SURROUNDI~ AREA: /ce road melting .aw. ay. ( Dirt, Gravel, Ice, Other) Clean: Yes Type & Quart. of Debris if any remaining on access road or surrounding area · CLEANUP WdRK I~EMAiNIN~'TO BE DONE' Removal of all man made materials required for abandonment of island. RECOMMENDED FOR APPROVAL OF ABANDONMENT: Distribution: Reason: orig - Well file c- Operator o - Database c- Inspector FI-000 (Rev. 3/93) Yes No X ( If "No" See Reason ) Location Clearance should be cq, mp, leted in August. Island abandonment efforts are,u..n, derwa, y. FINAL INSPECTION: Yes No X INSPECTED BY: Jerry P. Herrincj DATE: 6/g/94 199KFKBD.XLS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Surface Abandonment / Location Clearance Report ( Title 20 AAC 25, Article 2 ) Operator: Address: Arnerada Hess Corp. 1201 Louisiana, Suite 700 Houston, Texas 77002-5681 Surface Location: F L, F L Section 17 ,T 13N ,R 13E ,M Urn ,,, Well Name: PTD No.: APl No. 50- Unit or Lease Name: Field and Pool: Downhole P&A Date: North Star #3 g3-0203 029-22438-00 North Star Unit :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ;~:::.:?:-;::-~:;:;;:.::~:-?;-;~;:L;::.-;;;:;:;--.;; :;.:;:;~:~;::~:;;;?:~:~?~:?:~;:~:~:?::~:::~::~?:?~:.::;;::~::;:::~:~:;::~::..:;;:;;;.~- :.::;:;:.L:.: ::':.;;;; .L-:-' ::;'.-:?: ': ;,.';-:; .... ~~~ "~~!~ ~~{~ M~ ~ ~ ~i~ ~e~ Pi"~ ( Note'when differe~ from file info~ation): Date: 6/9/94 [.i.::,i,!,i,.i.;,i.:.i.!,i?;~.i~il2~;~6!~.i.~TiO,NiCL~N.UP:. ~,'i Approval Date: 6/9/94 PITS: Filled In: /V/A Liners Removed or Buried: N/A Debds Removed: Yes SURFACE CONDITION OF PAD AND / OR LOCATION · TemPorary ice Pad.. rnetting away. ( Rough, Smooth, Contoured, Flat, Compacted ) Clean: Yes Type &Quan. of Debris if any remaining on pad and / or location: TYPE AND CONDITION OF SURROUNDING AREA' Arctic Ocean surrounds temporarY ice island. (Wooded,Tundra,Grass,Brush,Dirt,GraveI,Sand) Clean: Yes Type &Quan. of Debris if any remaining on surrounding area · TYPE AND CONDITION OF ACCESS ROAD AND SURROUNDING AREA: Ice road melting away. (Dirt, Gravel, Ice, Other) Clean: Yes Type &Quan. of Debris if any remaining on access road or surrounding area · CLEANUP WORK REMAINING TO BE DONE · None. RECOMMENDED FOR APPROVAL OF ABANDONMENT: Yes X No, ( If "No" See Reason ) Distribution: orig - Well file c - Operator c- Inspector Reason: FINAL INSPECTION: Yes X No INSPECTED BY: JerrY P. Herring DATE: 6/9/94 FI-O00 (Rev. 3193) 199KFJBD.XLS R~II~RRDR HESS I;ORPORRTILIN May 23, 1994 1201 LOUISIANA, SUITE 700 HOUSTON, TEXAS 77002-5681 713-658-9770 Alaska Oil & Gas Commission Dave Johnson, Chairman 3001 Porcupine Drive Anchorage AK 99501 Att: Larry Grant RE: Northstar #3, Northstar Unit, Beaufort Sea AK Gentlemen: Attached is a copy of the Biostratigraphy Report for the Northstar No. 3 well, compiled by Micropaleo Consultants, Inc. for Amerada Hess Corporation. In accordance with provisions of 11 AAC 82.810(a), Amerada Hess Corporation hereby requests that this information be kept confidential. Please acknowledge receipt of this report by signing and returning a copy of this letter to me. If you have any questions, please call me at 713-752-5853. Sincerely, JAR:bmc AMERADA HESS CORPORATION · . _, J~-A~. Ready · Exploration Manager, Northstar Attachments cc.- C. R. Richard P. E. Bacon R. Gardner- Fairweather E & P Services 715 L Street Anchorage AK 99501 E & P SERVICES,/NC. May 24, 1994 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ATT: Blair Wondzell, Senior Petroleum Engineer RE: Disposition of unused 30" conductor on Northstar Island (Amerada Hess Corporation) Dear Mr. Wondzell: Three well cellars were installed in Northstar Island at the time of island construction in 1985. Two of these cellars were used for the Northstar No. I and Northstar No. 2 wells. The third cellar had a 30" conductor driven to = 270 ft., but was never occupied as a drilling location. This third well site was originally permitted as Northstar 3, AOGCC Permit No. 87-88. This permit expired on 8-31-89 without the well ever having been drilled. This 30" conductor was cut off at 80 ft. below the island surface (13 ft. below the original mudline) during Northstar Island well abandonment activities in late March and early April 1994, as part of operations preparing the island for abandonment. Please contact the undersigned if you have any questions. Agent for Amerada Hess Corporation RCG/js CC: C. R. Richard, AHC John Simon, AHC RECEIVED MAY 24. 1994 ^iaska 0il & 6as 0ohs. Commission /~nchorage 715 L Street Anchorage, Alaska 99501 (907) 258-3446 FAX (907) 258-5557 E & P SERVICES../NC. May 17, 1994 Mr. David Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ATT: Mr. Blair Wondzell, Senior Petroleum Engineer RE: Amerada Hess Corporation, Northstar No. 3 Dear Mr. Wondzell: The enclosed photographs are confirmation of the surface plug which was set at fifteen (15) feet below pad level (-11 ft MLLW) following excavation of the cellar at the above referenced well location. The photographs are submitted as per a conversation between Jesse Mohrbacher, our on-site representative and your inspector, Doug Amos. Please contact the undersigned if you have any questions. S in cere I~1~, _ .... R. C. Gardner Agent for Amerada Hess Corporation RCG/js Enclosures cc: John Simon, Amerada Hess Corporation RECEIVED 715 L Street Anchorage, Alaska 99501 (907) 258-3446 MAY 18 199~- AJaska 0il & Gas Cons. C0mmJssJ0n Anchorage FAX (907) 258-5557 ' STATE OF ALASKA x' ALASKA C~-AN D GAS CONSERVATION COMMI'~aEION WELL COMPLETION OR RECO IPLETION REPORT AND LOG 1. SlaP. Il ol Well Cla~ilicallon ol Service Well OIL Q GAS Q SUSPENDED O AOANOONEq ~ ' .~EgyrCE C A~E~DA }tESS CORPO~TION : ~ 93-203 . ,~o~ston, Texas 77092~- *- 50- 029-22438 ' 4. Location of w~ll ~t suHac~ 409 ft FSL. ~ 2120ft FEL~ Sec 17, T13N~ R13E, UM 9. Unit or teas~ Northstar Unit At Top Producing Int,rwl N/A lO. Well Number Northstar No. 3 A~TolalDepth 3680 ft FSL~ 2890 ft FEL, Sec 20~ T13N~ R13E~ UH 1]. F~eld and Pool 5. Elevation in le~t (indicate Kg, DF, ,tc.) 6. t,a~ O,~ignadon and S~rial No. No Pool Designated 37 ft KB ADL 355001 (Exploratory) 12. Date Spudded ,3. Da,~T.O. Reached 14. gate Comp., Susp. orAband, liE. Water DepdhiloHshore JlG. No. o/ Complel,o., Jan. 31¢ 1994 March 14~ 1994 Abd. - March 28~ 1994 , N/,A feetMSL , 0 "17. Tolal Depth (MD+TVD} 'IB.Plug BackDepd~(MO~g} lg. Directional SurveYl0000 .MD/9562 TVD N/A (gbd.) YES ~ NO ~ J 20. Depd~ where SSSV SelN/A h~et MD J 21. Thickness ol Permalrost1588, MD (KB) 22. Type ElecJric or Odle[ Logs Run ~haso~ Dua~ ~nduct~on~ Gamma Ray~ D~LLaZ A~ay Sonic. A~ay ~nduct~on~ ~Ltho- Dens~Ly~ Natu~a~ Gamma Spect~oscopy~ Hodu~a~ DynamLcs ~esLe~ Formation H~c~o ~ma~e~l A~so 23. CASING. LINER AND CEMENTING ~EconD SETTING DEPTH MD CASING SIZE UT. PEn FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING IRECOnD AMOUNTPULLEO 30" ~b~ X-52' ' sur[ace Z~2 - (D~ven) 52'(Lo 15~ be~ou Pad 20" 94~ K-55 Surface 995 26" CmL to Surface 52'(to 15' below pad 13-3/8" 68~ L-80 Surface 3~20 17-1/2" Cmt to Surface 52,',,(~0 15' below ,pad 9-5/8" 47~ L-80 Surface 9,001 12-1/4" 490 sx Glass G Blend 52'(to 1~'; below pad [(top ~ 24. Pe[ioradon~ ope. Io Production (MD~TVD o~ Top and DoHom and 25, ] UUING RECORD i.terval, ~ize add number) SIZE OEPIIi SE r (MO) PAcKEI~ SET (MD) No perforations , .(None) 2G. ACID, FRAC]URE, CEMENT SQuEEzE, ETC. OEPII{ INTERVAL (MD) AMOUNT& KINDOF MA]ERIAL USED ...(None) ~7, PRODUCTION TEST Dale First Production ] Method of Operation (Flowing, ga~ lill, etc.) No Production Dateo~Iesl i-lou¢~'[e~ted TESTPr{O~'UCTIO~PERIOO F~R~ OIL-UBL GASMCF WAT'ER-BUL CIIOKE SIZE . GAS-OIL RATIO Flow Tubi,g Casing g~e~su~0 CALCULATED OIL.BBL GAS-MCF WATEII-UUL OIL GI1AVITY.API P~e.. . . ~4-HounnArE ~ 20. CORE DATA BrJ~[ description o~ Ihhology, porosJW, lracture~, apparent dip~ and p~e~nc0 ol oil, ga~ or wa~er. Submit co~e chip~. .Core No. ~ (9~36-~b67 HD): 6~ sandstone~ 25~ mudstone and s~}tstone Core No. 2 (9500-9560 HD): 60~ sandstone Core No. 3 (~560-9620 ~): 30~ sandstone~ 30~ sandstone/sL~Cstone -' RECEIVED ~as~ Oil & Gas Cons. Commi~ level) level) level) level') · Form I0-407 . '"' "' -,=nc,orage Submit in duplica,e Rev, 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGICNI,~) ,EnS OIIMATION'[ES'IS - NAME Include interval tested, pressure data, all fluids recovered and graviW, MEAS. DEPTH TRUE VENT. OEPTH GO,,and time of each phase. Base of ?ermafrosl 1588 1588 No Tests Prince Creek/ Schrader Bluffs 4569 4563 Seabee 6698 6519 Top of I1RZ 8614 8271 Base of HRZ 8800 8441 Kuparuk 9427 9026 Miluveach 9818 9390 RECEIVED MAY - 9 1994 Naska Oil'& Gas Cons. Commission Anchorage _ 31. LIST OF ATTACIIMENTS 32., I hereby certily [llat Lite (oregoing is true and correct to tile best of my knowledge Signed ~.~'- Title Agent Oat0 April 22~ 1994 _ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection [or in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production Irrom more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals [or only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 AMERADA HESS CORPORAIION May 4, 1994 TO: SUBJECT: Amerada Hess Corporation 1201 Louisiana, 7th Floor Houston, Texas 77002 Attention: Jeff Ready Biostratigraphic Analysis, Amerada Hess Northstar No. 3 Well, Beaufort Sea, Alaska The 'attached report details our interpretations of the Foraminifera and palynomorph occurrences from the Amerada Hess Northstar No. 3 well. Work on this project was done at the offices of Micropaleo Consultants, Inc. in San Diego, California. A total of 183 samples were processed and examined for Foraminifera and palynomorphs. If you have any questions regarding the data or interpretations presented in this report, give us a call. Sincerely, Michael B. Mickey MICROPALEO CONSULTANTS, INC. Hiders5 Haga MICROPALEO CONSULTANTS, INC. MBM:HH:be Attachment Bate__ !,/~/O ( ..... 681 Encinitas Blv& · Suite 312 · Encinitas, California 92024 · (619) 942-6082 · FAX (619) 942-9623 Laboratory:. 4569/Vtission Gorge Place · Suite K · San Diego, California 92120 · (619) 284-7703 May 4, 1994 AMERADA HESS NORTHSTAR NO. 3 SEC. 17, TI3N/R13E UBM AP1 #50-029-22438 BEA~ORT SEA, ALASKA M.C.I. Job No. 94-103 BIOSTRATIGRAPHY REPORT TABLE OF CONTENTS INTEGRATED SUMMARY ......................................... 2 FORAMINIFERA REPORT ......................................... 5 FORAMINIFERA SUMMARY ...................................... 6 INTRODUCTION ................................................ 10 Scope ..................................................... 10 Procedures ................................................ 10 Format ................................................... 10 RESETS ...................................................... 11 CONCLUSIONS .................................................. 17 PALYNOLOGY REPORT .......................................... 18 PALYNOLOGY SUMMARY ....................................... 19 INTRODUCTION ............................................... 23 Purpose and Scope .......................................... 23 Procedures ................................................. 23 Report Format .............................................. 23 RESULTS ..................................................... 25 CONCLUSIONS .................................................. 33 ILLUSTRATIONS (In pockets at back of report) Figure F-1 Figure F-2 Foraminifera Distribution Chart High Resolution Biostratigraphy Chart (Foraminifera) Figure P-1 Palynomorph Distribution Chart INTEGRATED SUMMARY * 100-900' Tertiary to Quaternary Undifferemiated 900-1750'? Tertiary Early Pliocene 17507-2890' Tertiary Undifferentiated 2890-3330' Tertiary Probable Late Eocene 3330-3960' Tertiary Middle Eocene * Logs not available. 3960-4140' 4140-6300' 6300-7290' 7290-8010' 8010-8550' 8550-8730' Tertiary Early Eocene Tertiary Paleocene Late Cretaceous Maestrichtian Late Cretaceous Campanian Late Cretaceous Turonian to Santonian Early Cretaceous Middle to Late Albian 8730-8910' Early Cretaceous Barremian to Early Albian 8910-9573.3'C Early Cretaceous Hauterivian to Barremian KEHB(1), KEHB(2) ~ KEHB(3) 9573.3C-10,000'T.D. Early Cretaceous Probable Berriasian to Valanginian Discussion. See Foraminifera Report for possible alternate interpretation of this interval. FORAMINIFERA SUMMARY 100-900' Age. Environment. Tertiary to Quaternary Undifferemiated Probable Nonmarine to Inner Neritic (Alluvial Plain & Inner Delta Plain) 900-1750'? Zone. Environment. Tertiary Early Pliocene F-2A(2) Inner Neritic (Inner Shelf) 17507-2890' A~e. Environment. Tertiary Undifferemiated Nonmarine to Marginal Marine (Alluvial Plain to Inner Delta Plain) 2890-4140'? Zone. Environment. Tertiary Possible Eocene F-3B(4)? to F-3A(4)? Marginal Marine to Inner Neritic (Inner Delta Plain & Interdistributary Bay) 41407-6390' Zone. Environment. Tertiary Probable Paleocene F-4(1)? to F-4(2) Nonmarine to Inner Neritic (Alluvial Plain to Inner Delta Plain) 6390-8010' Age. Zone. Environment. Late Cretaceous Campanian to Maestrichtian F-5 to F-6 Middle Neritic to Middle Bathyal (Delta Plain, Delta Front & Prodelta or Slope) 8010-8550' Age. Zone. Environment. Late Cretaceous Turonian to Santonian F-7 Middle to Lower Bathyal (Base of Slope, Distal - Starved Basin) 8550-8730! Zone. Environment. Early Cretaceous Possible Albian F-Il? Lower Bathyal (Base of Slope, Distal - Starved Basin) 8730-8910' Environment. Early Cretaceous Undifferentiated Lower Bathyal (Base of Slope, Distal - Starved Basin) 8910-9573.3'C? Zone. Environment. Discussion. Early Cretaceous Hauterivian to Barremian F-12 to F-13 Middle Neritic to Upper Bathyal (Middle Shelf to Upper Slope) This interval probably contains KE~iB0) (8910-9030'); KElm(2) (9030-9210') and KE}m(3) (9210-9573.3'C) strata. 9573.3C?-10,000'T.D. Affe. Zone. Environment. Discussion. Early Cretaceous Possible Berriasian to Valanginian F-137 to F-147 9573.3C?-9800': 9800-10,000'T.D.: Inner to Middle Neritic (Inner to Middle Shelf) Middle Neritic to Upper Bathyal (Middle Shelf to Upper Slope) This interval is placed in the Berriasian to Valanginian on the basis of palynomorph occurrences. Diversity/ Abundance correlations with the Long Island No. 1 well suggest that these strata may represent the KE}m(3) and KElm(4) intervals. The following correlations are suggested by this alternate interpretation: Long Island No. 1 Northstar No. 3 KEHB(1) 8150-8255' 8910-9030' KERB(2) 8255-8380' 9030-9210' KEmp(3) 8380-8770' 9210-9710' KEHB(4) 8770-9100' 9710-10,000'T.D. INTRODUCTION Scope Micropaleo Consultants, Inc. processed, picked and analyzed for Foraminifera 150 ditch samples, 16 sidewall core samples and 17 conventional core samples from the Amerada Hess Northstar No. 3 well. These samples covered the interval 100 to 10,000 feet total depth. Ditch samples were composited on 90' intervals above 8460 feet and 30' intervals below 8460 feet. This work was done as part of M.C.I. Job Number 94- 103. Procedures Standard techniques were used to process the material. All samples were boiled in Quaternary-O and washed over 20 and 200 mesh screens. Frequency symbols correspond to the following numerical values: very rare (1), rare (2-10), frequent (11- 32), common (33-99) and abundant (100+). The ditch samples were processed by M.C.I. in San Diego, California, while the sidewall cores were processed by ARCO in Anchorage, Alaska. Certain factors such as shelf widths, basin configuration and overall basin depths associated with Arctic Mesozoic basins are not completely understood at present. The paleoenvironments presented in this report reflect relative basinal position only and should not be tied to specific water depths. Generally, neritic corresponds to shelf or deltaic environments, while bathyal corresponds to slope or prodelta environments, and bathyal (starved basin) corresponds to distal (far from the source) deposition. As an example, prodelta deposits could represent deposition as shallow as middle neritic or as deep as bathyal (slope) depending on the delta type and shelf width. With a narrow shelf, a river-dominated deltaic system could build across the shelf and the prodelta deposits would be in a bathyal (slope) depth. A tide-dominated deltaic system associated with a wide shelf could result in middle neritic prodelta deposition. Format A listing of the age, environment, fauna and occasional lithology comments for each biostratigraphic interval follows. A generalized summary of the well is presented in the Conclusions section at the end of the Foraminifera Report. A Foraminifera Distribution Chart (Figure F-I) and a High Resolution Biostratigraphy Chart based on foraminiferal data (Figure F-2) are in pockets at the back of this report. 10 RESULTS 100-900' Environment. Fauna. Tertiary to Quaternary Undifferentiated Probable Nonmarine to Inner Neritic (Alluvial Plain & Inner Delta Plain) El£hidiella hannai, E. ustulatum, Globulina inaequalis, plant debris, calcispheres, shell fragments, coal and pyrite. 900-1750'? Zone. Environment. Fauna. Tertiary Early Pliocene F-2A(2) Inner Neritic (Inner Shelf) Cibicides grossus, C. perlucidus, Dentalina soluta, Polymorphina sp., Cribroelphidium crassum, EIphidiella acutum, ostracods, shell fragments, calcispheres, echinoid spines, coal, pyrite and rare glauconite at 1000-1090 feet. 17507-2890' Environment. Fauna. Tertiary Undifferentiated Nonmarine to Marginal Marine (Alluvial Plain to Inner Delta Plain) Barren of Foraminifera. Calcispheres, coal and pyrite. 11 2890-4140'? Zone. Environment. Fauna. Tertiary Possible Eocene F-3B(4)? to F-3A(4)? Marginal Marine to Inner Neritic (Inner Delta Plain & Interdistributary Bay) Lenticulina sp., Haplophragmoides cadnatus, Bathysiphon sp. (large, coarse), megaspores, fish debris, pyrite, pyrite sticks and frequent to common pyrite oblates below 3420 feet. 41407-6390' Zone. Environment. Fauna. Tertiary Probable Paleocene F-4(1)? to F-4(2) Nonmarine to Inner Neritic (Alluvial Plain to Inner Delta Plain) Mostly barren of Foraminifera with very rare occurrences ofReticulophragmium borealis. Calcispheres, pyrite and tar. 12 6390-8010' Zone. Environment. Fauna. Late Cretaceous Campanian to Maestrichtian F-5 to F-6 Middle Neritic to Middle Bathyal (Delta Plain, Delta Front & Prodelta or Slope) Arenobulimina torula, Haplophragtnoides rota, H. excavata, H. cadnatus, Reticulophragmium borealis, Saccammina lathrami, Vemeuilinoides fisched, V. bearpawensis, Trochammina albertensis, T. dbstonensis, Bathysiphon varans, B. vitta, Ammodiscus cretaceus, A. mangusi, Anomalinoides pinguis, Praebulimina venusae, Pullenia cretacea, Eoeponidella strombodes, Quirutueloculina sphaera, megaspores, pyrite, tar, rare to frequent Trochamminoktes sp. (small, thin) below 7560 feet and frequent to common paper shale below 7740 feet. 8010-8550' Zone. Environment. Fauna. Late Cretaceous Turonian to Santonian F-7 Middle to Lower Bathyal (Base of Slope, Distal - Starved Basin) Bathysiphon vitta, Haplophragmoides excavata, H. rota, Trochamminoides sp. (small, thin), Saccammina lathrami, Inoceramus prisms, fish debris, megaspores, frequent to common radiolaria and common to abundant paper shale. 13 8550-8730' Zone. Environment. Fauna. Early Cretaceous Possible Albian F-11? Lower Bathyal (Base of Slope, Distal - Starved Basin) Haplophragmoides topagorukensis, H. excavata, Trocharnmina sp. (small), Inoceramus prisms, fish debris, megaspores, frequent to common pyritized radiolaria including Lithocampe N in the bottom sample (8700-8730'), and abundant paper shale throughout the interval. 8730-8910! Aee. Environment. Fauna. Early Cretaceous Undifferentiated Lower Bathyal (Base of Slope, Distal - Starved Basin) Essentially barren of indigenous Foraminifera. Very rare occurrences of Thuramminoides sp. and Ammodiscus sp. (very small, very thin) may be in place. Fish debris, lnoceramus prisms, megaspores, pyrite, frequent to common pyritized radiolaria, abundant paper shale and frequent rounded frosted quartz floating sand grains below 8850 feet. 14 8910-9573.3'C? Zone. Environment. Fauna. Discussion. Early Cretaceous Hauterivian to Barremian F-12 to F- 13 Middle Neritic to Upper Bathyal (Middle Shelf to Upper Slope) Arenaceous spp. (large, coarse), Bathysiphon scintillata, B. granulocoelia, Haplophragmoides duoflatis, H. coronis, Trochammina squamatc~ T. conicominutcl, Ammobaculites erectus, A. reophacoides, Glomospira subarctica, Glomospirella arctica, Gravellina 1, Lenticulina muensteri, L. sp. (raised sutures), L. gryci, Thuramminoides sp., Ammodiscus mackenziensis, Gaudryina tailleuri, G. subcretacea, G. cushmani, Lituomba gallupi, Nodosatia sp. (square), N. nana, Saracenaria projectura, Inoceramus prisms, pyrite, rare to frequent glauconite below 9420 feet and rare to abundant scattered rounded frosted quartz floating sand grains. This interval probably contains KEH~o) (8910-9030'); KEIm(2) (9030-9210') and KERB(3) (9210-9573.3'C) strata. 15 9573.3C?-10,000q'.D. Zone. Environment. Fauna. Discussion. Early Cretaceous Possible Berriasian to Valanginian F-137 to F-147 9573.3C?-9800': 9800-10,000'T.D.: Inner to Middle Neritic (Inner to Middle Shelf) Middle Neritic to Upper Bathyal (Middle Shelf to Upper Slope) Essentially the same fauna as above. Older age suggested on the basis of palynomorph analysis. Frequent Haplophragmoides inflatigrandis below 9830 feet and a single specimen of Gaudryina leffingwelli at 9862.0'SW are all the foram evidence we have for a Berriasian to Valanginian age and these may well be reworked. This interval is placed in the Berriasian to Valanginian on the basis of palynomorph occurrences. Diversity/ Abundance correlations with the Long Island No. 1 well suggest that these strata may represent the KE}m(3) and KEHB(4) intervals. The following correlations are suggested by this alternate interpretation: .,Long Island No. 1 Northstar No. 3 KEtm(~) 8150-8255' 8910-9030' KElm(2) 8255-8380' 9030-9210' KEI_m(3) 8380-8770' 9210-9710' KEHB(4) 8770-9100' 9710-10,000'T.D. 16 CONCLUSIONS The Amerada Hess Northstar No. 3 well penetrated the following biostratigraphic sequence based on foraminiferal analysis: 2790'+ (100-2890') of Miocene? to Pleistocene age (Upper Brookian) shallow nonmarine to inner neritic clastics. 1250' (2890-4140'?) of possible Eocene age (Middle Brookian) delta plain and interdistributary bay deposits. 4410' (41407-8550') of Turonian to Paleocene age (Early Brookian) base of slope bottomsets, slope foresets and shelf topsets. 1023.3' (8550-9573.3'C?) of Hauterivian to possible Albian age (Early Brookian & Beaufortian - Rift Sequence) base of slope bottomsets. 426.7'+ (9573.3C?-10,000'T.D.) of disputed age (Beaufortian - Rift Sequence) deposits. Paly indicates a Berriasian to Valanginian age while foram analysis suggests it may still be Hauterivian to Barremian, KE}m(3) and KEHB(4). 17 3960-4140' Zone. Environment. Tertiary Early Eocene P-Mllc Marginal Marine 4140-6300' Age. Zone. Tertiary Paleocene P-T10 Environment. Nonmarine 6300-7290' Late Cretaceous Maestrichtian Zone. Environment. P-Tll and marginal marine equivalent Nonmarine - Marginal Marine 7290-7830' Zone. Environment. Late Cretaceous Campanian P-T12 and marine equivalent Marine 20 7830-8190' Zone. Environment. Late Cretaceous Santonian - Campanian P-M14 Marine 8190-8550' Zone. Environment. Late Cretaceous Turonian - Coniacian P-M15 Marine 8550-8730' Zone. Environment. Early Cretaceous Middle- Late Albian P-M17 Marine 8730-8910' Zolle. Environment. Early Cretaceous Barremian- Early Albian P-M18a Marine 21 8910-9573.3'C Zone. Early Cretaceous Hauterivian- Barremian P-M19 Environment. Marine 9573.3C-10,000"r.D. Zone. Early Cretaceous Berriasian- Valanginian P-M20 Environment. Marginal Marine 22 INTRODUCTION Purpose and Scope Micropaleo Consultants, Inc. (M.C.I.) conducted palynological analyses on a total of 183 samples from the Amerada Hess Northstar No. 3 well. The samples consisted of 150 ditch cutting composites and 16 sidewall core and 17 conventional core samples taken between 100 feet and the total depth of 10,000 feet. Procedures All samples were processed by M.C.I. in San Diego, California. The processing involved standard palynologic techniques using hydrochloric acid, hydrofluoric acid and nitric acid treatments. The resultant kerogen residues were further concentrated by heavy liquid separation, sonification and a sieving/panning technique. Permanent slide mounts were made of the residues. Two square coverslips are placed on each sample slide. One square has the greater than 20 micron fraction and the second square contains the 10-20 micron fraction. As each sample was examined, an estimate of abundance for each palynomorph taxon was recorded in a microcomputer. These data form the basic elements of the species distribution chart. Based on the palynomorph assemblages observed, an age and generalized environment of deposition were interpreted for each palynostratigraphic subdivision. The environments, as interpreted from the palynological preparations, are simply categorized as nonmarine, marginal marine or marine. The categories are based on the absence or presence and diversity of microplankton. Report Format The following Results section gives the age, environment of deposition and significant palynomorphs for each palynological subdivision. This is an expansion of the brief Summary at the beginning of the report. After the Results, some generalized interpretations are outlined in the Conclusions section. 23 The palynomorph species distribution chart (Figure P-1) is located in the pocket. The reported palynomorph frequencies of occurrence represent the following quantities: Very rare = single specimen, Rare = 2-5 specimens, Few = 6-15 specimens, Common = 16-30 specimens and Abundant = greater than 30 specimens. 24 RESULTS 100-1000' A~e. Environment. Palynomorphs. Tertiary to Quaternary Pliocene to Pleistocene Essentially nonmarine This uppermost interval is characterized by a limited spore- pollen assemblage. The main constituent is the bisaccate pollen. Sporadic occurrences of reworked Mesozoic and Paleozoic spores and dinocysts. 1000-2890' A~e. Environment. Palynomorphs. Tertiary Undifferentiated Essentially nonmarine This interval recovered a nondescript Tertiary spore-pollen assemblage. The assemblage included Alnipollenites, Betulaceae, Ericaceae and Laevigatosporites. Scattered occurrences of Tiliaepollenites and Ulmipollenites were also recorded. The reworked spore-pollen constituents remain similar to the interval above. The few microplankton recorded are reworked Cretaceous species. 25 2890-3330' Zone. Environment. Palynomorphs. Tertiary Probable Late Eocene Probable P-Mlla Nonmarine The important characteristics for this interval are the consistent occurrences of Tiliaepollenites and Ulmipollenites. Due to the absence of any other age significant palynomorphs, the age assignment is qualified. No marine palynomorphs were recorded in this interval. 3330-3960' Zone. Environment. Palynomorphs. Tertiary Middle Eocene P-Mllb Marginal Marine The Middle Eocene interval is marked by the appearance of dinocysts. This assemblage includes the species Cordosphaeridium sp. (fine processes), Deflandrea wetzelii and Wetzeliella articulata. The reworked assemblage continues similar to the undifferentiated Tertiary section above. 26 3960-4140' Zone. Environment. Palynomorphs. Tertiary Early Eocene P-Mllc Marginal Marine The basal Eocene interval is identified by the appearance of Isabelidinium pellucidum. The reworked assemblage as seen above continues through this interval. 4140-6300' Zone. Environment. Palynomorphs. Paleogene Paleocene P-T10 Nonmarine The Paleocene section is marked by the appearance of the pollen Paraalnipollenites confusus. The reworked assemblage continues into the upper part of this section, but decreases in the lower part of this unit. 27 6300-7290' Zone. Environment. Palynomorphs. Late Cretaceous Maestrichtian P-Tll and marginal marine equivalent Nonmarine to Marginal Marine Separation of the Maestrichtian section is based on the presence of the pollen species Aquilapollenites magnus. The dinocyst assemblage includes species of Chatangiella biapertura and Chatangiella spp. 7290-7830' Zone. Environment. Palynomorphs. Late Cretaceous Campanian P-T12 and marine equivalent Marine The Campanian interval is identified by the appearance of the pollen Aquilapollenites trialatus and Aquilapollenites quadricretae. The dinocyst assemblage increases in diversity. The constituents include Chatangiella biapertura, Chatangiella spp., Isabelidinium cooksoniae and Laciniadinium biconiculum. 28 7830-8190' Zone. Environment. Palynomorphs. Late Cretaceous Santonian to Campanian P-M14 Marine The spore-pollen fraction is relatively unimportant in this interval. The important dinocyst species are Chatangiella decorosa, Chatangiella ditissima and Trithyrodinium suspectum. 8190-8550' Affe. Zone. Environment. Palynomorphs. Late Cretaceous Turonian to Coniacian P-M15 Marine This interval is marked by the occurrences of the dinocyst Isabelidinium globosum and Nelsoniella aceras. 29 8550-8730' Zone. Environment. Palynomorphs. Early Cretaceous Middle to Late Albian P-M17 Marine This section of Albian strata is separated by the appearance of a few dinocyst marker species. The marker forms are Luxadinium propatulum, Ovoidinium verrucosum and Spinidinium vestitum. 8730-8910' Zone. Environment. Palynomorphs. Early Cretaceous Barremian to Early Albian P-M18a Marine This interval is defined by the increased abundance of Odontochitina operculata and Oligosphaeridium complex. Also appearing in this interval is Fromea amphora, Gardodinium deflandrei and Micrhystridium sp. A. 3O 8910-9573.3'C Zone. Environment. Palynomorphs. Remarks. Early Cretaceous Hauterivian to Barremian P-M19 Marine The Hauterivian - Barremian interval is marked by the a diverse dinocyst assemblage. This assemblage includes the species Florentinia cooksoniae, Gardodinium trabeculosum, Herendeenia alaskaensis, Imbatodinium micropodum, Oligosphaeridium complex (thick-wall) and Tubotuberella uncinamm . This interval is marked by an abundant and diverse assemblage of reworked palynomorphs. The reworked forms include Mississippian spores and Jurassic to Valanginian dinocysts. 31 9573.3C-10,000'T.D. Zone. Environment. Palynomorphs. Remarks. Early Cretaceous Berriasian to Valanginian P-M20 Marginal Marine The Berriasian - Valanginian interval shows a change to a spore-pollen dominated assemblage and a relative decrease in dinocyst diversity. This nonmarine assemblage includes the forms Classopollis classoides, Exesipollenites tumulus, Gleicheniidites senonicus, Pilosisporites trichopapillosus and Trilobosporites spp. The dinocyst assemblage includes the marker species Gochteodinia villosa, Oligosphaeridium vasiforum and Tubotuberella apatela. The most common dinocyst is the longer ranging form Oligosphaeridium complex. The diversity and abundance of the reworked assemblage is significantly decreased in this interval. The sidewall and conventional core samples provide palynological evidence for defining the upper boundary of this interval. The cores show the absence of the Hauterivian form Gardodinium trabeculosum in this interval and the change to a poorer marine assemblage. The transition to this spore-pollen dominated assemblage is commonly seen in sequences when the Berriasian - Valanginian section is encountered. 32 CONCLUSIONS Palynological analysis of the Amerada Hess Northstar No. 3 well provides the following generalized palynostratigraphic succession: Nonmarine and marginal marine Tertiary age strata occur from 100 feet to 6300 feet. Marginal marine and marine strata of Campanian and Maestrichtian age are identified from 6300 feet to 7830 feet. Marine Santonian- Campanian age strata occur between 7830 feet and 8190 feet. Marine strata of Turonian- Coniacian age occur from 8190 feet to 8550 feet. Marine strata of Middle - Late Albian age are present from 8550 feet to 8730 feet. Marine Barremian - Early Albian age strata are identified between 8730 feet and 8910 feet. Marine Hauterivian - Barremian age strata occur from 8910 feet to 9573.3 feet. The core samples provide evidence for the placement of the lower boundary of this interval. The reworked spore-pollen assemblage is very abundant and diverse in this interval. Marginal marine strata of Berriasian - Valanginian age occur between 9573.3 feet and the total depth of 10,000 feet. 33 PALYNOLOGY SUMMARY 100-1000' Environment. Tertiary - Quaternary Pliocene- Pleistocene Essentially nonmarine 1000-2890' Environment. Tertiary Undifferentiated Essemially nonmarine 2890-3330' Zone. Environment. Tertiary Probable Late Eocene Probable P-Mlla Nonmarine 3330-3960' Zone. Environment. Tertiary Middle Eocene P-Mllb Marginal Marine 19 RIvt~:RRDR HI:SS ~ORPORRTI,~I April 28, 1994 1201 LOUISIANA, SUITE 700 HOUSTON, TEXAS 77002-5681 713-658-9770 Alaska Oil & Gas Commission Dave Johnson, Chairman 3001 Porcupine Drive Anchorage AK 99501 RE: Northstar #3, Northstar Unit, Beaufort Sea AK Dear Mr. Johnson: I am sending you under separate cover one (1) LIS Tape and support data for the MWD logs, four (4) MWD Log Films and Prints, two (2) Mud logs (no films were made), and a Core Analysis Report. A transmittal is attached. In accordance with provisions of 11 AAC 82.810(a), Amerada Hess Corporation hereby requests that this information be kept confidential. It has been so marked. Wet and dry samples were sent to you directly from the wellsite and transmittals were faxed to you. Also films & prints of the wireline logs were sent on April 20, 1994. I have not yet received signed copies of those transmittals. A Paleo Report, a VSP Report, LIS Tapes and core chips for the well are being prepared and will be sent as soon as they are done. Sincerely, AMERADA HESS CORPORATION J. A. Ready Exploration Manager, Northstar JAR:bmc Attachments cc: C. Richard P. E. Bacon R. Gardner- Fairweather RECEIVED MAY - 4 1994 Alaska Oil & Gas Cons. Commission Anchorage TRANSMITTAL SHEET FI~OM AC)ORE..SS · ~,o ~ ~,,~ e ,~ ~ ,'"'.~ /J /~,':,'~I ,.)- ~ fi. , ~ ,10EPA RTM ENT .4~ ~ . ~ANTITY OESCRI~TION I ; i ~' '- ' ~ I ~_ ~ ~~ ,' 'FYP . ~ ~orage RETURN ONE SIGNED COPY TO AMERAOA HE~ CORPORATION AT THE ABOVE AOORE~ PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA_PLUS 93-203 93-2O3 93-203 93-203 93-203 93-203 93-203 93-203 93-203 93-203 93-203 93-203 93-203 93-203 93-203 93-203 93-203 93-203 93-203 93-203 93-203 93-203 93-203 93-203 93-203 93-203 ARRAY/DDBHC/SDT L 132-9952 ARRAY/DDBHC/SDT L 132-9952 CBT L 5600-8862 CET L 5600-8862 CST L 9634-9863 DPR/GR DPR/GR DPR/GR DPR/GR FMI LDT LDT/GR LDT/GR LDT/NP MDT MUD NGT PIL/SFL/AIT/GR PIL/SFL/AIT/GR 407 CORE ANALYSIS DAILY WELL OP SURVEY DRY DITCH WET SAMPLES 6095 L 3920-9982, MD L 3920-9982, MD L 3920-9982, TVD L 3920-9982, TVD L 9230-9846 L 9001-9774 L 996-7784 L 996-7784 L 9001-9774 L 9001-9774 L 105-10000, COLOR (2) L 7500-9981 L 132-9989 L 132-9989 R COMP DATE: 03/28/94 R 9436-9595 R 01/31/94-03/22/94 R 0-10000 S 100-10000 SS#909 S 5 BOXES T 3824-10000, OH-DPR/GR RUN 1-4 1-4 3.5 3.5 4 1-8 1-8 1-8 1-8 4 4 2-3 2-3 4 4 4 124 124 4-9 Page: 1 Date: 05/04/94 DATE_RECVD 04/21/94 04/21/94 04/21/94 04/21/94 04/21/94 04/29/94 04/29/94 04/29/94 04/29/94 04/21/94 04/21/94 04/21/94 04/21/94 04/21/94 04/21/94 04/29/94 04/21/94 04/21/94 04/21/94 04/26/94 04/29/94 04/26/94 04/26/94 04/20/94 04/20/94 04/29/94 AOGCC Individual Well Geological Materials Inventory Page' 2 Date: 05/04/94 PERMIT DATA T DATA_PLUS RUN DATE_RECVD Are dry ditch samples required? ~yes) no And received? ~f_es~ Was the well cored? ~ no Analysis & description received? Are well tests required? yes no Received? yes no no Well is in compliance . Initial Comments ~-~ ~ ~'~-- ', .;~~--~.Z-~~',,] , ~ '~IF: ~~ Laboratories, Inc. 4342 West 12th Street · Houston, Texas 77055 Telephone (713) 680-2291 · Fax (713) 680-0763 CORE ANALYSIS AMERADA HESS CORPORATION NORTHSTAR NO. 3 WELL BEAUFORT SEA FIELD OFFSHORE ALASKA FINAL REPORT FILE NO.: 21126 APRIL 1994 RF. CEIVED AMERADA HESS CORPOP,~T~ 2 9 l~Zl. ~/aska Oil & Gas Cons. Commission CONFIDENTIAL ~,~o~ l/ /c Date . . ...... Reports submitted by ])TS Laboratories, Inc. are based on the analysis of materials and information supplied by the client, and cannot be guaranteed. These opinions and interpretations expressed represent our best judgment; however, ])TS Laboratories, Inc. assumes no responsibility nor makes any warranty regarding profits or performance resulting from the use of such reports. PTS Laboratories, Inc. April 22, 1994 4342 Wesl 12Ih Street · Houslon, Texas 77055 Telephone (713) 680-2291 · Fax (713) 680-0763 Amerada Hess Corporation 1201 Louisiana, Suite 700 Houston, Texas 77002 Attn: Mr. Jeff Ready Re: Core Analysis Northstar No. 3 Well Beaufort Sea Field Offshore Alaska File No.: 21126 The following report contains final data for core analysis performed on core material from the subject well. Descriptions of laboratory procedures have been included for your reference. Three sets of 15 foot format, color photographs were issued previous to this report. Per the request of Amerada Hess, the slabbed and bulk core sections, as well as the five preserved sections, of the Northstar No. 3 Well have been forwarded to C&M Storage in Schulenberg, Texas. All trimmed ends and plugs have been forwarded to Mr. Mike Volk and Mr. Scott Pluim of Amerada Hess in Tulsa, Oklahoma. Samples from twelve depths were forwarded to Mr. Jeff Ready of Amerada Hess in Houston, Texas. We appreciate the opportunity to have been of service to Amerada Hess Corporation. If there are any questions, or if we may be of further assistance, please telephone either Rick Schweizer, Routine Core Analysis Manager, or Mike Walker, General Manager, at (713) 680-2291. Sincerely, PTS Laboratories, Inc. Peter T. Schuyler President P~$ Laboratories, Inc. Amerada Hess Corporation File No.' 21126 TABLE OF CONTENTS SECTION I Procedures Documentation SECTION II Retort Core Analysis SECTION !11 Conventional Core Analysis SECTION IV Plots Basic Properties Gamma Log Four Parameter Log SECTION V Inventories Samples Inventory Core Box Inventory Laboratories, Inc. Amerada Hess Corporation File No. '21126 SECTION I PROCEDURES DOCUMENTATION Laboratories, Inc. Amerada Hess Corporation File No. :21126 PROCEDURES DOCUMENTATION A. CORE PREPARATION Core Handling Approximately 180 feet of 4 inch diameter core material was received at PTS Laboratories in Houston, Texas. PTS provided services at the rigsite. Prior to shipment to PTS, the core was cut into 3 foot sections. From selected sections, samples were taken and forwarded to PTS Houston for retort core analysis. The full diameter core, was secured in wooden freezer crates for shipment. Upon arrival at PTS, the core was uncrated and organized by depth. A core box inventory is presented in Section V. ,. Fluid Saturations and Porosity by Retort Method The summation of fluids retort analysis was performed on selected depths to provide quick information on porosity and fluid saturations. Prior to analysis, an end was trimmed from each sample and the material was forwarded to Amerada Hess in Tulsa, Oklahoma. The summaiion of fluids procedure involves the independent determination of gas, oil, and pore water volumes on fresh core samples. The volumes are combined to obtain pore volume. Bulk volume was determined by mercury displacement. The gas volume was measured by mercury injection at 750 psia. The oil and water saturations are determined by a high temperature retort. The retort temperature was initially 350°F to collect free water, then elevated to 1200°F to recover oil. The retort collection tubes were centrifuged to separate the mercury, water, and oil. The recorded water volumes were corrected to interstitial water saturation based on the clay content visually determined for each sample. The volume of oil was corrected for material loss during retorting and recorded as residual oil. The corrected water, oil, and gas volumes were converted to percent bulk volume and totaled to yield a summation of fluids porosity. The summation of fluids porosity data and saturation as a percent of pore space are presented in Section II of this report. 3. Surface Core Gamma Proceeding in reverse depth order, the natural total gamma radiation count of all core material received was recorded. A calibration tube of 200 APl units was used to monitor equipment accuracy. The resultant gamma was graphed versus depth with gamma radiation increasing to the right. This data is presented in Section IV of this report. Laboratories, Inc. Amerada Hess Corporation File No.: 21126 4. Core Preservation Five depths were selected for core preservation. A six inch section of the full diameter core was trimmed. The core was wrapped in saran wrap and foil, then placed into ProtecCore and sealed. The preserved sections remain with the bulk sections in storage. m Core Slabbing To retain saturations in place, all core material was refrigerated prior to slabbing into 1/3 - 2/3 sections with a masonry circular saw. As the core was cut, the core surfaces were cleared of slabbing residue. The core was remeasured and marked to the nearest 0.05 feet. Each section was placed into pre-cut poly bags and sealed to preserve saturation content (for photographic purposes). The 2/3 slab section was kept refrigerated while the 1/3 section was forwarded for detailed photography. 1 Core Photography To capture the full fluorescence visible in the core, color photographs were taken of the 1/3 sections within one hour of slabbing. A detailed, high quality, natural and ultraviolet light record of the recovered core material was presented in table format, eacl~ photograph representing approximately 15 feet of core. Three copies of the photographs were issued previous to this report. B. CONVENTIONAL CORE ANALYSIS Sample Selection Amerada personnel selected the depths for conventional core analysis. The sample locations were measured to the nearest 1/20th foot. An inventory of analysis depths with specific information is found in Section V of this report. = Sample Plugging One inch diameter, horizontal plugs were drilled from the 2/3 section using liquid nitrogen vent gas as the bit coolant and lubricant. In addition to the 150 horizontal plugs, 8 vertical plugs were drilled perpendicular to bedding. All plugs were packaged in a double layer of aluminum foil with 200 mesh stainless steel end screens taking care to minimize foil overlap on the plug ends. Foil and screen weights were recorded for future accountability. The plugs were stressed under 500 psi hydrostatic load to seat the foil. 3. Sample Cleaning Using a reflux soxhlet, the selected plugs were extracted of hydrocarbons with toluene, then leached of leached of residual salts with methanol. The very shaly Laboratories, Inc. Amerada Hess Corporation File No.: 21126 samples were dried in an oven at 145°F and 40 percent relative humidity. All other samples were dried to stable weights in a Iow temperature oven. 4. Sample Description A PTS geologist performed a brief lithologic description on each analysis depth, focusing on key characteristics such as rock type, grain size, color, cementation, accessory mineral constituents, fluorescence, and reaction to 10 percent HCI acid. The iithologic description is presented with the core analysis data in Section III. 5. Petrophysical Measurements a. Grain Volume Direct grain volume measurements were made on each porosity/permeability plug using a small volume porosimeter. This instrument utilizes Boyle's Law principle of gas expansion. Helium was used as the expanding gas. b. Grain Density Apparent grain density was calculated from the measured grain volume and the sample dry weight. Cl Plug Dimensions Sample lengths and diameters were measured using metric calipers. Six lengths and six diameters were taken for each sample. These values were averaged and corrected for foil and screen dimensions. Using the average, bulk volume is calculated as a cross-reference value to the Boyle's Law derived bulk volume. d= Porosity Each plug sample was mounted in a rubber sleeve that is flexible and durable enough to conform to the sample at overburden conditions, the loaded into an overburden cell for pore volume and permeability measurements. A net confining stress of 300 psi was applied. Pore volume was determined directly by expanding helium at 95 psig into a system of known volume. At pressure equilibrium, Boyle's Law was used to compute the pore volume. e. Permeability While loaded in the overburden ceil, the permeability of each plug was measured by the steady-state method. As nitrogen flowed through the sample upstream and downstream (i.e. atmospheric) pressures were monitored. Permeability was then calculated using Darcy's Law for linear gaseous flow. Basic properties data are presented in tabular format in Section III. Excepting the vertical samples, graphical presentations of the basic properties, individual zones and composite, are found in Section IV. Laboratories, Inc. Amerada Hess Corporation File No. '21126 SECTION !1 RETORT CORE ANALYSIS PTS Laboratories, Inc. Amerada Hess Corporation File No.' 21126 Well: Field: Location: Northstar No. 3 Beaufort Sea Offshore Alaska RETORT CORE ANALYSIS Date: · April 1994 Core Type: 4" conventional Mud Type: Water Base Recovered Inches Depth, feet Est. Perm to Air, md Sum. Porosity, percent Zone 1' 9436.00 - 9443.00 feet Saturation Percent PV Oil I Water Saturation Percent BV Oil Gas I I Critical Probable Comb. Water, ProductionI Gas ! percent Core 1:9436.00 - 9467.00 feet Lithological Description 1.4 9436.0 85. 22.8 1.0 23.6 0.2 17.2 GAS 0 50.0 Sst: It brn, vf-fgr, fnt yel fluor, fr cut 1.9 9439.0 57. 21.3 1.9 15.3 0.4 17.6 GAS 0 51.0 Sst: It bm, vf-fgr, fnt yel fluor, fr cut 1.8 9442.0 55. 21.2 2.0 19.0 0.4 16.8 GAS 0 51.0 Sst: grysh-brn, vf-fgr, sli slty, fnt yel fluor, fr cut Zone 2:9443.00 - 9467.00 feet 1.3 9445.0 0.11 6.1 0.0 94.4 0.0 0.3 LOK 0 75.0 Sst: dk gry, vfgr, vslty, cl (35% matrix), mic, no fluor, no cut 0.9 9448.0 0.16 8.4 3.2 86.3 0.3 0.9 LOK 0 78.0 Sst: gry, vfgr, s!ty, cl (20% matrix), mic, mott fnt yel fluor, p cut 0.0 9451.0 Not received 0.0 9454.0 Not received 0.0 9457.0 Not received 1.9 9460.0 0.2 8.6 4.3 88.6 0.4 0.6 LOK 0 76.0 Sst: dk gry, vfgr, vslty, cl (40% mott), mic, mott fnt yel fluor, sli cut 1.9 9463.0 0.11 6.5 1.0 95.0 0.1 0.3 LOK 0 73.0 Sst: dk gry, vfgr, vslty, cl (40% mott), mic, mott fnt yel fluor, sli cut 1.9 9465.0 0.1 6.8 5.6 79.0 0.4 1.1 LOK 0 75.0 Sst: grysh-brn, vf-fgr, vslty, cl (25% matrix), mic, mott fnt yel fluor, fr cut I1-1 PTS Laboratories, Inc. Well: Northstar No. 3 Field: Beaufort Sea Location: Offshore Alaska Recovered Inches Depth, feet Est. Perm to Air, md Sum. Porosity, percent Saturation Percent PV Oil I Water. Saturation Percent BV Oil i Gas Zone 2:9500.00 - 9510.00 feet 1.6 9466.9 0.11 6.9 1.1 89.7 0.1 0.6 1.2 9500.0 0.46 11.0 0.8 55.9 0.1 4.8 1.8 9503.0 1.4 15.6 1.4 53.3 0.2 7.1 1.9 9506.0 1.5 12.4 0.4 69.4 0.1 3.7 RETORT CORE ANALYSIS Amerada Hess Corporation File No.: 21126 Date:- April 1994 Corn Type: 4" conventional Mud Type: Water Base Probable ] Comb. Production] Gas Critical Water, percent Core 2:9500.00 - 9560.00 feet Lithological Description LOK 0 76.O LOK 0 66.0 LOKG 0 56.0 LOK 0 62.0 Sst: brnsh-gry, vfgr, vslty, cl (40% moA), mic, mott fnt yel fluor, sli cut Sst:, brnsh-gry, vfgr, slty, cl (20% mott), mic, mort fnt yel fluor, p cut Sst: It brnsh-gry, vfgr, sli slty, cl (5% matrix), fnt yel fluor, fr cut Sst: It brn-gry, vfgr, slty, cl (20% mot-t), fnt yel fluor, fr cut 1.9 9509.0 0.6 4.0 0.0 90.5 0.0 0.4 Zone 3:9510.00 - 9560.00 feet 1.9 9512.0 2.1 8.2 0.6 71.2 0.1 2.3 1.8 9515.0 4.4 16.6 2.3 65.2 0.4 5.4 1.0 9518.0 7.1 18.6 1.6 64.8 0.3 6.3 1.6 9521.0 1.5 13.9 0.0 64.0 0.0 5.0 1.0 9524.0 110. 23.5 1.0 70.6 0.2 6.7 1.7 9526.0 6.3 13.3 0.6 53.4 0.1 6.1 1.0 9528.0 1.7 11.9 0.9 50.8 0.1 5.8 LOK 0 74.0 LOK 0 65.0 LOKG 0 67.0 LOKG 0 67.0 LOKG 0 64.O GAS 0 48.0 LOKG 0 58.0 LOKG 0 62.0 11-2 Sst: brnsh-gry, vfgr, slty, dns, no fluor, no cut Sst: brn, vfgr, slty, sli calc, mort fnt yel fluor, fr cut : Sst: brn, vfgr, slty, sli calc, mott fnt yel fluor, gd cut Sst: brn, vfgr, slty, fnt yel fluor, gd cut Sst: brn, vfgr, slty, cl (10% moot), fnt yel fluor, gd cut Sst: grysh-brn, vf-fgr, sli slty, fri, mott fnt yel fluor, gd cut Sst: grysh-brn, vf-fgr, sli slty, cl (10% mott), sli calc, mott fnt yel fluor, gd cut Sst: brnsh-gry, vf-fgr, sli slty, cl (15% moA), mic, mort fnt yel fluor, fr cut PTS Laboratories, Inc. Well: Northstar No. 3 Field: Beaufort Sea Location: Offshore Alaska RETORT CORE ANALYSIS Recovered Inches Depth, feet Est. Perm to Air, md Sum. Porosity, percent Saturation [ Saturation Percent PV I Percent BV Oil IWater. l Oil Gas Probable Production [ Critical Com'b. ] Water, Gas I percent Core 2:9500.00 - 9560.00 feet Zone 3:9510.00 -9560.00 feet 1.0 9531.0 8.4 12.0 0.0 63.1 0.0 4.4 LOK 0 55.0 1.9 9534.0 55. 24.5 1.1 65.9 0.3 8.1 GAS 0 56.0 1.4 9537.0 0.11 7.0 0.0 72.9 0.0 1.9 LOK 0 75.0 1.5 9540.0 7.2 14.9 0.7 36.1 0.1 9.4 LOKG 0 60.0 1.0 9543.0 1000. 30.1 1.8 67.7 0.5 9.2 GAS 0 35.0 1.0 9546.0 210. 23.2 2.0 61.6 0.5 8.5 GAS 0 42.0 1.8 9549.0 0.5 10.9 0.0 40.5 0.0 6.5 LOKG 0 66.0 1.6 9552.0 24. 21.8 2.3 50.8 0.5 10.2 GAS 0 62.0 1.9 9555.0 120. 23.8 0.6 37.5 0.1 14.7 GAS 0 48.0 1.0 9557.0 140. 24.3 1.6 46.5 0.4 12.6 GAS 0 46.0 1.8 9559.3 11. 18.1 2.5 36.2 0.5 11.1 GAS 0 61.0 1.0 9560.0 21. 18.8 3.4 45.6 0.6 9.6 GAS 0 60.0 Amerada Hess Corporation File No.' 21126 Date: ' April 1994 Core Type: 4" conventional Mud Type: Water Base Lithological Description Sst: grysh-brn, vf-fgr, slty, cl (10% mot), fri, fnt yel fluor, gd cut Sst: brn, vf-fgr, fri, fnt yel fluor, fr cut Sst: brnsh-gry, vfgr, slty, sli calc, dns, mott fnt yel fluor, p cut Sst: It brn, vfgr, slty, cl (15% moB), mort fnt yel fluor, p cut Sst: grysh-brn, vf-fgr, fri, fnt yel fluor, gd cut Sst: grysh-brn, vf~fgr, fri, fnt yel fluor, gd cut Sst: brnsh-gry, vfgr, slty, sli calc, dns, no fluor, fnt cut Sst: brn, vf-fgr, fri, fnt yel fluor, fr cut Sst: grysh-brn, vf-fgr, slty, mott fnt yel fluor, fr cut Sst: brnsh-gry, vf-fgr, fri, fnt yel fluor, gd cut Sst: grysh-brn, vf-fgr, sli slty, sli fri, fnt yel fluor, fr cut Sst: grysh-brn, vf-fgr, fri, fnt yel fluor, gd cut II-3 Laboratories, Inc. Well: Northstar No. 3 Field: Beaufort Sea Location: Offshore Alaska Recovered Inches Depth, feet Est. Perm to Air, md Sum. Porosity, percent Zone 5:9593.00 - 9617.90 feet 1.5 9598.0 0.7 10.4 1.0 9601.0 0.11 8.7 1.8 9604.0 0.19 6.7 1.2 9607.0 0.2 11.5 1.0 9610.0 0.11 8.9 1.0 9613.0 0.11 8.8 1.0 9616.0 0.3 10.0 1.0 9616.1 0.4 10.1 0.8 9660.0 21. 23.0 0.4 9661.0 13. 19.9 0.8 9702.0 2.7 18.4 0.6 9772.0 370. 27.9 0.6 9774.0 75. 24.1 I pSeartcUernali;;PercentSaturati°nBV 'I Oil I Water Oil I' Gas I I ICore RETORT CORE ANALYSIS I I Critical Probable Com'b. Water, ProductionI Gas I percent 3:9560.00 - 9617.90 feet Amerada Hess Corporation File No.' 21126 Date: ' Apdl 1994 Core Type: 4" conventional Mud Type: Water Base Lithological Description 0.0 91.4 0.0 0.9 LOK 0 62.0 0.0 84.3 0.0 1.4 LOK 0 76.0 7.8 74.7 0.5 1.2 LOK 0 74.0 0.6 89.4 0.1 1.2 LOK 0 69.0 0.8 85.6 0.1 1.2 LOK 0 75.0 3.3 80.3 0.3 1.4 LOK 0 76.0 1.1 81.4 0.1 1.8 LOK 0 66.0 4.9 76.1 0.5 1.9 LOK 0 65.0 1.1 79.7 0.3 4.4 WTR 0 65.0 0.5 88.3 0.1 2.2 WTR 0 65.0 1.9 67.2 0.3 5.7 LOK 0 70.0 8.4 86.8 2.3 1.3 WTR 0 41.0 6.8 89.2 1.6 0.9 WTR 0 53.0 Sst: gry, vfgr, vslty, cl (20% thn lam), mic, no fluor, no cut Sst: dk gry, vfgr, vslty, cl (40% lam), mic, dns, no fluor, no cut Sst: dk gry-gry, vfgr, slty, cl (35% lam), mic, no fluor, sli cut Sst: gry, vfgr, vslty, cl (45% lam), mic, no fluor, fnt cut Sst: dk gry, vfgr, vslty, cl (45% lam), mic, no fluor, fnt cut Sst: dk gry, vfgr, slty, cl (45% lam), mic, no fluor, fnt cut Sst: brnsh-gry, vfgr, slty, cl (40% lam), mic, mott fnt yel fluor, p cut Sst: brnsh-gry, vfgr, slty, cl (40% lam), mic, mort fnt yel fluor, p cut Sst: brnsh-gry, vf-fgr, cl (20% thk lam), mott fnt yel fluor, fr cut Sst: It gry-gry, f-mgr, sli slty, cl (15% mott), sli calc, strk fnt yel fluor, sli cut Sst: brn, v'rgr, slty, cl (30% lam), mic, spot fnt yel fluor, sli cut Sst: brn, vfgr, sli clac, fnt yel fluor, gd cut, 27° APl Sst: It brn, vfgr, sli slty, cl (5% thn lam), sli calc, fnt yel fluor, gd cut, 25° AP II-4 ~$ Laboratories, Inc. Well: Nodhstar No. 3 Field: Beaufort Sea Location: Offshore Alaska Recovered Inches Depth, feet Est. Perm to Air, md Sum. Porosity, percent Saturation Percent PV Oil I Water Saturation Percent BV Oil Gas Zone 4:9561.00 - 9593.00 feet 1.9 9562.0 9.9 15.9 0.3 44.4 0.1 1.0 9566.0 13. 19.8 0.4 46.8 0.1 1.1 9569.0 1.9 16.5 0.0 41.8 0.0 1.0 9572.0 0.4 9.4 1.3 82.9 0.1 1.0 9575.0 0.7 11.1 0.0 55.9 0.0 1.9 9578.0 1.2 14.7 0.4 35.3 0.1 1.8 9581.0 0.3 12.0 0.5 41.6 0.1 1.1 9584.0 12. 16.3 0.6 29.2 0.1 1.4 9586.7 9.1 16.2 2.8 42.8 0.5 1.6 9589.0 6.1 15.3 0.5 41.5 0.1 1.0 9592.0 0.26 9.5 6.0 74.2 0.6 Zone 5:9593.00 - 9617.90 feet 1.0 9595.0 0.2 8.9 3.0 80.6 0.3 RETORT CORE ANALYSIS I I Critical Probable Corr{b. Water, ProductionI Gas I percent Core 3:9560.00 - 9617.90 feet 8.8 LOKG 0 60.0 10.5 GAS 0 65.0 9.6 LOKG 0 70.0 1.5 LOK 0 65.0 4.9 LOKG 0 64.0 9.5 LOKG 0 67.0 7.0 LOKG 0 68.0 11.5 GAS 0 56.0 8.8 LOKG 0 61.0 8.9 LC)KG 0 61.0 1.9 LOK 0 75.0 1.5 LOK 0 71.0 Amerada Hess Corporation File No.: 21126 Date:' April 1994 Core Type: 4" conventional Mud Type: Water Base Lithological Description Sst: brn, vf-fgr, slty, sli fri, fnt yel fluor, gd cut Sst: brn, vf-fgr, sli slty, cl (10% thn lam), sli fri, fnt yel fluor, gd cut Sst: It brn, vfgr, sli slty, cl (10% thn lam), fnt yel fluor, fr cut Sst: dk brnsh-gry, vf-fgr, slty, cl (35% mott), sli calc, mic, no fluor, fnt cut Sst: dk brnsh-gry, vfgr, slty, cl (25% lam), mic, no fluor, p cut Sst: brn, vfgr, slty, cl (10% thn lam), mic, fnt yel fluor, fr cut Sst: bm, vfgr, slty, cl (20% lam & matrix), mic, mott fnt yel fluor, fr cut Sst: bm, vfgr, slty, cl (10% thn lam), mic, fnt yel fluor, fr cut Sst: brn, vfgr, slty, cl (10% thn lam), mic, fnt yel fluor, fr cut Sst: brn, vfgr, slty, cl (10% thn lam), mic, fnt yel fluor, fr cut Sst: dk brn-brn, vfgr, slty, cl (40% lam), mic, mott fnt yel fluor, fr cut Sst: dk brn-brn, vfgr, slty, cl (40% lam), mic, mott fnt yel fluor, fr cut 11-5 Laboratories, Inc. Amerada Hess Corporation File No.: 21126 PROBABLE PRODUCTION SYMBOLS ALT EXP INS CDF LOK GAS COND OIL VVTR TRAN PGP PCP POP LOKG LOKO RFR ALTERED CORE EXPOSED CORE INSUFFICIENT SAMPLE CORE CONTAMINATED BY DRILLING FLUID LOW PERMEABILITY GAS PRODUCTION CONDENSATE PRODUCTION OIL PRODUCTION WATER TRANSITION ZONE POSSIBLE GAS PRODUCTION POSSIBLE CONDENSATE PRODUCTION POSSIBLE OIL PRODUCTION LOW PERMEABILITY GAS LOW PERMEABILITY OIL REFER TO ATTACHED LETTER II-6 ~"J"$ Laboratories, inc. Amerada Hess Corporation File No.' 21126 SECTION ill CONVENTIONAL CORE ANALYSIS Laboratories, Inc. Well: Northstar No. 3 Field: Beaufort Sea Location: Offshore Alaska Sample ID Depth, feet 300 psi NOB I Permeabilityl I Grain to Air, I Porosity, I Density, millidarciesI percent I g/cc Zone 1' 9436.00 - 9443.00 feet I 9436.30 387. 23.4 2.66 2 9437.00 208. 21.9 2.73 3 9438.00 340. 23.7 2.68 4 9439.00 146. 21.3 2.78 5 9439.01 163. 21.7 2.79 6 9440.00 274. 23.1 2.72 7 9441.00 474. 24.7 2.69 8 9442.00 224. 17.5 2.64 Zone 2:9443.00 - 9467.00 feet 9 9443.00 *2.6 7.3 2.65 10 9444.00 0.11 6.9 2.67 11 9445.10 0.04 7.6 2.65 12 9446.00 '0.12 8.0 2.68 Amerada Hess Corporation File No.' 21126 CONVENTIONAL CORE ANALYSIS Date: April 1994 Core Type: 4" conventional Mud Type: Water Base I Saturation ONV I Percent Pore Volume RatioI O Iwaterl Total Comments Lithological Description Core 1:9436.00 - 9467.00 feet Cut: 31.00 feet Recovered: 30.65 feet 0.04 2.0 50.1 52.1 Sst: brnsh-gry, vfsd, sli fri, mod cmt, no odor, It stn, v fnt fluor 0.05 2.9 54.0 56.9 Sst: brnsh-gry, vfsd, sli fri, mod cmt, no odor, It stn, v fnt fluor 0.07 3.7 50.6 54.3 Sst: brnsh-gry, vfsd, sli fri, mod cmt, no odor, It stn, v fnt fluor 0.08 3.0 35.6 38.6 Sst: brnsh-gry, vfsd, sli fri, mod cmt, no odor, It stn, v fnt fluor 0.02 1.1 43.8 44.9 Vertical Sst: It brn, vfsd, mod cmt, no odor, It stn, v fnt yel fluor 0.12 5.6 46.4 52.1 0.06 2.5 45.4 47.9 Sst: brnsh-gry, vfsd, sli fri, mod cmt, no odor, It stn, v fnt fluor Sst: brnsh-gw, vfsd, sli fri, mod cmt, no odor, It stn, v fnt fluor 0.01 0.7 46.7 47.4 Sst: gry, vfsd, wi cmt, no odor, v It stn, v fnt fluor 0.00 0.0 98.7 98.7 *Fractured Ka Sst: dk gry, cl-vfsd, shly, wi cmt, Mic, no odor, no stn, no fluor 0.00 0.0 99.3 99.3 Sst: dk gry, cl-vfsd, shly, wi cmt, Mic, no odor, no stn, no fluor 0.00 0.0 99.3 99.3 Sst: dk gry, cl-vfsd, shly, wi cmt, Mic, no odor, no stn, no fluor 0.00 0.0 98.3 98.3 *Fractured Ka !11- 1 Sst: dk gry, cl-vfsd, shly, wi cmt, Mic, no odor, no stn, no fluor Laboratories, Inc. Well: Northstar No. 3 Field: Beaufort Sea Location: Offshore Alaska Sample ID Depth, feet 300 psi NOB PermeabilityI to Air, I Porosity, millidarcies I percent Grain Density, g/cc Zone 2:9443.00 - 9467.00 feet 13 9447.00 0.07 7.4 2.66 14 9448.00 0.07 9.4 2.65 15 9449.00 *'0.15 6.7 2.67 16 9450.00 *0.87 7.0 2.65 17 9451.10 0.16 7.7 2.65 18 9452.00 0.11 8.8 2.67 19 9453.00 0.07 5.4 2.85 20 9454.00 0.09 8.4 2.65 21 9455.10 0.09 10.0 2.66 22 9456.10 0.09 8.6 2.64 23 9457.00 0.08 10.8 2.65 CONVENTIONAL CORE ANALYSIS I Saturation OAN I Percent Pore Volume Ratio I' oil IwaterJ TotaI Amerada Hess Corporation File No.: 21126 Date: April 1994 Core Type: 4" conventional Mud Type: Water Base Comments Lithological Description Core 1' 9436.00 - 9467.00 feet Cut: 31.00 feet Recovered: 30.65 feet 0.00 0.0 98.7 98.7 0.01 1.3 97.8 99.1 0.00 0.0 99.3 99.3 **Fractured, est. Ka 0.00 0.0 95.4 95.4 *Fractured Ka 0.00 0.0 98.7 98.7 0.00 0.0 96.8 96.8 0.00 0.0 99.1 99.1 0.00 0.0 98.6 98.6 0.00 0.0 98.9 98.9 0.00 0.0 98.3 98.3 0.08 7.6 89.3 96.8 Sst: dk gry, cl-vfsd, shly, wi cmt, Mic, no odor, no stn, no fluor Sst: gry, cl-vfsd, wi cmt, sps Mic, no odor, no stn, spt fnt yel fluor Sst: dk gry, cl-vfsd, shly, wi cmt, sps Mic, no odor, no stn, no fluor Sst: gry, cl-vfsd, shly, wi cmt, sps Mic, no odor, no stn, no fluor Sst: dk gry, cl-vfsd, shly, wi cmt, Mic, no odor, no stn, no fluor Sst: gry, cl-vfsd, shly, wi cmt, sps Mic, no odor, no stn, no fluor Sst: gry, cl-vfsd, shly, wi cmt, sps Mic, no odor, no stn, no fluor Sst: gry, cl-vfsd w/thn Sh lam, wi cmt, sps Mic, no odor, no stn, no fluor Sst: dk gry, cl-vfsd, shly, wi cmt, Mic, no odor, no stn, no fluor Sst: dk gry, cl-vfsd, shly, wi cmt, Mic, no odor, no stn, no fluor Sst: brnsh-gry, cl-vfsd, shly, wi cmt, sps Mic, no odor, It stn, mott fnt yel fluor [~$ Laboratories, Inc. Well' Nodhstar No. 3 Field: Beaufort Sea Location: Offshore Alaska Sample ID Depth, feet 300 psi NOB I Permeability'l I Grain to Air, I Porosity, I Density, millidarcies! percent I g/cc Zone 2:9443.00 - 9467.00 feet CONVENTIONAL CORE ANALYSIS i I Saturation : OAN I Percent Pore Volume i Rati° I Oil Iwaterl Total comments Core 1' 9436.00 - 9467.00 feet Cut: 31.00 feet Recovered: 30.65 feet 24 9458.00 0.08 10.6 2.65 0.05 4.3 90.6 95.0 25 9459.00 0.05 8.3 2.65 0.00 0.0 98.2 98.2 26 9460.00 0.08 10.7 2.66 0.00 0.0 94.6 94.6 27 9461.00 0.11 9.4 2.66 0.00 0.0 97.9 97.9 28 9462.00 0.25 9.1 2.64 0.00 0.0 98.4 98.4 Amerada Hess Corporation File No.' 21126 29 9463.00 0.13 8.2 2.66 0.00 0.0 98.2 98.2 Date: April 1994 Core Type: 4" conventional Mud Type: Water Base 30 9464.10 0.14 10.8 2.63 0.03 2.4 93.2 95.6 31 9465.00 0.04 10.8 2.75 0.00 0.0 98.7 98.7 Lithological Description 32 9466.00 *'0.10 8.6 2.66 Sst: brnsh-gry, cl-vfsd, mod cmt, Mic, no odor, It stn, sptd fnt yel fluor Sst: gry, cl-vfsd, shly, wi cmt, Mic, no odor, no stn, no fluor Sst: gry, cl-vfsd, shly lam, wi cmt, Mic, no odor, no stn, no fluor Sst: gry, cl-vfsd, shly lam, wi cmt, Mic, no odor, no stn, no fluor Sst: gry, cl-vfsd, shly lam, wi cmt, Mic, no odor, no stn, no fluor Sst: gry, cl-vfsd, shly lam, wi cmt, Mic, no odor, no stn, no fluor Sst: brnsh-gry, cl-vfsd, shly, wi cmt, Mic, no odor, It stn, mott fnt yel fluor Sst: brnsh-gry, cl-vfsd, wi cmt, Mic, no odor, It stn, no fluor 0.00 0.0 99.4 99.4 **Fractured, est. Ka Sst: gry, cl-vfsd, shly, wi cmt, Mic, no odor, no stn, no fluor Laboratories, inc. Well: Northstar No. 3 Field: Beaufort Sea Location: Offshore Alaska Sample ID Depth, feet 300 psi NOB PermeabilityI to Air, I Porosity, millidarcies I percent Grain Density, g/cc Zone 2:9500.00 - 9510.00 feet 33 9500.30 0.17 12.9 2.65 34 9501.10 0.27 12.8 2.65 35 9502.00 0.21 12.6 2.65 36 9503.00 1.1 15.5 2.65 37 9504.00 1.1 16.9 2.66 38 9504.01 0.66 16.7 2.65 39 9505.00 3.2 17.2 2.64 40 9506.10 2.9 15.3 2.66 41 9507.00 2.6 16.6 2.68 42 9508.00 3.6 17.0 2.64 43 9509.10 <0.01 6.4 3.04 Amerada Hess Corporation File No.: 21126 CONVENTIONAL CORE ANALYSIS Date: April 1994 Core Type: 4" conventional Mud Type: Water Base ! I Saturation ! OAN I Percent Pore Volume :Ratio I °il IWaterl T°tal I Comments Lithological Description Core 2:9500.00 - 9560.00 feet Cut: 60.00 feet Recovered: 59.60 feet 0.00 0.0 97.7 97.7 Sst: gry, cl-vfsd, shly, wi cmt, sps Mic, no odor, It stn, no fluor 0.02 2.2 96.2 98.4 Sst: grysh-brn, cl-vfsd, mod cmt, sps Mic, no odor, It stn, mort fnt yel fluor 0.01 0.9 96.9 97.8 Sst: grysh-brn, cl-vfsd, mod cmt, sps Mic, no odor, It stn, mott fnt yel fluor 0.08 6.2 80.2 86.4 Sst: grysh-brn w/blk gr, slt-vfsd, mod cmt, no odor, It stn, fnt yel fluor 0.08 6.4 83.4 89.8 Sst: brn w/blk gr, slt-vfsd, mod cmt, fr odor, It stn, fnt yel fluor 0.04 3.4 82.4 85.9 Vertical Sst: brn w/blk gr, slt-vfsd, mod cmt, fr odor, It stn, fnt yel fluor 0.08 5.9 72.4 78.3 Sst: brn w/blk gr, slt-vfsd, mod cmt, fnt odor, It stn, fnt yel fluor 0.00 0.0 82.2 82.2 Sst: brn/gn w/blk gr, slt-vfsd, mod cmt, Glauc, fnt odor, It stn, mott fnt yel fluor 0.04 3.4 83.1 86.5 Sst: brn/gn w/blk gr, slt-vfsd, mod cmt, fnt odor, It stn, mott fnt yel fluor 0.02 2.0 87.8 89.8 Sst: brn w/blk gr, slt-vfsd, mod cmt, fr odor, med stn, fnt yel fluor 0.00 0.0 94.0 94.0 Sst: gry, cl-crssd, wi cmt, Glauc, no odor, no stn, no fluor Laboratories, Inc. Amerada Hess Corporation File No.: 21126 Well: Northstar No. 3 Field: Beaufort Sea Locstion: Offshore Alaska Sample ID Depth, feet 300 psi NOB Permeability] to Air, I Porosity, millidarcies I percent Grain Density, g/cc Zone 3:9510.00 - 9560.00 feet CONVENTIONAL CORE ANALYSIS I Saturation OAN I Percent Pore Volume RatioIOilIWaterlTotal Comments Core 2:9500.00 - 9560.00 feet Cut: 60.00 feet Recovered: 59.60 feet Date: April 1994 Core Type: 4" conventional Mud Type: Water Base Lithological Description 44 9510.00 184. 23.3 2.76 0.03 1.8 69.8 71.6 Sst: brn, slt-fsd, fri, mod cmt, fr odor, mad stn, strk yel fluor 45 9511.00 119. 18.4 2.75 0.02 1.7 97.9 99.6 Sst: brn, slt-fsd, fri, mod cmt, fr odor, mad stn, strk yel fluor 46 9512.10 352. 24.0 2.93 0.00 0.0 59.8 59.8 Sst: grysh-brn, cl-msd, fri, mod cmt, Mic, v fnt odor, It stn, v fnt fluor 47 9513.00 541. 21.7 2.67 0.03 2.0 76.8 78.8 Sst: brn, vf-fsd, cly, fri, mod cmt, fr odor, mad stn, yel fluor 48 9514.00 328. 20.4 2.79 0.01 1.2 78.7 79.9 Sst: brn, vf-msd, cly, fri, prly cmt, fr odor, mad stn, mott yel fluor 49 9515.00 1.5 16.7 2.98 0.04 3.8 93.0 96.8 50 9516.00 211. 20.8 2.88 0.00 0.3 71.9 72.1 Sst: brn, slt-fsd, cly, fri, mod cmt, fr odor, mad stn, mott yel fluor Sst: brn, slt-fsd, cly, mod cmt, fr odor, mad stn, mott yel fluor 51 9517.00 880. 21.7 2.73 0.02 1.1 69.7 70.9 Sst: brn, slt-fsd, cly, fri, prly cmt, fr odor, mad stn, yel fluor 52 9518.10 92. 21.2 2.92 0.01 1.1 76.2 77.3 Sst: brn, slt-fsd, cly, fri, mod-prly cmt, fnt odor, It stn, mott yel fluor 53 9518.11 102. 18.6 2.97 0.01 0.6 74.9 75.5 Vertical Sst: brn, slt-msd w/sml cly mott, sli fri, mod-prly cmt, fr odor, mad stn, mo'ct yel fluor 54 9519.00 502. 18.2 2.69 0.00 0.0 80.4 80.4 55 9520.10 387. 21.4 2.76 0.00 0.0 75.8 75.8 Sst: brn, slt-fsd, cly, sli fri, mod-prly cmt, fr odor, mad stn, yel fluor Sst: brn, vf-fsd, cly, sli fri, mod-prly cmt, fr odor, mad stn, yel fluor Laboratories, Inc. Well' Northstar No. :3 Field: Beaufort Sea Location: Offshore Alaska Sample ID Depth, feet 300 psi NOB PermeabilityI to Air, I Porosity, millidarciesI percent Zone 3:9510.00 - 9560.00 feet 56 9521.10 189. 20.2 57 9522.00 250. 23.6 58 9523.00 108. 19.6 59 9524.00 305. 23.1 60 9525.00 190. 20.9 61 9526.00 520. 24.3 62 9527.00 225. 21.8 63 9528.00 0.58 11.5 64 9529.10 238. 19.9 65 9530.30 232. 24.6 66 9531.00 10. 20.2 Grain Density, g/Cc CONVENTIONAL CORE ANALYSIS I Saturation ONV I Percent Pore Volume , Ratio I .°il I waterl Total Comments Core 2:9500.00 - 9560.00 feet Cut: 60.00 feet Recovered: 59.60 feet 2.93 0.00 0.3 76.9 77.2 2.88 0.00 0.0 81.2 81.2 2.96 0.00 0.0 79.3 79.3 2.92 0.00 0.0 79.9 79.9 2.88 0.00 0.0 74.8 74.8 2.87 0.02 1.3 75.0 76.3 2.94 0.05 3.7 78.2 81.9 3.05 2.99 2.91 Amerada Hess Corporation File No.' 21126 2.97 Date: April 1994 Core Type: 4" conventional Mud Type: Water Base Lithological Description 0.00 0.0 86.4 86.4 0.13 9.3 71.1 80.3 0.18 12.4 69.6 82.0 0.11 8.6 80.9 89.5 Sst: brn, vf-fsd, cly, sli fri, prly cmt, fr odor, med stn, yel fluor Sst: brn, vf-fsd, cly, fri, prly cmt, fr odor, med stn, mott fnt yel fluor Sst: It grysh-brn, cl-msd, wi cmt, fnt odor, It stn, spt fnt yel fluor Sst: brn, fsd, cly, fri, prly cmt, fnt odor, med stn, fnt yel fluor Sst: brn, fsd, cly, fri, prly cmt, fnt odor, med stn, fnt yel fluor Sst: brn, fsd, cty, fri, prly cmt, fnt odor, med stn, fnt yel fluor Sst: brn/gry, slt-fsd, sli fri, prly cmt, fnt odor, It stn, mott fnt yel fluor Sst: It brn/gry, cl-vcrssd, wi cmt, no odor, v It stn, sptd yel fluor Sst: brn, slt-fsd, mod cmt, fnt odor, It stn, fnt yel fluor Sst: brn, vf-fsd wlind mott, sli fri, mod cmt, fr odor, med stn, mott fnt yel fluor Sst: brn, vf-fsd w/ind mot't, sli fri, mod cmt, fr odor, med stn, mott fnt yel fluor Laboratories, Inc. Well: Nodhstar No. 3 Field: Beaufort Sea Location: Offshore Alaska Sample ID I 300 psi NOB IPermeabilityl Depth, I toAir, I Porosity, feet I millidarciesl percent Grain Density, g/cc Zone 3:9510.00 - 9560.00 feet 67 9531.01 188. 19.4 3.04 68 9532.70 978. 28.7 2.71 69 9533.30 572. 26.1 2.77 70 9534.00 905. 26.0 2.70 71 9535.00 1.8 16.3 3.00 72 9536.20 772. 25.8 2.69 73 9537.00 315. 22.7 2.84 74 9538.00 547. 21.7 2.87 75 9539.00 1.1 12.4 2.83 CONVENTIONAL CORE ANALYSIS ,,, I I Saturation I OAN I Percent Pore Volume IRati° I oil I Waterl Total Amerada Hess Corporation File No.: 21126 Date: April 1994 Core Type: 4" conventional Mud Type: Water Base Comments Lithological Description Core 2:9500.00 - 9560.00 feet Cut: 60.00 feet Recovered: 59.60 feet 0.03 2.5 76.7 79.1 Vertical 0.01 0.7 78.2 78.9 0.00 0.2 76.4 76.6 0.01 0.6 74.4 75.0 0.02 2.1 90.6 92.6 0.01 0.8 70.2 71.0 0.02 1.4 76.9 78.3 0.04 2.8 79.6 82.4 0.03 2.7 95.8 98.5 Sst: brn, vf-fsd w/ind mot-t, sli fri, mod cmt, fr odor, med stn, mott fnt yel fluor Sst: brn, vf-fsd w/sps ind mott, fri, prly cmt, fnt odor, med stn, v fnt yel fluor Sst: brn, slt-msd, sli fri, prly-mod cmt, fnt odor, med stn, v fnt yel fluor Sst: brn, vf-fsd, sli fri, mod cmt, no odor, med stn, v fnt yel fluor Sst: grysh-brn, slt-fsd, mod-wi cmt, fnt odor, It stn, mott fnt yel fluor Sst: brn, fsd, fri, prly cmt, fnt odor, med stn, v fnt yel fluor Sst: brn, cl-fsd w/ind mott, mod cmt, fnt odor, med stn, mott fnt yel fluor Sst: grysh-brn, cl-msd w/ind mott, fri, prly/wl cmt, fnt odor, med stn, fnt yel fluor Sst: grysh-brn, cl-msd w/ind mott, fri, prly/wl cmt, fnt odor, med stn, fnt yel fluor Laboratories, Inc. Amerada Hess Corporation File No.: 21126 Well: Northstar No. 3 Field: Beaufort Sea Location: Offshore Alaska CONVENTIONAL CORE ANALYSIS Date: April 1994 Core Type: 4" conventional Mud Type: Water Base Sample ID Depth, feet Permeability[ Grain Saturation to Air, I Porosity, I Density, I O/W I Percent Pore Volume millidarcies I percent I .g/cc I Ratio J Oi.I I Wat~l Tota= Comments Lithological Description Core 2:9500.00 - 9560.00 feet Cut: 60.00 feet Recovered: 59.60 feet Zone 3:9510.00 - 9560.00 feet · 76 9540.10 805. 26.7 2.92 0.03 2.3 80.8 83.0 Sst: grysh-brn, cl-msd w/ind mort, fri, prly/wl cmt, fnt odor, med stn, fnt yel fluor 77 9541.00 384. 23.8 2.95 0.01 0.5 84.4 84.9 Sst: grysh-brn, cl-fsd w/ind mott, fri, prly/wl cmt, fnt odor, med stn, mort fnt yel fluor 78 9542.00 568. 24.3 2.89 0.04 3.0 79.5 82.5 Sst: brn, cl-msd w/ind mott, fri, prly-mod cmt, Glauc, fnt odor, med stn, mott fnt yel fluor 79 9543.50 .1040. 28.5 2.86 0.03 2.3 74.6 76.8 Sst: brn, vf-msd, cly w/sps ind mot-t, fri, prly cmt, Giauc, fnt odor, med stn, fnt yel fluor 80 9543.51 237. 24.4 2.98 0.08 6.2 78.5 84.7 Vertical Sst: brn, vf-msd, cly w/sps ind mott, fri, prly cmt, Glauc, fnt odor, med stn, fnt yel fluor 81 9544.00 253. 27.9 2.95 0.01 0.8 81.9 82.7 Sst: It grysh-brn, cl-fsd, sli fri mot-[, mod-wi cmt, no odor, It stn, mott yel fluor 82 9545.00 531. 28.7 2.90 0.02 1.5 76.1 77.6 Sst: brn, cl-fsd w/ind mott, prly-mod cmt, fnt odor, med stn, fnt yel fluor 83 9546.00 332. 23.4 2.95 0.07 4.9 70.9 75.8 Sst: grysh-brn, cl-vfsd w/ind mott, sli fri, mod cmt, v fnt odor, med stn, fnt yel fluor PTS Laboratories, Inc. Well: NorthStar No. 3 Field: Beaufort Sea Location' Offshore Alaska Sample ID 300 psi NOB PermeabilityI Depth, to Air, I Porosity, feet I millidarciesl percent Zone 3:9510.00 - 9560.00 feet 84 9547.00 494. 22.7 85 9548.30 *378 12.4 86 9549.20 0.22 10.2 87 9550.00 2.0 12.3 88 9551.00 1400. 26.2 89 9552.00 519. 22.7 90 9553.00 916. 23.5 91 9554.10 <0.01 3.5 92 9555.00 1430. 23.2 CONVENTIONAL CORE ANALYSIS IDensity' I O/VV I Percent Pore Volume I I g/cc I Ratio I oil I waterl TotalI Amerada Hess Corporation File No.: 21126 Date: April 1994 Core Type: 4" conventional Mud Type: Water Base Comments Lithological Description Core 2:9500.00 ~ 9560.00 feet Cut: 60.00 feet Recovered: 59.60 feet 2.93 0.01 0.5 72.6 73.2 2.98 0.00 0.0 78.5 78.5 *Fractured Ka 3.02 0.04 3.8 84.9 88.7 3.06 0.03 2.3 85.0 87.2 2.71 0.00 0.0 71.2 71.2 2.77 0.00 0.0 74.3 74.3 2.66 0.00 0.0 71.5 71.5 3.08 0.00 0.0 91.3 91.3 2.65 0.01 0.8 61.6 62.4 Sst: grysh-brn, vf-msd, sli fri, prly-mod cmt, Glauc, v fnt odor, It- reed stn,v fnt yel fluor Sst: brnsh-gry, cl-crssd, mod cmt, no odor, It stn, spks yel fluor Sst: brnsh-gry, cl-crssd, mod-wi cmt, Glauc, v fnt odor, It stn, mott yel fluor Sst: grysh-brn, cl-msd, fri mott, mod-wi cmt, Glauc, v fnt odor, med stn, fnt yel fluor Sst: grysh-brn, vf-fsd, cly, mod-wi cmt, Glauc, no odor, med stn, v fnt yel fluor Sst: grysh-brn, vf-fsd, cly w/ind mott, fri, mod cmt, no odor, med stn, v fnt yel fluor Sst: grysh-brn, vf-fsd, cly, fri, prly cmt, no odor, med stn, v fnt yel fluor Sst: brnsh-gry, cl-fsd, wi cmt, no odor, v It stn, no fluor Sst: grysh-brn, vf-crssd, fri, prly cmt, fnt odor, med stn, fnt yel fluor ~$ Laboratories, Inc. Well: Northstar No. 3 Field: Beaufort Sea Location: Offshore Alaska Sample ID Depth, feet 300 psi NOB PermeabilityI to Air, I Porosity, millidarcies I percent Zone 3:9510.00 - 9560.00 feet 93 9555.01 974. 19.3 94 9556.00 0.02 3.1 95 9557.00 1400. 24.9 96 9558.00 3890. 26.8 97 9559.00 593. 21.8 Grain Density, g/cc 2.68 CONVENTIONAL CORE ANALYSIS I Saturation OAN I Percent Pore Volume., Ratio I Oil IWaterl .Total Comments Core 2:9500.00 - 9560.00 feet Cut: 60.00 feet Recovered: 59.60 feet 0.02 1.3 66.0 67.3 Vertical Amerada Hess Corporation File No.: 21126 Date: April 1994 Core Type: 4" conventional Mud Type: Water Base 3.17 0.00 0.0 98.5 98.5 2.72 0.00 0.3 59.3 59.5 Lithological Description 2.65 0.01 0.5 52.0 52.4 2.72 0.02 1.1 65.4 66.5 Sst: grysh-brn, vf-crssd, fri, prly cmt, fnt odor, med stn, fnt yel fluor Sst: gry, cl-msd w/shly mott, wi cmt, no odor, v It stn, no fluor Sst: brn/gry, vf-fsd, cly, sli fri, mod cmt, Sid, fnt odor, med stn, fnt yel fluor Sst: brnsh-gry, vf-msd, fri, prly cmt, no odor, It stn, v fnt mott yel fluor Sst: grysh-brn w/blk gr, slt-fsd, sli fri, mod cmt, no odor, It stn, v fnt yel fluor Laboratories, Inc. Well: Northstar No. 3 Field: Beaufort Sea Location: Offshore Alaska Sample ID Depth, feet 300 psi NOB PermeabilityI Grain to Air, I Porosity, Density, millidarciesI percent g/cc Zone 4:9560.00 - 9593.00 feet 98 9560.40 174. 21.0 2.82 99 9561.00 <0.01 1.7 3.04 100 9562.00 148. 18.9 2.76 101 9563.00 350. 18.5 2.66 102 9564.00 4.1 14.8 2.66 103 9565.00 <0.01 1.2 3.07 104 9566.00 21. 18.5 2.70 105 9566.01 6.7 18.7 2.68 106 9567.00 8.1 18.5 2.73 Amerada Hess Corporation File No.: 21126 CONVENTIONAL CORE ANALYSIS Date: April 1994 Core Type: 4" conventional Mud Type: Water Base I Saturation O/W I Percent Po,re Volume Ratio I Oil, IWaterl Total Comments Core 3:9560.00 - 9620.00 feet Cut: 60.00 feet Recovered: 57.90 feet Lithological Description 0.01 0.9 63.3 64.2 0.00 0.0 66.7 66.7 0.00 0.0 70.0 70.0 0.00 0.3 67.5 67.9 0.06 4.8 76.0 80.8 0.00 0.0 68.0 68.0 0.12 8.3 70.9 79.2 0.14 9.4 68.7 78.1 Vertical 0.16 12.0 72.7 84.7 Sst: brn w/blk gr, cl-fsd, sli fri, mod cmt, fnt odor, med stn, v fnt yel fluor Sst: gry w/blk gr, cl-fsd, dns, v wi cmt, no odor, strk It stn, strk yel fluor Sst: brn w/blk gr, cl-fsd, sli fri, mod-wi cmt, Sid, v fnt odor, It stn, mott fnt yel fluor Sst: brn w/blk gr, cl-fsd, sli fri, prly cmt, Sid, v fnt odor, It stn, mott fnt yel fluor Sst: mott brn/dk grysh-brn, cl-fsd, mod cmt, no odor, It stn, mott y, fluor Sst: gry, cl-vfsd, v wi cmt, Sid, no odor, no stn, no fluor Sst: brn/dk gry, cl-vfsd w/ind strk, sli fri, mod cmt, v fnt odor, It- med stn, mott fnt yel fluor Sst: brn/dk gry, cl-vfsd w/ind strk, sli fri, mod cmt, v fnt odor, It- med stn, mott fnt yel fluor Sst: brn, slt-fsd, mod cmt, no odor, It stn, fnt yel fluor ~$ Laboratories, inc. Well: Northstar No. 3 Field: Beaufort Sea Location: Offshore Alaska Sample ID I 300 psi NOB I IPermeabilit~;I Grain I Depth, I to Air, I Porosity, I Density, feet I millidarciesl percent I g/cc Zone 4:9560.00 - 9593.00 feet 107 9568.00 9.7 17:7 2.68 108 9569.00 7.9 18.7 2.76 109 9570.00 2.3 17.8 2.93 110 9571.00 0.54 9.0 2.66 111 9572.00 '4.1 10.8 2.63 112 9573.00 '1.5 10.6 2.62 113 9574.00 425. 16.5 2.72 114 9575.00 0.19 10.7 2.65 115 9576.00 109. 19.3 2.64 Amerada Hess Corporation File No.' 21126 CONVENTIONAL CORE ANALYSIS Date: April 1994 Core Type:. 4" conventional Mud Type: Water Base I Saturation OAN I.,.Percent Pore Volume Ratio I Oil IWaterI Total Comments Core 3:9560.00 - 9620.00 feet Cut: 60.00 feet Recovered: 57.90 feet Lithological Description 0.12 8.5 73.8 82.3 0.15 10.8 72.8 83.6 0.11 8.8 78.8 87.6 0.00 0.0 97.9 97.9 0.03 2.7 0.01 1.0 84.1 86.8 *Fractured Ka 74.3 75.4 *Fractured Ka 0.00 0.0 72.5 72.5 0.11 9.8 87.1 96.9 0.10 5.3 55.2 60.6 Sst: grysh-brn, cl-vfsd w/sps msd, sli fri, mod cmt, v fnt odor, It med stn, mott fnt yel fluor Sst: brn, slt-vfsd, sli fri, prly-mod cmt, fnt odor, It~med stn, fnt yel fluor Sst: brn, slt-vfsd, sli fri, pr'ly-mod cmt, fnt odor, It-med stn, fnt yel fluor Sst: gry, cl-fsd W/hUm Sh lam, mod cmt, Mic, no odor, no stn, strk fnt yel fluor Sst: It brn/dk gry, cl-fsd W/hUm thk Sh lam, wi cmt, Mic, no odor, strk It stn, strk yel fluor Sst: It brn/dk gry, cl-fsd w/num thk Sh lam, wi cmt, Mic, no odor, strk It stn, strk yel fuor Sst: grysh-brn, cl-crssd, wi cmt, Sid, no odor, It stn, mott fnt yel fluor Sst: grysh-brn, cl-msd w/vcrssd strk, wi cmt, Sid, Mic, no odor, It stn, mort fnt yel fluor Sst: brn, vfsd, mod cmt, Mic, v fnt odor, med stn, fnt yel fluor ~'$ Laboratories, Inc. Well: Nodhstar No. 3 Field: Beaufort Sea Location: Offshore Alaska Sample ID Depth, feet 300 psi NOB PermeabilityI to Air, I Porosity, millidarcies I percent Zone 4:9560.00 - 9593.00 feet 116 9577.00 27. 15.5 117 9578.00 183. 11.7 118 9579.00 0.17 10.6 119 9580.00 9.2 17.3 120 9581.00 0.80 12.3 121 9582.00 3.0 16.0 122 9583.00 6.8 16.4 123 9584.00 35. 18.4 124 9584.01 8.4 19.0 125 9585.00 14. 15.1 Grain Density, g/cc CONVENTIONAL CORE ANALYSIS I Saturation O/W I Percent Pore Volume. Ratio I Oil Iwaterl Total Comments Core 3:9560.00 - 9620.00 feet Cut: 60.00 feet Recovered: 57.90 feet 2.63 0.21 11.1 52.8 63.9 2.62 0.12 10.3 86.1 96.4 2.65 2.67 2.65 2.64 Amerada Hess Corporation File No.: 21126 2.63 Date: April 1994 Core Type: 4" conventional Mud Type: Water Base 0.09 7.8 85.2 93.0 0.23 13.7 59.9 73.5 Lithological Description 0.01 0.5 80.5 81.1 Sst: brn, cl-vfsd w/thn Sh lam, mod cmt, Mic, fnt odor, med stn, fnt yel fluor Sst: brn, cl-msd, mod-wi cmt, Mic, fnt odor, med stn, fnt yel fluor 0.06 4.8 74.2 79.0 Sst: It grysh-brn, cl-vfsd w/thn Sh lam, mod-wi cmt, Mic, no odor, It stn, fnt yel fluor 0.12 7.0 60.6 67.6 Sst: brn, slt-vfsd, mod-wi cmt, Pyr, v fnt odor, med stn, fnt yel fluor 2.63 0.15 8.3 55.4 63.8 2.64 0.09 5.2 60.3 65.5 Sst: grysh-brn/dk brn, slt-vfsd w/thn Sh lam, wi cmt, Mic, no odor, It stn, mott fnt yel fluor Sst: brn, slt-vfsd wisps thn Sh lam, mod cmt, Mic, v fnt odor, It- med stn, v fnt yel fluor 2.66 Sst: brn, vfsd w/thn Sh lam, mod cmt, Mic, v fnt odor, It stn, fnt yel fluor Sst: brn, vfsd w/v thn Sh lam, mod cmt, Mic, v fnt odor, It-med stn, fnt yel fluor Vertical Sst: brn, vfsd w/v thn Sh lam, bur, mod cmt, Mic, v fnt odor, It-reed stn, fnt yel fluor 0.12 6.4 55.4 61.9 Sst: brn, vf-crssd, mod cmt, fnt odor, It-med stn, fnt yel fluor Laboratories, Inc. Amerada Hess Corporation File No.' 21126 Well: Northstar No. 3 Field: Beaufort Sea Location: Offshore Alaska CONVENTIONAL CORE ANALYSIS Date: April 1994 Core Type: 4" conventional Mud Type: Water Base 3o0 psi NOB I I I . PermeabilityI Grain Saturation Sample Depth, to Air, I Porosity, D . ity, I o/vv I Percent PoreVolume ID feet millidarcies I percent ....gl,cc. I Ratio I Oil I waterl Total I Core Zone 4:9560.00 - 9593.00 feet Comments 3:9560.00 - 9620.00 feet Cut: 60.00 feet Recovered: 57.90 feet Lithological Description 126 9586.00 8.1 17.8 2.63 0.09 5.5 61.6 67.1 Sst: brn, vfsd w/shly bur, mod-prly cmt, Mic, fnt odor, med stn, fnt yel fluor 127 9587.30 4.0 17.6 2.63 0.06 4.1 66.5 70.6 Sst: brn, vfsd w/shly bur, mod-prly cmt, Mic, fnt odor, med stn, fnt yel fluor 128 9588.00 3.1 15.5 2.62 0.05 3.3 71.1 74.3 Sst: brn, vfsd w/v thn Sh lam, mod cmt, Mic, fnt odor, med stn, fnt yel fluor 129 9589.10 5.6 17.7 2.63 0.01 0.9 66.0 66.9 Sst: brn, vfsd w/v thn Sh lam, mod cmt, Mic, fnt odor, med stn, fnt yel fluor 130 9590.00 0.67 13.6 2.61 0.04 3.2 71.6 74.8 Sst: It brnsh-gry, slt-vfsd w/v thn Sh lam, mod cmt, Mic, v fnt odor, It stn, fnt yel fluor 131 9591.00 6.0 15.0 2.59 0.03 2.2 66.5 68.7 Sst: grysh-brn, vfsd w/num v thn Sh lam, mod cmt, Mic, v fnt odor, It stn, strk fnt yel fluor 132 9592.00 0.19 12.7 2.65 0.02 1.7 81.0 82.8 Sst: grysh-brn, slt-vfsd w/v thn Sh lam, mod cmt, Mic, v fnt odor, It stn, fnt yel fluor 133 9593.00 0.10 7.7 2.60 0.00 0.0 92.6 92.6 Sst: gry/dk gry, slt-vfsd w/num thn Sh lam, mod cmt, Mic, no odor, no stn, strk v fnt yel fluor ill - 14 Laboratories, Inc. Well: Northstar No. 3 Field: Beaufort Sea Location: Offshore Alaska Sample ID Depth, feet 300 psi NOB PermeabilityI to Air, I Porosity, millidarciesI percent Zone 5:9593.00 - 9617.90 feet 134 9594.00 0.25 6.8 135 9595.00 0.16 6.8 136 9596.00 *3.5 5.0 137 9597.00 0.08 6.8 138 9597.01 < 0.01 7.1 139 9598. I0 0.10 8.5 140 9599.00 0.15 7.1 141 9600.00 0.05 6.6 142 9601.00 0.27 6.5 Grain Density, g/cc 2.61 2.58 CONVENTIONAL CORE ANALYSIS I Saturation OAN I Percent Pore Volume Ratio I Oil IWaterl Total Comments Core 3:9560.00 - 9617.90 feet Cut: 60.00 feet Recovered: 57.90 feet 0.00 0.0 97.9 97.9 0.00 0.0 97.9 97.9 2.60 0.00 0.0 2.61 Amerada Hess Corporation File No.: 21126 Date: April 1994 Core Type: 4" conventional Mud Type: Water Base 2.61 99.0 99.0 *Fractured Ka Lithological Description 0.00 0.0 96.5 96.5 0.00 0.0 97.9 97.9 2.62 0.00 0.0 80.2 80.2 2.64 0.00 0.0 98.0 98.0 2.63 0.00 0.0 97.8 97.8 0.00 0.0 99.3 99.3 2.60 Sst: It gry/dk gry, cl-vfsd w/num Sh lam, wi cmt, Mic, no odor, no stn, no fluor Sh: gry/dk gry, cl-slt w/vfsd lam, wi cmt, Mic, no odor, no stn, no fluor Sh: gry/dk gry, cl-slt w/vfsd lam, wi cmt, Mic, no odor, no stn, no fluor Sst: It gry/dk gry, cl-vfsd w/num Sh lam, wi cmt, Mic, no odor, no stn, no fluor Sst: It gry/dk gry, cl-vfsd w/num Sh lam, wi cmt, Mic, no odor, no stn, no fluor Sst: gry, cl-vfsd w/thn Sh lam, wi cmt, Mic, no odor, no stn, no fluor Sst: It/dk gry, cl-vfsd w/num Sh lam, wi cmt, Mic, no odor, no stn, no fluor Sst: It/dk gry, cl-vfsd w/num Sh lam, wi cmt, Mic, no odor, no stn, nor fluor Sst: It/dk gry, cl-vfsd w/num Sh lam, wi cmt, Mic, no odor, no stn, nor fluor Laboratories, inc. Well: Northstar No. 3 Field: Beaufort Sea Location: Offshore Alaska Sample ID Depth, feet 300 psi NOB PermeabilityI to Air, I Porosity, millidarcies I percent Zone 5:9593.00 - 9617.90 feet 143 9602.00 0.06 10.5 144 9603.00 *3.5 8.0 145 9604.00 0.38 9.0 146 9605.00 0.15 9.9 147 9606.00 0.17 7.5 148 9607.00 0.24 7.0 149 9608.00 *5.4 7.5 150 9609.30 '1.4 10.0 151 9610.00 0.14 8.6 Grain Density, g/cc CONVENTIONAL CORE ANALYSIS I Saturation ONV I Percent Pore Volume Ratio ! °il ]Waterl Total Comments Core 3:9560.00 - 9617.90 feet Cut: 60.00 feet Recovered: 57.90 feet 2.65 0.00 0.0 99.6 99.6 2.59 0.00 0.0 96.9 96.9 *Fractured Ka 2.64 0.00 0.0 98.4 98.4 2.64 Amerada Hess Corporation File No: 21126 2.57 Date: April 1994 Core Type: 4" conventional Mud Type: Water Base 2.56 2.57 Lithological Description 2.59 0.02 1.7 85.6 87.3 0.02 1.4 95.7 97.1 0.00 0.0 98.6 98.6 0.00 0.0 96.9 96.9 *Fractured Ka 0.00 0.0 86.2 86.2 *Fractured Ka 2.67 0.00 0.0 90.2 90.2 III - 16 Sst: gry, cl-vfsd w/sml shly bur & lam, wi cmt, Mic, no odor, no stn, nor fluor Sst: brnsh-gry, slt-vfsd w/thn Sh lam, mod-wi cmt, Mic, no odor, strk It stn, strk fnt yel fluor Sst: gry/dk gry, slt-vfsd w/num Sh lam, wi cmt, Mic, no odor, strk strk It stn, strk fnt yel fluor Sst: brnsh-gry, slt-vfsd w/thn Sh lam, mod cmt, Mic, no odor, It stn, strk fnt yel fluor Sst: gry/dk gry, slt-vfsd w/num Sh lam, mod cmt, Mic, no odor, str ',. It stn, strk fnt yel fluor Sst: gry/dk gry, slt-vfsd w/num Sh lam, wi cmt, Mic, no odor, no stn, no fluor Sst: gry/dk gry, slt-vfsd w/num Sh lam, wi cmt, Mic, no odor, no stn, no fluor Sst: gry/dk gry, slt-vfsd w/Sh lam, mod-wi cmt, Mic, no odor, v It stn, strk fnt yel fluor Sst: dk gry, slt-vfsd w/num Sh lam, wi cmt, Mic, no odor, It stn, strk fnt yel fluor Laboratories, Inc. Well: Nodhstar No. 3 Field: Beaufort Sea Location: Offshore Alaska Sample ID Depth, feet 300 psi NOB I Permeabilityl I Grain to Air, I Porosity, I Density, mitlidarciesI percent I g/cc Zone 5:9593.00 - 9617.90 feet 152 9611.00 0.14 7.8 2.59 153 9612.00 0.17 7.0 2.58 154 9613.00 0.16 7.5 2.61 155 9614.20 0.20 7.4 2.61 156 9615.00 0.25 9.2 2.61 157 9616.00 0.15 9.5 2.65 158 9617.00 0.23 7.3 2.59 CONVENTIONAL CORE ANALYSIS Amerada Hess Corporation File No.: 21126 Date: April. 1994 Core Type: 4" conventional Mud Type: Water Base I Saturation OAN I percent Pore Volume Ratio I Oil. I Waterl Total Comments Core 3:9560.00 - 9617.90 feet Cut: 60.00 feet Recovered: 57.90 feet Lithological Description 0.00 0.0 90.4 90.4 0.00 0.0 91.3 91.3 0.00 0.0 92.4 92.4 0.00 0.0 98.7 98.7 0.01 1.2 86.7 87.9 0.00 0.0 83.3 83.3 0.00 0.0 98.0 98.0 Sst: brnsh-gry, slt-vfsd w/num Sh lam, wi cmt, Mic, no odor, v It stn, no fluor Sst: dk gry, slt-vfsd w/num Sh lam, wi cmt, Mic, no odor, no stn, no fluor Sst: dk gry, slt-vfsd w/num Sh lam, wi cmt, Mic, no odor, no stn, no fluor Sst: dk gry, slt-vfsd w/num Sh lam, wi cmt, Mic, no odor, no stn, no fluor Sst: grysh-brn, slt-vfsd w/num thn Sh lam, mod-wi cmt, Mic, no odor, It stn, strk yel fluor Sst: grysh-brn, slt-vfsd w/num thn Sh lam, mod-wi cmt, Mic, no odor, It stn, strk yel fluor Sst: dk gry, cl-vfsd w/num Sh lam, mod cmt, Mic, no odor, no stn, no fluor Iii - 17 Laboratories, Inc. Amerada Hess Corporation File No.' 21126 Well: Northstar No, 3 Field: Beaufort Sea Location: Offshore Alaska SUMMARY OF CONVENTIONAL CORE ANALYSIS Composite - Core 1 & 2 Date: April 1994 Mud Type: Water Base FORMATION AND RANGE DATA Formation' Top. Depth: 9436,00 ft Bottom Depth: 9617,90 ft Number of Samples: 158 Range: Porosity (Minimum): 0,0 % Porosity (Maximum): 100,0 % Permeability (Minimum): 0,01 md Permeability (Maximum): 10000,0 md Saturation (Minimum): 0,0 % Saturation (Maximum): 100,0 % Grain Density (Minimum): 2,00 g/cc Grain Density (Maximum): 3,50 g/cc STATISTICS FOR SAMPLES REMAINING AFTER APPLYING EXCLUSION CRITERION Formation: Porosity: Permeability: Number of Samples: Thickness Represented: 145 Minimum: 1.2 % 181.90 ft Maximum: 28.7 % Arithmetic Mean: 15.2 % Median: 15.7 % Minimum: 0,02 md Maximum: 3890 md Arithmetic Mean: 198 md Geometric Mean: 6,8 md Median: 4,1 md Grain Density: Average Saturations: Minimum: 2,56 g/cc Oil Maximum: 3,17 g/cc Water Arithmetic Mean: 2,73 g/cc Median: 2,66 g/cc 3.71% PV 80.60 % PV Exclusion Criterion' Number of Samples Excluded: 13 Vertical Samples Sidewall Samples Samples with Permeabilities < 0,01md Samples with Permeabilities >10000 md Permeability Rounding Criterion: > 10000 md - Reported As > 10000 md 1000 - 29999,99 md - Rounded to Nearest 10 md 10 to 999,99 md- Rounded to Nearest 1 md 0,1 - 9,99 md - Rounded to Nearest 0,1 md 0,01 - 0,99 md - Rounded to Nearest 0,01 md < 0,01 md - Reported As < 0.01 md Miscellaneous Data: Type of Extraction' Dean Stark Confining Stress: 300 psi Measured Oil Gravity: 33,6° APl PTS Laboratories, Inc. Amerada Hess Corporation File No.: 21126 Well: Northstar No. 3 Field: Beaufort Sea Location: Offshore Alaska SUMMARY OF CONVENTIONAL CORE ANALYSIS Core 1- Zone 1 Date: April 1994 Mud Type: Water Base FORMATION AND RANGE DATA Formation: Top. Depth: 9436.00 ft Bottom Depth: 9443.00 ft Number of Samples: 8 Range: Porosity (Minimum): 0.0 % Porosity (Maximum): 100.0 % Permeability (Minimum): 0.01 md Permeability (Maximum): 10000.0 md Saturation (Minimum): 0.0 % Saturation (Maximum): 100.0 % Grain Density (Minimum): 2.00 g/cc Grain Density (Maximum): 3.50 g/cc STATISTICS FOR SAMPLES REMAINING AFTER APPLYING EXCLUSION CRITERION Formation: Porosity: Permeability: Number of Samples: Thickness Represented: 7 Minimum: 17.5 % 7.00 ft Maximum: 24.7 % Arithmetic Mean: 22.2 % Median: 23.1% Minimum: 146 md Maximum: 474 md Arithmetic Mean: 293 md Geometric Mean: 274 md Median: 274 md Grain Density: Average Saturations: Minimum: 2.64 g/cc Oil Maximum: 2.78 g/cc Water Arithmetic Mean: 2.70 g/cc Median: 2.69 g/cc 2.9% PV 47.0 % PV Exclusion Criterion: Number of Samples Excluded: 1 Vertical Samples Sidewall Samples Samples with Permeabilities < 0.01md Samples with Permeabilities >10000 md Permeability Rounding Criterion: > 10000 md- Reported As > 10000 md 1000 - 29999.99 md - Rounded to Nearest 10 md 10 to 999.99 md - Rounded to Nearest 1 md 0.1 - 9.99 md - Rounded to Nearest 0.1 md 0.01 - 0.99 md- Rounded to Nearest 0.01 md < 0.01 md - Repoded As < 0.01 md Miscellaneous Data: Type of Extraction: Dean Stark Confining Stress: 300 psi Measured Oil Gravity: 39.0° APl Laboratories, Inc. Amerada Hess Corporation File No.: 21126 Well: Nodhstar No. 3 Field: Beaufort Sea Location: Offshore Alaska SUMMARY OF CONVENTIONAL CORE ANALYSIS Core 1 & 2 - Zone 2 Date: Apdl 1994 Mud Type: Water Base FORMATION AND RANGE DATA Formation: Top Depth: 9443.00 ft Bottom Depth: 9510.00 ft Number of Samples: 35 Range: Porosity (Minimum): 0.0 % Porosity (Maximum): 100.0 % Permeability (Minimum): 0.01 md Permeability (Maximum): 10000.0 md Saturation (Minimum): 0.0 % Saturation (Maximum): 100.0 % Grain Density (Minimum): 2.00 g/cc Grain Density (Maximum): 3.50 g/cc STATISTICS FOR SAMPLES REMAINING AFTER APPLYING EXCLUSION CRITERION Formation: Porosity: Permeability: Number of Samples: Thickness Represented: 33 Minimum: 6.4 % 67.00 ft Maximum: 17.2 % Arithmetic Mean: 10.3 % Median: 9.3 % Minimum: 0.04 md Maximum: 3.6 md Arithmetic Mean: 0.60 md Geometric Mean: 0.21 md Median: 0.12 md Grain Density: Average Saturations: Minimum: 2.64 g/cc Oil Maximum: 3.04 g/cc Water Arithmetic Mean: 2.67 g/cc Median: 2.65 g/cc 1.4 % PV 95.8 % PV Exclusion Criterion' Number of Samples Excluded: 2 Vedical Samples Sidewall Samples Samples with Permeabilities < 0.01md Samples with Permeabilities >10000 md Permeability Rounding Criterion: > 10000 md- Reported As > 10000 md 1000 - 29999.99 md - Rounded to Nearest 10 md 10 to 999.99 md- Rounded to Nearest 1 md 0.1 - 9.99 md - Rounded to Nearest 0.1 md 0.01 - 0.99 md - Rounded to Nearest 0.01 md < 0.01 md - Reported As < 0.01 md Miscellaneous Data: Type of Extraction: Dean Stark Confining Stress: 300 psi Measured Oil Gravity: 36.20 APl Laboratories, Inc. Amerada Hess Corporation File No.: 21126 Well: Northstar No. 3 Field: Beaufort Sea Location: Offshore Alaska SUMMARY OF CONVENTIONAL CORE ANALYSIS Core 2 - Zone 3 Date: April 1994 Mud Type: Water Base FORMATION AND RANGE DATA Formation: Top Depth: 9510.00 fi. Bottom Depth: 9560.00 ft Number of Samples: 54 Range: Porosity (Minimum): 0.0 % Porosity (Maximum): 100.0 % Permeability (Minimum): 0.01 md Permeability (Maximum): 10000.0 md Saturation (Minimum): 0.0 % Saturation (Maximum): 100.0 % Grain Density (Minimum): 2.00 g/cc Grain Density (Maximum): 3.50 g/cc STATISTICS FOR SAMPLES REMAINING AFTER APPLYING EXCLUSION CRITERION Formation: Porosity: Permeability: Number of Samples: Thickness Represented: 49 Minimum: 3.1% 50.00 ft Maximum: 28.7 % Arithmetic Mean: 21.1% Median: 22.3 % Minimum: 0.02 md Maximum: 3890 md Arithmetic Mean: 434 md Geometric Mean: 157 md Median: 352 md Grain Density: Average Saturations: Minimum: 2:65 g/cc Oil Maximum: 3.17 g/cc Water Arithmetic Mean: 2.86 g/cc Median: 2.88 g/cc 1.7 % PV 78.8 % PV Exclusion Criterion' Number of Samples Excluded: 5 Vertical Samples Sidewall Samples Samples with Permeabilities < 0.01md Samples with Permeabilities >10000 md Permeability Rounding Criterion' > 10000 md- Reported As > 10000 md 1000 - 29999.99 md - Rounded to Nearest 10 md 10 to 999.99 md - Rounded to Nearest 1 md 0.1 - 9.99 md- Rounded to Nearest 0.1 md 0.01 - 0.99 md- Rounded to Nearest 0.01 md < 0.01 md - Reported As < 0.01 md Miscellaneous Data: Type of Extraction: Dean Stark Confining Stress: 300 psi Measured Oil Gravity: 32.0° APl Laboratories, Inc. Amerada Hess Corporation File No.: 21126 Well: Nodhstar No. 3 Field: Beaufort Sea Location: Offshore Alaska SUMMARY OF CONVENTIONAL CORE ANALYSIS Core 3 - Zone 4 Date: April 1994 Mud Type: Water Base FORMATION AND RANGE DATA Formation: Top, Depth: 9560.00 ft Bottom Depth: 9593.00 ft Number of Samples: 36 Range: Porosity (Minimum): 0.0 % Porosity (Maximum): 100.0 % Permeability (Minimum): 0.01 md Permeability (Maximum): 10000.0 md Saturation (Minimum): 0.0 % Saturation (Maximum): 100.0 % Grain Density (Minimum): 2.00 g/cc Grain Density (Maximum): 3.50 g/cc STATISTICS FOR SAMPLES REMAINING AFTER APPLYING EXCLUSION CRITERION Formation: Porosity: Permeability: Number of Samples: Thickness Represented: 32 Minimum: 1.2 % 33.00 ft Maximum: 21.0 % Arithmetic Mean: 14.6 % Median: 15.8 % Minimum: 0.1 md Maximum: 425 md Arithmetic Mean: 52.4 md Geometric Mean: 6.5 md Median: 6.4 md Grain Density: Average Saturations: Minimum: 2.59 g/cc Oil Maximum: 3.07 g/cc Water Arithmetic Mean: 2.69 g/cc Median: 2.65 g/cc 4.8% PV 72.0 % PV Exclusion Criterion: Number of Samples Excluded: 4 Vertical Samples Sidewall Samples Samples with Permeabilities < 0.01 md Samples with Permeabilities >10000 md Permeability Rounding Criterion: > 10000 md - Reported As > 10000 md 1000 - 29999.99 md - Rounded to Nearest 10 md 10 to 999.99 md - Rounded to Nearest 1 md 0.1 - 9.99 md- Rounded to Nearest 0.1 md 0.01 - 0.99 md - Rounded to Nearest 0.01 md < 0.01 md - Reported As < 0.01 md Miscellaneous Data: Type of Extraction: Dean Stark Confining Stress: 300 psi Measured Oil Gravity: 32.0° APl PTS Laboratories, Inc. Amerada Hess Corporation File No.' 21126 Well: Northstar No. 3 Field: Beaufort Sea Location: Offshore Alaska SUMMARY oF CONVENTIONAL CORE ANALYSIS Core 3 - Zone 5 Date: April 1994 Mud Type: Water Base FORMATION AND RANGE DATA Formation: Top. Depth: 9593.00 ft Bottom Depth: 9617.90 ft. Number of Samples: 25 Range: Porosity (Minimum): 0.0 % Porosity (Maximum): 100.0 % Permeability (Minimum): 0.01 md Permeability (Maximum): 10000.0 md Saturation (Minimum): 0.0 % Saturation (Maximum): 100.0 % Grain Density (Minimum): 2.00 g/cc Grain Density (Maximum): 3.50 g/cc STATISTICS FOR SAMPLES REMAINING AFTER APPLYING EXCLUSION CRITERION Formation: Porosity: Permeability: Number of Samples: Thickness Represented: 24 Minimum: 5.0 % 24.90 ft Maximum: 10.5 % Arithmetic Mean: 7.8 % Median: 7.5 % Minimum: 0.05 md MaximUm: 5.4 md Arithmetic Mean: 0.70 md Geometric Mean: 0.26 md Median: 0.17 md Grain Density: Average Saturations: Minimum: 2.56 g/cc Oil Maximum: 2.65 g/cc Water Arithmetic Mean: 2.61 g/cc Median: 2.61 g/cc 0.1% PV 94.0 % PV Exclusion Criterion- Number of Samples Excluded' 1 Vertical Samples Sidewall Samples Samples with Permeabilities < 0.01md Samples with Permeabilities >10000 md Permeability Rounding Criterion: > 10000 md - Reported As > 10000 md 1000 - 29999.99 md - Rounded to Nearest 10 md 10 to 999.99 md - Rounded to Nearest 1 md 0.1 - 9.99 md - Rounded to Nearest 0.1 md 0.01 - 0.99 md - Rounded to Nearest 0.01 md < 0.01 md - Reported As < 0.01 md Miscellaneous Data: Type of Extraction: Dean Stark Confining Stress: 300 psi Measured Oil Gravity: 32.0° APl III- 23 Laboratories, inc. Amerada Hess Corporation File No.: 21126 SECTION IV PLOTS GAMMA LOG FOUR PARAMETER LOG Laboratories, !nc. Amerada Hess Corporation File No' 21126 Well: Field: Location: 100000 10000 1000 ---- 100 u.l 10 0.1 0.01 POROSITY - PERMEABILITY CROSSPLOT 300 psi NOB Northstar No. 3 Beaufort Sea Offshore Alaska Depth Interval, ft: 9436.00 - 9617.90 Exponential Regression Equation (b x Porosity) Permeability = a x e where: a = 0.48086 b = 0.0037692 0 I0 20 30 40 50 POROSITY, percent Laboratories, inc, Amerada Hess Corporation File No.' 21126 PERMEABILITY HISTOGRA~ 300 psi NOB Well: Northstar No. 3 Field: Beaufort Sea Location: Offshore Alaska Depth Interval, ft: 9436.00 - 961 7.90 100 90 80 70 60 50 40 30 20 10 i ' ii i Pi i ii -- - - - - -- Geometric Mean: 6.8 md - - Median Value: 4.1 md .01 .02 .O4 .08 .18 .32 ,64 !,25 2,5 I l I I I 10 20 40 80 160 320 640 2560 10240 1280 5120 P~RMEAiSILITY, miiiidsrcies 100 90 80 70 60 50 40 30 20 10 Laboratories, !nc. Amerada Hess Corporation File No,' 21 126 100 90 POROSITY HISTOGRAM 300 psi NOB Well: Northstar No. 3 Field: Beaufort Sea Location: Offshore Alaska Depth Interval, ft' 9436.00 - 961 7.90 80 70 60 50 40 30 20 10 -- Arithmetic Mean: 1 5.2 % - - Median Value: 15.7 % 0 10 20 30 5o 100 90 80 70 60 50 40 30 20 10 POROSITY, percent Laboratories, Inc. Amerada Hess Corporation File No.' 21126 UJ Well: Field: Location: 3.50 3.40 3.30 3.20 3.10 3.00 2.90 2.80 2.70 2.60 2.50 GRAIN DENSITY - POROSITY CROSSPLOT Porosity: 300 psi NOB Northstar No. 3 Beaufort Sea Offshore Alaska Depth Interval, fi:: 9436.00-9617.90 0 10 20 3O 4O 50 POROSITY, percent Laboratories, inc. Amerada Hess Corporation File No.' 21126 POROSITY - PERMEABILITY CROSSPLOT 300 psi NOB Well: Field: Location: Northstar No. 3 Beaufort Sea Offshore Alaska Core: 1 Zone' 1 Depth Interval, ft: 9436.00-9443.00 100000 10000 1000 100 10 1 0,1 0.01 0 I0 20 30 4O 5O POROSITY, percent IV- 5 Laboratories, Inc. Amerada Hess Corporation File No' 21126 100 90 80 70 60 50 40 30 20 10 PERMEABILITY HISTOGRAM 300 psi NOB Well: Northstar No. 3 Field: Beaufort Sea Location: Offshore Alaska Core: 1 Zone: 1 Depth Interval, 9436.00-9443.00 -- Geometric Mean: 274 md - - Median Value: 274 md .01 .02 .04 .o8 .16 .32 .64 1.25 2.5 5 lO 20 40 80 16o 320 640 2560 lO24O 128o 512o PERiV!EABILITY, millidarcies 100 90 80 70 60 50 40 30 20 10 IV - 6 Laboratories, Inc. Amerada Hess Corporation File No' 21126 Well: Field: Location: 100 90 80 70 60 50 40 30 20 10 0 Northstar No. 3 Beaufort Sea Offshore Alaska 10 POROSITY HISTOGRAIV] 300 psi NOB Core' I Zone' 1 Depth Interval, ft: Arithmetic Mean: 22.2 % 9436.00-9443.00 100 -- -- - - Median Value' 23.1% .................................................................. -- 20 POROSITY, percent 50 90 80 70 60 50 40 30 20 10 Laboratories, Inc. Amerada Hess Corporation File No' 21126 GRAIN DENSITY- POROSITY CROSSPLOT Porosity: 300 psi NOB Well: Field: Location: Northstar No. 3 Beaufort Sea Offshore Alaska Core: I Zone: 1 Depth Interval, ft: 9436.00-9443.00 3.50 3.40 3.30 3.20 3.10 3.00 2.90 2.80 2.70 2.60 2.50 10 20 30 40 50 POROSITY, percent IV- 8 Laboratories, ~nc. Amerada Hess Corporation File No.' 21 126 Well: Field: Location: 100000 1OO0O 1000 100 10 0.1 0.01 POROSITY - PERMEABILITY CROSSPLOT 300 psi NOB Northstar No. 3 Beaufort Sea Offshore Alaska Core: 1 &2 Zone: 2 Depth Interval, ft' 9443.00 - 9510.00 Exponential Regression Equation (b x Porosity) Permeability = a x e where: a = 0,0055746 b = O,3348149 0 10 2O 3O 4O 5O POROSITY, percent IV- 9 Laboratories, inc. Amerada Hess Corporation File No.' 21126 100 90 80 70 60 50 40 30 20 10 PERiVIEABIL~TY HISTOGRAM 300 psi NOB Well: Northstar No, 3 Field' Beaufort Sea Location: Offshore Alaska Core: 1 &2 Zone' 2 Depth Interval, ft: 9443.00 - 951 0.00 , -- Geometric Mean: 0.21 md , _ .................................................. ' .......... - - Median Value: 0,12 md ] ................................................................. L , ! ! ! ! $ ! I ! I ! ' ! I ! I ! ................................................... I ! ! ! ! .................................................. 1 I ' ! .01 .02 .O4 .08 .16 .32 .64 1.2.5 2.5 5 10 20 40 80 160 320 640 2.560 10240 1280 5120 PERMEABILITY, miilidarcies 100 90 80 70 60 50 40 30 20 10 IV- 10 Laboratories, Inc. Amerada Hess Corporation File No' 21126 100 90 80 70 m 6o o ~ 50 40 30 20 10 POROSITY HISTOGRAM 300 psi NOB Well: Northstar No. 3 Field: Beaufort Sea Location: Offshore Alaska Core: 1 &2 Zone: 2 Depth Interval, ft: 9443.00 - 9510.00 - I _ ,/ -- Arithmetic Mean: 10.3 % ................................... ' ......................... i - - Median Value: 0.3 % ................................................................. I ! ! ! ! I I I ! ! I ! _ I ! I I ! ! I ! ! ! I -- ! -- ! -- ! ! I i ' ! ! F ! ! 1//9// .~-~ , I, I, I i I,.I, I, I., 1,~ I I I i I i I, I, I, I ! - 0 10 20 3O 5O POROSITY, percent 100 90 80 70 60 50 40 30 20 10 Laboratories, Inc. Amerada Hess Corporation File No.' 21126 Well: Field: Location: 3.50 3.40 3.30 3.20 3.10 3.00 2.90 2.80 2.70 2.60 2.50 GRAIN DENSITY - POROSITY CROSSPLOT Porosity: 300 psi NOB Northstar No. 3 Beaufort Sea Offshore Alaska Core: 1 &2 Zone: 2 Depth Interval, ft: 9443.00 - 9510.00 - . 10 2O 3O 4O 5O POROSITY, percent IV- 12 Laboratories, Inc. Amerada Hess Corporation File No.' 21 126 Well: Field: Location: 100000 10000 lO00 .--~ 100 u.I 10 0.1 0,01 0 POROSITY - PERMEABILITY CROSSPLOT 300 psi NOB Northstar No. 3 Beaufort Sea Offshore Alaska : Core: 2 Zone: 3 Depth Interval, ft: 9510.00 - 9560.00 Exponential Regression Equation (b x Porosity) Permeability = a × e where: a = 0.0064248 b = 0.4637441 10 20 30 40 50 POROSITY, percent IV- 13 Laboratories, Inc. Amerada Hess Corporation File No.' 211 26 100 90 80 70 ~o 60 0 L_ r., 5o 40 30 20 10 PERMEABILITY HISTOGRAM 300 psi NOB Well' Northstar No, 3 Field: Beaufort Sea Core: 2 Zone: 3 Location: Offshore Alaska Depth Interval, ft: 9510.00 - 9560.00 _ m Geometric Mean: 1 57 md , _ .............................................................. - - Median Value: 352 md ............ ~ ................................................... ! ............................................................................................................................................................... 1 ! I ! I ! I ! ! I I ! ! I ! ! ! ! ! ! , I I · O1 .02 .04 .08 .16 .32 .64 1.25 2.5 5 10 20 40 80 160 320 640 2560 10240 1280 5120 PERMEABILITY, millidarcies 100 9o 80 70 60 50 40 30 20 10 IV- 14 Laboratories, inc. Amerada Hess Corporation File No.' 21126 100 90 80 70 co 60 o ..o 50 40 30 20 10 POROSITY HISTOGRAM 300 psi NOB Well: Northstar No. 3 Field: Beaufort Sea Location: Offshore Alaska Core' 2 Zone' 3 Depth Interval, ft: 9510.00-9560.00 Arithmetic Mean: - - Median Value: 21.1% 22.3 % I I I ! I ! 10 20 30 50 POROSITY, percent 100 90 80 70 60 50 40 30 20 10 IV- 15 Laboratories, inc. Amerada Hess Corporation File No.' 21126 GRAIN DENSITY- POROSITY CROSSPLOT Porosity: 300 psi NOB Well: Northstar No, 3 Field: Beaufort Sea Core: 2 Zone: 3 Location: Offshore Alaska Depth Interval, ft: 3.50 3.40 3.30 3.20 3.10 3.00 2.90 2.80 2.70 2.60 2.50 9510.00 - 9560.00 POROSITY, percent iV- 16 Laboratories, inc. Amerada Hess Corporation File No.: 21 126 POROSITY - PERMEABILITY CROSSPLOT 300 psi NOB Well: Field: Location: Northstar No. 3 Beaufort Sea Offshore Alaska Core: 3 Zone: 4 Depth Interval, ft: 9560.00-9593.00 100000 10000 1000 100 10 : i: -! : ~i" ::i'~ ............... i! ..................... i .................... ii .... Exponential Regression Equation ............ O. 1 ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: where: a = 0.0063156 - -:::::::::::::::::::::::: , .'.'.'z'_"_ ~.~..~....~.~.~~~...~~~~~......~~..~.~..i..~.~~~~..~.~..~.~~~.~.~..~.~.~.~.~.~~i..~..~.....~.~~...........~...i- '" '"'" "'" '" ' -" -" ............................................... b = 0.4506038 ' '"':'""""'"'"'"""i 0 10 20 3O 40 50 POROSITY, percent IV- 17 Laboratories, Inc. Amerada Hess Corporation File No.' 211 26 PERMEABILITY HISTOGRAM 300 psi NOB Well: Northstar No. 3 Field' Beaufort Sea Location: Offshore Alaska 100 90 80 70 60 50 40 30 20 10 Core: 3 Zone: 4 Depth Interval, ft: 9560.00-9593.00 _ -- Geometric Mean: .............................................................. - - Median Value: 6.5 md 6.4 md .Ol .02 .o4 .08 .16 .32. .64 1.25 2.5 5 lO 20 40 80 16o 320 640 2560 10240 128o 512o PERMEABILITY, millidarcies 100 90 80 70 60 50 40 30 20 10 IV- 18 Laboratories, Inc. Amerada Hess Corporation File No.' 21126 POROSITY HISTOGRAM 300 psi NOB Well: Field: Location: Northstar No. 3 Beaufort Sea Offshore Alaska Core: 3 Zone: 4 Depth Interval, ft: 9560.00-9593.00 100 90 80 70 60 50 40 30 20 10 -- Arithmetic Mean: 14.6 % - - Median Va!ue: 15.8 % , I, I,-,-k.- _,1, 1, !, 1,__1 LI, I, I, I, I, I~,_1, I, 0 10 20 30 50 POROSITY, percent 100 90 80 70 60 50 40 30 20 10 0 IV- 19 Laboratories, Inc. Amerada Hess Corporation File No.' 21126 Z GRAIN DENSITY - POROSITY CROSSPLOT Porosity: 300 psi NOB Well: Northstar No. 3 Field: Beaufort Sea Core: 3 Zone: 4 Location: Offshore Alaska Depth Interval, ft: 3.50 3.40 3.30 3.20 3.10 3.00 2.90 2.80 2.70 2.60 2.50 9560.00-9593.00 POROSITY, percent IV- 20 Laboratories, inc. Amerada Hess Corporation File No.' 21126 POROSITY - PERMEABILITY CROSSPLOT 300 psi NOB Well: Field: Location: Northstar No. 3 Beaufort Sea Offshore Alaska Core: 3 Zone: 5 Depth Interval, ft: 9593.00 - 9617.90 100000 10000 1000 100 10 0.1 0.01 Exponential Regression Equation (b x Porosity) Permeability = a x e where: a = 0.0008108 b = 0.7269431 0 10 20 3O 4O 50 POROSITY, percent IV - 21 Laboratories, inc. Amerada Hess Corporation File No.' 21126 100 90 80 70 ~ 60 r~ 50 40 30 20 10 PERMEABILITY HISTOGRAM 300 psi NOB Well' Northstar No. 3 Field: Beaufort Sea Core: 3 Zone: 5 Location: Offshore Alaska Depth Interval, ft: 9593.00-9617.90 i ..... ~ i i . , -- Geometric Mean: .26 md - ....................................................... ' ...... - - Median Value: 0.17 md ................................................................. ... · ! ! I ! ! -, I - ! I .......................................................................................................................................................................................................... ! ! ! I ! .......................................................... , ......................................................................................................................................................... I I I I ....................................................... ~ ............................................................................................................................................................ ! ! ~ ....................................................... [ ............................................................................................................................................................. .-. i , ....................................................... ! ............................................................................................................................... ...................................................... I ........................................................................................................................................... - ¢ -_ .01 .O2 .04 .O8 .16 .32 .64 1.25 2.5 5 10 20 40 80 160 320 640 2560 10240 1280 5120 PERMEABILITY, millidarcies lO0 90 80 70 60 50 40 30 20 10 IV - 22 Laboratories, !nc. Amerada Hess Corporation File No.' 21126 GRAIN DENSITY- POROSITY CROSSPLOT Porosity: 300 psi NOB Well: Northstar No. 3 Field: Beaufort Sea Core: 4 Zone: 5 Location: Offshore Alaska Depth Interval, ft: 9593.00-9617.90 3.50 3.40 3.30 3.20 3.10 3.00 2.90 2.80 2.70 2.60 2.50 0 10 20 30 40 50 POROSITY, percent IV - 23 Laboratories, Inc. Amerada Hess Corporation File No.' 21126 POROSITY HISTOGRAM 300 psi NOB Well: Northstar No. 3 Field: Beaufort Sea Core: 3 Zone: 5 Location: Offshore Alaska Depth Interval, ft: 9593.00-9617.90 100 90 80 70 60 50 40 30 20 10 ,i , -- Arithmetic Mean: 7.8 % ............................. ' ................................ - - Median Value: 7.5 % ................................................................. I -- ! _ ! _ ! I ! II ! , !1 I ! ! ! ! ! .............................. ! i ' I ~ I,.-~..~/, .,-.~ ~ I ~ I, I, I, I, I, I, I, I, 1, I ~ I, I, I, I, 1, 1.., I.,- 0 10 20 30 50 POROSITY, percent 100 90 80 70 60 50 40 30 20 10 IV- 24 PTS Loborotories, inc. COMPfiNY: WELL: FIELD: FORMfiTION: 6MERfiDA HESS CORPORfiTION NORTHSTfiR NO.3 BEfiUFORT SEA · JOB ORDER NO. '~ll2G OfiTE' fiPRIL 21, l~J9 FOUR P R NETER PLOT Vert ic~l Scale I inch: 20 Feet Depth ~.®1 ~""* Io. x ~1 9950 9q90 9500 9510 9530 9550 9%0 9570 9580 9590 %OO 9610 96q0 9650 %70 nrnN ~ I IUl{lll{l Illlill~{~ lllllllll n{{lilll Ill[fill }lllllll m~ ' -> itlllll{ I IIlIIIIT'~,. 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'- ~ -/~"/: I ~i iiiiiii i ! .. ~I t,1 I illllil Ililll I llllil I Itl flt11111 It1111111 111111111 11111111 11111111 ! ' ..1{~~111111 I!ill II I{1tll I 111 ii I . i I I I [[I]]ZLL~'~IIII! I III11][ t 1111tll I ! ] I I mlli~ iIUillli ill~l] ifil[II! !~ II ! I I PTS Laboratories, Inc. 00MPSNY: WELL: FIELO: FORMATION: 6MER6D6 HESS OORPOR6TION NORTHSTRR NO.3 BE6UFORT SE6 JOB ORDER NO.' gllg6 D6TE: M6RCH gO, 1999 LOG Vertical Scale 1 inch: ZO Feet >1 ,, , , ,~' ~'~"~ ~ ,,. ~- Imm m m mm m m .... ..... , ..... ...... ................ , , ,,, ~ ~",':. ,,~.,' ......... ,,, ..... .... , ,, , , . , ....... 9q50 9960 9q?O 9q80 9990 9500 9510 95Z0 9530 95'10 9550 9560 95?0 95B0 9590 9600 9610 96q0 9650 9660 96?0 Laboratories, Inc. SECTION V INVENTORIES Amerada Hess Corporation File No. '21126 Laboratories, Inc. Well: Northstar No. 3 Field: Beaufort Sea Location' Offshore Alaska SAMPLE INVENTORY Amerada Hess Corporation File No.' 21126 Sample ID Depth Interval, feet Core ID Zone ID Conventional Core Analysis Retort Core Analysis Paleo Sample Preserved Whole Core 9436.00 I 9436.30 2 9437.00 9438.00 - 9438.5 3 9438,00 9439.00 4 9439.OO 5 9439.01 6 9440.00 7 9441.00 9442.00 8 9442.00 9442.40 9 9443.00 10 9444.00 9444.30 9445.00 11 9445.10 12 9446.00 13 9447.00 9448.00 14 9448.OO 15 9449.00 16 9450.00 9451.00 17 9451.10 18 9452.00 9452.30 19 9453.0O 9454.OO 20 9454.00 21 9455.10 22 9456.10 9457.00 23 9457.00 24 9458.00 25 9459.00 9460.00 26 946O.OO 27 9461.00 1 1 1 1 1 1 1 1 1 1 t 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 X X X X X X X X X X X X X X X X X X X X X X X X X X X X X X X X X X Laboratories, Inc. Well: Northstar No. 3 Field: Beaufort Sea Location' Offshore Alaska SAMPLE INVENTORY Amerada Hess Corporation File No.' 21126 Sample ID Depth Interval, feet Core ID Zone ID Conventional Core Analysis Retod Core Analysis Paleo Sample Preserved Whole Core 28 9462.00 9463.00 29 9463.00 9463.50 30 9464.10 9465.00 31 9465.00 9466.00 32 9466.00 9466.90 33 9500.30 9500.00 34 9501.1 0 35 95O2.OO 9505.00 36 9503.00 37 95O4.OO 38 9504.01 39 95O5.OO 9506.00 40 9506.10 41 9507.00 42 95O8.OO 9509.00 43 9509.10 44 9510.00 45 9511.00 46 9512.10 47 9513.00 48 9514.00 9515.00 49 9515.00 50 9516.00 51 9517.00 9518.00 52 9518.10 53 9518.11 54 9519.00 55 9520.10 9521.00 1 1 1 1 1 1 1 1 1 1 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 X X X X X X X X X X X X X X X X X X X X X X X X X X X X X X X X X X X X X ¥-2 Laboratories, Inc. Well: Northstar No. 3 Field: Beaufort Sea Location: Offshore Alaska SAMPLE INVENTORY Amerada Hess Corporation File No.: 21126 Sample ID Depth Interval, feet Core ID Zone ID Conventional Core Analysis Retod Core Analysis Paleo Sample Preserved Whole Core 56 9521.10 9522.00-9522.5 57 9522.00 58 9523.00 9524.00 59 9524.0O 60 9525.00 9526.00 61 9526.00 62 9527.00 9528.00 63 9528.OO 64 9529.10 65 9530.30 9531.00 66 9531.00 67 9531.01 9532.70- 9533.2 68 9532.70 69 9533.30 9534.00 70 9534.00 71 9535.00 72 9536.20 9537.00 73 9537.00 74 9538.00 75 9539.00 9540.00 76 9540.10 77 9541.00 78 9542.00 9543.00 79 9545.50 80 9543.51 81 9544.00 9545.00- 9545.5 82 9545.00 9546.00 83 9546.00 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 X X X X X X X X X X X X X X X X X X X X X X X X × X X X X X X X X X X X X V-3 Laboratories, Inc. Well: Northstar No. 3 Field: Beaufort Sea Location: Offshore Alaska SAMPLE INVENTORY Amerada Hess Corporation File No.: 21126 Sample ID Depth Interval, feet Core ID Zone ID Conventional Core Analysis Retort Core Analysis Paleo Sample Preserved Whole Core 84 85 86 87 88 89 90 91 92 93 94 95 96 97 98 99 100 101 102 103 104 105 106 107 108 109 110 9547.00 9548.30 9549.00 9549.20 9550.00 9551.00 9551.00 9552.00 9552.00 9553.00 9554.10 9555.00 9555 00 9555 01 9556.00 9557.00 9557.00 9558.0O 9559.OO 9559.30 956O.0O 956O.4O 9561.00 9562.OO 9562.00 9563.O0 9563.80 9564.00 9565.00 9566.00 9566.00 9566.01 9567.00 9568.00 9569.00-9569.5 9569.00 9569.00 9570.00 9571.00 9572.00 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 X X X X X X X X X X X X X X X X X X X X X X v X X X X X X X X X X X X x V-4 Laboratories, Inc. Well: Northstar No. 3 Field' Beaufort Sea Location' Offshore Alaska SAMPLE INVENTORY Amerada Hess Corporation File No.: 21126 Sample ID Depth Interval, feet Core ID Zone ID Conventional Core Analysis Retort Core Analysis Paleo Sample Preserved Whole Core 111 9572.00 112 9573.00 9573.30 113 9574.00 9575.00 114 9575.00 115 9576.00 116 9577.00 9577.50 9578.00 117 9578.00 118 9579.00 119 9580.00 120 9581.00 958 .5o 121 9582.00 122 9583.00 9584.00 123 9584.00 124 9584.01 125 9585.00 9586.7O 126 9586.00 127 9587.30 128 9588.OO 9589.00 129 9589.10 130 959O.OO 131 9591.00 9592.00 132 9592.00 9592.20 133 9593.00 9593.30 134 9594.00 9595.O0 135 9595.0O 136 9596.00 9596.70 137 9597.00 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 5 5 5 5 5 5 5 5 X X X X X X X X X X X X X X X X X X X X X X x X X X X X X X X X X X X Laboratories, inc. Well: Northstar No. 3 Field: Beaufort Sea Location: Offshore Alaska Sample ID Depth Interval, feet 138 9597.01 9598.00 139 9598.10 140 9599.00 141 9600.00 9601.00 142 9601.00 143 96O2.OO 144 9603.00 9604.00 145 96O4.OO 146 9605.00 147 9606.00 9607.00 148 960'/.00 96O7.7O 149 96O8.0O 150 9609.30 9610.00 151 9610.00 152 9611.00 153 9612.00 9613.00 154 9613.00 155 9614.20 156 9615.00 9616.00 157 9616.00 9616.65 158 9617.00 9660.00 9661.00 9702.00 9772.00 9774.00 Core ID 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 ? ? ? SAMPLE INVENTORY Amerada Hess Corporation File No.: 21126 Zone ID Conventional Core Analysis Retort Core Analysis Paleo Sample Preserved Whole Core 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 ? ? ? X X X X X X X X X X X X X X X X X X X X X X X X X X X X Laboratories, inc. Amerada Hess Corporation File No.: 21 126 CORE BOX INVENTORY Well: Northstar No. 3 Field: Beaufort Sea Location: Offshore Alaska I' CORE' NUMBER BOX DEPTH INTERVAL, NUMBER feet 1 1 9436.00 - 9438.95 1 2 9438.95 - 9441.90 1 3 9441.90 - 9444.90 1 4 9444.90 9447.90 1 5 9447.90 - 9450.90 1 6 9450.90 - 9453.80 1 7 9453.80 - 9456.90 1 8 9456.90 - 9459.90 1 9 9459.90 - 94.62.85 1 10 9462.85 9465.75 1 11 9465.75 - 9466.65 2 12 9500.00 - 9503.05 2 13 9503.05 - 9506.00 2 i4 9506.00 - 9509.05 2 15 9509.05 - 9512.10 2 16 9512.10 9515.15 2 17 9515.15 - 9518.10 2 18 9518.10 ~ 9521.15 2 19 9521.15 - 9524.15 2 20 9524.15 - 9526.15 2 21 9526.15 - 9528.15 2 22 9528.15 9531.20 2 23 9531.20 - 9534.20 2 24 9534.20 - 9537.15 2 25 9537.15 - 9540.10 2 26 9540.10 - 9543.00 2 27 9543.00 - 9545.30 2 28 9545.30 - 9548.10 2 29 9548.10 9550.90 2 30 9550.90 9553.90 2 31 9553.90 - 9556.70 2 32 9556.70 - 9559.60 ICORE IBOX I DEPTH INTERVAL,! NUMBER NUMBER feet 3 33 9560.00 o 9562.90 3 34 9562.90 - 9565.50 3 35 9565.50 - 9567.45 3 36 9567.45 - 9570.20 3 37 9570.20 - 9572.50 3 38 9572.50 - 9575.45 3 39 9575.45 - 9578.40 3 40 9578.40 - 9581.50 3 41 9581.50 - 9584.40 3 42 9584.40 - 9586.75 3 43 9586.75 9589.70 3 44 9589.70 - 9592.70 3 45 9592.70 - 9595.70 3 46 9595.70 - 9598.80 3 47 9598.80 - 9601.75 3 48 9601.75 - 9604.75 3 49 9604.75 - 9607.80 3 50 9607.80 9610.70 3 51 9610.70 - 9613.75 3 52 9613.75 - 9616.65 3 53 9616.65 - 9617.90 V-7 MORNING DRILLING REPORT- OFFSHORE ^..~'-:~,.~ I.AC~S~DE~ L~-l[~^s~ ~.~.~. - ..... .. ~ ........ _ ....... ~PRES~T OPERATION ' '- 3 IAFE NO." }FORMATION ' OE~-PEST/CASiNG - OD ,.SHOE 'rEST. PPG I'UNIHt$. DESCRIPTION OF OPERATIONS OD TOP AND SHOE DEPTHS J DATE ...... -'"'"" 0EP1-H .... 10R~L'EO ....... TOTAL PROJECTED ..... DOWNTIME IC,C~RACTOR ANO"'~' NO. j RI~PAIR J TVD WEIGHT. SPEED AND HYDRAULICS RECO~D 5 6 rGrl B,~ PEH j WT MLB iO?ai -- · , -PC i MIN · NOZ pUMP NO I PUMP N~. 2 ~TEj ANN. V~L. ~ .... PM VEL FPM FPS. LIN SFM LIN 5PM , MUD PROPE~RTIES, MATER!ALS ADDED AND COSTS ~-U:,,,r L FILTRATE A J , m/..,v F O~'LS DH cc/30 C KE ~ ". % jMUO MATER~L~ AND QUANTITIES ADDED IN LAST 24 HOURS CHLORIDES DF, fA ME.~$UREO INSTRMNT. Ffl. PT M 12' 131" iD~IIFT ANGLE · I DIRECTIONAL $~JRVEYS COORDiNAtES VERTICAL ! MEASURED DGPTH ! ..... · OEPTI-I I\'K8) SEC, rlON INSTRMNIT VERTICAL OE~'TH ! SECr,0~ IVKB) COORDINAI'E S OPERATIONS IN SEOUENCE EXPENCASLE SUPPLIES ON BOARD: -~UBL RRC;D..GAL$, I M/V '" DATE. 1 7 , .a. , --- i , .~. .. '.. ~, :_ P/U BOTTOM HOLE ASSEMBLY' {BHAI I 0 [] I~t., k H~NUI::: ISkk PHIOI~ [~NEW BHA. ~:mr HRS S,NCE INSP. TOOL OD. ID. DESCRIPTIOD~ lIN) (IN) EFFOC ~q'. COSTS: S/O "fl APPR?____VED AF.__~[~, ~ OT ~RE__V TOT..~AL DALLY J OTAL TORQUE CUM. TOT~C REPORTED BY ~CEiVEO BY , ~ -_ .~. t'lUb.l-O:g SSBH--UO~Bt,JU: O I SO: 8~ P6 ,-l ~-l'.lUf LENG1 H (FEET) MORNING DRiLLiNG REPORT - OFFSHORE Bi'T, WEIGHT. ,SI:'~E D AND HYDf~AUi. I" q.... RECOR~ ' ~4 ~" ', 4 ...... -~-' t MUD PROPE,)TIES. MATER;ALS ADDED AND COSTg ..... ' '-r----~- ~, _, ~__~__~. __~°° .... ,.. MUD C'OST~ DALLY j TC,'fAL Il MEASURED INSTRMNT DFm'H D~REC- TIDN C O0 F:.DI NA'FE S ' DRIF r'~r ANGLE._t !'iC, I'.J C(JORD N&'f'ES OPERATIONS IN ' EPF DC 'WT. COSTS AIDPRO'VE D Af"E __tPREV TOTAL DA~L'¥ / O] AL CU~¢ 10'FAL ROT TOROUE. ~Ot~EO ~Y '[k~CE:VE, D 80TTOM HOLE ASSEMBLY IBHA) '~ 6. [~] NO C~iANGE iSt~E PRIOR REPORT) ROT Hq$ S~/,I(:E INSP. 1 7. TOOt. T OD ID LENGIH DESCRIP'FIOt.,I iH'"~ ) fin ) (FEET} MORNING DRILLING REPORT- OF AHEm,2884 (19ACKSIDE) tORE DEEPEST CASING - OD SHOE TEST- PPG IBRIEF DESCRIPTION OF OPERATIONS -- fit~ILLE0 ' MD DEPTH OUT BIT. WEIGHT, SPEED AND HYDRAULICS RECORD ] F[F'I Bl"i j Rr.q I E"'U(;-L..C,ur:r"D F -.CTAr'.,ll) CW;,'-'. [ ,M,.I,!,~, I NOZ I PUMP NO. '/ Vv ~ . ' PiPE RA, t: . t. EL,. · . I.., / _ .~ I .. -., ~ ' .... ~ MUD PROPERTIES. MATERIALS ADDr-'D AND COSTS PUMP NO. 2 } MUD MATERI'KL§ AND 60ANTITIE'$ ADDEfi iN LAST ~'4 HOUR'S, ........ i ' c.~\.., 0, s,,~,~, _. ~ % ¢.~..' ,~ .~,,~, ~.v, .... g x~. MEASUREO INSTRMN, T. OEPTH .-- ANGLE I TION I COO~Oll'qATE..g DIRECTIONAL £ URVE'Y'S L_. vf: RTICAL DEPTH 'c M£ A-Su.rtF D ~NSI'RMNT DP_PTtt OPERATIONS IN S~QUENCE 0HI?T MU ..... · WO COORDINAI'E~; I EXPENDABLE SUPPLIES ON BOARD: ~'--' iDRILL WATER IFOf. WATER tBAFtlTE ICEM'NT IFUEL .... [FUEL REC'D.-GALS. '~' [M/V ..... IDATE WIND IWAVES IM~N ABOARD [~',~TE LAST BOP TEST L ___,~.,,_~J '---~"~L,./-~:- ~_¢_ ..... DEPTH -- BOTTOM HOLE ASSEMBLY fBHA) ~6, ~ NO CHANGE (SEE PRIOR REPORT) '""~ NEW 8HA- ROT. MRS SINCEINSP, ?. TOOL 0['~, ID. [.EN0'fH DESCRiPTiON (IN.I fiN.) (FEET) £FF. D.C. w'f. COg f 5' -- APPROVEO AFk / ROT --t PREV. TOTAL OAIt v TOI'AL TORQUE ~' ~ CUM, IOIAL REPORTED BY MORNING DRILLING REPORT- OFFSHORE IPRESENT OPERATION ., ' ..... IFORMATiON 'DEEPEST CASIN~ - 0D SHO~'T~ST - PP~[kUNERS - OD TOP AND SHO~ DEPTHS~R~PAIR DOWNTIME ........ ~ . .. ~, ,~ i '~EPTH ...... -"' IDmL~O "' TOTAL PR6'~ECTE~ DEPTH I SERIALNO. TYPE 8 D~'PTH OuT WEIGH'r, SPEED AND HYDRAULICS RECORD I F~Ti~:~:'~.~;I p~ vv'r I ~o,', J COND · ,~ ' . MUD PROPERTIES. MATERIALS ADDED AN~ COSIS ,~. NO2, PUMP NO. i PUMPNO. 2 VEL ~ FPS. LIN SPM LIN ~PM ., MUD COSTS DAILY J ~ TOTAL~ MEASURED ~NS'FRMNT. COORDINAT[ S DgF'TH DIRECTIONAL SURVEYS IN'.-~ I'R M N'f DRIFI DIR~ C. ANGLE T ON D~PTH . OP6RATIONS IN SEQUENC6 PlH .% , ' BO'FrOM HOL6 ASSEMBLY (8HA) 16. BI NO CHANGE (SEE PR)OR REPOF1T) ~ NEW 8HA- ROT. HRS. SINCE INSP 1 ? TOOl. OD. ID. LENGTH [)ESCRIPIION fiN.) (il,l) (FEET) F0-~Z' R-~:'-'~'..GAL~: ........ J'~.~7~;" DATE JWAVES JM~,N ABOARD JDATF. ~AST BOP TEST ROT TORQUE EFF. DmC. COSTS, AF'PROVED Arr_. PRFv, TOTAt. DA)I Y TOlAt C U Mm 10TA, L RECEIVED REPORTED BY MORNING DRILLING REPORT "-FSHORE AHEP-2654 (BACKSIDE) ..... . ....' . ..... J¢RES6NT OPERATION ' ' ]FORMATION .1.--~_ , ~'- ?~'- 'DEPTH"' JO6, L[Eb '~-~'~_~ -J TOTAL PROJECTED OEPTH 32NOS B~T. W~HT. SP~ED ^r,,~ ~¥D~A,.,ucs F~ECORD DEPTH I FEET II II :I IH.~;I I>~R I ~' J RX','- I =/H~ I PII)[ ~}AT~ , V_L ..... ~ .._ ,. MUD PROPERTIES, MATERIALS ADDED AND COSTS J SAMPLEI FUN L FILTR TE EAK oz. r MUD PV/ I~S. Cb]4~';~0 22NDS E;ANO ,;(~ll);; OIL PPM Al.. HFHP COSI'$ l TiME V'CT... V'S'. 'YP GE.. P: .r.' . ,E ,~ ".. % :HLORID6S ~, - __. .. '__' DALLY TOTAL JMUD MATERIAL$ AND QUANTITIES ADDED IN LAST 2,4 HOURS 11 12 13 MEASURED tNSI'RMNT DFPTH ., . , DRIFT DIREC. ANGL6 TiON COORDINATIES J _~: OPERATIONS IN SEQUENCE / . EXPENDABLE SUPPLIES ON BOARD: _DRIU, WATER IPOT. WATER ~-G~[ R EC'D.-GALS,. .Ju/v 81WIND ' WAVES JMEN ABOARD IDATJ~ LAST BOP TI~$T P/U BOTTOM HOLE ASSEMBLY (BHA) J--] NO CHANGF (SEE PHIOF1 REPORT) E~ NEW BHA- ROT. HRS, SINCE INS,r'. 1 7. TOOL OD. ID . t. ENGTH DESCRIPTION (IN.) (IN.) (FEET} APPROVED AFF ;/O PREV. TOTAL ROT DAILY 10TAL TORQUE CUM TOIAL REPORTED BY 'J'RECEIVED ...........1 £FF, b C Wl COS1 £: TOTAL PROJECTED DEPTH TVD ~ CONTR--"~?OR AND~IG NO," - '/ DEPTH OUT BIT, WEIGHT, SPEED AND HYDRAULICS FJECOFID MUD PROPERTIES. MATERIALS ADDED AND COSTS PUMP r,tO. 2 MUD COSTS DAILY 'J I'OTAL DR~F'[' ANGLE MEASURED tNS'I'~MNI'. .DEPTH COOflDINATE 5 DIRI~CTIONAL SURVEYS -D.- VE~'T~ k.4EASUnEO r. PTH ,. HI INSTRMt,,,T {'~K ~) ~EOTIO'--I' DEPTH OPERATIONS IN SEQUENCE ORIFT ANGLE D~REC. COORDINATES h'V?) J ,.,,.,.,"'VE~iC';.A~- J P, OTTOM HOLE ASSEMBLY (BHA) iL--T] NO CHANGE (SEE PRIOR REPORT) ~ NEW BI-iA - ROT. HRS. SINCE mNSP. 1 ?. TOOk OD iD. LENGTH DESCRIPTION liN.) (IN.) (FEET) WiNg :J P/U S/O ROT t~XPENDABLE SUPPLIES ON BOARD: )R,LL WATER I¢'0T, WATER :tARITE CEMENT',~.:,-,.. !FUEL REC'D.-GALS. M/V WAVES MEN ABOARD DATE LAST BOP TEST PORTED BY EFF. DC.WT. COS1S' APPROVED AFE PREV. I'OTAL O,~.ILY 'fO'I AL .... 4 CUM TOTAL :~ECEIVEu B' MORNING DRILLING REPOhI'- ,,,..FSHORE AHEP-2B$4 {BACKSIDE) LINE PRESENT OPERATION .... I FORMATION ;DEEPEST CASING - OD SHOE TEST - ?PG ILINERS - OD TOP ANO SHOE DEPTH5 REPAIR, DOWNTIME ~'~, -' ¢ .?~ / '- - ....... BRIEF DESCRIPTION OF OPERATIONS DATE TOTALPROJECTED DEPTH TVD CONTRACTOR AND RIG NO. ,'~,~.._,~...¢.~..*' / MD 15 SERIAL NO A[',JC) [YP~: DFPTtl OIJT BIlZ.'WEIGHT. SPEED AND IwI')RAULICS RFCORD ............ ~f'F~L' I E,I' J/gL.ILL CONg. . MUD PHOPEHrlES. MAI EHtALS ADD[C)ANF.) CO.O, TS .STAND (_'IH(_' PIPF Itl\ l ~. PRFRg GPM II SAMPLE ~ FIIF'I ' 'r ~ ;~H ¢"r'/'~0 CAKE % ".. % " ' SAND F('~]II)~; OIL PPM ti ] I t.'l MUD MATERIALS AND QUANTITIES ADD~O ~N LAST 2~ . lMFA:-~LSRF D iNSTRMNT F)RIFT I ~RFC COL~H DINA'I'~S DIREC !IONAL SURVEYS vF RTICAi IV~t SE C, TIt-JN MEAEUHI:D INf.; I HM I'll D~PIH OMiF-F L)IM~_C. AN¢";L ~ 'l' ON I ¢.)F'L tAT QN.S IN SEQUENCE .... -z- ............ I ~X. PENDABLE SUPPLIES ON BOARD' DRILL WATER I~O'r. WATER BARITE ICEMENT FUEL FUEL R EC'D. ·GALS. JM/V DATE {WI'~ID IwAVES IMEN ABOARD DATE LAST BOP TEST ...~ ,s I., . ¢'-...z I '"---~'/- ?. gAlL'( TOTAl.. TORQUE .... ClJM T()TAL REPORTED BY [~J;CEIVED BY ANN VFI \ EL FPM I FPS PUMP t'lr.) 1 ! LIN I5PM PUMP N(..1 2 LIN I 5PM Al t' '"q HTHP k MUD Cf..)ST5 f ' / / C)A'LY i IO"AL 4 I -'s / -- / So~ COOHL)INAi ES ,.. ~ PF 0 C, WT ('. (.1.L; 15. AI'I'HOVE [1 -, PilrV IOTAL rOM HOI. F. ASSEMBLY IBHA) 7 70¢). Dr. 5(.: HIP I'lO[',l 6 E~] I,J(.') CHANCE ISEE PRIOR REPORT) ] NI W HHA - ()D, ID. LENGTH fiN.} (INI (FEEl) AMER/HESS N,STAR 3 90? 659 2391 P.OI MORNING DRILLING REPORT - OFFSHORE AHEP - Z68~,. (;BACKSIDE) .... 2/7/94 1 State Trac~ 39,,0,1,.No .rt~. Star #3 193 M 40 1,001 1,001 0 PRESENT OP~RAllONS "' FORMAl'ION " - tOTAL PROJECTED DEPlld 2 Tes~n~l B,O,P.E. TVD MO 3 20" 995" "I , 4 Parker#141 !BRIEF DESCRIPTION OF OPErATiONS ' ' ' 4 02~0 bm. Comple, taS.O,P,E testing. Laying down test joint &pre, padn9' to pis up drilJln~ 8,H,A. , .... ... i , , , , , ,m,, ., ,,,, ,. i,, ..... . , , , · m', .,m , , , ,,, BIT, WEIGHT, SPEED, AND HYDRAULICS 81~i' SIZE SEF%[A'L" NOZZLES [~EI~TH ~EI:T H0~S Fl'/ m~ll' ROT O~[L'COND. STAND CIF~'¢.ANN NOZ LIN SPM LIN ,,, # TYPE '~ 23 4 O~IT HR WT. RPM ~'~a VEL VEt, · 5 / 6 . ,, . ,, 7 MUD PR(~ ' MATER ; ADDED AND CC ;TS SAM'PLI'"M~.,~'FUN,L ,~/ YP GELS I=H FiLT. C',~KE -%' % MDT CHLORIDES "~F MF "THP '' MUDCOSTS ,, I TIM~ J ~. v~s., .. cc/m~ ~md$ SAND ~OLID$i PP .... ~AILY TOTAL 8 ~!:00 8,8 40 8 13 10 ~8 ._. 9,5 ,1~.~ . 2,0 0.5 &0. 4,1~0 ,, 5~ 14, t50 ... ., 9 No mud prod~ds add~, , ............ 10 DIRECTIONALSURVEYS · ,, , ME. ASUR~D OR~FT OlREC COORDINATES OEP'TH V MEASUR~I~. DRIFT DJREC COORDINATIVe DEPTH V '. D-cPTH ANGLE TION VKB SECT DEPTH ANOLE T1ON VK-J~ SECT , . 12 14, Ht~S I .. '" OpERATIO, NS IN,~'EQUENCE Ir, ' ..... BO--I r'OM H_OLI~ ASSEMBLY __ 0001/1700., hrs. Finish nipplin~ up ~,O,P,s,,Finish dean.!n_~ ~lravel out of cellar with Super Sucker. Cut . 16 [ ] NO CHANm~ (SE~ ¢'R~OR REPO~'O balance of 30" tO bottom of cellar and remove, [ ] N~W , =, _, 11700t2100 bm, Rig repa!,r - RePair choke and k,[!l line valves, choke manifold valv.e$, safe~ valve,.,and ROT. HRS SINCE IN,SPEC. 17 .~' ,.,,upper kelley cock. TOOL DESCRIPTION OD ID LNGT 2100/2400 h~,rs. Run test plu~. F!!I stack with water. Pres,,s,ura tastln[l (~300 and 2000 p.s.i. .~_ ~uel consumption, - 2,¢a§ ~1~ , ............. Weathe_¢ ~18:30 hrs. ,Partia, ll¥ abscured, Fo~l with 1,/8 to 3/8,,,m, L visJbilJb/., Tamp, -8 Wind from .. :S.E. ~ 3~ .knot$...Pre$~ure 30,21 and fall!n{j. Wind chill-12,. ........... TOTAL LENGTH 0,00 EFF DC WEIGHT APPROVED AF~ 0.0 EXPENDABLE SUPPLIES ON BOARD pR~V. TOTAL '~RILL WAT~=~ .... POT WA1-E~, I B',~IYE ..... IC~M~NT ~UF.L ,OT" DALLY TOTAL FIJEL"I~EC'D; GAL,.Cl MOTOR VESSEL DATE T0~QU~ CUM TOTAL WIND IWAVES M~:N A[;~QARD IDATI~ LAST BOF~ TEST REPORTED BY 50 2/7194 I~Han Ro~e ~LING REPOF ~'~FSHOR E /C:KSIDE) .,. ' .......... ' IAFE NO, ' .... JD/~"~ -' )~PTH JDRILLEO '. ~AND WELL NO. J I ~ ~ - I ~ ~ '%. ~ - ~-- I ~ .... O I ~ ~~ J /~o " IPRESENT OPERATION ~ 2 ~/.~~ ~ ~~ . / .... '----'; · --" 'R~PAIR DOWNTIME CONTRACTOR AND RIG NO. --' ~DEEPEST CASING - OD SHOE TEST · PPG ]~IN~H~ · OD TOP AND 5HOE DE~HS ~ ~'~ DES~F~T~O~ ~ OPE~A~,6~'~ ............................ Bi~. WEIC;HT. SPLLO AND HYDI'iAUI ICS REC DULL ¢.:ONF3 , ' NOZZLER I HOT I ~'rl I."~ '-' l ..I . ..... MUD ~a<}F, FRTIFS, MATERIALS ADDED AND COSTS MATERIALS AND OUANTITIES ADDED IN ~ST 24 HOURS MUD C;O J TOTAL 1() Jl 12 ]3 14 fME/;SUHbU DHIFT ¢)iRFC DIR ECTIOJ'-JAL $ U RVF'Y.q I Vt: M I' I(:AI ,"/,b A f:.;tJ H I: 0 C¢.)OHOINATF ~ DEr'iH I INSIHMN[ IVKIS) SI-UTION Db.l'lH . I ¢.QOftDINAI b ..".".".S ., VERTICAL 'J L)b. HFH ~'~ (VF. ¢~) J ....... l, '1 J HOUI(S OPERAi 0N.q IN SEQUENCE BOTTOM I IOL[ ASSEMRLY (BHA) .., 16-'"~ NO CHANGE (,gl.:l- PRIOR REPORT) L~u~_~_. '"~.~.~.~t~ 'a/.3_,. /j~_._... ROT. HRS. SINCEINSP ~~_....~_ ,---- g.~¢ ~%1~ ~0 L~..~~ -17'" TOOl Om. ID. ['ENGTII D[:;CllII'IlON liN) (Ir,i) (PEET) _ .... - . ' ..~ ~ p~. ~a 6.c~%~0~. ~, ~. Go~.~~- .... ~'" _ _~~.co.~- . ' .... ___. . ~..- -". I - .... __. l ~o ~.~ ..... ~r _~:, r~7 ~o~ .~~ .-- ~ ~. D c'. WT.~ ~-.. ~~ . ~ ~~ ~..~" ~,v~..~-~ tlr- ~q~q/ ~ .... 5/0 .... ~ I ~XPENDA~L~ SUPPLIFS ON ~OARD' ~'~EV TC}IAL .j .. DAli Y ) U'I'AL FUEL REC'D.-GAL5. }M/V , . jDATE TORQUE CUM. ' - .... ~r~ ... _...~ 1~ .-- MORNING DRILLING REPORT- OF'"~ORE LEASE AND WELL NO 1 8tare Tract 39-01 North Star #3 PR~ENT OPERATIONS= Drilli.n_~ 16" hole, 2Jg/94 Mb -- 3,233 , 1,2.20 , I ~-OR M~TION PROJECTED DEPTH 60%sand40% c-ston ! ..3,900, -rVD 3,900 MD J R~PAIR DOWNTIME JCONTRACTOR AND RIG NO. 4 . jPa.rker #1_41 . . 20" 998 .... J BRIEF OES(~RIPTI_.._~O~ OF OPERATIONS 4 0200 hrs._. Ddllin~t 16" hole @3389 JL!NERS - Ob TOP AND SHOI~ D~PTHS JAFE NO. 93 M 40 t BIT, WEIGHT, SPEED, AND HYDRAULICS BIT ~'IZE "SERIAL' NOT"-~LE $ OEPTHr FEET HOURS FT7 ~ ~E 1 ~ ~., 4 OU~ HR %~. RPM , 8t~s . VEL VEL _ 3RR 16" ATX-G1 14 14 141 ,r20 90 1,100 10b MUD ROPERTIES MATERIALS AND COSTS MUB FUN'L PV YP 'GELS PH FILT. CAKE '--~,' ' .... ~' "'~I~T T~H~ORI~I~ -- ~'~' MF HYHP 'MUD COSTS ~. ViS. . CC~ ~Ads ~ND SOLIOSm PP ' O~ILY ~ --TOTAL ...... . . , ~ , ~ . . 9;5+ 42 12 11 i2 ~ 9.0 12,0 2.0 1,0 9,0 20.0 3,9g0 0.2 1.1 ,. 2,988 20,59~ , , ,, .-, ;Benex 8 - Bicarb 1 - Soda Ash 2 - Ddspac L 12 - CF Desto 4 - Ddg_,,_slow_er R.O,?, a,nd H20 helping lower solids, 3000' + or - drilling into high,.~ lots of water,~ · DIRECTIONAL SURVEYS -MEASL4=~ED DRIFT -- DIRge' COORDINATES DEPTH V MP__ASURI~O D~IFT DIREC COORDINATES DEPTN V DEPTH_ , _ANGLE TI,ON .... VKB, SECT DEPTH ANGLE TICN .. VK~ S~ECT 11 _ _ HRS OPERATION~ lN SE~'UENCE " 'BO-I-rOM HOLE ASSEMBLY , ._ . __ __ _ .,. . 15 0001/0130 - Circulate and condition mud, 16 XX NO CHANGE (SEE PRIOR R~POR'r) _ . 0130/;~400 - Control drill from 2013 to 3233. [ ] NEW ~A see 2-2-94 report ROT. NR5 SINCE INSPEC. ..... 17 ' TOOL DESCRIPTION OD lO LNGT ,,, , _ _ . I I I I Il ~ I' · ' ' ,. . , . · . . ._ .., ,,, , ,, ..... ..... , . . 1, . ., , ., - . , ., -- -. Fuel consumption: ..4,558 ~lals. ._-- ...... 11.730 wee!her: Visblllt~10 mi. Light,snow, Temp. -12F, Wind ca!m - Pressure 29,89 and risiq9 TOTAL. LENG,TH ] , 0.=00 slowly - Chill ,12F ...... ~F nc WEIGHT _ -- P/U APPROVED AFE 0,0 EXPENDABLE SUPPLIES ON BOARD ¢,REV. TOTAL D~ILL WA"~,A ;,~T WATF_,~ "IIBARIT~ I0~MENT FUEL ROT · DALLY TOTAl, PUE[ REC'D - GAL-~ MOTO~ V~SEL ' " DATE TORQUe' CUM TOTAL --. 50 MORNING DRILLING REPORT - OFFSI', AHEP. 2684/~BA.CKSI .DE) ......... ~A~ AND WE~ NO. 1 State Tract 39-01 North Star :~3 P~NT OPEFu~TION$ 2 Drilling 16" hole· , .... 3, 20" 995 .... iBi~lC-F DESC,RI?TION OF OPERATIONS 2/!0/94 i^~E.o. "lo^Ys ' po "!TM 11 I 3,?11 ! 3,711 I ]60 Y~ sand 40% ~ston ~ 3,925 ~D 3,925 MD IL~NER~ ~ OD ~ AND SHO~-DEPTH~ ~R~PAIR DO.TIME ]OON~CTOR AND RIO NO. ..... I 2 jPa~er ¢141 .._ 10200 HRS DRILLING 16" HOLE ~ 3800 BIT, WEIGHT, SPEED, AND HYDRAULICS 8 918AR-29 BEN-EX - 2 BICARB - 1 SODAASH - :2 9APP - 4 DRISP ~ 7 DESCO - 5, ADDING WATER TO REDVCE MUD W-F, DIRECTIONAL SURVEYS MEASURED DR~T DIREC 00OP, OiNATES DEPTH V MEASURED DRU~T DIREC COORDINAI'E8 DEPTH V DEPTH ANGLc_ .... T, ION, ,, VKE, ,S ~C,,T . DEPTH ANGLE TION .... VKB ,. , ,11 L 13! ..... .... "t "'' =' "' '"' "' " .... ' ~4i ........... . .... ...... HR,~ ...., ,.... I'0'p~RATIONS, . ,-, iN'SEQUENCE'.. .,,, ,, BOTTOM HOLE ASSEMBLY 6.0 0001 - 0600 DRILL 16" HOLE FROM 3:233 TO 3648, 16 ,x~ NO CHANGE {SEE PRIOR REPORT) 2,50S00 - 08~O__C.B.U, . ....... 5,0 '0830.- 1330 P0.,H SLM, T!.GH_.T HOLE ~ROM ,3~.4, 8 TO 170,0, NO CHANGE O.N_SLM. [ ] NEW BHA ,ee 2-2-94 report .....1,1330, .'1430 MADE kip EIT,~2 RIH TO. SHOE~ ...... 17 1,0, 114,30- lg30 SLIP ~ND CUT DRILLING LI.N.E .......... .TOOL ,D~$.C. RIPTION OD ID LNGT · .. O.B 1530 . 1600 SERVICE RIG .... . .... ,.- ,. -' 4,,5 I~.800- 223q. OONT. RIH.,,TIGHT HOLE AT 1830,.- 1875, 2220- 2260, 2~45,2600 ........ 1.5 12230- 2400 BREAK CIRC. DRILL 16" HOLE FROM 3648 TO 3711 .... _ · .... , ,, , ,-_ ,, ,, !Fuel consum, ptbn: .2.2.B8 ~als. . ................. . .; !730 weather: Visibility 7mi, CLOUDY. Te,n?p. -11F Win~ c~lm - Press,y. re 30.39 STEADY- 24 CHILL TOTAL LENGTH ............. {;),DO APPROVED AFE · .r. ,= ..... . H.iI __.,._. . i,.i _ 24.0 EXPENDABLE SUPPLIES ON BOARD prier, TOTAL ..... I "1 F'UEL ROT D~ILL WAT[R POT WATER BARITE 0~:MBN'i' ........... ...... DAII, Y TOTAL FbEL I~BO'd - 6,~[-~ IMOTOR VESSEL DATE ' TORQUE ..... .CUM TOTAL ........ ~ ....... WIND IWAVE8 ]MEN ABOARd' IDATE LAST' TEST 18 49 2/9/94 JOHN MORNING DRILLING REPORT - OFF,~MORE AHEP - 2684 (BACKSIDE) .......... 2/11/94 ......... ¢A¥$ J TVD O~I[L[~ 1 State Tm~ $9-01 No~h Star ~3 I ~3M40 ,. 12 3 ~zs, 3,9~5 214 .__ --- PReSeNT OPiniONS '" FORMATION TOTAL'~ROJ[CTED DEPTH 2 Drilling 16" hole, 60% sand 40% c-sion 3~925 ~D 3,925 MD .... ~iNBRS .'~'D TOP AND SHO~ DEPTHS " RBP~'I'~ ~OWNTIME C~T~CTOE AN~ RIG NO." 3 20" 995" ~.._ " . ...... 2 Parker ~141 ..... -.. ~RIEF D~SCRIPTION OF OPERA. ON8 4 .. 0200 LOGGING WELL WITH LDT - SDT - OR - ~S. ,i . ¢,, . ,. ,, ,i .. .... ,, . ,,. _. . .... . . i,, .. BIT, WEIGHT SPEED. AND HYDRAULICS BIT SLZ~- SERIAL NOZZLES DEPTH F~==T ~OURS ........... :': ..... " ri'/ BIT ROT DLILI'"~OND.STAND ClRC ANN NOZ LIN 5PHI LIN SPl,3 # TYPE I 2 3 4 OUT HR %rt. RPM St'ms VEL VEL 5 RR#I 16" ATX-GI 14 14 ,1._4, 3,640 2,645! 34,5 ,,77 20 90 5 1 I 1~,900 10b ...... ,6" 95 6" 0 _._6. ~ 16.00 ATX CG1 12 12 12 3,925 285 2.0 143 20 90. _._1 1 I 1,900 378 .... 6" 100 6" 0 ... 7 .... MUD PR MATERIALS ADDED AND COSTS MUD FUN'L PV YP GELS PM FILT. CAKE ~Al ' .... ~'-'.v '-~I~T'~ CHL(~,IOE$ PF ~F' ~HP MUDCOSTS g,6 40 10 12 13 9.0 14,4 2,0 1.5 8.0 20.0 ~ 3,I00 1.5 1.3 :~ 3,262 23,391 BEN- EX.:.8_,_B_ICARB - 1, SODA ASH- 1, SAPP - I,DRISPAC-L - 6. XC-POLYMER - 2, NUT PLUG- 1. TD WELL PUMP HI VIS SWEEP, MADE TEN STD, SHORT TRIP,CBU WITH HI ViS SWEEP, POH FOR LOGGS. DIRECTIONAL SURVEYS NlrA.SuREr) OR[F-f hlREC COORDI,N~-,TES DEPTH V MEASURED DRIFT DIREC COORDINATES DEPTH V D~:PTH ANGLE TION VKB SECT DEPTH ANGLF, TION VKB SECT 11 · . , , 12 13 14 _ __ HRS O.p...ERATION~'I N..@_,,E ,Q, U ENC E .. ' ...., r, 1~5'TTOM.,..,HOLE AssEMBLy._ 2,5 0001 - 0230 DRILL 15" HOLE FROM 3703 TO 3925 TD 16" HOLE, 16 XX NO OHANG~ (SEE PRIOR REPORT) 2,5 0230- 0500 PUMP HI- v~S SwEEP,C.~U. ..., 1.5 0500 - 0630 MADE 10 STD, SHORT TRIP TO 2970 [ ] NEWBHA see 2-2-94 report ,, .... . , 2 0630 - 0830 PUMP HI-VIS SWEEP, CBU, ~OT. ~RS S~NCE INS~EC. 17 3,5 0830 - 1200 POH FOR OPEN HOLE LOGGS. HOLE CAME CLEAN NO TIGHT SPOTS. TCOL DESCRIPTION OD ID LNGT .. ~-_5_ ~ ,12_,00- 1530 RIG UP SCHLUMBERGER TOOL,.,H, ,A,D COMMUNIO.ATION FAILURE,C, ,H. ANGE OUT ,,. TOOLS THE ,5"..,~..T t.,o ~'t,,r,,/¢,o/ ,4,/¢¢ ~,,.,,o/,'./'~.. c,u'/'/"k '~'"'/1~,'...¢..~,¢"~x'7'LT', ...... 8,0 1,530 - 2330 RIH WITH AlT- OR - AMS LOG WH~L~_ OOING IN HOLE TAG BOl-rOM AT :3922, LOG 0,5 MADE UP RUN #2 WITH LDT~ 8DT- GR- AMS RIH .... ....... ,, · .. 'Fuel consumption: 3213 ~lals, , .............. 1700 HRS, WEATHER REPORT 5 MI VISE TEM - 15 CHILL - 50 WINDS S W AT 12 MI, TOTAL LENGTH 0.00 EFF DC WEIGHT APPt~OvED AFE 24,0 EXPENDABLE SUPPLIES ON BOARD PREY. TOTAL .... C)RILL WATER :POT WATER .... DS~Y TOTAL FUEL REC'D - ~AL5 Mo-foR VESSEL DATE TORQUE CUM TOTAL IWIND tWAVE$" IMEN ABOAF~D [C~ATE LAST BOP TE$?" I~'EPORTED BY .... 1_..8 .. i..49 2/9/94 J. SA, LARIO , ~0I a $6£C 6S9 ~.06 £ WUIS'N SSBH/W3NU S£:T. 0 P66~-];~-~-t DATE MORNING DRILLING REPORT, ;~'~-HORE .... . AHEP - 2684 (_BACKSIDE) ....... 2/12J~4 LEA'E AND WELL NO, -- IAFEN'O. ' ,DAYS ,-MD T'VD DRILLED 1'State Traut 39-01 North Star #3 ] 93M40 .[ [13 3,925 3,925 ., " PRESENT OPERATIONS FORMATION TOTAL PROJECTED OEPTH 2 Drillln. g 16" hole. 3,925 TVD 3,g25 MD ' ]LINER~ - OD TOP ANO'$HOE DEPTHS RbPAIR DOWNTIME CONTRACTOR AND RIG NO. 3 20" 995 ....[ 1 Parker #141 ._ 4 0200 RIH WITH 13 3/8 CSG. .. __. .. ,. , ,, ,,, ,, __ ... ,, BIT, WEIGHT, SPEED, AND HYDRAULICS , . ,. BIT ~IZE SERLAI" NOZZLES DEPTH FF=r=~' HOUriS FT/ BFq: ROT DULLCOND. STAND ~IRC ANN NOZ: LIN SPM LIN 5PM 2 3 4 OUT HR WT. RPM 8~8 VEL VEL 'tYPE 1 .i ' _. , , . MUD PRO TE 1ED AND ~ STS 8~ 9 BAR - 24, BICARB - 1 DRISPAC-L - 3, XC-F~OLYMER - 1, 10 LOGGED HOLE RIH NO FILL CBU SHORT TRIP POH FOR CSG. '. "i'l MUD FUN'L PV YP GELS PM FILT, 'CAKE %' "% ::~OT- CHLORIDES~ PF MF HTHP ~UD COSTS '~. ~8. C~ 32nd~ SAN~ SOLIDS PPM DALLY TOTAL ' " , 9,7 40 10 ? 12~39 .~.6 13.2 2,0. 1.0 8.0 ,,, 20,0 3,100 0.2 1.1' 1,673 . ,, 28,226,, , , , DIRECTIONAL SURVEYS MI~ASUR~_D DRIFT DIREC COO,~DINATES DEPTH V MEASURED DRIFT DIRE¢ COORDINATES DEPTH __ DEPTH ANGLE TION VK~ SECT DEPTH ANGLE T[ON VKB ,,, ., . 11 , .. 13 _ ~4 _ H~RS ,. OPERATIONS IN' SEQUENCE .... BO-FFOM HOLE ASSE.M, BLY .. . .=_ 5.0 0001 - 0500 RIH WITH LOT. SOT - GR - AMS,LOG WELL WITH SAME. ,,, 16 XX NO CHANGE (SEE PRIOR REPORT) t .00~00. 0600 LAY DOWN TO,OLS, STAND BY FOR OI~DERS FROM ,. _ GEOLOGY , ,. [ ] NEW aHA r~e 2-2-94 report 1 0600 - 0700 RIG DOWN SCHLUMBERGER. ROT. HR$ SINCE INSPEC. . .. 17 3.6 0700 - t030 PICK UP TWO NON - MAG COLLA.R@, RIH FOR CLEAN OUT RUN, TOOL DESCRIPTION OD ID LNGT ~2.0 , 030 - 1230 CIRC AND COND MUD,NO FILL ON BO1-FOM; ( kole.in ~o,o,d_sh~p.e) .. _1.0 1230- 1330 MADE 10 STD SHORT TRIP. '~2,0 1330- 1130 PUMP HI -VIS PILL, CBU, ,, ,5 1530 - 1600 DR,,QP MULti. SH,OT, PUMP PILL. _ ~3,0 1600- 1900 POH TAKE SURVEY EVERY STD, RETRIEVE TOOL. .. , 1.0 1900- 2000 CHANGE TOP RAMS TO 13 3/8, , ,, . 3.5 2000 - 2330 RIG UP TO RUN 13 3/8 CSG. RIH WITH SAME. RIH TO 20" SHOE. 0.5 2330 - 2400 WORK ON ELECTRICAL SYSTEM SCR AND DRILLERS CONSOLE, WORK ON LAY DOWN MACHINE, ___ · 24,0 __ _. Fuel consumpti,o,n: 4964 ~lalSr .......... t700 HRS, WEATHER REPORT 5 MI VISE TEM · 15 CHILL. 50 WINDS S W AT 12 MI, TOT^L LENGTH 0.00 ........ EFF DC W..EI~HT P/,J · APPROVED A~IE · · S/O " ' r'=XPENDABLE,,,SUPPL1E8 ON BOARD p~nv. TOTAL DRILL WATER POi' WATER '[BAI~ITE "ICEMI'--NT ' FUI~L ROT ,, DA~LY TOTAL FUEL REC'D'. ,¢.2~AL$ ' MOTOR VE.88EL D,~E TORQ'U¢ · CUM TOTAl, '-- .. r ,~ii,,j! 2/9/~94 ,JOHN 8ALARIO , . MORNING DRILLING REPORT. OFFSHOK__ 'oi~ AHEP - 2684 (BACKSIDE) ....... 2/13/94 LEASEANOWELL NO. - - )AI~I~ NO. IDA'¢~ 1MD" - TVO DRILLED "-- 1 State Tract 39-01 Nodh Star #3 [ 9,,,3, M40 14 3,925 3,925 _ PRESE~I"f' OPERATIONS ' ' FORMATION TOTAL PROJEC]'ED I~PTH ' 2 RtH WiTH BIT # 2 RE I OLEAN OUT FOR 13 3/8 CSG, 3,925 TVD 3,925. , ME) ....... LINERS, - 00 TO~' AND SHOE E~EPTHS REPAIR D~WNTIME CONTRACTOR AND RIG NO. ._320" @ 995' 1 Parker#141 ~RIEF DE$C;,RIPTIO~ DF OPEP~-rlOHS ....... 4 0200 RIH WITH WITH BIT # 2 FOR CLEAN OUT. _ ii r. . I i · i __ , . ,il ,,, -.i ...... , , .. _ BIT, WEIGHT SPEED AND HYDPJMJLICS lC TYPE % 2 3 4 OiJ~T I ,, HR WT. RPM BBC, VEL VEL . 5 2 RR !6.00 A'TX CG1 0 U !T CLEAN IOUT t' ' _6 .j 7 MUD FU~I'L PV '~P G~LS'' PH' FILT, CAKE % % I'4BT CHLORIDE5 Pr MF ~'}HP MUD~OST$ WT. VIS. CC~ 32n~s SAND SOLIDS PPM DAILY ~ TOTAL I 8 9,7 41 10 0 ? 41 8.5 13.4 2.0 1.0 8,'0 20,0 ~ 2,800 0,2 1,1 1,377 [ , 29,60 8 L. ~.9 ~- 19, G~LL- i3 D~ISPAC-L ;~, SOD~.~SH- ~ - 10 RIH TO CL~N OUT. DIRECTIONAL SURVEYS MEASURED DR?'r BLEED COORD[NATE.e5 DEPTH V MEASURED DRIFT DiREC COORDINATES DEPTH V .DI~PTH ANGLE TION VY,.8 SECT DEPTH ANGbE TION VKB ~ECT ..,. ... , ,. , .. .. 1t , . . 12 .__ ... ,, , 1:3 14 ,.. , ,.. ~R$ ........ OPE,~TIONS ,l~ SEQUi=~cE ,, ' .... ] Bo'TToM HOLE ASS6,MBLY __ 1.0 0001.0100 WORK ON SCR, WORK ON LAY DOWN MACHINE. r16 xx NO CHANGE [SEE PRIOR REPOR~ 4,0 0100 - 0500 RIH WITH 13 3/8 CSG. HIT TIGHT SPOT @ 1175 MADE UP CIRC. HEAD WORK PAST .' TIGHT SPOT. CONT. R[.H HIT_~FIGH,,T SPOT ~ 2734. ,, ,, [ ] NEW BHA see 2-2-94 report 2.,6 0500 - 073,0, MADE UP CIRC HEAD, ClRC A~,.D WORK PIPE COULD NOT ,W, ORK PiPE PAST 2734. R. OT, HR$ SINCE INSPIZC. _ 2.5 0730- 1000 RIG UP TO POH AND LAY DOWN 13 318 CSG 17 .... , ..... , ...... TOOL DESCRIPTION OD ID LNGT · _ 13.0 1000,,- 2300 POH AND LAY D,OWN 13 3/8 OSG, H~_'[' AND BREAK BAKERLOCK CONNECTION. .. _ 1._..,___0: 2300 - 2400 CLEAN FLOOR OF 05~.. TOOL,% ,, . . ,, , __ _ , ., f ,-- ,,,, ,, , ,, ,, ; ..__ _ __ '~. .. T0~'AL LENGTH 0.00 _ '" · "' _ ......... ,, .. EFF DC WEIGHT 24.0 Pro ., ........ APPROVED AYE . EXPENDABLE SUPPLIES ON BOARD: sro ..... I I ,. PREV. TOTAL ~RILL WAT~=~ .POT WATE~ BAAITE CEMENT FUEL nOT - '-- ' .... , DAILY TOTAL FUEL REO'D {(~ALS} ,FU=-LCO~ISUMPTION (-~ALS) ~,ENAaOAR'D TORQUE 1,801 1,801 53 CUM TOTAL YEMP (F.} IW~U[~ (~.~,'D~I/~jR) ' 'lWi~D CHILI,. [~ IVIS]'~I-~I]f'Y (MI> DATE LA'ST BOP TEST "' R~:JQr~T£D 8¢ ' -7 18-37SW. . -59 1/2 MI B-S 2/9/94 ~ ~ JOHN SA,____~_~I_.0_O £ ~UIS'N SSBH/H~I.,.IU 9%:~B PF, G[-P[-Rqq ~HER×HESS N.ST~R 5 90? 659 2591 P.01 MORNING DRILLING REPORT ,- OFFSHORE D,~T~' AHr:p _ 2684._(BACKSIDE) ........ 2J/~,/1994~ _ t .State Tra¢~ 39.01 North Star #3 I 93M40 15 3,92g 3,92~ PRESF. NT QPI~ATI{~NS ......... FORMATION TOTAL PRbJECTJ~O BEI~TH -- 2 RIH WiTH ,17 1/2 "HOLE OPEN, ER, ,, 3,.925 TVD 3,925 MD I LINER$ -O'D TOP A NO 5HOE D~PTH~, !REPAI~ DOWNTIME ' CONTRACTOR AND RIG NO. 3 20" (~ 995' , ......... Parker#141 8PJEF.D~CRIPT1ON OF OPERATIONS 4 0200 DRILL WITH WITH 17 i/2" HOLE OPENER. --, , , , ,= , =, . --. ~T iii I Iii BIT, WEIGHT, SPEED, AND HYDRAULICS eft StZS E~RIA~ __NOZZLES OEPTH F~i.T ~OuR~ FTI ROT DULL COHO. STAND CIR¢ AN'~q NO;~ LIN SPM LIN' # TYPE I 2 ;3, "4 GUT HRt~I RPM 8th':. VEL VEL 5 2 RR 16.00 ATXCGI 12 PI B '[7.5 !HOLE PENER WT. VIS. C,.C~ ~n~ SAND 5OLIDS PPM DALLY- '~ 'I'O~.L - ! 9.7. 41, 1.2 11 10 34 9,0 ,12.4. 2.0 20.0 8,0 20.0 2,600 0.2 1,4 2,83O,, J ,32,433. , CELL - 24 DRJSPAC-L · 6, SODA ASH - 1 BEN EX - 3, BICARB - 1, NUT PLUG - 3. " DIrEcTIONAL'SURVEYS M~S{JRBD DRIFT DIREC COO.~OINATES DEPTH V MEAC3URE~) DRIFT DIREC COORDINATES DEPTH V __. DEPTH ANGLE TION VKB SECT DEPTH ANGLE TION VK8 SECT 11 12 · ,, · ['~RS OPERATIONs IN S,E, QuJSNCE - '~oTToM HOLE ASSEMBLY " · I 2,0 0001 - 0200 LAY DOWN 3 DRILL COLLARS, MADE UP NEW BHA. 16 X.X NO CHANGE (SEE PRIOR REPORT') _ 2.0 02,00 0400 RtH WITH, 16" BIT ,F,O. UND TIG, HT' SPOT (~ 2734, ,,, _ 0.5 0400- 0430 THAWED OUT KELL,Y, !CE PLUG @ GROUND L. EVEL, ,,. [ ] N~W ~HA .~ee 2.2-94 report ..2,5[0430 - 0700 WORKED.,PIPE (~ 27~,4, RIH TO,,,BOT.T. OM, FOUND 10 .FT.. FILL, CBU WITH HI-ViS. , ROT. ERg,-qlNCE INSPEC. ~ __..-:-. !SWEEP WORK PIPE, 17 , ,, TOOL O[;SCRIFq'ION OD ID LNGT 3.6 0700- 103,0. PUMP PILL MADE .SHORT TRIP TO 20" S~rOE, FOUN ,D, NO TIGHT,SPOTS ON TRIP, , ..... . NOTE DECISION WAS MADE TO OPeN HOLE TO 17 1/2". 4,5 ~03o..- l~q0, R~G UP TO, LAY D, OWN, DRILL PIPE POH LAYIN,,G DOWN DRILL PIPE. , .... 3.5 1500- 1830, MADE UP 17 t12 ,, HOLE OPENER,~ WELD STRA,.PS ON SAME. , ...... 0,~ i,830- 1900 SERVICE RIG. · 1.0 1~00-2000 RIH TO 20" SHOE. 4,0 2000-2400 D~ILL OPEN HOLE TO 17 ii2". --. ,,, , ,, ,, - , ,, , . , .... · TOTAL I. ENGTH 0.00 EFF DC WEIGH'r 24,0 120 App~O~c~ AFE EXPENDABLE SUPPLIES ON BOARD: 100 pF~av TOTAL DRILL WATER PO¥ WATER ll]iARITE' ' IC,-~MEI~T FUEl, ~tO'-i: ' . 3,044 110 DALLY TOTAL FUSE I~¢'D (GALS} FUEL CoNSUMPTION (OALS) MEN A.~OARC) TORQUE .... 1,801 1,801 83 300 CUM TOTAl. TE~5 (r-.) IW,ND (MPH/D,R) ]WIND CHILL {'F3 IVISIBILITY (Mi) DATE LAST B4~P TEST REPeRT~D BY 18 -8 I 28 -35 SW ,, -65 1118 MI B-S 2/9/94 JOHN SALARIO MORNING DRILLING REPORT- L._ ~ "' IORE '~DATE AHEP-2684 (.BACKSJD,E) , .,, 2_J1.5,/94 1 State Tract 39-01 North Star #3 193M40I J16 3,925 3,925 PRESSNT OPERATIONS ...... FORMATION '" TOTAL PRO',)ECTED DSPTH " 2 RIH WITH BIT # 2 RR 1 OLEAN OUT FOR 13 3/8 CSG. 3,925 -FVD 3,825 MD " tUNER§- ~)O TOP ANO SHOE D~'PTHS REPAIR I~OWNTIME C(~NTRACTOR AND RI(~ NO. 3 20"@ 995'I I Parker #141 -- ~EtRI,EF DE~SCRIPTION OF OPEtAAT~ONS ' ' ' -- 4 0200 OPEN 16" HOLE TO 171/2". ,, . ,.,, , _ , ,. ,, , -- ., ... ,., ,, BIT, WEIGHT, SPEED, AND HYDRAULICS ~IT SIZE SERIAL N~ZZI. ES DEPTH F[;~¥ HOURS F'~; i~iT ROT DULL COND. 5TANG '~IRO ANN NOZ 'LIN SiM LiN SPM ~ TYPE 1 2 3 4 OUT HR YV'I'. RPM 81t18 VEL VEL -, 5 2 RR 16.00 ATX CC1 0 U T OPEN HOLE 17 1/2" 6 7 MUD PROPERTIES IATERIALS ADDEDAND COSTS SA~L Mu TIME ..WI 0;001 ~. MUD FUN'L PV yP' GELS PH :FILT. 'CAKE ¥~,' % MBT CPILORII~ES PF MI: HTH¢' MUD ..WT. VIS. CO/'3O 32nd8 SAND SOLIDS pPM DALLY' I ' --TOTAL ,', 9.8 ,,40 11 12 10 35 9,0 12.8 2.0 2,3 9.0 20.0 2,500 0.2, 1.5 1,65,~ 34,088 DIRECTIONAL SURVCYS MEASURED DRIFT i..'DIREC COORDINATE$ DEPTH V MEASURED DRI¢'~" DtREC CC)QROINATI~$ DEPTH V DEPTH ANGLE TION VKB SECT D~:PYH ANGLE TION VK!~ SECT 11 12 ............... 14 -' HRS ~ OPERATIONS IN SEQUENCE BOTTOM HOLE ASSEMBLY 2,5 0001 - 0230 OPEN 16" HOLE TO 17 I/2 FROM t645 TO 2149, 16 NOCHANGI~ ($~E PRIOR REPOR~ 0.8 0230 - 0300 CU'i-TINGS TRUCK CAN NOT MAKE IT TO CUTTINGS DUMP, 8LOWING SNOW. FORKLIFT HAD PLOW SNOW IN AND OUT FO[~ TRUCK, X NEW a~ see ~-2-94 report 1.0 0300- 0400 OPEN 16" TO 17 112 FROM 2149 T02428. ROT. HRSSINCE INSPEC, 17 0,5 0400 · 0430 WAITING ON CU'I-I'INGS TRUCK AND FORKLIFT. T.OOL DESCRIPTION OD ID LNGT 1,0 0430 - 0830 OPEN 16' HOLE TO 17 1/2" FROM 2428 TO 2400. BIT la. COO ~.$o 12,5 0530 - 1800 ,POH TO 20" SHOE, RIG AND CAMP LOW,,O.,.,N, ,W, ATER, E~LOWING SNOW REDUCING,, XO lO 3 4.63 VISIBILITY TO NEAR ZERO. WINDS 35 KT, GUSTS TO 45 KT. WATER TRUCKS WAITING ON HOLE OPNER ~ 3 7.87 ,. ~ LOCATION FOR WEATHER TO BREAH. XO 8 __ 3 ~r~.~ 6.0 1800-2400 RIH TO 2490 OPEN 16" HOL,~,TO 17 1/2" FROM 2490 TO 3400. ,,, D.C, ~ 3 3~.o,8. . STAB ~s 3 5.56 D.C. STAB 6-D.C. . ~ '~.~e , ,,. JARS _ , 30-HWDP 5 · TOTAL LEN (';iT H 1237.88 . , , ~,FF I~(~ WEt(~HT p/1j 24,0 APPROVED AF.E EXPENDABLE SUPPLIES ON BOARD: Pnl;v. TOTAL ~UEL REC/D (GALS) FU~L CONSUMPTION (GAGS) &II~N A~OARD TO/-'-qQUEi 4,1~8 4,1.~ 51 CUM TOTAL TEMP (FI ~";,i~/TN--D'(MPHIDIR) Iw[N° CHILL (1:) p?S-~L~' (,~7~ ..... DATE' LASt iii015 TEST REPORTED BY ~8 -8~j 20- 30WSWI -63~INF--AR O ......... _2/9__/.94 JOHN SALARIO MORNING DRILLING REPORT - OFFa, ...,RE ~^T~ AHEP - 2.684 (BACKSIDE! , __ 2/16/94__ I 1 State Tract 39.01 North Star #3 I 93M40 I 17 I 3,930 3,330 5 PRESGNT OPER'ATION$ ............. FORMATION ' TOTAL PROJECTEB~ DEPT'H 2 RIH WITH BIT # 2 RR 1 CLEAN OUT FOR 13 3/8 CSG, 3,900 -I-VD 3,90Q.__ MD .3.. 20" ...... .~ 995' Id-~i:-~s ' oD TOP, AND .... SHOE DEI~:i"~'S ............ REPAIR DOWNTIME ..... CONTF:~"~TORpsrker #1,41 AND RIG NO, .... BRIEF DESCRIPTION OF OPERATIONS , 4 0200 . RIH WITH 13318 CSG. TO 3920. CIRC. COND. FOR CEMENT. BIT, WEIGHT, SPEED, AND HYDRAULICS BIT SIZ= ' $~]AL NOT-.ZLE5 DEPTH FEET HOUR5 FT/ BIT ROT DULLCOND. STAND CIRC ANN NOZ LIN SPM LIN--- SPM ¢¢ TYP~ '1 2 3 4 OUT HR Vel'. RPM B~'~ VEL VEL .... j MUD PROPERTIES. MATERIALS ADDED AND COSTS SAMP~-' = MUD [ T~ME ._.WT. 8 0:00 9,8+ 9 BAR - 20 GEL. 10 BEN-EX - 11 DRISPAC;-L - 10. 10 MUD FUN'L' 'PV YP GELS PH FILT. CAKE %' % MBT CJ-JLORIDJ[S P~: MI~ h'THP ---D~,iI"~---'MUD COSTS i - - 'TOTAL WT. VIS. CC/30 32nd8. SAND SOLIDS PPM 9,8+ 48 1~ .j,9 18 12 8.5 12.0 2.0 0.5 8.0 15.0 2,500 0,2 1,2 3,205 [ 37,293 DIRECTIONAL SURVEYS MEASURED DRIF-r DIR.F,C COORDINATE5 DEPTH V MEASURED DP, ir--i' DIRI=C COORDINATESDEPTH V DE~TH ANGfF TION VK~ SI:CT DI~PTH ANGLE TION VF, B SECT 11 ~,_ 12 13: 14. HRS ......... OPERATIONS IN SEQUENCE ........... BOTTOM HOLE ASSEMB'I._Y -,~ 8.0 00D,!,,;. 0800 OPRN 16" HOLE TO 17 1/2"FROM3181 TO 3@25, DRILL JUNK 5 FT. NEW HOLE, 16 NO CHANGE (SEE PRIOR 2.0_,0800 - 100.0. PUMP HI- VIS SWEEP cgu AT, .1__.7_'p. ,,S, PM,,2,100 ,,PSI. 1.5 1000-1!~0 PUMP PILL MADE lg STD SHORT TRIP NO FILL NO TIGHT SPOTS, NEWBHA 2.0 1130 - 1330 CIRC HI-VIS SWEEP AROUND. ROT. HRS SINCE INSPEC. 1.5 1330 1500 POH TO 20 ' SHOE. 17 ' TOOL DESCRIPTION OD ID LNGT 1.0 1500- 1600 SLiP AND CUT DRILL LINE. 1,.____.~0 :, 1600 - 1700 OONT, POH , 1.0 1700 - 1800 PULL WEAR.RING RIG UP TO RUN 13 3/8 CSG. · . 6.0 1800- 1700 RIH WITH 13 3/8 CSG. , _..,ri , , ............ NOTE 13 3,/~ CSG. D w-r 235, uP WT 250. , · . ,~, .,, . . , --' ' lr r TOTAL LENG ~--H ........ EFF DC WEIGHT 24.0 ............. 250 APPROVED EXPENDABL,,E SUPPLIES ON BOARD: 23~ PREV. TOTAL DRILL WATER POT WA~E~ JeAR~E .... JO~M~N, ,UEL" RO~ ........... DALLY TOTAL FUEl.REC'B (GAL~) FLJF=LCONSUMPTION (GALS) MI~N A~"'~ARD ,TORQUE ......... 1,731 5t CUM TOTAL '12 . I 1 S SW -SO ISMJ ,2J9/94 .. JOHN SA.L~.RIO MORNING DRILLING REPORT - L.. JHORE 1 'State Tract 3~1 No~h Star ~3 0 3 ~ 0001 - 06~ Ni ledo~ 20" B,O.P.E, and movin out of ~llar. Cleanin ~s element ~ntamJnat~ mud and ravel. - : _ :~ .... ~. ~ ~_ . ~ ~ - _ ._ _ .. ~ - ~- ~ _ ... ~ ~ _ ~- . _ -- ~ _ ~-. _ -. , 9; 1. gbarb . 2 - SAPP - Hauling cement ~ntaminated mud to disposal site. Cleaning gravel out of p ts. _ ..... DIRECTIONAL SURVEYS M-.5,~URF=D DRIFT OlREC COORDrNATE$ DEPTH V MEASURED DRIFT DIRI::¢ COORDINA'fE _ OEPTH ANGLE TION VKB SECT DEPTH ANGLE TION VK@ SECT tl. ,m , ,, , .__= ,, 13 -- -- ' ' -- ' -- " -t --J' ' -- ' - -- ~4 _-- HRS _ , , '- .6PERATIONS I~i SEqUENcE , ~ BOll'OM H(~LEASSI~ZMBLY --' _ 0001-0130-.Fi_ni,shP_,U. 133./8"casing. Total.ofO,9, Jts, pluslandlngjt. Shooa_t392~, _ _, . 16 NO CHANGE (SE~ PRIOI~ REPORT) _ 10130.-.0400 - Rig up ~rnentlng head. Circ. and redp, H,a.u?x~_~_jC. it ¥_ol.ume.~t..o disposa~l site,_ t _ 0400 · .0,948.] Test cml. lines. Pump 50 bblB. water. Mix?nd pum~ 46,3,2 cu. ft. - 825 bbls.. - Cold,et III w~/. GHS. FP~L @12.2 p.p.s, followed by 760 c,.u: fi,_- 135_bbls. - Cla$~ e w/~2% Ca~C.,1 2wi 1 ?.H,S F?_-6L , aO.T HRS SIN?,,.E.INSP_EC. 17 _ ,~ Drop plug_and .d, bpla, ce wi .~57 bbls. mu.d. Had approx, 4.80 bbfs. of cement retums t surface. ., reel O6SCRIPTIO, N, OD ID LNGT Tail s,lurry 1~.8 P,P,9,_ ,S.h¢~dgwn_displace-me_nt once_to oleo_n, pu_mE suc~ttions.,_ D. Id ?t bu~mp pru,.~. _ _ _ ! :-C.I,P. 0945 , _,, , _ _ ~ __ __-- ._ = _ ,. 0945- 1500 - C_lean eat. out o_f stack. Sta~ cl.e, aning pits. P,U. stac.,k a.n.d s?~lip,? wl 280,o00 .... ~. . 1 SOO - 240,0,-~Rou~h cut arid_lay _down_ landing Joint,~RIcj do~wn Ce_m?.nting_a, nd cs~, ?qujpment_. ..... N?~Ie down :~_0" .~.Q,_P, .,E. _Cleani_n~, ,cem_ent ¢r.o? troughs and pits, Hauling cement Conta. minated mud ....... _ ~ , _ . . , . .__ , . · , _ __ _ -. _. _ _ __1 ~.~ . _ 11 --. _ - , -- _ ~ . . = _ · , . .1 -- 1, . __ _ . , _ __1 _ = _ __ _ _ ~ .1 _ : _ _ _ . _ _ _ = _ J , ,. -- in _ _ , ._ ,~ __ . , _ , , . _ , ;~ ,. , _ ._ - ,t ,. __ _ _ __ ,. ..... . , TOTAL LENGTH 'EFF CC WEIGHT -- _ .__ .................... ~r,7 0,0 250 · ' ~ !EXPENDABLE SUPPLIES ON BOARD; 235 PREv TOTAL ,--~]~ W^ ,--E, -- '-- ~'rW^T~R 'j,A~iT~ - ICEMENT FUEL ' ~6T .... -, DAILYTOTAL _ __'- FUEL REC'D (GAL¢~ ' FUEi_-C;~i,..RUMPTiON iGAL8) MEN ABOARD"' TORQOE ' 4,533 53 cuu TOTAL -221 ~ West . . -~1 112 ml!e, .. Z~94 t~dan MORNING DRILLING REPO' OFFSHORE LJNF[L'~AsE AN'~'V~J'L NO."" ' "' ...................... ' .... ! IPRESENT OPERATION DEEPEST CA~ING · OD SHOE TEST. PPG tUNERS - OD TOP AND SHOE DEPTHS IREPAIR DOWNTIME DEPTH ' TOTAL PHOJECT~D DEPTH CONTR~'~CTOR AND RIG NO 4.~,BRIEF DESCRIPTION OF OPERATIONS ' NO IZ~ AND TYP~ · . 32t'iD:'; .. MUD PROF'F. R~E$. MATER~A~ .q AOL)L D AND COST$ I MUI~ MATERIALS AND QUANTITIES ADDED iN LAST 24 HOURS O ,,~z~.~ ,,-~.c~....,,,~,/~,,¢,#o. ,_.~'7~>-"".,~.,,,,-,-,~., Cf DOM DIb,%l [: ~J DIREC~TIONA[ ~URVLY$ vJ:.H I ICA,.L ..... ME.A.SUHED MUD CO5T5 TOTAL MEASUHb. L) IN.S IH, MN 11 ~2 ~4 EXPENDABLE" SUPPLIES ON BOARD' P/U $/O ROT TORQUE REPORTED BY ,.. 80'[ I'OM HOLE A,-':'JSFMfll Y (BHA) [~ NC) C..iAHGE (SEE PRIOR REPORT) [-1 Nr W nm ~A. TOOL OD. ID. F)FSCR PTK)N (~N ] (IN } ~;FF DC VVT, APPROVED AFF: PREV TOTAL C. UM lC)IAI F~'~i~i'VEO m LENG I H (FEET~ MORNING DRILLING REPORT-L, ,':SHORE' AHEP-2584 {BACKSIDE) L~C ~_-/~'5'~ ~E~' W'~EC'~'o. "- IA~ NQ, DAYS ]PRESENT OPERATION DEEPEST CA~[NG . OD SHO~ TE~T · PPG BRI~F DESCRIPTION OF OPERATtONS i FORMATION~ ILINERS - OD TOP AND SHOE DEPTH,~ iREPAIR DOWNTIME M 0 .¢.) -~- R.)T { , , . .......... !N -'~7/~NO CIHC MIN No7 PUMP NO ~ IUNII' NO 2 ' ] I'll'E Hfkl L, ANN V:) , . ¢PM -. ,., LIN 51'NI LIN SPM , ............. ~ I MUD PROPFRTF.'$. MA LfttALS.ADL)LDA. NL) COS[5 I I I ! I'ILIF, AiE MUD COST.q WT , PUN'L f.:AK ~ w ., ALK IITIIP · · ilM~ Vl'$ PV./YP GELS I'H CC/~OMtN L4'2NO$ S~O :.;f :i'lt )K 04i.L C:HLOHIOESF, i:M F)AH Y .... ...... i OIAL MUD MATERIALS AND ~UANTITtES ADDED IN ~ST 24 HOOR5 , DIt4EC i IONAL SLJHVEYS MF. ASLtRFD [)RIFT OII4. b[:. [, VI~ RTK':AI MFA%U~!ITO . '_¢ E~H i.!!~ P:.L ..... IN$'fRMNT ANGLE ~ON COOAf) NATFR D~PrH ] iN.~TRMNT DRIFT F~sPF¢.. f.;OOHDINAI E5 DEPTH Ui:j P'[ N {v~,.; A) ¥~- cJ'00N f3FPTi i A/q(',L F TI C., I'J fVKB) - · ' .. ..... OPERATIONS IN SEQUENCE I I ~.....r... ~z,~ ~,~.~~ ~ ] ~ e._~.~ ............ .... .., · ..,, . . . ~ ........... ..- , .... . . EXF'ENE)ABL, E SUPPLI£S ON ~"o~,/,~D" CE NT IF EL ~¢ DRLLLWATER '"[POT. WATER BARITE --J ME ~ U _' "' [ . / /~¢~ .... Io~/~ .. IWIN~- ~~ I~ ~ [MENABOARB IBATE~STBOPTEST P/U I~OTTOM HOt. E ASSFMBLY IBHA) ~8 r~ NO (:H/~N(,';E (SEE PRLOR REPORT) ._ EFF r3 (] :A/I COSTS AI't'HOVE ~ A. FE PI!i V, I OTAL ROT DAILY TOTAl T~Jt~O'UE (':~JM. TOTAL REPORTED BY REC~IVF, D ... MORNING DRILLING REPOR'~ AHEP-2684 (BACKSIDE) LINE :FSHORE ~I~-~ND WELL NO. ' .... ' ...... ""' iAFE NO. IDAYS PR ES E NT OPERATION l F(~RMATiON ..... I 0EEPEST CASING · OD SHOE TEST - PPG LINERS - OD TOP AN0 sHoE D~PTHS JREPAIR DOWNTIME 13 ~EF DESCRIPTION OI~'~'~ERA'tl6~5 'BEPTH I/DAT E I DRILLED TOTAL PROJECTED DEPTH CONTRACTOR AND RIG NO. -- ............. 4~ ~,..~ - /Q O. ,~o__~ /~- ;"~' H~'.,-,. . .2~_. .~-~ .;x7...<o...0 ....... BIT, WE IHT. ,':.';I"FE D AND I.~'.."DRAUL!CS RECORD I'££T I-' r ~ VV T IIOIJRl Mil /.t"./ J r)tli i CON[') I!()T ~t~. I H~; "J 5T,~ND ........ :~ j pl~,r.~ ... blLJl~ PROPLH~iES. MATERIALS I-'o I /'"¢ CIRC RATF GPM ., ,~o_,:,: J ::;AMI'L E WT I ,, t ,,..,..,,,, I z. 7 J MUD MATERIALS AND QUANTITIES ADDED IN LAET 24 HOURS I DIR~_C. ] IONAL .SURVEYS ....... MFA.~[jRFQ VF. RT CAi. M ~. A.'~.UR ED I L li',JSTRMHT C. OQRFJINATF.~ O ~i-'TH iNS I'~ N11q I L'~ HII- l FJ!~ F C. COOHDINATE5 DEPTH ("/K WI 5ECIIUN L)I-I'I M AtB;LE TION ...... ., ........... PUMP/'iCg 2 LIN J qPM OPERATIONS IN SEQUENCE ROTTOIVl 10. r--'] No CPq'¢.,lGE {SPF I"HIOH HbI"(')HI') I r NGrlt {FEET] EXPENDABL F ,'-.;I.~!PPL[ES ON BOARD CEMENT BRIg, WATER COT. WATER M"/V-'.~r~'~/~-~ ~ ¢.. ....... FUEL RECD.-GALS. J W,ND ~, I,~:,~.,'~,~ 'JMENABOARD JOATE~STBOPTEST =/U ROT TORQUE REPORTED BY ..... rrr F).. (: COSTS' APPROVED ArE I'HkV. TOTAL DAILY TOTAl. CUM. TOTAL RECEIVED BY MORNING DRILLING REPORT .~%FFSHORE ..... FX-~ ..... AHEP-2684 (BACKSIDE) E--e -,-~-/..-. ¢'¢' ., LINE LE'~,SE AND WELL NO. ' ..... iAFE NO. DAYS ' IOEPTH DRILLED" ~PRESENT OPERATION ..- .... ][~=OR M ATIONG~ ~,.. C ¢_...~ y..~ ,¢'-o,~ ~,,, .... /¥OTAL PR OJE~TED DEPTH IDEEPICST CASING- OD SHOE TEST- PPG ]LINERS -'OD TOP' AND SHOE DEPTNS IREPAIR DOWNTIME I /z' - ,-/. ,r ,.--_,- t . -- . I " I BRIEF DESCRIPTION OF OPERATIONS 'Bll:. WE C;HT..".';I:'LLD At, ID HYDRAUUCS ~tl.:CO!iD OUT ~'I' I I 1... MUD PROPLHTIES. N1ATFR'~AI'.S AUOED AND CF STS TIMC W I. ] ! MUD COL;TS SAMPLE . I F' N" FILTF]ATF .... ~ % , % CI!LORIF)F!.'-, Al.h: IIT[IP i -" , ,~",, ~ PV/YP ~]F .S ~H CC,' 30 -~;.~' '~¥ MUD MATERIALS AND QMANTITIES AODED IN ~ST 24 CI';iFF &N G L L' HOURS Oi:'E~ATJONS IN .~LL]ULNC. L I _PP,2 .~ 9",¢, _~ pn~"..P'--'.~ ...... I I I I. ¢0 /~ ¢ /~/- . ............. ~ ~ /~ ~,~ ~ ~ ~~., ~/~..~: /,~../~ '~ ................ ~. ~ ~/~ ..................... ......................... ........................................................................... ........... ...................... ....... COSTS' P/U ...... . ................. ................................ EXPENDAB! F M.JPPLIES ON BOARD: 'DRILL WATER POT. WATER BARITE CE~'~'N'-~--- - 1FUEL ~--~""~ FUEL REC'D.-GAL$. M.g-V ~~ ]DATE-- I ~--~ ~~ I ................. ~ _ I~ IM[N A~OA~' IDNT~'~?'g6~ ?[ST .... r~ ..... I,. ~.~z..~... J. ~-~ ..i...~r~.:7~ ROT TOROUE iREPORTED BY ._. CuM. TOTAL IRECEIVED BY .,, DAIL ¢ TOTAl. FIOTTOM I IOLL ASSEMBLY I'II I')(l Vv'l AF'I'ROVEO AFE I'HbV. TOTAL __ MORNING DRILLING REPORT- 0__F~FSHORE Il°A'r~ .... ~,~.-~4 I~,~CKS,D~ ' " .... tl .2....2.2.5'2Z .... , UNE LEASE AN'b WELL NO. -' ...."~=' .... iAF~ NO. ~ ~DEPTH ~ DRILLED IPRESENT OPERATION FORMATION ¢~ ~ TOTAL PROJEUTED DEPTH DEEPEST CASING · OD SHOE TEST - PPG LINERS - OD TOP AND SHOE DEPTHS REPAIR DOWNTIME CONTRACTOR AND RIG ] BRI~ 0ESCRIPTION OF OP~RATION~ ..... ; .. .... ~ ~~.....~ /_3 ~. ~.~ ~~ ~.~ ~ MD lb ,, ~IT. WFIGHT..".qP6 El.) ~.ND I-IYDHAULICS RECORD ~',/i L'b~,, J.. "HS' 'IFF J I,ATF ... I ,,_L [ .'-.PMt ~[~lJ,,,~,,I;!, ~.E ~ r,,,Lu ...... I ,---r-:~.-~-] r, nr.~s c,m¢ j ~u~,~ I ~,~,~. ~ ~.,N .......... ' .............. ..... i ..... 4UD F'ROPERTIb-..S. MATLrilALS .aDDED AND COSTS MUD MATERIALS AND QUANTITIES ADDED IN ~ST 24 HOURS ~ t 1 ' " I ' 1 ...... '- DIRECTIONAL SURVEYS M Et\51_[HE L1 [ I¢4S'rRMN I. DRIFT IHOURS J OPLRA'r~ONS ~N SEOUENCF EXPENDABLE S[..IpPI.IE2 ON BOARD ... -- FUEL REC'D.-GALS. j.,M.,'V,t=.~'.,lfw,~,' ~,"',~ ~ ~'~-~,~__,. ROT TORQUE BOTTOM HOLE ASSEMBLY (BHA) , 16,~ NO CHANCE (SEE PRIOR REPORT) r~ flew i.'.() i I 7 TOOL OESCRIPTION RECEIVED BY EFF 0 C. wr -. Al 'I'HC)VI' L3 AFE .... PF', EV 'l () f AL DAILY '[OTAL CUM 1' O'fAt, REPORTED 8Y I OD ID. LENGTH (IN I (lhl) (rEEl) AH~_P-2684 (SACK~IDE) LF_A~,ND WE ll NO.'-" ' ~ ..... tAFE NO. DAYS" IDEPTH IDRILLED PRESENT OPERATION ...... FDI~,~ATi~N ~,¢,¢, _ /f'~TOTAL PRO~C~ED DEPTH - DE~PESTCASING-ODSHO~TEST-PPG ILI~ERS'OD~AND SHOE DEPTHS IREPAIR DOwNTIME CONTRACTOR AND RIG NO'I ~ BRIEF DESCRIPTION OF OPERATIONS Mr. BlT 'WEIGWI. SF'FFD AND HYDI~AIJI IC:S RECOI?D MUD PROPCHT[[S. MATE RIALS AL)O~D AND COS1S I MUD MAfEA~ALS AND QUAN¥fflE~"ADDED IN ~Sf'~4 HOURS ...... lO .... DIRECIIONAL SURVEYS MEASUR.rD ,-,'~, ,--,' ....... I L_.~_ .*:'..b. ~TtOA'L { ,'¢.~ ^$,.,P, .F r'.~ NS"RMNT ~'[?A',~ u2.n.~? ¢.O(]flE,!N.,",,IE$ i C~FPTH r- .... i'15 HMNT .,,! "l .... I :'-'__..I.-----:-'-7 ...... ' D[IlI' 1 J DIHbC. Ai',it'H [' l~Jf,l COORDINATES ,, VF RTIC/'~L L, P/U -~,"O EXPENDABLE SUPPLIES ()N BOARD: "JDRILL WATER [POT. WATER IBARITE ~CEMENT '~UEL ~;.¢..,~,.=,,¢, RO-~'f~ t t /FUEL REC'D.-GAL~. IM/v/'~,-.,~.-",~.,..--"~, lB, c,z-~ ."~-'".,,,-..,~,~ TORQUE 1;0'd ;BEE 6qcj &06 £ ~tUIS N SS~H/~3I.,IU BOTTOM I lOI F AS.SEMBL'Y IUHA) · I(L'~ NO CI IAN(';E ISEE PRtOi"{ t'.tFf"ORT) F-] NEW BHA · Hr.)l HRS. £,INCE 1N.ql'. TOOL DESCRIPTi()N E'F~ I] C WT A. PPIt()VED AFL __ Piti V TOIAJ DAli Y "fOTAI C JM TOTAl RECEIVED BY :S0 OD. ~D LENGTH (iN.) 0N.) (rcrl) MORNING DRILLING REPORT- mEFSHORE AHffP-2884 IBACKSIDE) ' L'~-~ASE__ AN~ V{/~LL NO. ' ......... ~AFE ~.' .... I OA S DEEP~ST CASING- OD SHOE TE$T- PPG ' [LINERS T~~N~H~T~~EPAiR DQWNTIM~ BRI~ DESCRIPTION OF OPERATIONS ' 4 ,. l0 Bll. W~IEHT..?,F'LLD AND HYDRAULICS HECORD DUL[ 8 T H -, r-,. HAib F'R F.~ ~T~ ljl"M ¸ . !DEPTH ~'",%. T~TAL PROJECT'ED DEPTH '" CONTRACTOR AND RIG NO. MUD PROPERTIES. MAFERIALS ADDFF) ANL) ........... MiN MUD MATERIALS AND QUANTITIES ADDED IN LAST 24 HOURS DRIFT Ah'Gl F fx) r4 t:OORF}INATE$ h',~.':'; T R ;vhN T DEPTH 15 OPERATIONS iN SEQLJENCE - FUEL t/3'~ [XAI;E ;~ DATE L,.AST BOP TEST P/U '~/0' ROT I-V.')TTOM 19,:)1 I. A:.;SLMDLY (BI-iA) I$ ["x'l NO CHANGE tSEE PRIOR REPOR'FI l..J NEWBH~-- ROT HRS. S~r,l'2E if,tSP. REPORTED SY TORQUE CUM TOTAL I'REV. TOTAL ................ DAILY TOTAl. E F F O C. W T CO.E, TS -- APPROVED AFE 7 TOC)L OD ID. MORNING DRILLING REPOR] - .FSHORE i~d^~ ......... [PRESENT OPERATION .... IFDRMAT~O~jm~ ITOTAL PROJEClfiD DEPTH ..... ~BRIEF D6SCRIPTION OF OPERATIONS ~~ ~, c~ ~m .... /~,~...~:.~5~~ ~ /~.o~ ..... G~m~,~ NQT?i FR 3~NDS BI1. v.,/LIGI41. SPEED AND HYDRAULICS RECORD J JF RiI t;l.,".J,,l[) t ll(~. ~i~N, NE)/ I"tJMPh,I(') 1 i H0'UH R I." M :~ -..~j I'll', H~.II ,~','.' J V[L J L'"'"' '""' -"-"-t MUD PROP~-RTIES. MA'IER~ALS ADDED AND COSTF; 1 O HOURS ~ , -- . ~,~. 'H CC/30 ~ .~... ~., . · .,, ClitORIC)ES ALK liTIIP ' MUD MATERIALS AND QUANTITIES ADD~B IN ~$T 24 HOURS DIRECTIONAl. SURVEYS DIREC. CO ~HDJNAII:5 ~ VL H11'C-/(L .... MI A.SURFD :..= i MEASUHI" U J INSTHMN[ DRIFT DEPTH ANGI F Cf_)ONDINAI ES L~OI"IOM HOLE ASSEMBLY (BHA) P/U J EXPENDABLE SUPPLIES ON BOARD' J¢EMENT FUEL ~ILL WATER I POT. WATER JBARJTE ... , -~~¢~ - ~ ~ J, - ¢~ .... J ~ .... ~ -/~- z¢ ...... T~3 '8 S/O ROT TORQUE REPORTED ~y ~6£U 6S9 L, OG £ ;:'"JU..LS'N SS3H/,~BI.,.IU lb '~ i'4L)CHANC, L (5/-E PHIOH HLI'OHII ~] NEW 8HA - ROT [t1.~$ SINCe. INSP I t lOOt OD iD LENGTH Ut- SCHII'ilON ~IN I fin ) ...... . EFF D C WT COSTS AI')'I~OV[ O AFE __ PHEV 'l('JlA[ J)~ll 'f I'OTAL CUM I¢)IAL ,- '...~ ..... J tRECEIVED Gq: GO MORNING DRILLING REPORT- OFF.~H_ORE .,-~.. ~D^TE AHE__P. - 26{]4 IBACKSlDE) . 2J2§/94 I S~te Tm~ 39~01 No~ Star~3 ~ 93M40 I 27 } 7,414 7,175 639 P~SENT OPE~T~O~5 '~ndst~ and ~nd 45~ sil~t6ne 40%' FORMATION ' TOTAL PR~ECTGD O~PTH 2 P.~.H. f~r bit ~ange, , ,, c[aystone 13% ~n~lomomta 2% 8,452 ~D 0,818 MD LINERS - OD TO~ AND SHOE DEPTH~ RE~XIR ~[ ' CONT~CTOR AND 'RiO NO. '" ~ 133/8" 3920' FIT 11,6 0 Pa~er ~141 BRIEF DEgCRIPTION OF OPERATIONS .... 4 000~./0600 , P.O.H. Chan~e out ~otor and blt. ~uage all stabilizers and odent meier. Drop. lead ~llar. Down I~d M.W.D, Pr~parlqg to ~p in . holm ,, ,,, ~. , , ..... ,, . , ., BIT, WEIGHT, SPEED, AND HYDRAULICS · , BIT SIZE ~ir--'~lAL N,O.Z. ZLI[ $ DEPTH FEET HOURS PTI' 8IT ,ROT DULL C.gNO. STANO C;IRC ,~N~ NOZ LIN '~PM LIN SP[',~ ~ TY~=E 1 2 3 4 OUT . .HR ,,,z~rr. RPM 8th~- V-=L VE _L._. 5 6 12.~5 MFDSHCL 12 12 12 10 7,414 1,025 19.8 52 20 100 3 3 /-%t 2,500 27 147 6" 63 6" 63 ...... ,, . 6 LC010@ I . . . , , ~./,,,~,_~,,~'4;.4. " MUD PROPERTIES MATERIALS ADDED AND COSTS MUD ' ',~UN'L PV" YP GELS PH FILT. ~,AKE %' % MBT CHLORIDES PF MF HTHP MUDCO8~'S WT. ,, ViS. ,iC¢~3° 32n~ls SAND 8OL~$ pP... ~ P' PAILY TOr~ 99+ 47 11 19 8 18 8,0 .. 7.2 1.0 0,~5 9.0 12.0 2,209_ O.0 0,6: 5,61~ 85,117 ,, , DIRECTIONAL SURVEYS MC=A'SuRED J DRIFT DIR[[O COORDINAYE$ DEPTH V M E.A~IRI~ O DRIFT DI~G COORDINATES DEPTH V DEPTH 'ii ANGLE TION V .K..8. SC=CTDEPTH A.?GL[ TION ....... VKB SIZCT · . ,%., =,, ,, HRS- .... bPERATiONS IN SEQUENCE r , E~OT~oM HOI~'E ASSEMBLY ' 0001/0200 h~: Motor drill from 6775 to 6073. 16 NO CHANGE (0~ PRIOR REPORT) 0200t~0 bm: C,B,U, ~863 220 m~. gas units, , ......... 0330~2030 hrs: Motor drill, and su~ey from 6873 to 7414. , ,, __ ,.. 203012200 ~s: Su~ey and C,B,U for bit bipr ......... ROT' HR5 51NCR [NSPEC. ., 220012400 hrs: P.O,H, Tight ~00- 6250. ' TOOL DESCRIPTION OD ID LNGT . -- _'] Note: 8u~eY0rs su~eytng a~..s~king 100 ff. stations for u~mlng V.S.P. .. ...... . ~ ~~ ~ ~_~ .......... ...... ., ...... ..~ ....... ...... ,...- ...,, ...... ...... EFF DC WEIGHT , r """' .... ,, ~, . . ~P~NDABLE SUPPLIES ON BOARD; 195K 'REV, TOTAL .. FULL R~C'O [G~L$) FUEL CONSU,MPTION ('GALS) MEN A~ARO T()R'~ij~ ........ I 4,8~ 52 5-6000 GUM TOTAl. NO DRILLING REPORT -OFF. ~smte Tree 39-0~ No~h Star ~ Motor ddt~ 12 ~14 hca 7060 - 7660. 13 3/8" 3920' FtT 11.6 001/0600 Motor drill 12 1/4 hole from 7660 - 7780. AHER/HESS N, STAR ~.~-%. -_ NO. DAYS 26 907 659 ~391 P.O1 Congolomerate 2% Claystone 18% WNTIM6 iL ~Oe O~.~THS 0 -- 'FVD 7.760 7,394 ~6PTH FVD 8,8' NO, #141 2/271~ _ BIT WEIGHT, S~ 'EED, AND HYDRAULICS .............. _ 8 . ~ ~ DIRECTIONAL SURVEYS MP_.AE, UR~ D E~RiFT DIREC COORDINATE8 O~PT)t V NIEASUR¢~ DRIFT OI~EC O00~OI~T~S DEPTH V DEPTH ANGL~ TION VKa S~ DEPTH ANG~ lION _.. .., VKB SEc'r 14 ...... ,,, ..... Hp, S. OPERATIONS IN SEQUENCE ..... BOl-r'OM HOLE. ASSEMBLY_. 0001t0§00 P.O.H. La~ down motor and lead collar. P,U. new bit an,d,.,m,,o!o,,r. Orient motor. Down load M,W, 16 ~(8~ PRIOR R~PORT) 0600/0g00 R.I.H Test M.W.D. and motor. 0900t1030 Slip and cut ddllin~ line, , ....... NEW BHA 1030/1230 R.I.H. Ream down last Joint for M.W.D. Io¢. ~Of. MRS S~NC~ ~NSPEC. 1'7'" ~. 1230/2400 Motor drill and surve)/from 7414 to 7760. .. 'fOOl. b~$¢l~lr, l'lON OD ID LN~T . .. Noto: Surv~or~ completed stakln~1100' stati.o, no for UPcoming V,$.P, , ....... ~,. IOTA[ L~NGTH 230K APPROVED ~E ~,. EXPENDABLE SUPPLIES ON BOARD: 195K PREV. TOTAL 'DEILLWAT-SR POT WATER [BARITE ICEMENT I~UEL ROT 20§K DAILYTOTAL c,. FUEL R~C'D {~A.L$} FUEL ~ON,zUMPT1ON (GAL5} MEN ABOARD TORQUE ~¢ S,458 52. 5-8000 CUM TOTAl, TEMPIF) IN'NU(M"H/O'R, --" IWI~CHILL(F) v,~,a,F.,~{M,, DATELASTBOPTEST REPORTEPBY -34 IWSK 6 mi. , 2/,J,,9/94. Bdan Rose MORNING DRILLING REPORT AHEP-Z684 {BACKSIDE) LI'~E ....... "S H O R E ''- [~"~',~,TE " ~'~',SE AND WELL N~':" '" " IAFE NO. ~DAYS iDEPTH'' IDRILLED PRESENT OPERATION "~ ~~FORMATI'~ ~g ~TOTAL PROJEgT~D DEPTH '/~/~* ~¢~ - '~~' ~CONTRACT~ AND RIG NO~ DEEPEST CASING - OD SHO~ ~; PPG TOP AND SHOE DEPTHS REPAIR DOWNTIME BRIEF DESCRIPTION OF OPERATIONS BiT NO ? RIT. WLIG.H r. SPEED AND HY[)t'IAULICS RECORD · ~,,;L ~<, I ?'..' ~4'~, ::-;s t l~' ' ~" I 1~''~'-~:o~'~' I ~:~'~' I ..... ' .... . .l .... l MUD PROPEF{;18S. MATERIAt ~ AD[)~D AND COSTS SAMPI ff FV/hP EL~ H CC/30 ~'~ ~ TIMr ~l' ~(S. -- i ~.~'f"~ I'~1 ~ I~ ....... MuB MA~EAIAL~ AND QUANTITIES ADDED IN ~ST 24 H~URS i PUMP h,'O 1 ~'UMI'N(2 2 LIN I .~PM I IN .~ I ITl IP I MUD t DALLY I0 IAL .. ., , tO * ~, cfi,,. ~ .... DIRECTIONAl SURVLYS I I I VLHIICAL ' I M L,6,%Ui~F D MEASI. IHED ~RIFT OlHir. F ¢........ IN:.;'TI~MNr ~.1(' e · ¢¥,.,T ¢.OORDINATF.-, ~H [~ INSTnMNT 18. H©L.JRS OPEl. IAI IONS IN SEUUENCE ..... I:'"EXPENDABLE SUPPLIES ON BOARD J DRILL WATEFI "JPOT. WATER J BARITE ~EMENT IFU:~I- I FUEL REO'D.-BALS I M/V is" "~'""'7"7 I1~, T::m,'- · .. Lt_,"<r---e-- ~¢--¢.¢',¢,c UOll'I'C)M I IOLL ASSEMBLY (BHA) ] fj.'~] NO CHANf.'i~ I~;kl- I'HI()H ltl PC)FIT) U NPW H[IA. H(}I IIt]:.:, :.;INC£ INSP 1 7 I (.)C')l DESCRIPTIOI'I E F F D C VuT COSTS: P/U ........ S/O~---~-~ .... ~]:J ?_OZ~Z ;iF E. .~/'Ox ¢2e2'~ /DAILY I'O'rAL I TO~U[ IEUM ~OIAI. REPORTED BY IRECEIVED 8', .__~~~~. ... OD ~D LENGTN dN.) (IN.) (FEET) ~_-~MORNING DRILLING REPOR'~ FFSHORE [~ .... AHEP-2684, (SACK$1DE) · ' ( D~L~O ~ ~~~1 ~ ~TION ITOTAL PROJE~TED DEPTH -- -- -- oilieST C~S~N~ O0~O'~[S~~~s .... 0~~. 5~~~~-- I ~~ Tvo ~¢~ ~ SIZ[ 8lT. WEK~I.tT. SPEED AND HYORAt)LI(.:S RECORD I' I i-~'cT ' ~,r I O,.,CL '..'.,~,'~0 i' ~T I'~'~,l ,,ca ~ROT ~THg '- J 5TA~U At,IN PPM PUMP NO 2 MUDf-'ROPEItTIES MATERIALS AF)DED AND .... $AMPLF PUNt' ' ,., ,~ ", ' , FI[.'THArF i. "I "' .i ' ~,,. .... -- ' EXPENDABLE SUPPLIFS ON BOARO' J ' BI, ILL WATER 'JPOT, WATER (8ARIrF ICEMENT I ...... t ..... J FUEL RE~'D.-GALS. JM/V _J. ~.. ~ coorlDINA'[ ~:5 ~ ~VFRTICAL BOTTOM I'IOLE ^..-,I::MOLY (8HAI ]0 '~ NOCHAN(;r' (SEE PRIOI'{ ~ NEW BH&. I(.]T HRS. Sff~CE INSP. 1 7. TOOL OD ID. Lr NGT~ DESEHIPrc}t,I dN) (IN) ~FEEI') _ , BY P/U C. OSTS' ..-2;r,/¢ ¢',¢,..~..__ ~P~ROvED AFl. 's/~i ........ ."~'~'~.' ~'~,"~ . __ PREV. TOTAL aOT · ,'~/,,,~_.¢__~,d' F.~AIt. Y TCITAL .o~ TOROUE REPORTED BY (RECEIVED irt C:C V,/T. MORNING DRILLING REPORT- FSHORE AHEP-2684 {BACKSJD~) LT~"~ LEASE'ANb WELL'Nb.' ..... ' ......... iAF. E-~-~)' ,,, iOAy$ . BRIEF DESCRIPTION OF OPERATIONS ' ' ult. WF~GH r. SPEED AN~) IIYDRALJLIC:~ F~LC )RD ' AND L 32NBS J ¢' T F~'i *~i' H'H WT ..;" J ~!TI.IR . -- _ PflFSS 2I'M ~M FPS .... MUD PROPERT ES. MAI LRIALS AOI')F r_) Al,ID COST,-':';, lIME... .. . [~1~- . . ~2NiJR ~ 5AND %OIID~.. 011 p.'M ALK HTHP .. MUD MA'rEmALS AND QUA~TrfiE$' ADDED IN ~S~ ~4 HOURS ......... ' -' ' DEPTH ] DRILLI~'D TOTAL PROJECTED DEPTH-- CONTRACTOR AND RIG NO. PLJMP N() 1 J I'L.IMP i',IC) 2 Mur> Cf.)515 DAH. 'F TO'~ AL BOTTOM HOLE A.SSEMULY (BHA) EFF DC \,',JT HC')I Itll!; SINCE INSP 'f ('~(]L DESCRIPTION COSTS. P/U .......... ~, ~ I'H~V. TOTAL ~~ ~) ~II.Y TOTAL TORQUE ~~ ~ ~ CUM TOTAL REPORTED BY ~[ ~-[~E D' OD. tlN I ID LENGTH (IN) IrEETi IDEEpesT CAS]N~I ' ~ ~HOE ~T ' ~G {LiNERs' OD TOP AND SF:O~ DEPTNs ]R~AIR OOWNTIME'[CONT~ACTO~ AND RIG NO. BIT. WEIGHT. SPEED AND HYDRAULICS ~ECORD OUT FCFT fIIIH~; p~ I WT ROI ~[ll~ PiP~ I ~¢ [ Ar . N0771. E S 32ND5 MU'¢J PilOPERTIILS. MATe RIALS AD~(~D AND CO$IS ~ ' I I I I ~'![ T~AI,[· I l JMUD MATERIALS AND QUANTITIES ADDEO IN ~ST 24 HOURS' :: 8~.. ~... t ;' , ....' .P NO. 1 I PUMP NO 2. 1,__ k VF qTI(.:AL ~ / OPERATIONS IN SEQUENCI~ [ 130110M HOI il:{. ASSEMBLY (BHA) ..... I10~ ~S. SINE[ IN.;P ...... OESCRII~ flON fin ) fiN.} '~'~Ii~L'R EC'B. · GA LB. [M/V DATE WIND }'"/'T'.~.,~,~ i~--,' ~.M-EN ABOARD' DATE LAST BOP TEST ... '-- ~:FF D C. V',/I "().'-; P/U...... I I S/OZ'~ - AI-'PF40'/E D AFE ROT ~:}~:;~ '" PREV. TOTAL ,., 1TO~OU~ I ~~ ~/lb~. CUM. TOTAL MORNING DRILLING REPOR'~ -"~L~-t~SHORE _ .............. '",:~,,. ~;~ AhD WELL NO.' -' "' .... 1' =' ' ............ ~'h'O -' ~~ -~" ' -' PRESENT OPERATION ................ ~0R~ATION ' ~TOTA~ PROJE .TED DEPTH --~~ 'BiNER= - od TOP AND SHOE OEPTH~ IREPAIR DOWNTIME Ib-b~cTon AND RIG NO. ~~~~ b-bE~t'~'b~S ~,, ......... TYP~ · HIl', V',/LIGI t f, :.4~-'EED AND HYDRAULICS RFCORO ~'./CIZZ L f7 ~ 3 2 N D S DEPTH OUr ......... .... MUD I-'I-iUPERTIE$. MATERIALS ADI'JFD AFIF) Cos'rs , , .LE "/fT. I-I. ~.,l L PV/YP GI~Lfi P T~M~ VI:5 '~,'1~ .')2ND~ ,Al.,1 t; ~ll'):, O I ' 'F-'F.'M MUD MATERIALS ANO QUANTITIES AODED IN LAST 24 IA,.~c Irrl ir, [ ........... M-?R ¢ C~$T~ , ", ............ ...... . ..... ._.'__ . ~/.'~ P/U ' ~/0 ' ' EXPENDABLE SUPPLIES ON ROARD: D~,LL WATER I POT WAT,. ).ARITE ~EM'NT FUEL nOT rtl l'., c wi /,PPROVED AFE PI{I-.V. TOTA, ., D~L'Y TOTAl CUM. TOTAL ~/~ ~--3~ 0."~..~,-.-~'~,EPO'I;ci:E{~GY "' ]RECEIVED BY ?Jf OPERATIONS IN SEQUENCE BO IIOM I.IOLL &SSEMBL¥ (BHA) ,, ~ .... ....', . ,, 16 ~ NC) CI-IAh,IGEISEEPf~IORt4EPORT) ................ J t I' ~ ~ ~ · ' l.) b SC HII"'I'ION liN.) (IN.I (FEET) MORNING DRILLING REPORT- OFFSHORE AHEP-2684 (BAC. KSIDE1 -~--'.. LJ~jLEASE AND WELL NO, - .... ~ ' , -J~ JArl[ NO. '"-"~'.~'~ .... JPRES~NT OPERATION , ' .... JFORMATION ......... TOTAL PROJECTED DEPTH DEEPEST CASING - OD '~HOE TE~T · PPG J L NER~['-~P AND SHO~ ' I~EPAIR DOWNTIME CONTRACTOR AND RIG NO, JBRIEF DESCRIPTION O~ 0~E~'~iO~$ ,,j P.o, ~. . .......... ~ ............... , ....... .. L~ WEIGHT. SPEED AND HYDAAULICS ......... . .~ MUD PROPERTIFS. MATCRrALS ADDED At,JD COSTS .... .... ~ ....... ~ ....... J OA,LY TOTAL MUD MATERIALS AND QUANTITIES ADDED IN ~ST 2~ HOUR~ ' 'i.~W~Ec'r~ONAL S JqVE",'S MEA.SU~E g DRIC'T OIR~.,'~;. J VERTICAL M£.t,,.~L]R F D - --DF~Tll ] __ _ I INSTnMNT I,"ISTF~MN I ANGI F TION j UOOHDIt,IAI ~-~;.. ) 11 l ; ....... /I 12 ........... 13 .............. · L.~ ......... l . HOI.JR$l OPERATIONS IN SEQUENCE ,, ,II ' ,, 1 ~,~t.~] ~t~ P~r ~ /~m...-4.F~$r~' .. EF¢ D C WT EXF'ENDAet F St.;PFUES ON BOARD: J,oT ~.. .!D'rAL ~ ................. I . I 18~%...L. ~ ...... t~~ ~ ...... COORI3 NATES BOTTOM HOLE ASSFMRLY CBHA) If.-", U,J NO CNANGE (SEE PRIOR REPORT} UJ t,l[W BNA - ROT HR$ SIr. ICE INSP. / TOOL OD. ID. LENGTH Dr..'-.;(.:fllPtlc)r,I (IN) liN) [PPI-I) t. cEWEO BY · ' DEEPEST bA~ING - OD SHOE TEST - PPG illNESS: ~~ND ~HOE DEPTHS 8EPAIg DOWNTIME JCONTaACTO~ AND ~IG NO. 4 SE,q~AL NO AND [YPb .-- NO ~lfr _5 7 NOZZLE .% J ..t.:/1" BIr. WFIGHT. SPLED AND HYDRAULICS RECORD Ol. JII CONE) I r'rAN ~'l H~: '~- r ._ 5 J ~"~ MUD PR(.')PEFt IIES. MATFRtALS ADDED AND CO~T$ -'=-'-' ' WI' ".Ccc PV/YF' O.CL$ ] I'H CC/.'~() t'AKFr' ¢, %. . "... ,& ,,,,~ ........ ,,... . J..?~ .... .,,,.,o., ...,,~..?.,..,.., o,, MUD M~J~$ AN~ QUANTITI'ES ADO~'b IN ~$T 24 HOURS ..... ~ D ,, J MFAStIRFr'J IN.~TRMNT OFPTH 11 C'IHC MiN ~AI [- ANN UI'M i FpM. P. M w ,N 0 2 .L.l. t4-' r:; ~'M~ MUD COS 13 0ALLY TOTAL ,, j DiRFC D~IF I' J TION ANGLE / L'.¢.)O H L)h"l A [ I::S .. C)EPTH IVKSI C]IRECTIONAL SURVLY.5 C OUH D1N,'k rE 5 VEF. iff;AL' '4 P/KB) ..... JP./U I EXPENDABLE SUPPLIES ON BOARD' DR LLWATER JPOT WATER BARITE /CEMENT /fUEL I I ............. I ........ .J ............ I ........ I IFUEL REC'D.-GALS. IM/V /DATE J .... 1 .~.,~_.,_..~,,,~ ........ / ............... tWtND I~-F- ....... I-aEN AIBOARD IDATI~ I_~ST BOP TEST JS/O ROT '1' '¢ l'OOL DESCRIPTION z.~.. (a~. ~) ..... ,'qo~. d"-'b 2-4, ' FFF FJ C. VVT l.'. O.c., T ?, APPROVED ArE PREV TOTAl IDAJl Y I () I A~ TOROUE CUM, TOTAL fl'~'' b ~' ~/~''-'EPO~TED2' /'~' Ry l RECEIVEO B OD ID LENGTH (11,1) lin ) 04 ¢.~. .... .. ~ .,._ MORNING DRILLING REPORT ' OFFSR,..,E ~TE AHEP- 26~.4 IBAC, K$1DE1 ...... 3../7/94 'i I LEA~E AND WELL N[~. IAFE NO, A¥S MD YVD DRILLED I __1 State Tr~c¢.39-0t North 8_~r #-,3 ,., I 93M4° _ 37 .9,001 _ .8,~627 0 PRESENT OPERA¥1ON8 FORMATION TOTAl, ~ROJECTF_.D ,r2.P.U. BHA. 8,452 TVD ,,.8~818 MD I LI~I~R~ - O0 T(~P AND ~HOE DEP-I'H~ ~EPAIR EX.)wNT~ME o~NTRACTOR AND RIG NO, 3 ...9_,S~,8 9,001 ............ 0-0-2 1/2 Perker #141 , BRIEF DC..SCRIPTION OF OPERATiONa ..... 4 P,O.B. , , , _ . PARKER-25 EPOC,H-6 ................... C.C.I.-6 AHC-3 .. ,, ..... , FAIRWEATHER-1 AIC-6 ,,,, ,,, .... B,H ~IT, WEIGHT, SPEED, AND HYDRAULICS BIT aiZE ~ERIAL NOZZLES DEPTH FEET HOLJRt~ F'r/ BIT ROT DULL CC)ND, .SfAND C~RC ANN NO~, LIN ~-PM LIN 5 7 MUD PROPER MATERIALS Al :::)ED AND GO~T; 8 8 ~lih ~¢JI'L~¥ "j'J~'-- G~L~ PI"I ~ILT C, AF..~_. ~' % MBT CHLORIDES PF 'MF I'~HP .... MUO CO.~'rs w-r, vis. , cc~,,0 32nd~ BAN~ 8OLID~ ~, ~AIL",",:' ' TOT. LL 10.1 44 15 11 3 6 6,5 5.0 2.0 ,0.50 10.0 1~,5 1,900 TR 1.0 10.0 3.,2_09 ...... j, DIRECTIONAL SURVEYS M.~,,,SURED ~RIFT DIREr' ¢OOR01NATE$ DEPTH '] V ,MF~,S,UREB DRIFT DiEEC COOEDINA~E8 OE~H "V ~fiPTH AN~ TION . . VKB ~CT OEPTH I. ~NGLE TION V~ 8~CT 1t .... , . i , ,, ,,,, , ,,, ., HRS 3 . ' oPERATIbN$ IN sEQUENCE ...... ' BOTT. OM HOLE ASSI~'MBLY ,,, "' 3.~ FINISH RUNNING CBT, CET. 16 NO CHANGE ((;RE PRIOR REPORT) ,20.5 R\~.& RU ~SP & PER~FRO~T STUDY. ,. PROJECTED DRILL OUT BHA. _ ROT. HRB i7 TOQL DESCRIPTION OD ID LN~T , ,, ,, , , BIT i ,, ,, . , , .. NBSTAB 3,82 __ ~ ,= mm, PC 9.01 ~ . ..~ . , ,-, , mm, ..... "' MSTAB 4.46 ~., , ,,, ,, MWD 53.46 m . , ,,,, m ,= - MSTB 5.3O , m m m ,m MDC 29,90 ,. . MSTB 4.68 ,, , m,m , MDC 2~.58 , ,, , ,, 5DC 149.3t ,, , ,m, ,, , m '" .. , XO ......... 6HWDP _ , = JARS & 26HW ._ ~OT~ 289,5~ ., EFF ~ WEIGHT APPRO~D AFE ' SO' ~P~NDABLE SUPPLIES ON BOARD: PR~.I TOTAL , 1,732 .... 49818 GALS ,, DAILY TOTAL FuEL REC'~ {GA~) F0~L CONSUMPTION (GALS) MEN ABOARD TORQUE rm~ I~Nu (h~m~i) IW,,O CH,LL (F) 'J~ma,u'r~ (M~) ~TE ~af ~P TEBT REPORTED aY . -3~ ISw~ ~?H.J ~ ,'1 ~O .. 3~5~ . .y~C SAUC~F~ .-- MORNING DRILLING REPORT - OFFSHORE 1 b"-l~te Tracf .~-01 North St~r ¢¢3 . J g3,M40 38 g,001 8,627 0 -- '" '" " ' .FORMATION TOTAL PROJECTED DEI~H P R ¢-_~EN~ OPERATIONS 2 DRILLING @ 9057. , SHALE 8,452 TVD 8,818 MID ' ' ' OD TOP AND ~HQE ~EPTH8 REPAIR DOWNTIME CONTR~CTDR AND RIG NO. 3 g;~\8 9,..001 13PPG , ., , , , 0-.0-2 11~.. Parke¢#141 ~;' BRIEF D~SCRI~'TION OF 4 P.O,I~. · , ' ' PARKER-25 EPOCH-6 ....... L. Ill C,C.._!,-6 .... AHC-3 ,, , '- FAIRWEATHER-1 AtC-6 ,. , .... -- ,, BHI-7 ". ~ .............. ,L. ..... % ....... SERIAL NO77. Lr--E TYPE KX9670 BIT, WI[IGHT, SPEED, AND HYDRAULICS DULL ODNO. I~th~ CHLORIDES MUD COSTS _ pp ' ' TOT ,AJ.. _. __ NEW DRILL-l, PAC-L 4, 8APP-2, DESCO-5, SOLTEX-10,BICARB-3, BIOLOSS-3, E, AR-357. 138,956 DIRECTIONAL SURVEYS M F,A,~U R F..D O.W.l#l' O!REC ..... COORDIN,~TE~ DEPTH V M~URED DRl~ OIREC C~RDi~TES DEPTH V DEPTH ~4GLE .. ~QN ~ 0~T OEPTH ANOLE TION ~ SECT " HRS 3 OPERATIONS iN SEQUENCE BOTT,OM HOLE ASSEMBLY _ 1,0 FINISH RUNNING PERMAF,,P, OST STUDY.PJD SCHLUMBEREER. , , 16 No C~.Ner= (SEE ~OR RE~'ORT', ,, _'!.5 GET,, ,WEAR BUSHING & L/D $" DC. , 5.0 I~/U ~, 1/2" BHA ,.HANG TEST MWD, TIH WIHWDP, TEST MWD, t~'w aHA ROT. ERS SINCE INaPEC. 1,0 CUT DRILL LINE. ' t7 3.0 T}H TAG TOO,,@ a872. , , , TOOLOF..9~,?IPTION OD 10 LNGT 1,0 BREAK CIRC & TEST CASING TO 3000 PSI FOR :~0 MIN. O.K. BIT 1 .O~ -- 1.5 DRILL CEMENT TO TOP OF..F..L. OAT COLLAR (~ 8917. NBSTAB . , 3.~2 --_ . 1.5 C. IRC. & CONDITION CEMENTCONTA,MINATED MUD. ,, PC 9.07 1,,5. DRILL HARD CEMENT TO SHOE (~ a999. . ..... MSTAE, _ , 4.40 2,0 !CIRC & CONDITION CEMENT OONTAMINATE,D MUD PR,I,OR TO DRILLING OUT OF CSG SH, OE. MWD ........ 53.46 1..5. DRILL S,HOE & 10' OF NEW FORMATION TO ~011'. MSTB 5.30 _. 1,0. CIRC HOLE CLEAN F,i,~.R FORMATION INTER, ,GIT~. TI[S'I'. MDC 1.0 P-JU & TEST SHOE TO 13PPG EMWW/1300 P.,SI, JUG TEST. , MSTB ,. 4,68__ MDC 29.58 1.5 CIRC &.COND MUD PRIOR TO DRILLING AHEAD. ,, 513C 149.31 , , , , XO 1,11 6HWDP 183.05 JARS & 2OHW 130.26 TOTAL __ EF~ DC WF-!,a.H? " PU 24,0 TOTAL HRS. A~'I~ROVE[O PREY, TOTAL _ EXPENDA,LE SUPPLI!~S ON [~OARD: , , DRILLWATE. R ' ' POT WAFER ' JEARJ'i'E Jc'EMEN1~' ,U~L ROT 1,732 4912B7 DALLY TOTAL 4,33.1 5,4 CU~ TOTA~ T~MP " [W1N'I~ (MPHIDIR) IWIND CHILL {~ [VtSlI~ILiTY (Mi) DATE L.,~,T BOP "rEST ....~a *43 , ,J,sWS[ ,,I ..88 j1/2~ MI,, . 3\5\94 iViC SAUCIER H~R-09~199~ 0~: 17 ~h~R/H~SS N~ST~R ~ 90? 659 ~91 MORNING DRILLING REPORT - OFFSHORE AHEP- 2~84 tBACKSlDEt 2 3 4 LEASE AND WELL NO. State Tract 3~-01 North Star #3 PRE~ENT OPERATIONS DRILLING ~, g313. ... NO. 93M40 J gATE 31g/94 MD TVD ORILLEO ~ 312 ITOYAL PROJECTED 'DEPTH ImRU~nON I,, 8,452 WD 8,818 118HA~E 1~6N~CTO~ A~o .:e N&. - LER - OD TOP ~O SHOE DEPTHS iREPAI~ DOWNT~E I i gS~a 9,001 13PPG ~ 0-0-2 1/2 ERIEF DESCRIPTION OF P.O.B. PARKER-2$ EPOCH~ C.C.I.~ AHC-3 =AiRW~THER-1 AIC-5 BHI-7 B~, SPEED, AND HYD~ULICS $~RIAL EO~LE~ DULL TYPE ~9670 MUD PROPER MATERLAU AND CHkORIDE-~ PP MUD COSTS TOTAL 148,502 DIREC I 1'iON ~_16.60 _. COORDINATES DIRECTIONAL SURVF_Y8 DRIFT DIREC ~OORDI~'iATE s ME.ASU R¢.{3 9,157 g,249 D,~IFT' J ANGLE 22.:i 0 2j .~o 20.70 1769s 535,5w 1797.1 558.3w 18228 579W ANGLE _. , TION ~'Zz,.4"' l~?.?__..~s ~oo.3w -- ~ 3 . OPERATIONS IN SEQUENC~ Bo]rOM HOLE ASSEMBLY 16 NO CHANGE (SEE PRIOR REPORT) 1,0 FINISH COND. MUD. - --. 0.5 DRILL 10' TO 9021, , NEW BHA 2.0 'CIRC. B/U FOP, GE0. PURPOSES ..... ROT. 20.5 DRILLING FROM 9021-9313, AVG R,C)P 14.25 F'r/HR, 17 fOOL DESCR,~P33ON OD ID .... LNGT , " sit ~.og_ -' N B STAB 3..82__ · ..... PO 9.0_._7 , MSTAB 4.46 ... .... MWD 53.46 · , MSTB 5.30 , MDC 2g,-°o._ ,, - ' ' MSTB 4.68 ,, ,, MDC 29.58_ -' 5DC 149.31 ,, .-. XO 1.11 6HWDP t83.05 J .... JARS & 26HW 730.26 TOTAL EFIc DC WEIOHT 245 APPROVED 24.0 TqTAL HRS. ~, eD EXPENDABLE S ,UPPLIES ON t~OARD: 190 PRC. V. TOTAL -- 48,5,72 210 DAILYTOTAL ~UEL RE~"O (GAL~,} #UEL CON.SUMPTION (GALS) M~N AB~DARD TORQUE 4,098 54 210 cuR,. (OTAL __ " REPORTED 18 ,, ICALM -44 JJMPH, 3\5\94 ViC SAUCIER MORNING DRILLING REPORT O-~FSHORE ..... AHEP-2684 IBACKSlDE) 113 L~ ~LEASE AND WELL NO. ' ................... ' ' "- AFE NO. ~DAYS- ~ ...... ~EPTH -' ~DRIL~EO P"E~ENT OPERATION I"O~MAT~ON ]'~~O~CTED ~EpTH ' D~EFEST CASING - ' HOE T~T%PP~"' '~klNERS - SHOE ....... ODTOPAND DEPTHS R~PAIRDOWNTIMEf /¢,¢O~ TVD /~ / MD ~CONTRAETOR AND RIG NO. BRIE~ DE~CR]PTION OF OPERATIONS ' ' NO. SERIAL NO SiZE AND .. c/co- o C~ ~, .... .~ ? 8,, ;I L ~.,¢' '~ ¢¢r,'~ ~ BiT. wFIOHT...qPLLL) AND R'G~RAULI.f.:S RFCORD t. L?..[ ~ .! ?~j.'q rz MUO PROPEHFIES. MATERIALS At')OFF.) ARB.') COS PUMP I'JCI. 1 .LIN vFRTI( &r L1E. P'rH , . t',/K BI 5ECtlON ~NSTRMNT DHIFI O L)E PT.~H ANGLt: ¢;O¢)RDINAT['.~ VERTICAL I I -- ~ -- -- . I ~ NEWBHA- · - 1 7. TOOL O0 mD LENGTH cXPENDABLF S,,PPLIk_S Oh/BOARD DRILL WATER IPOT, WATER iBARITE _ ICI~MI~NT _ _ i/~/-(._.. -. DATE OATE LAST BOP TEST P/U ... _,_ k k F [) ¢." V"iT CfJq IS. AI'I'ROVED AFE Prll v. I OTAL ..... OA]LY TOTAL TORQUE S/O CL.JM, I L')'i'AL "[~ECEIVED B'~ . . . MORNING DRILLING REPORT - (".-~C:SHOR E " 11 -~ AHEP-2684 (BACKSIDE) - ..... ' .... '"~ ' ....?~FE NO IDAYS ..... DE~H -" [DRILLED ~F~'EI~EASE AND W~LL mU. ~ ~ '-- ' ' -- ~ ' ~ ~O ' ~ ~ ~~ON ' , ..... ' .......... i FORMATION ~fOTAL PROJECTED DEPTH DEEPE~~Y~'~T' PPG ~L,NER~-O~ ~AND SHOE DEPTHS IRE A O0 ~ n~ . . ., WEIGHI. SPEFD AND HYDI-tAULIC$ RECORD MD t'u,-- ~AT~, '~'~:'," 'VEL, ~-I-~P-----T%..-':~--. F'nC"'-: I ,',r,~ I [LL~ [ fPS lUN ISVMI '~N ISPM ,.~ :OSTS ALK HT OAH Y MUD PHOF'LI'IFIE$. MATERIALS ADDED ANF; ~- " /" I PILTRATF CAKE % ".. % CH~ C)RIDFfi .~Ai,,/,pL£ I ,._ I t:UN'L I PVIYP ,'.AEI.$ PH UC/:~0 :I2NDS SAND :,~il'~:~ OIL -F'F't,.I · TIME I '..NI VI.~ / MIN. 'MUD ~ATCRIAL$ AND QO'ANT1TIE$ ADDED 1N LAST 24 MOUR.e, ~D --['ME.~$U~FDi .... It,,l$ t-R MNT Dr~!F i' I lION - ANGLE D~PTM I ... DIIIEF!TIONAL S U H V L",'.':.; VFFtllCAL U~:'°T~'~ ! ' ' ' ,.. ,'~.7,'z ~z.,_,~....%:~i/9._~... M[ASIJHFL) i ~9IFT IN.% i'ItMN I ANG[F BI PI H _ I .. -r C41't~r_'- i IC. N t.:Lh ORDIN ATE S '-~.~URSi .... OPFRATION$ tN .C;E.QUENCF . .Z-Z,-/ ~. ~ ~ ~ z~ ~~,.~ ~~ ~ , .~. - · ~~,~. ~~q~,~-',~ , ,, · .~ .: .,~ ............ , '1 ~ ~ ~ .... III ~ i ~ ~ i PREVIOTAL I EXPENDABLE SUPPLIES ON BOARD' ." T W~E~ - -- ~EUEL AEC'D.-GAL~, ~M/V / I" ~'- -~ CUM TOTAL .~ ~ /~ 17/~ ~ ,..._ ., .... .. . BOl-rOM }IC')L F AF;SEMBLY iBHA) 1 ~½ [~ NO CI iA;',~C;E iSEE PiRI¢)H REPORT) F~ NEWBItA. I]()~' HRS SIHCI' INSP.___ 11. TOOL C_) E S C RII-"I ION .... OD ID. LEN(.;I H fiN) UFJ.) (PEET) ECEIVEO B' 90? 659 ~91 P~01 MORNING DRILLING REPORT- OFFSHORE ANEP3_6$4 (BACKSIDE) LIN'E[LE,~S['~,N'D,/'-~'~ '']''~''' ~,~/c~ ¢-~ ~' ''-~ t WE~L' NO'. .......................... 3t¢, c .1~,, ~ ~5 AFE~,...~/"~ ~L.~NO' I-~-'A';r'd'~ 'Z__ FORMATION tPRESENT OPERATIO,; D E_'~'~ J~-- ' ~ I~T~_~C)RILLEO p-,co. ..... / TOTAL PROJECTED DEPTH IDEEPEST. CASING;t . ' OD SHOE TEST ' PPG /[LINERS ' OD TOP AND SHOE DEPTHS RE~AIRDOWNTIME CONTFt~CTOR AND RIG NO. ' RT. WEIGHT.'SP~'~'ANO HYDRAULiGS RECORD L.51[ our ¢,r'/. ¢ MUD PROPERTI I~l MI B HPM S, MATERIALS ADDED AND IqJMF NO 2 PUN'L ' ,' ' ,":- '-' H ...... ..... VI~ Pc', yI ':"-'-' P C.~fi~40 221'J1'3.~ ~Ar',iD ~¢.'~I11):, OIL PPM A~,. MTN [)All Y IQ]AL JMuD MATERIALS AND QUANTITIES ADDED IN LAST 24. HOU~'"~" ¢) IN.";Tr~M N 1', FJF PTi[ ANGL[' (:UOHDINATF. S DIBEC f IONAL 5tjI'~VEYL~ V,'-..q TICAI \,'K 8, M["A5 Ul~r D DHrPI OIF,[' C IhlSfl~r'l'4t'lT'I ANL;Lb t DEPIH ....... , ! OPi~RATIC,'.f.!S IN SEQUENCE ........ / .,. ., -~-~ ........... __ ........ 1 . .... ..... I EXP~NDABLE SUPPLIES ON.~pAF~D ...... [FUEL ROT /~ ..... DRILL WAY~R J POT. WATER J BARITE ICEMENY ..... I .... 1~9~ I ...... FUEL REC'D..GALS M/V I I~.,,~z. /'m / TORQUE 7~ VERTICAL COORDIt4ATE5 D~PTH J UOTTOM HOL F ASSEMBLY (BHA) ~.i ~1 NO CH,:,,,',IGE tSEE PRIOR 1IlTPO/IT) ['~ NEw BHA - ~OT HRS YNCE ~NSP. 17. TOOL D E$CRIPTI(.')N OD I[~ LENGTH (IN.) liN.) (FEET) EFF D(: WI COSTS' i!APPROVF.~__.D. Al'lb I'F~E v' TOTAl DAll Y I O'I'AL · CUM. TOl.~,t F.'IER/HESS N, STRR :3 ,. 90? 659 2391 P.01 MORNING DRILLING REPORT- OFFSHORE AHEP-2654 (~ACK$1D~) LINE LEASE AN~ WELL NO. PR [SENT OPERATION DEEPEST CASING · OD SHOE TEST - PPG IUNERS - OD ? ~,~.,2__~_L ....... /~.:..¢...?.-,~r.: ...... 1 ....... BRIEF DESCRIPTION OF OPI[RATIONS APE NO. IDAYS ....... I..¢-~ ~ q ~ FORMATION TOP AND SHOE DEPTHS I~F..PAIi~ DOWNTIME ....--..... DEPTH q~/.J / ~'~ ...... TOTAL PBOJECTED DEPTH CONTRACTOR AND RIG NC). ~iT NO · ~../~: 7 Uli. W'LIGI-Jl. SVL[D AN0 I PK[.)RAUI. ICS RFCORD DULL ~;T~t,~r~ ~-- ~ · . F~I ~lr 11oi COND HC)UH~L A ll['M T B G F'RFG:~ ................ MtJD PROPFRTIF~. MATFRIAL fi ADDED AND COSTS CIR[- !IAT[' GPM H~,~J, J Noz PUMP NC~ 2 i FILTRATE J ,.~: % CI()©nIDrA ~LK IITIIP MUD MATERIAL5 AND OUANTITIES ADDED IN ~ST 24 HOURS 1.0.. DIREC TIC)NAL S UIh,.'LY$ ll M~.ASUREO IN~ I HMN'F DEl'IH ,, , 13 i 14 DHIFT J L1~RF'.L':. ANGLE 1 I C¢)CII1DINAI ES D~:IJ'I'H 15bCTIQN .......... (VKB) I VFI1TICAL L/IRb(;. Ct)O~I'HNATF$ F.)EPTM SEC Il(iN. TION ' (vkP.,) AN~3L F .'-, L~ NC~ CHANCE (SEE PRIOR ItrP¢)lll) SINCE INSP .. DESCRIPTION lin ) (IN.) (FEET) X~ /b 7 Aaa- l'l [ U C. WT -- C.('ff; I ':; APF'I lC)',/': C.) AFE F'RF.V I OTAL I.~AILY TOTAl CUM I OTAL JF1ECEIVED BY ) H~R-~-199~ 05:55 ~H~R/~SS N~ST~R ~ 90? 659 ~1 P~01 MORNING DRILLING REPORT- OFFSHORE AHEP-26a4 {BACKSID£) LINEI LEASE AND WELL NO. ' .... , 'IAFE NO. I DAYS [DEPTH '~...~ '~d~O DRILLED ...... ~PRESENT OP~R~fi'b'tT- ~ ....... I FORMATION, ..... [ /TOf~PROJECT~b DEPTH OEEPEST CASING - O~ SHOE TEST - PPG -" [LIN'~'~ - ~D TOP ANQ SHOE DEPTHS REPAIR DOWNTIME ~CONTRACTOR AND ~G NO. ~ ~0,~, . ....... MD No .q 7~. S~rAL NO ]'f'p[ I I-..:r i ~,:,'- ('[~,[ 11t:4, JJ{]', F'ER WT Ht'i!JH ! blL '.A nOT CIHC MiN I NO~' ,Z.g_r__o [ -- PUMP NO. 1 LIN I SPM MUD PROPERTIES. MATERIALS ADDFD AND MUD MATERIALS AND QUANTITIES ADOED IN LAST 24 HOURS 1 ('J PIJMP tqO 2 LIN F... P&t TOTAl. DtREC i lONAL SUHVLYS iNSTRMNT I.)AIFT L~IP, EC. (O,')RF) '-IATF.q OEPTH I v,',' ....... I INSTI1M, NT DtiIFT DIr~FC Ut.)(')HOiNATE$ DEPIH Dt:t-"¢H I'ION A,~4,'.}L r TIQN ' {VKbl} SFC:T~QN , ..................... ........... I II ................... I ....................... ,,. HOIJH$ . OPERATIONS IN Si'OUEN',;F . . UOTTOM HO[ F AS.SFMBLY (BHA) bi 7._ I,~qO0 *¢~0 "-" 1~ ~] NO CHANGE fSEE PRIOR REPORT} % ..... ' .... DBSCRIPT]ON liN.} (IN.) IFEET) ......... ........ ~,?. ~l.~)¢~ / ~-. -... ... .... . .... ~FF DC WT ~,'r ~, ,. ~' ~' ~ "- oUPPLIES ..~ ... EXPENDABLE" ON BOARD' f DRILLWA, ER ~POT. WATER ~B~~ ~C,MENT ~FUEL, 2,/~ROT ~R~5~1~94 07:04 ~rq~R/~SS N.ST~R ~ 90? 65~ ~91 f; DATE MORNING DRILLING REPORT - OFFSHORE l! AHEP-2684 (BACKSIDE) j[ 3"*/~J ~..,~_._¢ AFE NO DAYS ~)'E'IST ...... 1 DRILLED /PRESENT O~TION ~ I ~ ~DEE 5S . S ~6~S ETaS -PPG ]LINERS - OD TOP AND SHOE DEPTHS REPAIR DOWNTIME ~CON~TORANbhlGNS. BRIEF D~$CRI~TIQN OF OPERATIONS _ ........ ..LO ~9 ~ ~. Z~ ¢,'. ~ ,'~/~/~_e,_~_¢,~._'_~..,:,. .......... BI:i:'.'W'~IGH'T. ~'PEED AND I. tYL)Ii~,ULICS Rk'( ORB i ,' ,, ~_ I I] ii It IH~,I · MUD PROPFRTIES, ldATERIALS ADDED AND MUD MATERIALS AND QUANTITIES ADDED IN ~ST 24 FLOURS PUbIP NO 2 DIRECTIONAL SURVEYS Vt:HiICAL I"A[ ASIJRb O t ,,/:.?, ] ~.:,,,.,,, i"?:rS';~" .~,',,~ %%?' .~.~ I zo~ I ...... / .... C00ROINAT?.q MLJD CO5T5 TOTAl D['F'Tll iVKB) .., I'HOURS OPERA'I IONS IN ..qFQUENCE lh ~ ' ,t ~,,) ...... 'Z .... J I ~.Z°°_,~:~o /¢;¢.c ~,..,'ll,'..,,13r~:~..I< ~,¢.,~2~_,~,',-~ , ~-' l ' "'&~ , J'-, "-' ..... ' ' .... ' - / ' ' , , , . .¢_D,.,.ll,.,,t,Cc, c,~.e~a~-/¢,~.....(,,¢W ~e Z,.zT/-,~.~, I ~... .... EXP!-NDABI E SUF'PL!ES ON BOARD DRILLWATER [POT WATER 1BAFUTE//'/~,¢ 1~EMENT .... J /,,:¢._"~f~}~ Fd~L~'' ¢2'~' FUEL REC'O.-GALS. IM/V I DATE ~OT BOI IOM HOI. F AgSEMBLY (BItA) 16. r~ N() CHANCE (SEE PRIOR III ~ / IOOL I)E SC RIPTION I--'] l,,IFW Itt. lA - ROT ~IIL'-.~ .qlNCE iNSP. OD Ili, l ) z.,'g ¢/,,'1,'- cIN) LENGTH $.$z_ ~ lr. FF DC. wl AIq'HOvED AFr' ..~ PRFV I OTAL __ DALLY TOTAL C I.J ,¥1.' TOTAl IRECEIVED B ~kd'F b,)'~ ,-',5~ 1 i-'. Ld i MORNING DRILLING REPORT- Ur;FSHORE AHEP-26B4 (BACKSIDE) ,INf. ILEA'.;~E AND WEL,~L ~'~.' ........ "'" "' ~ 'AFE NO. ..... I DEEPEST C.~ING - OD SHOE ~'EST · PPG ""' [LINERS - OD TOP AND SHOE DEPTHS IREPAIR DOWNTIME I BRIEF D~.~£A~PTION OF OPERATIONS ~ ] ~ ~' $ ' I ...................... -- nT 'l SFRIALNO NOZZLES :.'4?ND~ j DATI[ .... . ...... ?- z DEPTH~/,,~ ,,'~-- .~-. ~. T'K. Ji~ IORILLED TOTAL ?ROJECTED DEPTH CONTRACTO~ AND RIG NO. ouI BII ROT V,/l' RPM M[.Lf ..~ MUD PROPLI~I'IF.R. MATERIAL'S"ADDED AND COSTS .~AMPLE XAt FUN'L I'V/YP I U~L$ I Pti I cC/3~ I q~N~SI~ANDI",a'~[*' I Oil I FFM ~~MATER1AL$' ~D QUANTI~IE8 ADDED tN '~ST 24 MOU~'~ - " ~oI ....... I')IREC'FION.¢L RURVEYS Ii'IS I HMNT E,l= I"' I'H 11 MUD TOTAL COORDINAI ~ DFPTH T I INSTRi'4NT (,.'KB) ,':; t- ¢.; I~N )FP~I, __A."i Gl' F .... - (..:(:;oRr NAT~5 !JOTTOI'd HOLL ASSFMBL¥ (BI IAI --.. lf-; La HO C. IIA/',I(~p.. (SEE PRIOI1 HbI'ORT) ~/1 NEW BllA Il(Df HRS .SINCF INSP. TOOL DESCRIPTION . OD. I() LENGIH (IN1 IIN.I (FEI'f) Fit- O C. W'l c.. ().~; I S, .. rje,,,u '~ ~ AI'I'HOVED AI-E : .~~ ' '~ '1"~'~'~ __. E,X,P,.E. NDABLL SUPPLIES ON BOAR,O: I- - ~_~0 P~I.V. TOTAl.. DRILL WATEP;-~V;~'ATER "IBARm; fOEMEN1' ~'0~L.J.'"LA~U'~'r'"~OT ..-- Z/~ ~" ~ ' ...... DATE ' [T~QUE~ ,--, -- ...... FUEL P.F.C'D.-GAL5. B"~ WIND MORNING DRILLING REPORT- OFFSHORE AHEP,~684 (BACKSIDE) ~"~'- i-iN~'I. EA~E'~ND WELL NO. ' .................. '~ NO ..... rDAYS PRESENT OPERATION ~ORMATION DEEPiiST CASING - OD ~;HOE Ti~;T. PPG ILINERS - OD TOP AND SHOE DEPTHS BRIEF DESCRIPTION OF OPERATIONS DFPTH OUT IDATE ITOTAL FROJ[CTED DEPTH REPAIR DOWNTIME CONTRACTOR AND RIG .. .,,'~,~_.~..~.,~, / q / Bi I.WEIGHT 5~-FFDANU I. rYD~,AULiCS RF¢:ORF) !,,~¢1, ,~, ~,~ ',, '¢"."'-'::':"""' ,~.',~¢,'-';" ""'"" ' ~..-" ~ I ' , -' , ~ i C;J ~'~$$ I ~I'M ~ ~ ~ H'~/ " I ..... , ._ .... , ....... I .... MUD PROPFRT~L$. MATERIALS ADDFO AhJl') (.:()SIS P. H'¢ P t.,!O l IN / IMUD ~D PUMP NO '2 MATERIALS AND QUANTIFIES ADDED iN LAST 24 HOURS ~rq ST R.'vIN T D~I~T ~EPrH ANGLE I TIC)hi DIRI~ CT[ONAi '.S URVLYS C OOR D NATT- S ,MEASUPiE D [ ' IN5 [HMN1 DRIFTJ i':~:Pf~t /',NGI F ] TIOH OPERATIONS tl',l SEQUENCE - ._ v~.~____~,! ~.CA.~_..~ DEPTH tSk C lION (VKBi ; F,X, ,_NDA~LE oUP~cl~$ ON BOARD: DRILL WATER POT. WATER BARITE ]CEMENT FUEL. · , I .... I -- ~ i FUEl,. R EC'D,, G A'L--~: Jt~/V/~-'~/-~ ~"~2,..-- ~- ....... DATE WIND 'T~L~.S /,,~,.,..,,...~. ,,., ~EN ABOARD JDATE LAST BOP TEST ,-,z~-,.--..~ !:5-5 - ~o ~ ~.zT. I J-,'z- ¢,¢ ..... S/O ROT .-.Z/O'"' TORQUE REPORTED BY i~O'I-7OM HOLF ASSF. MRI Y fRHAt "~ NO CHANGE ISEE PRIOR REPORT) LI NEW 8HA - ROT HRS. SINCE INSP DbSL'H[P'rION lIN I UN.I (FEET) --I~H L) C.vv'r L'.O ST R APF'RC, VED ArE } I.'Hi:V. TOTAL DAtJ.Y TOTAl. . .. CLIM. TOTAL JRECEIVED BY I ,HOtJRS C". O 0 R F,~ NATFg MORNING DRILLING REPORT ,~--~FFSHORE AH~P-~S,~ mACKS~D~ LIN=~'~ASE AND'WELL N~). ' .................... l A,i,' NO. ' ' f~)~,YS ~ ' -. 5...~~'~. I ~ PRESENT OPERATION ..... ~ FORMATION , I DEEPEST CASING - OD SHOE TEST. PPG [LINERS - OD TQP AND SHOE DEPTHS ~R~PAIR DOWNTIME BRIEF DESCRIPTION 0F OPERA~'IO'N~ ' TOTAL PROJECTED D~PTH ~ -- IEbNTRACr'OR ~,ND RiG NO. ' NOLZLr~ I I,.1 OU I RI'F. WEIGHT. SPLED AND HYI)i,!AULICS RFCOltD ... , TIM~ Jr~IN'IvI5 I PH CA,Kb % ',. PPM SAN~ ?.,()III):.; OIL .L ..... MUO N1ATERIALS AND QUANTITIES ADDED iN LA~T 24 HOURS 0 50..~ ~ z- ~>~ L ~..Z. ~~¢~..; 4-~,~ .~ ~ - u~ ~ 1(.), ... I DHII- 1 [ OiRF(;, ANGLg TiQN i t r.'¢.',rJH DiNA r ~r 5 IN ~TRMNT DF F'T'*. t MUD PROPERTIES. MATERIAl ~ ADDED AND (':O$ l 'j DIRECTIONAL 5URVEYR ' I MFASUR~D IN.~TRMN F ANC;LL EXPF. NF.~ABI F St.J, PL.,FS ON BOARD: DRILL WATER POT. WATER IBARITE ICEMENT FUEL R EC'D,-GALS. WIND P/U $/O PUMP I I MUD COST:.:; HtHP [)ALLY i tOTAL IDATE LAST BOP TEST TORQUE REPORTED BY 0 F.. r-' r H ";::'~ ROTTOM HOLL ASSEMBLY (BHAI ,,. 'i6 ~ NO CHAN(;I (!.;C!' PFIIOR REPORT) E~ I, IEVV BHA ROT, HRS. SIN¢.:I~ N.~iP TOOL I OI2.). ID. I)F~("HII~IIC]N I (IN I fin ) . 1 I:FF Ur.: VVI (: ().q l ,~i ~PPROVEO AFE PREV. TOTAL DALLY I r.) I AL LbNGIH f~EETI CUM TOTA ,I .t RECEIVEIP BY MORNING DRILLING REPORT . OFFSHORE AHEP-2684 (fIACKSIDE) ~_,~,~ i'~A.,~A-~:, w~,. ~o.' ............ i-;~'~-~'No. PRESENT OPERATION I FO~I~'ATION ~7 DEEPEST CASING - OD SHOE TEST - PPG ILLNESS - OD TOP AND SHOE DEPTHS I ¢----~ ¢. ¢",¢,, ../~... BRIEF DESCRIPTION OF OPERATIONS iR EPA..~I~ DOWNTIME /I II 3-...' 'C- DEPTH "' I O R-'[LLEO I / .¢,.,~ ~,¢,m I .... :roTan'PROJECTED DEPTH ~ 'I'VD -"'--.,- CONTRACTOR AND RIG NO. ..w~.4¢__.~,...~_. ~'/..~r/ .. =I SI7F I I I NOZZLES gr. RI,AL NO I AND L,'EPTH Our BIT, 'v'VEK31.11'. SDFED A',~D I.I','L)RALII ICS REC:OFiO '~ FFFT BI[ ' ___ DULL CON[') STANF) ' N,'ILJD PROPEItlIE$. M;kTERIALS AC)[':JFKJ ANO 'C H4[.' j ,~';',"L I ANN , ,. NOZ : PUMP I'-lO 'i VFI ~~ FP~ LIN 5FM · ¢'UMP NC) 2 lO ~LK. H 1 HF DAILY I 0TAI , '"'"" I- "~;~"["""""l'~''''''' '"'l~::~;~° [~'~'"~"'l-~'~'~°l"":'"""i °''' I'~''v'''-~:'" .... I MUD MATEI~IALS AND OUANTITIE$ ADDED IN LA,ST 24 HOURS IN§TFtMN f OCm'i' H ORI,rT . ,. I DIP..'- C. j I I,qN " L','i'R ~ CTI ONAL ,, V,2 It [IL'AL ;U'-RVFYS f,.,4.'- AS U R F D; ,., F.h RFC. i TiON -7- .... C UOR r.r')lr,lAT E S 'ROURSI OPE~AI'ION$ IN St: OUENCE I ,~ .._ Jo,¢,¢,,,_/~.;,-~o ~..,..,,.--,_,~,~_~-,,..,,¢.-.~ ~ .... e,,.,~,'.,_.~--.,... ~ ,¢,..~,..¢'.-~,:: ,:,.~' ','...,,,~-~..~.,,_ ~ ' . ..... ~.¢'¢.~'¢~*-- /. _. EXPENDABLE SUPPLIES ON BOARD. 7~ ~E~_ ~c'D.-~,~-,. ~,~',~,,¢,~., ~-~ 'I~ ~'~'"" ~- DATE LAST BOP TEST P/U S/O BOT IOM HOLE ASSLMRLY (BHA) ~-; r'-'l NO CH.,.'xNGE ISEF t'HIOR REPORII ~ NFW ','SP;A - ROT I{1t.'-; SINCE INSP IOOL I>ESCRIPTIr.)N b FF [3 C WT COSTS' AI'I'HOVE F) APE __ PRFV TOTAl 'ROT ~L~ TORQUE ?LY "rt.:, i,% ..... JCUM TC, l AL REPORTED BY [F1ECEIVE~'BY OD. Ii). LENGIH liN) Ilfl. I (FEET) MORNING DRILLING REPORT ~DFFSHOR,C Jo~'~ ..... ' ..... AHEP-2654 JBACKSIDE) ..... '.., ......... L.~ -.~ J ~ . ~E~P~ST CA~I~G- OD S~~ iLINERS- Ob TOP ANg SHOE DEPTHS i~EPAIR gOWNTIM~ AND ~lg NO BRIEF DE5CR~ION OF OPeRATiONS "' _,~ ~ir. WF~C':m'. SPk[O A'ND HYDRAI.JI. IC$ I'{LCOhD i .... MUO PiIOPERTIES, MATFR'I'~f.~3 ADDED AHD CClST~ JMUD ~YiR~AL~ AND QUANTITIES ADDED IN .... DIRECTIONAL SLJRVFY~ ..... vE~ rlCAL J M~ASURED DR FT DIHEC. · ........ M~ASUHED DFPTN ANGL~ liON ~vg~~ ..... D~P;H ANGLE TION COORF)iNATF~ ......... 11 ..... ~2 ' ....... ::1 ..... .- . ..... .... '-' ~;~:;U'R~ OPERATIONS )N SEQUENCE BOTTOM HOJF ASSEMBLY ' ' ~ ~JEW BNA - ~ ~ ~ ~_~ ~~ ~.~.~~~ ~ - I 7 TOOL OD. ID. LENGTH ~z.~,/~ ~.~ ..... ~~.~~.__~.~ ~m~ ~ ................. .................................. ,. j ~ - . P/U .......... S/O ~_L~P~NDABL~ SUPPLIES ON BOARD' P~EV TOTA. I~"~'~''~'' ~zL.~;.~. ~~'~' I ~ ~m~ CUM WIND ~ [~,,z.~,.. IMENABOARD i DATE LAST BOP TEST REPORTEDBY [RECEIV~O~Y I ~D Pt,IM~' r,~O 2 MORNING DRILLING REPOR1 OFFSHORE IIDATE AHEP-2684 (BACKSIDE) _INE LEASE AND WELLNO. A FE NO. DAYS DE PT H ]~ RILLE~D PRESENT OPERATION FORMATION TOTAL PROJECTED DEPTH 2 ~" ~p ~...7~, /~-~"~__ ~W.t~ ~<-r-F~'..~ - ~ ~ TVD ~ MD DEEPEST CASING - OD SHOE TEST - PPG LINERS - OD TOP AND SHOE DEPTHS REPAIR DOWNTIME CONTRACTOR AND RIG NO. BRIEF DESCRIPTION OF OPERATIONS BIT. WEIGHT. SPEED AND HYDRAULICS RECORD MIN NOZ PUMP NO 1 PUMP NO 2 BIT SERIAL NO NOZZLES FEE[ BI[ ROI DULL COND STAND CIItC ANN VI'L NO SIZE TYpEAND 1 32NDS2 3 DEPTHouT FEET I t( )1111~ HOuRPER MLBW[ RPM T 8]ttSB G PHEssPiP[ HAIl:GpM V[.I[:i,M fPS LIN SPM liN SPM 5 6 7 MUD PROPERTIES. MATERIALS ADDED AND COSTS SAMPLE FUN L ~ H CAKE % ",. % CHLORIDES TIME WT. VIS. PV/YP ~ELS. P CCMfN30 32NDS SAND F;()III)% OIL PPM MUD MATERIALS AND QUANTITIES ADDED IN LAST 24 HOURS -'. ,,,~-t'"~ ,~,,,<2.,~ ,,~ ~"/~.,O,,~.,'~ ,/ ,.5'.,,,0.~',~~ DIRECTIONAL SURVEYS MEASURED VERTICAL MEASURED VERIICAL INSTRMNT DRIFT DIREC- COORDINATES DEPTH INS~RMNT DRIF[ DI[~EC- COORDINA] ES DEPllt SECTION DEPTH ANGLE TION (VKB) SECTION DEPTH ANGLE TION IVKB) 11 12 13 14 HOURS OPERATIONS IN SEQUENCE BOF[OM HOLE ASSEMBLY (BHA) 15 ~:::~:~::~,!/~:~,~:::~::~ ~::76::9.,~/' ~.~_ ~ ~.~ 16 ~ NO CItAN(;E (SEE PRIOR IIEPORI) ~ N[W BIIA - 1OO1_ OD ID L[NO'[H ~ I~ ~~ ~~/~~ ~~~~ ~ &~'/~~S~ D[SCRIPIION liN) (IN) (FEED / EFF D C WI COSIS: P/U AIq'ROVED AFL S/O EXPENDABLE SUPPLIES ON BOARD: PREV 10TAL ~AILY TO[AL ~~ TOROUE I~; /~.~o~ ~-~~ CUM 10TAL w,~ ImenA OA D ~ATE mST BOP TEST 'Ia[PORTEOB~ RICE,VErB:. MORNING DRILLING REPORT-OFFSHORE AHEP-2684 (BACKSIDE) AFE NO. - - F~F[MATION . I DATE I1_. ~ ~..~ DEPTH /DRILLED TOTAL PROJECTED DEPTH '-'----- TVD CONTRACTOR AND RIG NO. I .-'~~,-'-.,~, / .~,,' LINE LEASE AND WELL NO. PRESENT OPERATION DEEPEST CASING - OD SHOE TEST- PPG 3 ,,~.,-//,,,'-'-~ DAYS ILINERS - OD TOP AND SHOE DEPTHS IREPAIR DO~WNTIME 4 BRIEt~ DESCRIPTION OF OPERATIONS MD BIT. WEIGHT. SPEED AND HYDRAULICS RECORD MIN NOZ PUMP NO I I'UMF' NO 2 BIT SERIAL NO NOZZLES FEET BIT ROT DULL COND STAND CIHC ANN 8IHS PIPE HAl E VF L NO SIZE AND 32NOS DEPTH FEET II I( )111.L~ PER WT RPM V[ I [ PS LIN SPM I IN SPM TYPE 1 2 3 OUT HOUR MLB T B G PRESS GPM FPM 5 6 7 MUD PROPERTIES. MATERIALS ADDED AND COSTS MUD COSIS FILTRATE CAKE % " % CHLORIDES ALK HTHP SAMPLE WT. FUN'L PV/YP GELS. PH CC/30 32NDS SAND ~;()I'I'I)S OIL PPM TIME VIS MIN DAILY tOTAL MUD MATERIALS AND QUANTITIES ADDED IN LAST 24 HOURS DIRECTIONAL SURVEYS MEASURED VERTICAL M EASUR E D VE H I ICAL INSTRMNT DRIFT DIREC- COORDINATES DEPFH INSTRMNT DRIFT DIREC- COORDINATES DEl>IH ANGLE TION SECTION ANGLE I ION SEC T ION DE PTH (VKB) DE PTH IVK B) 11 12 13 14 -- HOURS OPERATIONS IN SEQUENCE BOTTOM HOLE ASSEMBLY (Bt]A) 16 r-] N0 CHANGE (SEE PRIOI~I][.PORT) ~' ( - _- . . . . / - ~- /~ '~ ~ ~ ~ f~~ ~. ~. ~~ ~M~~. ROT. tills SINCE INSP ~ ~ ~ ~ ~~ ~~ ~ ~/ *//~~ ~O~.~ 17 TOOL OD ID LENGTH . ~ DESCRIPTION (IN ) fin ) ([-EE'r) / - - / ~ .. EFF D C COSiS P/U Al PROVED AFE S/O EXPENDABLE SUPPLIES ON BOARD: PREY tO~'AL omuu~Ate~ t eOt.~ate~ ~Amte CEMENT I FUELBEC'D.-~ALS. ~V~+~~ ~~ ~ TOHOUE FIMERAOA HESS CORPORATION April 28, 1994 1201 LOUISIANA, SUITE 700 HOUSTON, TEXAS 77002-5681 713-658-9770 Alaska Oil & Gas Commission Dave Johnson, Chairman 3001 Porcupine Drive Anchorage AK 99501 RECEIVED APR 2 9 I994 Alaska Oil & Bas Cons. Commission Anchorage RE: Northstar #$, Northstar Unit, Beaufort Sea AK Dear Mr. Johnson: I am sending you under separate cover one (1) LIS Tape and support data for the MWD logs, four {4} MWD Log Films and Prints, two (2) Mud logs (no films were made}, and a Core Analysis Report. A transmittal is attached. In accordance with provisions of 11 AAC 82.810(a), Amerada Hess Corporation hereby requests that this information be kept confidential. It has been so marked. Wet and dry samples were sent to you directly from the wellsite and transmittals were faxed to you. Also films & prints of the wireline logs were sent on April 20, 1994. I have not yet received signed copies of those transmittals. A Paleo Report, a VSP Report, LIS Tapes and core chips for the well are being prepared and will be sent as soon as they are done. S i ncere 1 y, JAR:bmc Attachments AMERADA HESS CORPORATION a. A. Ready Exploration Manager, Northstar cc: C. Richard P. E. Bacon R. Gardner- Fairweather , ~ANSMITTAL SHEET QUANTITY DESCRIPTION TITt.[ PLEASE RETURN ONE SIGNED CO Y TO AMERAOA HES~ CORPORATION AT THE ABOVE AD0flESS AMERADA HESS Corporation North Star #3 NS #3 slot #1 Exploration North Slope, Alaska S U R V E Y L ! S T ! N G by . Baker Hughes !NTEQ Your ref : EMS <995 - 3905'> Our ref : svy4365 License : Date printed : 22-Apr-94 Date created : 22-Apr-94 Last revised : 22-Apr-94 Field is centred on n70 28 24.450,w148 49 2.487 Structure is centred on n70 28 24.450,w148 49 2.487 Slot location is n70 28 28.469,w148 50 4.822 Slot Grid coordinates are N 6024550.706, E 642655.984 Slot local coordinates are 409.00 N 2120.00 W Reference North is True North RECEIVED 2. 6 i994 Gas Cor~s. Commis,sion .~chorage AMERADA HESS Corporation North Star #3,NS #3 Exploration, North Slope, Alaska Measured Inclin. Azimuth True Vert. R E Depth Degrees Degrees Depth C 0 0.00 0.00 0.00 0.00 995.00 0.00 0.00 995.00 1039.00 0.49 10.15 1039.00 1100.00 0.51 0.54 1100.00 1191.00 0.52 17.29 1190.99 SURVEY LISTING Page 1 Your ref : EMS <995 - 3905'> Last revised : 22-Apr-94 C T A N G U L A R Dogleg Vert 0 R D I N A T E S Deg/lOOFt Sect 0.00 N 0.00 E 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.18 N 0.03 E 1.11 -0.19 0.71 N 0.08 E 0.14 -0.71 1.51 N 0.21 E 0.16 -1.51 1282.00 0.53 70.61 1281.99 1376.00 0.54 75.11 1375.99 1471.00 0.67 94.99 1470.98 1566.00 0.50 103.11 1565.98 1661.00 0.42 82.00 1660.97 2.05 N 0.73 E 0.52 -2.17 2.30 N 1.57 E 0.04 -2.65 2.37 N 2.55 E 0.26 -3.00 2.23 N 3.51 E 0.20 -3.13 2.18 N 4.26 E 0.20 -3.30 1755.00 0.46 84.33 1754.97 1850.00 0.50 91.30 1849.97 1945.00 0.42 82.76 1944.96 2039.00 0.49 83.27 2038.96 2134.00 0.06 281.66 2133,96 2.27 N 4.97 E 0.05 -3.58 2.30 N 5.77 E 0.07 -3.83 2.33 N 6.53 E 0.11 -4.08 2.42 N 7,27 E 0.07 -4.37 2.48 N 7.62 E 0.58 -4.53 2229.00 0.38 277.47 2228.96 2323.00 0.33 246.59 2322.96 2417.00 0.34 178.99 2416.96 2508.00 0.44 181.33 2507.95 2600.00 0.51 207.29 2599.95 2.53 N 7.26 E 0.34 -4.48 2.46 N 6.70 E 0.21 -4.26 2.08 N 6.46 E 0.40 -3.82 1.46 N 6.46 E 0.11 -3.22 0.74 N 6.26 E 0.24 -2.48 2694.00 0.50 227.63 2693.95 2789.00 0.61 205.51 2788.94 2883.00 0.73 184.16 2882.94 2976.00 0.93 180.28 2975.93 3071.00 0.89 184.28 3070.91 0.09 N 5.77 E 0.19 -1.72 0.64 S 5.24 E 0.25 -0.86 1.69 S 4.98 E 0.29 0.22 3.04 S 4.94 E 0.22 1.52 4.54 S 4.88 E 0.08 2,98 3165.00 0.86 172.12 3164.90 3260.00 0.60 214.03 3259.90 3352.00 0.45 234.57 3351.89 3447.00 0.39 234.11 3446.89 '3541.00 0.29 186.15 3540.89 5.97 S 4.92 E 0.20 4.34 7.09 S 4.74 E 0.61 5.46 7,70 S 4.18 E 0.26 6.21 8.10 S 3.61 E 0.06 6.76 8.53 S 3.33 E 0.31 7.24 3636.00 0.30 166.62 3635.89 3729.00 0.40 162.67 3728.88 3823.00 0.42 192.95 3822.88 3886.00 0.26 118.21 3885.88 3905.00 0.64 153.13 3904.88 9.01 S 3.36 E 0.10 7.70 9.56 S 3.51 E 0.11 8.18 10.20 S 3.53 E 0.23 8.79 10.50 S 3.60 E 0.68 9.05 10.61 S 3.69 E 2.38 9.14 All data is in feet unless otherwise stated Coordinates from slot #1 and TVD from wellhead (37.00 Ft above Mean Sea Level). Vertical section is from wellhead on azimuth 196.39 degrees. Declination is 0.00 degrees, Convergence is 1.11 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ AMERADA HESS Corporation North Star #3~NS #3 Exploration~North Slope, Alaska SURVEY LISTING Page 2 Your ref : EMS <995 - 3905'~ Last revised : 22-Apr-94 All data is in feet unless otherwise stated Coordinates from slot #1 and TVD from wellhead (37.00 Ft above Mean Sea level). Bottom hole distance is 11.24 on azimuth 160.82 degrees from wellhead. Vertical section is from wellhead on azimuth 196.39 degrees. Declination is 0.00 degrees~ Convergence is 1.11 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ AMERADA HESS Corporation North Star #3 NS #3 slot #1 Exploration North Sloper Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : PMSS <3905-10000'> Our ref : svy4226 License : Date printed : 22-Apr-94 Date created : 3-Mar-94 Last revised : 22-Apr-94 Field is centred on n70 28 24.450,w148 49 2.487 Structure is centred on n70 28 24.450,w148 49 2.487 Slot location is n70 28 28.469,w148 50 4.822 Slot Grid coordinates are N 6024550.706, E 642655.984 Slot local coordinates are 409.00 N 2120.00 W Reference North is True North AMERADA HESS Corporation North Star #3,NS #3 Exploration,North Slope, Alaska Measured Inclin. Azimuth True Vert. Depth Degrees Degrees Depth 3905.00 0,64 153.13 3904.88 3960.00 0.40 119.20 3959.88 4056.00 2.40 186.30 4055.85 4151.00 7.50 189.00 4150.46 4245.00 8.10 188.80 4243.59 4339.00 8.30 189.10 4336.63 4432.00 9.50 186.70 4428.51 '4526.00 11.30 187.70 4520.96 4621.00 12.20 194.80 4613.98 4714.00 14.20 194.40 4704.52 4809.00 16.50 193.00 4796.12 4903.00 17.10 194.80 4886.11 4997.00 19.50 197.20 4975.35 5090.00 21.40 194.80 5062.48 5185.00 24.20 187.70 5150.07 SURVEY LISTING Page 1 Your ref : PMSS <3905-10000'> Last revised : 22-Apr-94 R E C T A N G U L A R Dogleg Vert C 0 0 R D I N A T E S Deg/lOOFt Sect 10.61 S 3.69 E 2.38 9.14 10.98 S 4.00 E 0.69 9.40 13.14 S 4.07 E 2.37 11.46 21.25 S 2.88 E 5.37 19.57 33.85 S 0.91 E 0.64 32.22 47.09 S 1.18 W 0.22 45.51 61.34 S 3.14 W 1.35 59.74 78.18 S 5.27 ~ 1.92 76.49 97.11 S 9.08 g 1.79 95.72 117.66 S 14.43 ~ 2.15 116.95 142.09 S 20.37 ~ 2.45 142.07 168.46 S 26.90 W 0.84 169.21 196.81 S 35.07 ~ 2.68 198.71 228.05 S 44.00 ~ 2.23 231.20 264.12 S 51.03 ~ 4.13 267.78 5276.00 24.60 187.40 5232.94 5369.00 24.90 188.10 5317.40 5462.00 25.00 188.80 5401.72 5554.00 25.40 188.80 5484.96 5647.00 25.60 188.10 5568.90 5742.00 25.80 187.40 5654.51 5832.00 25.60 189.90 5735.61 5924.00 24.90 192.70 5818.82 6018.00 25.10 192.00 5904.01 6111.00 25.50 191.60 5988.09 301.38 S 55.97 ~ 0.46 304.93 339.96 S 61.22 g 0.45 343,42 378.76 S 66.99 W 0.34 382.28 417.48 S 72.98 g 0.43 421.10 457.08 S 78.86 ~ 0,39 460,76 497.90 S 84.42 ~ 0,38 501.49 536.48 S 90.28 W 1.22 540.15 574.95 S 97.96 g 1.50 579.23 613.76 S 106.46 W 0,38 618,86 652.66 S 114.58 ~ 0,47 658,47 6204.00 25.90 192.30 6071.89 6329.00 24.30 194.40 6185.09 6422.00 24.70 194.10 6269.71 6515.00 25.50 194.10 6353.93 6607.00 25.80 193.00 6436.86 692.12 S 122.94 W 0,54 698.68 743.71 S 135.15 W 1,46 751.62 781.09 S 144.64 ~ 0.45 790.16 819.35 S 154.25 g 0.86 829.58 858.06 S 163.58 g 0.61 869.35 6702.00 24.60 193.40 6522.82 6794.00 25.40 193.40 6606.20 6889.00 25.90 193.40 6691.84 6981.00 24.30 197.60 6775.16 7075.00 22.50 199.70 6861.42 897.44 S 172.81 ~ 1,28 909.74 935.27 S 181.82 ~ 0.87 948.57 975.27 S 191.35 ~ 0.53 989.63 1012.86 S 201.74 ~ 2.60 1028.63 1048.24 S 213.65 ~ 2.11 1065.93 7168.00 21.80 201.10 6947.56 7260.00 22.40 201.50 7032.80 7354.00 23.30 200.40 7119.42 7444.00 24.00 201.50 7201.86 7536.00 24.30 202.50 7285.81 1081.10 S 225.86 g 0.94 1100.90 1113.35 S 238.44 W 0.67 1135.39 1147.44 S 251.48 ~ 1.06 1171.77 1181.15 S 264.39 ~ 0.92 1207.76 1216.05 S 278.50 W 0.55 1245.22 7630.00 24.60 202.50 7371.38 7724.00 24.60 202.20 7456.85 7817.00 24.80 202.50 7541.34 7910.00 24.70 202.90 7625.80 8004.00 24.10 202,20 7711.40 1251.99 S 293.38 ~ 0.32 1283.90 1288.18 S 308.26 ~ 0.13 1322.82 1324.13 S 323.04 g 0.25 1361.47 1360.04 S 338.07 ~ 0.21 1400.17 1395.91 S 352.96 ~ 0.71 1438.78 8096.00 23.90 201.80 7795.45 8188.00 23.30 202.90 7879.75 8282.00 23.60 203.20 7965.99 8375.00 23.20 203.60 8051.34 8467.00 23.20 204.60 8135.90 1430.60 S 366.98 ~ 0.28 1476.02 1464.67 S 380.98 g 0.81 1512.65 1499.09 S 395.63 W 0.34 1549.80 1532.98 S 410.30 W 0.46 1586.46 1566.07 S 425.09 ~ 0.43 1622.38 All data is in feet unless otherwise stated Coordinates from slot #1 and TVD from wellhead (37,00 Ft above Mean Sea Level). Vertical section is from wellhead on azimuth 196.39 degrees. Declination is 0.00 degrees, Convergence is 1.11 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ AMERADA HESS Corporation North Star #3,NS #3 Exploration,North Slope~ Alaska SURVEY LISTING Page 2 Your ref : PMSS <3905-10000'> Last revised : 22-Apr-94 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 8562.00 23.30 206.00 8223.19 1599.97 S 441.12 W 0.59 1659.42 8656.00 23.30 209.20 8309.53 1632.91 S 458.34 W 1.35 1695.88 8750.00 22.90 208.50 8395.99 1665.21 S 476.14 W 0.52 1731.89 8843.00 22.90 208.10 8481.66 1697.07 S 493.29 W 0.17 1767.30 8936.00 22.80 212.70 8567.37 1728.20 S 511.55 W 1.92 1802.32 9064.00 22.10 213.80 8685.67 1769.08 S 538.34 W 0.64 1849.09 9157.00 21.20 216.60 8772.11 1797.12 S 558.10 W 1.47 1881.57 9249.00 20.70 220.40 8858.03 1822.85 S 578.56 W 1.57 1912.03 9341.00 20.70 222.50 8944.09 1847.22 S 600.08 W 0.81 1941.49 9372.00 20.60 222.50 8973.10 1855.29 S 607.47 W 0.32 1951.30 9433.00 20.30 224.70 9030.26 1870.72 S 622.16 W 1.35 1970.26 9521.00 20.50 225.40 9112.74 1892.39 S 643.87 W 0.36 1997.17 9614.00 20.30 225.70 9199.90 1915.09 S 667.01 g 0.24 2025.48 9708.00 20.60 225.00 9287.98 1938.17 S 690.38 W 0.41 2054.22 9801.00 21.00 226.10 9374.92 1961.30 S 713.95 g 0.60 2083.05 9895.00 21.70 229.60 9462.47 1984.24 S 739.32 W 1.55 2112.22 9955.00 22.10 232.00 9518.14 1998.38 S 756.67 W 1.63 2130.68 10000.00 22.10 232.00 9559.84 2008.80 S 770.01W 0.00 2144.44 Projected Data - NO SURVEY All data is in feet un[ess otherwise stated Coordinates from slot #1 and TVD from wellhead (37.00 Ft above Mean Sea Level). Vertical section is from wellhead on azimuth 196.39 degrees. Declination is 0.00 degrees, Convergence is 1.11 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ AMERADA HESS Corporation SURVEY LISTING Page 3 North Star #3~NS ~3 Your ref : PMSS <3905-10000'~ Exploration~North $lope~ Alaska Last revised : 22-Apr-94 Comments in wellpath MD TVD Rectangular Coords. Comment 10000.00 9559.84 2008.80 S 770.01W Projected Data - NO SURVEY Targets associated with this wellpath Target name Position T.V.D. local rectangular coords. Date revised Target #1 not specified 8712.00 1802.00S 530.00W 19-Jun-93 All data is in feet unless otherwise stated Coordinates from slot #1 and TVD from wellhead (37.00 Ft above Mean Sea Level). Bottom hole distance is 2151.32 on azimuth 200.97 degrees from wellhead. Vertical section is from wellhead on azimuth 196.39 degrees. Declination is 0.00 degrees, Convergence is 1.11 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ I I V 350 0 35O 7OO ~050 _ t400_ _ 17.~0_ _ 2100_ _ _ 2800 _ _ 3150_ _ 3500_ _ _ 4200 _ _ 4,550_ _ 4900_ _ 5250_ _ 5600_ _ 5950_ _ 6300_ _ 6650_ ~350 ?70O 8O5O _ _ ~75~_ 9450_ _ 9800~ , AMERADA HESS ,. I I I I I I I I I / I I I I I I I I I I 700 350 0 350 700 1050 1400 1750 21 O0 2450 2800 Scare 1 : 175,00 Yerfl¢,=l ~ecflon on 196.~9 azimuth wlth reference 0.00 ti, 0.00 E from slot Corporationi Structure : North Star #3 Field : Exploration Well : NS #3 i Location : North Slope, Alaska! !reoted by : jones ate plotted : 22-Apr-g4 9O0 I I JPIot Reference is PMSS <3905-10000'>. jCoordinates ore in feet reference slot #1. iTrue Vertical Depths ore reference wellhead. Baker Hughes INTEQ L 750 I , I <-- West ....... 450 300 1500 150 I I .II I I I I .. g 450 O _ 1050 _ _1650 _ _1800 1950 L _22,50 E & P SERVICES.,/NC. April 22, 1994 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ATT: Larry Grant Completion Report: Amerada Hess Corporation Northstar No. 3 Gentlemen: On behalf of Amerada Hess Corporation, we are submitting herewith the following materials as pan of the Final Well Report as required under 20AAC 25.070 and 20AAC 25.071: 1. Two (2) originals of AOGCC Form 10-407; Well Completion Report. 2. Two (2) copies of Daily Repons of Well Operations. 3. Two (2) copies of Directional Survey. I believe you have already received the copies of well logs and samples of cuttings requred under 20AAC 25.071. Core analysis data and log tapes will be submitted as soon as they are prepared. Amerada Hess Corporation requests that all materals and repons submitted under the above mentioned 20 AAC sections be treated as "Confidential" under 20 AAC 25.537(d). 1L C. Gardner Agent for Amerada Hess Corporation RCG/js RECEIVED Enclosures CO; John Simon, Amerada Hess Corporation Jefe Ready, Amerada Hess Corporation APR 2 6 1994 ~1 & Gas 6ons. 6omraission Anchorage 715 L Street Anchorage, Alaska 99501 (907) 258-3446 FAX (907) 258-5557 FAIRWEATHER E & P SERVICES, INC. FIELD PROGRESS REPORT CLIENT: PROJECT: Report No. Date' Job No. AFE No. AMERADA HESS CORPORATION NORTHSTAR NO. 3 Ice Road and Pad Construction ReporL Period' ¢,~¢/ hrs Activity Report: ~ ~ OECEIVrD APR E6 i994. Gas Cons. Commission Anchorag~ Weal. her @ 0600 I~rs: Temp: Pressure: ~~' ~' Precipitation: Wind: ,~--~/~,~/f~,t~ Visibility: Submitted by' Operator's Representative FAIRWEATHER E & P SERVICES, INC. FIELD PROGRESS REPORT CLIENT: PROJECT: Report No. Date: Job No. AFE No. AMERADA HESS CORPORATION NORTHSTAR NO. 3 Ice Road and Pad Construction Weather @ OO00 I~rs: Temp: Submitted by: Operator's Representative FAIRWEATHER E & P SERVICES, INC. Report No. FIELD PROGRESS REPORT Date' Job No. AFE Not CLIENT: PROJECT: AMERADA HESS CORPORATION - NORTHSTAR NO. 3 Ice Road and Pad Construction Report Period· Activity Report: Wead~er @ 0600 hrs: Pressure: R¢_~Z~ Temp: '-"//~' ~ Wind: ~'~~.~ Visibility: //u,~.~/'l.,~_~ . Precipitation' v ky: · ~ ,:¢,~,) S ~!/'~ Clfill F.ctor: ,.-/.,~,~ I,~.,/'~,t,~,' ' ' ' Submitted by' ~ Operator's Representative .. FAIRWEATHER E & P SERVICES, INC. FIELD PROGRESS REPORT CLIENT: PROJECT: Report No. Date' Job No. AFE No. AMERADA HESS CORPORATION NORTHSTAR NO. 3 Ice Road and Pad Construction Report Period' Weather @ 0600 hrs: Temp' . '"/~. ~ Wind' ~'~/~ ?'~::~, Visibility: Precipitation:~/~,_~llr) Sky: ~ CI,illFactor: Submitted by: ~ Operator's Representative FAIRWEATHER E & P SERVICES, INC. FIELD PROGRESS REPORT CLIENT: PROJECT: Report No. Date: Job No. AFE No. AMERADA HESS CORPORATION NORTHSTAR NO. 3 lee Road and Pad Report Period' ~? hrs ,.,¢'.-~__.~'- ¢ ~// to ~.~ I~rs Weather @ 0600 hrs: Pressure: Temp: Submitted by: ~~~~'. FAIRWEATHER E & P SERVICES, INC. Report No. FIELD PROGRESS REPORT Date' Job No. AFE No. CLIENT: PROJECT: AMERADA HESS CORPORATION NORTHSTAR NO. 3 Ice Road and Pad Construction Report Period' Oo~l hrs. ~_ ~ _ ~ to ~.~f~O hrs Weather @ 0600 hrs: Pressure' ~'~'. 7~'"7 Temp: -,/~ ~Z' Wind' ,~-'<~/~',~- Visibility: . Chill Factor: Submitted by: ~ Operator's Representative PERMIT 93-203 93-203 93-203 93-203 93-203 93-203 93-203 93-203 93-203 93-203 93-203 93-203 93-203 93-203 93-203 93-203 ~OGCC Individual Well Geological Materials Inventory DATA T DATA_PLUS ARRAY/DDBHC/SDT L 132-9952 ARRAY/DDBHC/SDT L 132-9952 CBT L 5600-8862 CET L 5600-8862 CST L 9634-9863 FMI L 9230-9846 LDT L 9001-9774 LDT/GR L 996-7784 LDT/GR L 996-7784 LDT/NP L 9001-9774 MDT L 9001-977 NGT L 7500-9 1 PIL/SFL/AIT/GR PIL/SFL/AIT/GR DRY DITCH WET SAMPLES Are dry ditch samples Was the well cored? Are well tests requ Well is in compliance Page: 1 Date: 04/22/94 RUN DATE_RECVD 1-4 Comments 1-4 3.5//t .5 2-3 2-3 4 4 L 132- 89 124 L 13 9989 124 S 1 -10000 SS#909 S BOXES 04/21/94 04/21/94 04/21/94 04/21/94 04/21/94 04/21/94 04/21/94 04/21/94 04/21/94 04/21/94 04/21/94 04/21/94 04/21/94 04/21/94 04/20/94 04/20/94 d? ~ no And received? ~no no Analysis & description received? yes yes no Received? yes no tial I=IMERI:::IDI::I HESS CI:3RPEIRFITIEJN April 20, 1994 1201 LOUISIANA, SUITE 700 HOUSTON, TEXAS 77002-5681 713-658-9770 Alaska Oil & Gas Commission Dave Johnson, Chairman 3001 Porcupine Drive Anchorage AK 99501 RE: Northstar #3, Northstar Unit, Beaufort Sea AK Dear Mr. Johnson: I am sending you one (1) print and (1) sepia of all composite wireline'logs under separate cover. A transmittal is attached. In accordance with the provisions of 11 AAC 82.810(a), Amerada Hess Corporation hereby requests that this information be kept confidential. It has been so marked. Wet and dry samples were sent to you directly from the wellsite and transmittals were faxed to you. I have not yet received signed copies of those transmittals. Because of the "tight hole" status and the resulting need to restrict the transmition of information, data from the cores, paleo data, VSP's, LIS tapes and the final directional survey are not yet completed. All the data is in progress and will be sent to you, as completed, over the next few weeks. Sincerely, AMERADA HESS CORPORATION JAR.'bmc attachment" cc: C. Richard P. E. Bacon R. Gardner- Fairweather Ready Exp/~ration Manager, Northstar TRANSMITTAL SHEET ~-o /~L ~,' · 4-.5 ,,4. QUANTITY DESCRIPTION P,.z , ;/ F - ! ~, ,, ~ ~{ ~- -. , PLEBE RETURN ONE SIGNEO COPY TO AMESAOA HE~ CORPORATION AT THE A~VE AOORE~ TRANSMITTAL SHEET , , , TO: QUANTITY ~)E$CRIPT~ON PLEASE RETURN ONE SIGNED COPY TO AM )A HE$~ CORPORATION AT THE ABOVE ADDRESS _ , ....... -.-_ 1Ill'- CONFIDENTIAL DATA TRANSMITTAL SHEET · ~ ' ';~" --ii "j'm' ' ~ m. J .. 'Il jJ I ' L.~ - mm -- . OATE: __ ' ...... ' · " : FR0~: N4ERAOA HESS CORPORATION " .Ill -. ~ _ lZ01 LO, UI..SIA.NA? .SUITE..700 ! = .~ HOUSTON, TEXAS 7700Z ..:, _ SEHDER.* J. A. Rea,d~, ALASKA OXL AMD GAS CONSERVATION COIV~ISSZON ATTN; MR. BOB CRANDALL 3001 PORCUPINE DR. ANCI'iORAGE, ALASKA g950,].-3192 L " IPL ~L J' -- [ tN !0 : . DEPT; NORTHSTAR PROJECT LTM ............ __,~ ,,, ...,,.. . , qU6NTZ y . ., :. ~ _ ,, .DESCRIPTION eo~,, ,m Drill cut:lng, / / . f ., ...... . . . . _ ,. 0-- ~ il . i T ] i i · . ,,. _ _. DATE PLEASE RETURN ONE Eft TO NeE HES CORPORATION AT THE ABOVE ADDRESS. " - AOGCC COMPLIANCE REVIEW & REPORT PTD # OPERATOR INITIAL CONTACT DATE ! DATA REQUESTED WELL NAME CONTAC~T NAME ,3 U INTERIM CONTACT DATES COMP. DATE PHONE #.....~ FINAL COMPLIANCE DATE COMMENTS MEMORANDL TO: THRU: State [ Alaska Alaska Oil and Gas Conservation Commission David Joh,.~, Chairm.~,g/~ Blair Wondze~'~ P, I. Supervisor ~ FROM: John_ Spaulding/j~~.fi' --Y/~ SUBJECT: Petroleum Inspector DATE: March 28, 1994 FILE NO: 19WLC2BD .doc Location Clearance Inspection Amerada Hess North Star 3 Exploration P.T.D. # 93-203 Monday March 28, 1994: I traveled to Amerada Hess's North Star #3 well site to witness a surface location clearance. i was contacted by Jesse Mohrbacher, agent for Amerada Hess requesting an inspection of the North Star//3 well site for a location clearance. The pad area is a gravel island and was covered with ice and bermed around the edges with snow and ice. I informed Mr. Mohrbacher that I would not be able to recommend North Star #3 for a location clearance until such time that the snow and ice had either melted or had been removed to facilitate a better inspection. Summary: I recommend that the AOGCC does not grant a location clearance for North Star #3 at this time MEMORANDU,.i TO: THRU: State o) Alaska Blair Wondzell, P. I. Supervisor '~/~,z,,, Bobby Fos~L'~' Petroleum Inspector Alaska Oil and Gas Conservation Commission DATE: March 19, 1994 FILE NO: N9WICSBD.doc FROM: SUBJECT: P& A Cmt. Plugs Amerada Hess - N. Star #3 PTD # ~ - 203 - Exploratory Saturday, March 19, 1994: I traveled to Amerada Hess' exploratory well North Star #3 to witness the open hole P&A plug. The open hole cement plug had been set before ! arrived at the location which I had approved. The plug was set from 9,950' to 9,265' COTC. After waiting on cement for 12 hours the drill pipe was run in the hole and the cement was tagged at 9,337' with 14,000 #s of drill pipe weight. Soft cement and stringers was tagged 40' above the hard cement. This plug was set to cover a hydrocarbon zone from 9,428' to 9,442'. This gave 91' of hard cement and 40' of soft cement above the top of the zone. Sunday, March 20, 1994: I was notified by Brian Rose, Amerada Hess rep., at 4:30 AM that he was ready to set the cement retainer in the 9.625" casing and perform the cement job. The 9.625" casing shoe was at 9,001' so the retainer was set at 8,940' - 61' above the shoe. A 26 bbl. ( 130 sks. ) slurry of 15.8lb./gal. Class G cement was mixed and pumped down the drill pipe with 10 bbls. of water ahead of it and 2 bbls. behind. When 5 bbls of the water was out of the drill pipe the sting-in tool was stung into the retainer and 5bbls. of water and 15 bbls. of cement was pumped into the formation. The injection rate was 2.5 bbls./min, at 2350 psig and rose to 2800 psig at 2bbls./min. as the last of the cement was pumped. When the 15 bbls. of cement was injected below the retainer, the pump was shut down and the sting-in tool was unstung from the retainer and 11 bbls. of cement was placed on top of the retainer. The crew began laying down the drill pipe to set the top plug. Monday, March 21, 1994: I was contacted by Brian Rose at 9:00PM, Sunday, March 20, 1994, informing me that he would be ready to set the top in the 9.625" casing and squeeze the annuls of the 13.375" and 9.625" casing strings at approximately 11:00 PM. I arrived at the rig at 9:45PM and at and discussed the setting of the plugs. We agreed on the procedure to be used and BJ cementing Company began mixing NaCI water and preparing to mix cement. Page 2/2 The squeeze job on the 9.625" by 13.325" annuls consisted of mixing and pumping 9.5 bbls. ( 55sks. ) of 14.9 lb/gal, of Cold Set Cement between the casing strings. This gave a 175' plug between the casings. The top plug in the 9.625" casing was set by pushing a wiper plug down the casing with the drill pipe to 200'. An 11 bbl. (66sks. - 160'+-) was mixed and pumped down the drill pipe and up the casing. Since the casing is to be cut off 10' below the ML,I could not verify if the cement came up high enough in the casing. After the 9.625", 13.375" and the 20" casings have been cut off another inspection will have to made to verify this. ! informed Brian Rose of this and he said he would inform his supervisors. The cement was all in place at 2:20AM and I departed the location. Summary: I witnessed the setting of the wellbore P & A cement on Amerada Hess' North Star # 3. Attachment: Welibore Schematic ~?18-94 · 4'02P~ ; ,.~ ~ 907 659 2391;# ATTACHMENT I Pluggincj and Abandonment. Wellbore Diagram Amerodo Hess Corporation, Northstar No. ,.3 (Attached to and made a par[ of P and A Summary Progrom) Coslngs to be cut off minimum of ¢ ft. oelow p~ane or seofloor (os projected through toe of i.~lond SURFACE PLUGS IN 9 5/8' CASINO AND 9 5/8" x 13 3/8" ANNULUS, T~ e 50' MD AND BOTTOM e 4.2' MD 995' MD 13 3/8" 0 39Z0' MD MINIMUM 60' C~MENT PLUO ON TOP OF' RETAINER CEMENT RETAINFR 0 8940' MD MINIMUM 125' C£1~IENT PLUG BENEATH RETAINER ALL DEPTHS AI~L KB DRAWING NOT TO SCALE TOP OF CEMENT · 8880' · ii · · - TO 10,000 FT. MD TOP OF CEMENT O 6750' MI) 9 5/8' O 9oo1' TOP OF CEMENT PLUC O 9:Z50' MD HYDROCARBON-BEARrNc ZONE 9428' - 9442' MD BOTTOM OF CEMENT PLUG 0 9550' MD E & P SERV/CES,/NC, March 18, 1993 Mr. David Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Blair Wondzell, Senior Petroleum Engineer Re: Plugging and Abandonment of Amerada Hess Corporation Northstar No. 3 Gentlemen: Please find attached three copies of AOGCC Form 10-403 and supporting documentation covering the above-referenced work. We anticipate starting the work on or about March 20, 1994; therefore your timely review will be appreciated. Please contact the undersigned if you have any questions. Sincerely, RG:jh Attachments cc: John Simon, Amerada Hess Corporation Greg Manry, Amerada Hess Corporation 715 L Street Anchorage, Alaska 99501 (907) 258-3446 FAX (907) 258-5557 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type el Request: Abandon ~ Suspend __ Operation shutdown __ Re-enler suspended well __ Aller casmg ~ Repair ,.veil ~ Plugging __ Time exlenmon __ Stimulate Change approved program ~ Pull lubing ~ Variance ~ Perlorale __ OIher 2. Name el Operator Amerada Hess Corporation 3. Address 1201 Louisiana St., Std. 700 Houston~ Texas 77002 5. Type el Well: Development Exploralory Strafigraphic Service 4. Location of well at surlace 409 ft FSL, 2120 ft FEL, Sec. 17, T13N, R13E, UM 6. Dalum elevation (DF or KB) 37 ft KB 7. Unit or Property name Northstar Unit 8. Well numL)er Northstar No. 3 leer Attopof productive interval N/A At effective depth N/A At total depth 3235ft FSL, 2889ft FEL, SEC 20, T13N, R13E, UM OP, G NAL 12. Present well condition summary Total depth: measured true vertical 10,000 9,562 feet Plugs (measured) leer 9. Perrnitnumber 93-203 10. APInulmlbe_~¢- 50-- 029-22438 (None) Il. Field/Pool Bo.pool designated Eflective depth: measured 10,000 true vertical 9,562 leer Junk (measured) (None) feet Casing Length Structural 142 ' ,. Conductor 995 ' Sudace 3920' Imermediate 9001' Production Liner Perforation depth: measured true vertical (None) Size Cemented Measured deplh 30" (driven) 142' KB 20" cemented to 9~' KB surface 13-3/8" cemented to 3920' KB 925/8', surface 9001' KB 490 sx. of Class G bleed - top @ 6750 ft MD ~ueverticaldepth 142' KB 995' KB 3920' KB 8627'KB See attached sheets for summary of proposal Tubing (size, grade, and measured depth) (None) Packers and SSSV (type and measured depth) (None) 13. Attachments Description summary of proposal ~ Detailed operations program __ BOP sketch __ 14. Eslirnated date for commencing operation 15. Status el well classilication as: March 20, 1994 16. II proposal ,,",,as verbally approved Name of approver /~ Date approved Service 17. I hereby certily that ~h..,h.,h.,h.,h.,h.h~~i~~a"~d c~r--~; ecl to ,he best o, ,-ny knowledge. · R. C. gardne ~~~ .~..~ >~ Signed ~~~ Title Agent, Amerada Hess Corporation FOR COMMISSrON USE'ONLY Oil_;~L Gas__ Suspended__ Date March 17, 1994 Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test __ Location clearance ~ Mechanical Integrity Test __ Subsequent Iorm required 10- /"t"' r..P 7 Approved by order of the Commission O~Efi-NAL SIGNED BY qI.ISSELL A. DOUGLASS Form 10-403 Rev 06/~5/88 SUBMI'I-IN TRIPLICATE Summary Operations Program for Northstar No. 3 Plugging and Abandonment Present Well Status: As per attached Form 10-403. No geopressured zones or commercial hydrocarbon-bearing zones are present in this well. Plugging and abandonment will be in conformity with wellbore diagram attached hereto (Attachment I). Ail depths are KB. Summary Program: · Lay balanced plug across hydrocarbon-bearing zone at 9428' - 9442' MD. Calculate cement volumes based on 300 ft plug with bottom at 9550 ft. and top at 9250 ft. WOC and have plug witnessed by AOGCC representative. · Set cement retainer in 9 5/8" casing at 8940 ft. MD. Test retainer for pressure integrity. Sting into retainer and downsqueeze sufficient cement to place a 125 ft. cement plug under retainer. Slurry volumes will be calculated based on 200 ft. plug length beneath retainer. · · Unsting from retainer and lay 60 ft. cement plug on top of retainer. Have plug witnessed by AOGCC representative. Set 15© ft. surface plug in 9 5/8" casing from 200 ft. to 50 ft. MD. Use cold set cement. Have plug witnessed by AOGCC representative. · Leave 13 3/8" x 9 5/8" annulus open for disposal of waste fluids during rig down. Prior to move-out (and loss of heat to wellhead area), place 150 ft. surface cement plug in annulus through injection line on wellhead. Use cold set cement. Displace plug with mud or water so top of plug is at 50 ft. KB (bottom at 200 ft. KB). · Cutoff all casing strings as close to top of surface plugs as possible and recover same. Cutoff depth must be minimum of 4 ft. below toe of island slope (where it meets seafloor). The surface plug depths have taken this requirement into account. No steel plate on casing stubs is required. BJ SERY~CE$ Mer=h 18, 1994 AMERADA HESS CORP NORTHSTAR #3 NORTH SLOPE, ALASKA PLUG & ABANDONME_NT CEMENT Cement: 300' Plug from 9550' MD to 9250'MD 20 Bbls (100 sks) Class G + 0,2% CD-32 + 0.15% R-~ + 0,5 ghs FP-6L mixed @ 15.8 ppg 1.15 cf/sk, 4,98 gals/sk, T.Time -- 3:00 Cement; Retainer set @ -8940' MD inside 9 5/8" csg set @ ~9000'MD, (185' cmt below & 1OO' above retainer) BH C;rc Temp = 1 30OF '26 Bbls (130 sks) Class G + 0.2% CD-32 + 0,15% R- 0.5 ghs FP-12L mixed @ 15,8 ppg 1.15 cf/sk, 4.98 gals/sk. T,Time = 3:30 150' Surface Plug w/11 Bbls (65 sks) COLD SET II, mixed 14.95 ppg, 0.96 cf/sk, 3.89 gals/sk. T. Time = - 2:45 Displace cement to - 15' below ground level. Down Squeeze 150' of 13 3/8" x 9 5/8" Annulus w/9.5 Bbls (55 sks) COLD SET II, mixed ~ 14.95 ppg, 0,96 cf t sk ATTACHMENT I Plugging and Abandonment Wellbore Diagram Amerada Hess Corporation, Northstar No. 3 (Attached to and made a part of P and A Summary Progrom) casings to be cut off minimum of 4 ft. below 'plane of seafloor (as projected through toe of island slope) SURFACE PLUGS IN 9 5/8" CASING AND 9 5/8" x 13 3/8" ANNULUS. TOP @ 50' MD AND BOTTOM @ 200' MD 50" @ 142' MD 20" @ 995' MD 3920' MD MINIMUM 60' CEMENT PLUG ON TOP OF RETAINER CEMENT RETAINER @ 8940' MD MINIMUM 125' CEMENT PLUG BENEATH RETAINER ALL DEPTHS ARE KB BRAWlNG; NOT TO SCALE TOP OF CEMENT @ 8880' ..a,l.' .- ~t. · " *' · ~..~ ..~. :-: -,; TD 10,000 FT. MD TOP OF CEMENT @ 6750' MD 9 5/8" @ 9001' MD TOP OF CEMENT PLUG @ 9250' MD HYBROCARBON-BEARING ZONE 9428' - 9442' MD BOTTOM OF CEMENT PLUG @ 9550' MD CONFIDENTIAL DATA TRANSMITTAL SHEET ALASKA OIL AND GAS CONSERVATION COMMrSSION ATTN; MR. BOB CRANDALL 3001 PORCUPINE DR. ANCHORAGE, ALAS~ 9950!-3192 .,,I ._J_ _ _ Il .il ,. [] ._ I ~ , ,, DATE ~ . i ..J . m ___ mil . .. i _~ .... F~OM: AtIERN~A HESS CORPORATION ..m . m ,. iml . im ~ . m 1201 LOUISIANA~,r SUITE 700 HOUSTON. TEXAS 77002 ==~ ., .... i __ - ._L I~ .$EMOiiR_; ,), ,A,. Re~d¥ .... :m m i ~, DEPT: NORTHSTAR PROJECT '- '- Il' ' ...... ~ , I . mm . E/ I' QU~TITy .......... DESCRIPTION ...... , Boxes ~ DP!Il eutttngs f~ NPrths.~lr fl, (Lea~e 39-01) , . mm ji . ~,, ~ m ~ j m ~ _ i ~ m m . m .Jim ..... ....... i i il i i r- . [ mm ri i mi m m i i m m m ,~ ~ m m I r .... -'" II ,i ~- , I I .... I I . I ._. . , .............. qq' ...... i I m mm .._ m T I m )m m m. mm mm m ~ .. m II mml'll i ii ~m mm ----- mm .__ -I mm ..... r m m m ~ . m ·, ' m~ ) m m m m ~ ~. ~ . ,., ," nm lm n m m m . m m m I · m m lm m _ m m, ~ II I m . I __ I ii m m m, - · , , ,,, _ ,. .. , PL~ R~ ~E SI~ED ~Y TO ~~A HESS C~~TI~ AT ~E A~VE ~DRESS, ~)3/07~4 1~~ 29 Facsimile Cover Sheet LTO; ~ David Johneton AOGOC N~JTI~ F~ml/LOcatlon 276-7§42 Fax Number i FROM: I Lee Ann Gardner N~ITIG Environmental Department Division/Dept. 313 Tel. Ext. ' i !DATE: I --- March 7, i994 10:13am Date Time i RE: Amerada Hess Spill Report COMMENTS: Attached for your records is a Spill Report for a small diesel spill (<30 gallons) that occurred on Friday evening. .tLI . _ I II __ I II . _. Ill II Cover Page + ;3 Pages Accounting No: 0250-014-290 Call (907) 561-5700 regarding problems with this transmission. 4640 Business Park Blvd, Bldg. D Anchorage, AK 99503 (907) 561~5700 FAX (907) 273.4555 . III ~3/'07/94 10: 30 ~'907273455~ ENSR 5PlL~ REPQRT ,. Name of Facility or Vessel: Name, Address, and Telephone Number: Person(s) causing or responsible for discharge: P,o. ~,~.~j_~ - ~~~~, Address; Telephone: ., Name: Telephone: - Type of substance(-<) discharged: Amount of substance(s) dis~argaci: ,1 , i _ ii . ... i Figure 1A-I. 1A-3 Spill Report Form, RECE1VCD ~:~ 0 7 ~99 Alaska Oil & Gas bons. Anchorage I~q~-B4-L994 LEI; 04 .... ?tmE~/HE55 N. [TR~ ~ SPILL R~[PORT (¢ont'~ . ~ -- / Environmental damage causec~ by di$oharge or containment: 11 i-- _ -- 7. 10. F.~tLm atecl AmounL~: ga. Haza, rdo~, Substance cJeaned 8b. Hazarclous waste general, ed; ._~,~,.,)d"- ~.~.__,~_ ~'~ ;,~ Date of u~~ disposal: Location. of uttimate disposal: Me, od of ultimate disposaJ: Figure 1A-1. Spill Report Form (D..a~t'tt).L 'V ~.- ~-' IA.-4 ~.3.,"07/94 10' 31 ~'9072734555 ENSR tl, 12. SPILL REPORT (C~ont'd) ACtions taken to prevent re~rmnce of discharge: --- Other inlormation: Figure 1A-1. Spill He'port Form (Oont'd). 1 TOT~ P.03 MEMORANDUM f--_ State Alaska Alaska Oil and Gas Conservation Commission TO:- ~avid J~ Chairmi~n~-~' DATE: March 5, 1994 TtlRU: Blair Wondzeil, ¢¢~ FILE NO: P. I. Supervisor a9wIcebd.doc FROM: John Spaulding . · SUBJECT: Petroleum Inspector BOPE Test Parker Rig 141 Amerada Hess No. Star 3 Exploratory PTD 93-203 Saturday March 5, 1994: I traveled to Amerada Hess's North Star 3 Exploratory Well to witness the BOPE Test on Parker Rig 141. As the attached AOGCC BOPE Test Report indicates,one methane gas detector in the cellar area was found to be defectiv~and was to be repaired. One flange leak on the choke manifold was repaired and testing was resumed. The rig was well layed^considering space on the island was at a premium. Two ice roads lead into the island from opposing directions to take good advantage of wind direction.. Summary: I witnessed the BOPE Test at Amerada Hess's North Star 3, on Parker Rig 141, no failures, 4hours. Attachment: agwlcebd STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: XXX Workover: DATE: Drlg Contractor: PARKER Rig No. 141 PTD # 93-203 Rig Ph.# Operator: AMERADA HESS Rep.: JIM KOTHE Well Name: NORTH STAR 3 Rig Rep.: VIC SA UCIER 3/5/94 659-2585 Casing Size: 9 5/8" Set @ 9001' Location: Sec. 17 T. 13N R. 13E Meridian UMIAT Test: Initial Weekly XXX Other Test MISC. INSPECTIONS: FLOOR SAFETY VALVES: Ouch. Location Gen.: OK Well Sign OK Upper Kelly / IBOP 1 ! Housekeeping: OK (Gen) Drl. Rig OK Lower Kelly / IBOP 1 Reserve Pit NA Ball Type 1 Inside BOP 1 Test Pressure P/F 250/3500 P 250/3500 P 250/3500 250/3500 P BOP STACK: Quan. Annular Preventer 1 Pipe Rams 1 Pipe Rams Blind Rams Choke Ln. Valves 2 HCR Valves Kill Line Valves 1 Check Valve NA Pressul-~ 250/3000 250/3500 1 250/3500 250/3500 250/3500 250/3500 250/3500 P/F P P P P P P P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 14 250/3500 P 33 250/3500 P 2 Functioned Functioned ACCUMULATOR SYSTEM: System Pressure 2800 [ P Pressure After Closure 1800 I P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 54 sec. , Trip Tank OK OK System Pressure Attained 3 minutes 28 sec. Pit Level Indicators OK OK Blind Switch Covers: Master: XXX Remote: XXX Flow Indicator OK OK Nitgn. Btl's: 4 @ 2600 AVG. , Gas Detectors OK OK Psig. Number of Failures: ~ '/,Test Time: 4 Hours. Number of valves tested 22 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: REPAIR METHANE GAS SENSOR IN CEH_.HR I FLANGE LEAK ON CHOKE MANIFOLD REPAIRED AND CONTINUED TESTING ' I I I I Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES XXX NO 24 HOUR NOTICE GIVEN YES XXX NO Waived By: Witnessed By: JOHN H. SPA ULDING FI-021L (Rev. 2/93) AgWLCEBD.XI.3 AMERADA HESS CORPORATION NORTHSTAR NO. 3 Summary of Proposed Program Change (Attached to, and made a part ofAOGCC Foan 10-403, dated 2/18/94) The drilling procedure approved under the Permit to Drill specified a 16" hole to 13-3/8" casing depth (approx. 3900 ft MD & TVD). The procedure also included a cement bond log fi'om the 13-3/8" float collar to the sinS'ace. A 16" hole was drilled to 3925 feet, and an attempt was made to mn 13-3/8" casing to this depth, as per the original well progrant The casing stopped at 2734 feet, and could not be advanced further despke circulating and working the pipe. The casing was then pulled and laid down. The hole was then opened to 17-1/2" and the casing nm to 3920 feet without incident. The casing was then cemented to sinS'ace as per the original program, except that the slurw volumes were adjusted for the increased hole size and a 100% excess. The casing xvas cemented while reciprocating the casing, and mfinte~Tupted returns were observed tlu'oughout the job. The full 100% excess was pumped and displaced, with approximately 450 bbls of cement slurry rettmfing to the surface. Based on the results observed dm4ng the cementing operation, it ~vas decided to eliminate the cement bond log. A call was made to AOGCC requesting this program change, and xvas verbally approved on February 16, 1994. A VSP survey was subsequently nm in the cased hole. The quality of the seismic signal indicated a good cement bond tlu'oughout the surveyed interval. tL C. Gardner Agent, Amerada Hess Cool, oration RCG/js RECEIVED MAR ....-1 1994 f~iasl<a uil & Gas Cons. Cornrnissio~', Anchorage E & P SERVICES,/NC, February 28, 1994 Mr. David Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Blair Wondzell, Senior Petroleum Engineer Amerada Hess Corporation, Northstar No. 3 Dear Mr. Wondzell: Please find attached three copies of AOCJCC Form 10-403 which describes a minor change to the drilling program for the above-referenced well. Sincerely, _ K C. Gardner Agent, Amerada Hess Corporation RCG/js Attachments cc: John Simon, Amerada Hess Corporation Greg Manry, Amerada Hess Corporation 715 L Street Anchorage, Alaska 99501 (907) 258-3446 FAX (907) 258-5557 STATE OF ALASKA ALASKA OiL AN O GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ,.% Type ol RequesI: Abandon __ Suspend __ Alter casmg __ Repair ,,veil Change approved program X Operation shuldown __ Re-enler suspended ,,,,,ell __ Plugging __ Time extens,on __ Stimulale __ Pull lubin9 __ Variance ~ Per lorale ~ Olher __ 2. Name ol Operator Amerada Hess Corporation 3. Address 1201 Louisiana St. Suite 700 Houston, TX 77002 5. Type ol Weih Development Exploralory Strmigraphic Service 4. Location ol well at surface 409 ft FSL, 2120 ft FEL, Sec 17 T 13 N~ R 13 E, UM At top o[ productive interval (Kuparuk Target) 3980 ft FSL, 2670 ft FEL, Sec 20, T 13 N, R 132, UM At effective depth 3235 ft FLS, 2889 ft FEL, Sec 20, T 13N, R 132, UM At total depth 6. Datum elevation (DF or KB) 37 [t KB 7. Unit or Prope~ly name Northstar Unit 8. Well number Northstar No. 3 9. Permitnun~ber 93-203 10. APInumbor 50-- 029-22438 Il. Field/Pool No pool designated 12. Present well condition summary Tolal depth: measured 3930 feet true vertical 3930 feet Plugs (measured) (None) Ellective depth: measured 3930 feet true vertical 3930 leer Junk (measured) (None) Casing 'Structural Conductor Surlace Intermediate Production Liner Perforation deplh; Length Size 142' 30" 995' ' 20" 3920' 13-3/8" measured N/A I true vertical N/A Tubing (size, grade, and measured dep'th) N/A Packers and SSSV (type and measured depth) N/A Cemenled (driven) Cemented to surface Cemented to surface Measureddeplh 142' KB 995' KB 3920' KB See attached sheet for Summary of Proposal ~ueverlicaldepth 142' KB 995' KB 3920' KB RECEIVED MAR -'1 1994 Aias'ka Oil & Gas Cons. Comm Anchorage 13. Attachments Description summary ol proposal ~ Detailed operations program __ BOP skelch __ 14. Estimaled date lot commencing operation 2/16/96 16. If proposal w'as verbally approved Blair Wondzell 2/16/94 Exploratory Name of approver Uate approved Service 17. I hereby certily that the loreg?~ is true and correct to Ihe best ol my knowledge. . ~'"'/ "'~'-"~-"~/ - FOR 'CGtd~ZfS'STOTq USE'ONLY Conditions of approval: hlotify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance Mechanical Integrity Test ~ 15. Status of ,,veil classilication as: Oil ~ Gas __ Suspended __ Dale 2/18/94 Subsequent form required I0'"-7-/',/ Approved by order o[ Ihe Commission Original Signed By Oavid W. Johnston Form 10-403 Rev 06/15/88 J, Approval l,lo.e ,Do oved Copy. Returned oUBMl'r IN TRIPEICAIE SSJOli MEMORAND ., I TO: THRU: State Alaska Alaska Oil and Gas Conservation Commission David J o h~,,.~ n,'~ Chairp~--~ Blair Wondzell, ~-~,~q P. I. Supervisor % FROM: Grimaldi, SUBJECT: Petroleum Inspector DATE: February 19, 1994 FILE NO: A9WJBSBD.DOC BOP test Parker rig # 141 Amerada Hess Northstar #3 Sec. 17, T. 13N, R. 13E, Umiat PTD. # 93-203 Saturday, February 19, 1994: I traveled to Amerada Hess exploratory well Northstar # 3 to witness the initial BOP test on Parker rig # 141. The rig was just finishing up with some logging work when I arrived and the test was begun within four hours, due to the shut down time there were some frozen lines that needed to be thawed out. Some of these were the pipes downstream of the choke manifold. I found this situation to be unacceptable in that this equipment should be ready for use at any time and not after two hours of thawing, after speaking with Bill Campbell (Parker Drilling Supt.) work was begun to enclose and heat these lines to avoid a repeat occurrence of this problem. The test went well with all BOP equipment functioning properly and holding it's respective pressure test. The gas detectors were tested and although were found to be working the high limit on the methane was set at 60% versus the 50% set forth in our I guidelines, the contractor supplying these will reset the high limit. As the company man was not aware of our policy I did not count this as a failure but I did supply him with a copy of our guidelines on gas detection. Summary: I witnessed the initial BOP test on the 13 5/8 stack on Amerada Hess well Northstar # 3. Test time five hours, no failures. Attachment: A9WJBSBD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Parker Operator: Well Name: North Star #3 Casing Size: 13 3/8 Set @ Test: Initial X Weekly Rig No. 141 PTD# Rep.: Rig Rep.: 3,912 Location: Sec. Other DATE: 2/19/94 93-203 Rig Ph.# 659-2585 Brian Rose Fred Herbert 17 T. 13N R. 13E Meridian Umiat MISC. INSPECTIONS: Location Gen.: P Well Sign P Housekeeping: P (Gen) Drl. Rig P Reserve Pit N/A BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Test Quan. Pressure P/F I 30013000 P I 50015000 P 1 50015000 P 1 50015000 P I 50015000 P 1 50015000 P 2 50015000 P NrA N~ FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 50015000 P 1 50015000 P I 50015000 P I 500t5000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 14 Test Pressure P/F 50015000 P 36 50015000 P 2 P ACCUMULATOR SYSTEM: System Pressure 3, 000 P Pressure After Closure 1,750 P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure *0 minutes 33 Trip Tank P P System Pressure Attained 4 minutes 35 Pit Level Indicators P P Blind Switch Covers: Master: OK Remote: Flow Indicator P P Nitgn. Btl's: Four Bottles (three spare) Gas Detectors P P*1 2500 Average Psig. sec. sec. OK Number of Failures: 0 ,Test Time: 5.0 Hours. Number of valves tested 21 Repair or Replacement of Failed Equipment will be made within n/a days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Gas alarm passed test but high level needs to be lowered to 50 % LEL, is presently at 60% Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c -Inspector FI-021L (Rev. 7/19) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: A9WJBSBD.XLS Louis R Grimaldi E & P SERVICES, INC. February 7, 1994 Alaska Oil and Gas Conservation Commmission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: David W. Johnston, Chairman RE: Location Survey, Amerada Hess Corporation, Northstar No. 3 AOGCC Permit No. 93-203 Gentlemen: Please find attached three (3) copies of the above-referenced as-built survey plat, as per 20 AAC 25.005(j). Please contact the undersigned if'you have any questions. R. C. Gardner Agent for Amerada Hess Corporation RCG/js Attachments cc: John Simon, Amerada Hess Corporation Greg Manry, Amerada Hess Corporation RECEIVED FEB - 8 1994 Alaska 0ii & Gas Cons. Commission Anchorage 715 L Street Anchorage, Alaska 99501 (907) 258-3446 FAX (907) 258-5557 Sec~clon 17, T}3N, R~3E, Umi~c Meridian, A~ask~ SECTION LINE REFERENCE The center of well casing for North Star No. 3 is located 2120 feet from the east line and 409 feet from the south line of section 17, T. 1.:3 N., R. 1.3 E., Umiat Meridian. AMERADA HESS NORTH STAR NO. 3 2120' 409' ~ -g, ~ NDTES: i. Locoti~ oF well site was mccomplished us;rig GPS Sa~teLl;te Positioning ~nd ~onvent~l ~urvey;n9 ~. All ~ension~ ore in Peet 3. Coordinotes ~re referenced ¢o ~h~ NotCh Amerlc~n D~¢um of 4. D~e o? survey wos Jon. lB, 1994. 5. Control used wos ~ DIS 438 DTS 439 State Plane Zone 4 Co~'~tes in Feet. Y = 6~024,552 X = 642,654 I hereby certify that ! am properly registered ~nd licensed ¢o proc¢;ce Land surveying ;n the State oF Aloska and that this plat represents tocatlon survey mnde by me 6nd oil d;menslons and other deters are correct. Section 17, TI3N, RI3E, UM, Ak. Long ]sl~ncL, BeauFort Se~. At~sk~ ~ , , FairweaLher E & Surveyed By LCMF LimiLed 139 E. 51s¢ Ave. Anchorage, Ataska Date Robert Kohut, LS 8207 MEMORANDUM TO: THRU: Blair Wondzell, P. I. Supervisor State of ~-,,aska Alaska Oil and Gas Conservation Commission DATE: February 6, 1994 FILE NO: A9WIBFBD.doc , FROM: Bobby Foster,~ ..~ SUBJECT: Petroleum inspect:or BOPE Test - Parker 141 Amerada Hess- N. Star # 3 PTD # 93-203 - Exploratory Saturday, February 5, 1994: I traveled to Parker rig 141 to witness the upcoming BOPE test on Amerada Hess's North Star # 3 after being notified by Brian Rose, company rep., that the test would start between 1:00 am and 6:00 am. i arrived at the rig at 9:00 p.m. Sunday, February 6, 1994: After numerous delays to repair and alter equipment, the test began at 10:30 p.m. and was concluded at 2:00 am Monday, February 7, 1994. As the attached BOPE Test Report shows~there were no BOP equipment failures, however, there were no gas detectors installed on the rig. I spoke with Jim Kothe, Parker toolpusher, and Brian Rose, both of whom said they did not know that they were required. I got the drilling permit and show them where it stated that they were required. They both told me that they would order the detectors this date and they would have a technician come up to the rig and install them. I told them to have them operational before drilling out the 13.375" casing shoe. I also showed them both where the requirements were located in the AOGCC regulations of 1986. Summary: I witnessed the satisfactory BOPE test on Parker rig 141drilling Amerada Hess's North Star #3. Test time 3.5 hours - No failures - 1 nOncombliance. Attachment: AgWIBFBD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drig: X Workover: ~ Drlg Contractor: PARKER Rig No. Operator: Amerada Hess Coperation Well Name: North Star # 3 Casing Size: 20" Set @ 995 Test: Initial X Weekly Other DA-I-E: 2/6/94 141 PTD# 93-203 RigPh.# 659-2585 or 2640 Rep.: Bdan Rose Rig Rep.: Jim Kothe Location: Sec. 17 T. 13N R. 13E Meridian U MISC. INSPECTIONS: Location Gen.: OK · Housekeeping: OK (Gen) Reserve Pit N / A Well Sign OK Drl. Rig OK BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. 1 Test Pressure 250/1000 P/F 1 250 / 2000 P I 250 / 2000 P 1 25O / 2OOO P I 250 / 2000 P 2 250 / 2O0O P N/A MUD SYSTEM: Visual Alarm Trip Tank YES YES Pit Level Indicators YES YES Flow Indicator YES YES Gas Detectors NOTE NOTE FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 250 / 2000 P 1 25O / 2OO0 P 1 250 / 2000 P 250/2000 CHOKE MANIFOLD: No. Valves 14 No. Flanges 32 Manual Chokes 2 , Hydraulic Chokes 1 Test Pressure 250 / 2000 250 / 2000 Functioned Functioned P/F P P P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 6 Blind Switch Covers: Master: Nitgn. Btl's: 4 @ 2350 3,000 I P 1,400 P minutes 55 sec. minutes 2 sec. YES Remote: YES Psig. Number of Failures: 0 ,Test Time: 3.50 Hours. Number of valves tested 22 Repair or Replacement of Failed Equipment will be made within NOTE days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 I r I REMARKS: ~ ~- The only ~las detectors for the rig is located in the mud Io~t~in~l trailer - ! informed Mr. Rose that there would have to be have to be a system installed with methane and H2S monitors per AOGCC re~lulations - He said that the equipment would be order, ed this date7/7/94- This system must be in and operational be for drillin~l out the 13.375" casing. Distribution: orig-Well File c - Oper./Rig c - Database c - Tril5 Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: BOBBY D. FOSTER FI-021L (Rev. 2.293) A9WlBFBD3(LS E & P SERVICES., INC. February 1, 1994 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: David Johnston, Chairman Subject: Notice of Spud, Amerada Hess Corporation, Northstar No. 3, Permit No. 93-203 Gentlemen: Please be advised that the above-referenced well was spudded at 2300 hours (11:00 P.M. ) , January 31, 1994. Please contact the undersigned if you have any questions. Sincerely, R. C. Gardner Agent for Amerada Hess Corporation RCG/js cc: John Simon, Amerada Hess Corporation Greg Manry, Amerada Hess Corporation Jeffe Ready, Amerada Hess Corporation RECEIVED FEB -$ 199zi Oil & Gas Cons. Commission Anchorage 715 L Street Anchorage, Alaska 99501 (907) 258-3446 FAX (907) 258-5557 MEMORANDUM State of. ,taska Alaska Oil and Gas Conservation Commission TO: THRU: David Joh n~~, Chairm~n~,'~ Blair Wondzell, P. I. Supervisor FROM: Doug Amos, ~ SUBIECT: Petroleum Inspector DATE: FILE NO: January 31, 1994 egwha4bd.doc Diverter Inspection Parker 141 Amerada Hess N. Star State #3 Exploratory Sec. 17, T. 13N., R13E., U.M. PTD No. 93-203 Saturday January 30, 1994: I traveled to Amerada Hess North Star No. 3 ExploratiOn Well to witness the Diverter System Function Test and to conduct a Diverter System Inspection. As the attached Diverter Inspection Form indicates/with the exception of the alternate access road and the accumulator performance, the Diverter system was in compliance. The accumulator was serviced and retested before I departed the location and passed the retest. The Diverter Systems had a 30" Annular Preventer with one 16" Hydraulically Operated Full Opening Knife Valve and one 105' 16" Vent Line facing in a Southwesterly direction. Monday, January 31, 1994: I traveled back to the location this date to verify that the alternate access road had been installed. The access road was (~,z~ ~,- installed. Summary: ! witnessed the Diverter system function test and conducted a Diverter systems inspection. One Failure. Attachment E9WHA4BD.XLS ..... STATE OP ALASKA ,-. ALAS£ ~IL AND OAS CONSERVATION COMK SION Div©rtor Syst~u~s Inspection Report Operation: Drig Contractor; Parker Drilling Co. Rig No. Operator: Amerada Hess Oper. Rep.: Well Name: North Star No. 3 Rig Rep.: Location: Sec. 17 T. 13 N. R. 13 E. Development 141 PTD # Date: 1/30/94 Exploratory: Yes 93-203 Rig Ph. # 659-2585 John Salario Fred Hebeart Merdian Umiat MISC. INSPECTIONS: ACCUMULATOR SYSTEM: Location Gen.: Ok Well Sign: Ok Systems Pressure: 2900 psig Housekeeping: Ok (Gen.) Drlg. Rig: Ok Pressure After Closure: 1050 psig Reserve Pit: N/A Flar~ Pit: N/A 200 psi Attained After Closure: min. 44 sec. Systems Pressure Attained: 8 min. 53 sec. DIVERTER SYSTEM INSPECTION: Nitrogen Bottles: 4 @ 3,400 Divorter Size: 30 in. psig Divert Valve(s) Full Opening: Yes Valve(s) Auto & Simultaneous: Yes MUD SYSTEM INSPECTION: Light Alarm Vent Line(s) Size: 16 in. Trip Tank: OK OK Vent Line(s) Length: 105 ft. Mud Pits: OK OK Line(s) Bifurcated: No Flow Monitor: OK OK , ,, , , Line(s) Down Wind: Yes Line(s) Anchored: Yes GAS DETECTORS: Light Alarm !Turns Targeted / Long R~dius: N/A Methane OK OK . Hydrogen Sulfide: N/A N/A '~ NORTH Camp & SDS ~ i , / Pits, Pumps, Motors Alt. Access Rd./ Access Rd. . . , j Rig & Sub Base 30" Annular ---__/'%~.:'~ _~__.____~__,--~ aos' -___,__________~.._,~ 16' Full Opcning Pipe Shed Non Compliance Items 2 Repair Items Within 1 Day (s) And contact the Inspector @ 659-3607 Remarks: The Accumulator Failed the performance test, it was repaired and retested. Retest results , , System PSI =3,000, PSI After Closing 1,200. An Alt. Access Rd. had to be added for access to pad away from the vent lines. , , , Distribution orig. - Well File AOGCC REP.: c - Oper/Rep c - Database OPERATOR REP.: c - Trip Rpt FII~ EgWHA4BD.XL$ c - Inspector Doug Amos John Salario diverter.xls (Rev. 1/94) E & P SERVICES, INC. January 12, 1994 Mr. David Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ATT: Robert Crandall, Senior Petroleum Geologist RE: APD, Amerada Hess Corporation, Northstar No. 3 (Velocity Analysis) Dear Mr. Crandall: Please find attached three (3) copies of a velocity analysis and interval transit time versus depth plot for the above referenced well. This analysis has been prepared by Jeffe Ready of Amerada Hess Corporation to address 20 AAC 25.033 E(1) . A separate submittal will be made to address 20 AAC 25.061 (geophysical analysis of shallow gas) later this week. R. C. Gardner Agent for Amerada Hess Corporation RCG/j s Attachments cc: John Simon, Amerada Hess Corporation Jeffe Ready, Amerada Hess Corporation RECEIVED JAN 1 2 1994- Oil & Gas Cons. Commission Anchorage 715 L Street Anchorage, Alaska 99501 (907) 258-3446 FAX (907) 258-5557 VELOCITY ANALYSIS FOR OVERPRESSURE NORTHSTAR NO. 3 SF-84-401 The attached velocity plot from five (5) Vibrator points straddling the wellbore has only one significant break back in velocity. That decrease in velocity is at the surface and indicates the break between the permafrost and normal sediments. The generally higher velocity on VP 564 above 1.6 seconds could be due to poor data, near the end of the line. Analysis of nearby lines, however, suggest that it is probably part of an increase in velocity toward shore, due to thicker, high velocity permafrost. The Seabee Shale, the HRZ and the Kingak Shale are the thick shales in the section and significant geopressure would be expected there if it exists at all. No evidence for this is indicated on the velocity plots. Data from several thousand velocity gathers were analyzed in the course of our work. The green lines are the Northstar Unit data set. Velocity gathers were taken every 20 shotpoints (1640 feet) on these lines. No significant indication of overpressure was noticed. A strong set of multiples in the data could mask this effect, however, if it is present. RECEIVED ,J/~,[t! 'i 2 1994 & Gas Cor~s. Commission Anchorage TABLE OF DATA POINTS Line Number: SF-84-401 VP 564 Time(sec) RMS vel (ft/sec) 0.000 0.250 0.710 0.850 1.090 1.280 1.490 1.620 1.900 2.060 2.360 2.520 2.630 2.840 3.100 4.000 8310 7120 7460 7540 7580 7690 7900 7950 8430 859O 9040 9200 9380 9810 10840 11765 VP 540 Time ( sec ). 0.000 0.130 0.280 0.450 0.550 0.750 0.900 1.130 1.320 1.450 1.650 1.980 2.230 2.450 2..800 4.000 RMS vel (ft/sec) 7700 7050 6720 6640 6560 6900 7100 7260 7420 7560 7960 8440 8590 9300 9820 11605 VP 516 Time (sec) 0.000 0.280 0.510 0.850 1.010 1.120 1.400 1.660 1.770 2.000 2.260 2.390 2.460 2.770 2.970 4.000 RMS vel (ft/sec) 7940 6832 6620 6880 7130 7170 7550 7700 7780 8290 8430 8640 8930 9740 10200 11465 VP 492 Time(sec). 0.000 0.310 0.490 0.660 0.790 0.970 1.230 1.460 1.680 1.900 2.080 2.260 2.430 2.620 2.740 4.000 RMS vel (ft/sec) 7750 6590 6750 6860 7010 7140 7160 7450 7720 7950 8160 8310 8700 8970 9270 11613 , ECE!VED _,',.,~-:.~:i.',a. Oil & 13as Co[~s. Co~-ni'nissior, VP 468 Time ( sec ) 0.000 0.140 0.280 0.500 0.670 0.780 0.960 1.130 1.340 1.680 1.820 1.990 2.100 2.370 2.500 2.640 3.060 4.000 RMS vel (ft/sec) 7780 7070 6910 6640 6890 6950 7020 7160 7290 7690 7770 8070 8120 8500 8670 8880 9830 11,563 PECEIVEb .500 ] .500 2.000 2,500 Z 5,000 S.500 4.000 APPROXIMATE TD OF WELL LINE SF-84-401 CONTINENTAL SANDS AND SHALES. SEABEE SHALE 1.600 BASE HRZ 2.040 LKU 2.170 KINGAK 2,560 SAG RIVER 2,550 V~P SYMBOL s6, ® 540 X 516 V 492 /\ 468 ?.5 VELOCITY IN FT,/SEC. L~5O-O14-3~ O/VEL/SSR/O1/10/94/CS=l.~ 5 AM~IqADA HESS OORPORFITIO'~,~ JOHN V. SIMON, MANAGER OFFSHORE CONSTRUCTION 1201 LOUISIANA, SUITE 700 HOUSTON, TEXAS 77002 713) 752-5920 PHONE:FAX: (t13) 752-5657 January 11, 1994 Alaska Oil And Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Attn: Mr. Robert P. Crandall Re: AHC Northstar #3 APD Dear Mr. Crandall: In response to your December 28, 1993 letter and to satisfy the reporting requirements of 20 AAC 25.300, please be advised that Mr. R. A. Samonte of this office will generate our weekly status report for Northstar #3 operations subsequent to commencement. At this time, AHC anticipates well spud to occur the first week of February, 1994. Further, please be advised that the undersigned will be the primary contact for the Northstar #3 wel 1. Pertinent contact information is as follows: R. A. Samonte J. V. Simon (713) 752-5965 "~ · (713) 752-5920 "'~" '' Amerada Hess Corp. 1201 Louisiana, Suite 700 Houston, TX 77002 Please advise if any further information or action is required on this matter. Si ncerely, John V. Simon JVS:dld/O08 cc: R. A. Samonte B. Gardner, Fairweather E & P Services, Inc. RECEIVED JAN 1 2 1994 Ai~ska Oil & Gas Cons. Commission Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 December 28, 1993 John Simon, Mgr Offshore Prod & Constr Amerada Hess Corp 1201 Louisiana St Ste 700 Houston, TX 77002 Re: Exporatory well Northstar No. 3 Dear Mr Simon: This is to review the reporting requirements (20 AAC 25.300) associated with the approval of Amerada Hess' application for a permit to drill the Northstar No. 3 exploratory oil well. Please designate an Amerada Hess employee to generate the weekly status report. This report is required from the time the well is spudded until it is suspended or plugged and abandoned; it should be a generalized synopsis of the week's activities. This information is exclusively for the Commission's internal use, and will be kept strictly confidential. It can be phoned or faxed to me or, in my absence, to Blair Wondzell. Following suspension or abandonment of the Northstart No. 3 well, a member of your staff who is familiar with the project will be expected to coordinate the submission to the Commission of reports and materials as required by 20 AAC 25.070 and 20 AAC 25.071. If you have any questions regarding those regulations, please call me at 279-1433. Please advise me in writing of the name(s) of Amerada Hess contact(s) for this well. This information is required prior to approval of your application for permit to drill. I look forward to working with you and your staff. Yours very truly, Robert P Crandall ' Sr Petr Geologist /jo c: well file A:\RPCexpl-rpt ALASKA OIL AND GAS CONSERVATION COMMISSION January 21, 1994 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 R. C. Gardner, Agent Amerada Hess Corporation 1201 Louisiana St., Ste. 700 Houston, Texas 77002 Re: Northstar No. 3 Amerada Hess Corporation Permit No: 93-203 Sur. Loc. 502'FSL, 2140'FEL, Sec. 17, T13N, R13E, UM Btmhole Loc. 3235'FSL, 2889'FEL, Sec. 20, T13N, R13E, UM Dear Mr. Gardner: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Commissioner BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. AiViERADA HESS CORPORATION Houston, Texas Application for Permit to Drill Northstar No. 3 Exploration Well Beaufort Sea, Alaska Fairweather E & P Services, Inc. ! December, 1993 E & P SERVICES, INC. December 21, 1993 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: David Johnston, Chairman RE: Application for Permit to Drill Amerada Hess Corporation, Northstar No. 3 Gentlemen: Amerada Hess Corporation (AHC) submits herewith three copies of their Application for Permit to Drill the Northstar No. 3 exploration well in the Long Island area of the Beaufort Sea. The required $100 filing fee is attached. Bond information is included in the Application packets. An exemption to 20 AAC 25.055 (Drilling Units and Well Spacing) is required for this well. This application has previously been submitted and approved (AOGCC Conservation Order No. 322, November 4, 1993). Thank you for your consideration of this application. If you have any questions, please contact the undersigned at 258-3446 or John Simon, Manager of Offshore Production and Construction, AHC, at (71 3)752-5920. R.C. Gardner Agent for Amerada Hess Corporation RCG/js Attachment cc: John Simon, Amerada Hess Corporation RECEIVED DEC 23 199,~ Alaska uli & Gas Cons. C0r~rnJssJorl Anchorage 715 L Street Anchorage, Alaska 99501 (907) 258-3446 FAX (907) 258-5557 :SIAl b_ UI- ALAURA ? ~ ALA,SKA O,_ AND GAS CON,SERVATION CO,, ../lIS,SION PERMIT TO DRILL 20 AAC 25.005 I la. Type of work Drill I~ Redrill ~l lb. Type of well. Exploratory ~J StratigraphicTest [] Development Oil Re-Entry [] DeepenE}I Service [] Developement Gas [] Single Zone ILl Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Amerada Hess Corporation 37ft KB feet Northstar Unit 3. Address 1201 Louisiana St., Ste. 700 6. Property Designation No pool designated Houston, Texas 77002 ADL 355001 4. Location of well at surface 502ft FSL, 2140ft FEL 7. Unit or property Name 11. Type Bond(see 20AAC25.025) SEC 17, T13N, R13E, UM Northstar Unit Blanket-Statewide At top of productive interval (KupaTuk Target) 8. Well nu .tuber Number Seaboard Surety 3980ft FSL, 2670ft FEL, SEC 20, T13N, R13E, UM Northstar No. 3 No. 948498 At total depth 3235ft FSL, 2889ft FEL, 9. Approximate spud date Amount $200,000 SEC 20, T13N, R13E, UM February 1, 1994 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line SOHIO Long Island No. 1 2140 feet Approx. 22,500 feet 5744 acres 10,521ft MD 10~000ft TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 4000 feet Maximum hole angle24.70 Maximum surface 3790* psig At total depth (TVD) 4940'ir psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement w, , Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) Driven 30" 310 lb X-52 welded 14Oft Surface 140ft 140ft Driven to rain 100' below OOI 26" 20" 94 lb K-55 BTC 1000ft Surface [00Oft 1000ft 2000ft3+(permafrost cmt to 16" 13-3/8" 68 lb L-80 BTC 3900ft Surface 3900ft 3900ft 2300ft3 (cmt to surface) 12-1/4" 9-5/8". 47 lb L-80 BTC 8818ft Surface ~818ft 8452ft l125ft3 (cmt to 2550ft abow 8-1/2" 7" 26 lb N-80 LTC 2291ft B428ft 8051ft [0~521f lO~O00ft cmt volumes from caliper 19. To be completed for Redrill, Re-entry, and Deepen Operations. +15% + 150SX Present well condition summary Total depth: measured feet true vertical feet WWNote: Cement volumes reflect expected excess - See casing and cementing Effective depth: measured feet program for details. true vertical feet Casing Length Size Structural *Pressures based on normal gradient (0.465psi/ft) plus 0.029psi/ft. Safety factor, and assumed Conductor gas gradient of 0.115psi/ft. Example assumes Surface column of gas to surface from TD .(Wo~.~,ase). Intermediate RECE IVtU Production Liner DF_C 2 ~) Perforation depth' measured true vertical A~.~S~,~ ul[ & Gas Cons. Commission /mch0ra~e - 20. Attachments Filing fee E~ Property plat ~ BOP Sketch ~ DiverterSketch Fy,,] Drilling program ~ Drilling fluid program ..~ Timevs depth plot [] Refraction analysis [] Seabed report [] 20AAC25.050 requirements 21.1 hereby certify that the fore~trL;e and correct to the best of my knowledge Signed ~,f,~/'~~/,~".~d~C~g,..--~--*~ Title Agent, Amerada ,tess Corporation Date 12/21/93 Commission Use Only Permit Number Apl number J Approval date See cover letter ?'?- ~'-~3 50-- ~5.~-¢- ,-_-~.~ ~_. .~'¢ ~J ,/~ ,,~ (__ ~ C/ for other requirements Conditions of approval Samples required ~Yes [] No Mud Icg required ~1 Yes ~ No Hydrogen sulfide measures ~ Yes [] No Directional survey required ~Yes IZ} No Required working pressure for BOPE []2M; [] 3M; ,~SM; [] 10M; [] 15M Other: ORIGINAL SI~NED BY by order of Approved by RUSSELLA. DOUGLA~ Commissioner the commission Date ¢-%///~' urf. ) shoe: Form 10-401 Rev. 12-1-85 Submit in triplicate AlVlERADA HESS CORPORATION NORTHSTAR NO. 3 PROPERTY PLAT NW 1/4 I NE 1/4 SEC. 17 SEC, 17 sw SE SEC. 17 I S~ L 2140' - NW 1/4 ~1 267o' SEC. 20 2889' SW 1/4 SE 1/4 SEC. 20 SEC. 20 .-- SURFACE LOCATION KUPARUK TARGET LOCATION -~-~.. -F 3235 3960' T. 13 N. R. 1,3 E. UM. NOTE: An application for fhe required spacing exemption has been submitfed under separate cover. ENSR CONSULTING & ENGINEERING DRAWING: SDLOC DRAWN: SR C/SC: 1:2000 DISK: 775/,93 DATE: 10/,,11/93 CHECK: B.G. SURFACE AND DOWNHOLE LOCATIONS 0 1000 2000 SCALE IN FEET AMERADA HESS COR.PORATION NORTHSTAR NO. 3 PROJECT 0250-01 4-230 AIVIERADA HESS CORPORATION NORTHSTAR NO. 3 APD FORM 10-401 ' ' I l/' NORTHSTAR NO' 3 SURFACE I'OCATION; 502 FT. FSL, 2140 FT. FEL SEC. 17, T.13N., R.13E., UM 17 _____18__ / "~~~ KUPARUK TARGET LOCATION: ----__ SEC. 20, T.13N., R13E., UM BHL LOCATION: 3235 FT. FSL, 2889 FT. FEL, 19 20 SEC 20, T.13N., R.13E., UM 0 1 000 2000 SCALE IN METERS 0 5000 10,000 SCALE IN FEET OURCE: 0250-01 4/LSTAT 29 ENSR CONSULTING & ENGINEERING DRAWING: STABH DRAWN: SR C/SC: 1:1500 DISK: 775/9,3 DATE: ~0/11193 CHECK: 28 ~ I t I I 27 I 26 I I I ADL-555001 I I ! I 25 Pt~OPOSED SURFACE TARGET, AND BOTTOM HOLE LOCATIONS NORTHSTAR NO. 3 AMERADA HESS CORPORATION NORTHSTAR NO. 3 PROJECT 0250-01 4-2.50 AMERADA HESS CORPORATION NORTHSTAR NO. 3 BOND INFORIVIATION AIVtERADA HESS CORPORATION NORTHSTAR NO. 3 BOND INFORMATION Amerada maintain AOGCC, Hess Corporation has maintained and a Statewide Blanket drilling bond in in the amount of $200,000. continues to favor of the The bond is issued by Seaboard Surety and 948498. the bond number is i i \-~,,~ ~~,~. /NORTHSTAR. .~~'~m,~ UNIT AN~ERAD -----~! '---- ---~~ ~ m=~ aa i~,~ ~ ~ ~ m~ ~ ~ 0 1000 2000 l~ NORTHSTAR ISLAND ~ ~ SCALE IN METERS ^o,-~oo, I[ ~ ~ o sooo ~o,ooo F ''~'' AkI£RADA HE:SS A'£RADA H£SS~~N' '~iIImI~ IIBI IlI.~ll~'~l SOALE F~ FEF'T / l~l oCW~T~y[ ~ [] BOUNDARY [] I:[, HBU 7 SHELL [] ~ [ ADL-312.798 I~U RPHY ~! Y-ol~ [] · C B! ~- NORTHSTAR · ~ O ID LONG ~1 ~ ND, 3 HBO · \ I"'1.~,.., ~ ~ ISLAND ND, 1 .~ X SIAL .~.0 X o4~ LONG ~]~~~ / / .~ ~ = B Y/////~/~ ~ ~ ... ~ m · ' ~ //~//, ,v /// ' "'.'~/;'"~ ~,o, ~ ~~ ~ ~ ~ ' V I ADL-~770~ '~'L~N ~ ~.' ' . ~ I ~~~~ ~'L4No ~ i i General Location Map and Land Status in Vicinity of Amerada Hess Corporation Northstar No. 3 Exploration Well AIVIERADA HESS CORPORATION NORTHSTAR NO. 3 DIVERTER DIAGRAM FLOW LIN E ~ ~ FILLUP LINE /// I I I /\\\ R-95 RING GASKET 5" GATE VALVE 3" KILL LINE ~ 30" 500 PSI ANNULAR PREVENTER .D-ON FLANGE 4" HYDRAULIC VALVE (OPENS AUTOMATICALLY WHEN ANNULAR PREVENTER CLOSES) -- -- I [~TO SINGLEPOINT DISCHARGE 14" DIVERTER LINE ,30" MINIMUM 1" WALL STRUCTURAL CASINO ENSR CONSULTING & ENGINEERING DRAWING: DIVSY~;TM DRAWN: ABB/SR C/SC: 1:1 DISK: 775/93 DATE: 12/22/93 CHECK: B.G. 30" DIVERTER SYSTEM AMERADA HESS CORPORATION NORTHSTAR NO. 3 PROJECT 0250-01 4-250 SINGLE POINT DISCHARGE - DOWNWIND TO'PREVAILING WIND DIRECTION WELLHEAD FLANGE AND 50"ANNULAR PREVENTER 14" DIVERTER DISCHARGE LINE 14" HYDRAULIC VALVE (NORMALLY CLOSED) OPENS AUTOMATICALLY WHEN ANNULAR PREVENTER IS CLOSED. "'"' ENSR CONSULTING &: ENGINEERING DRAWING: DIV2 DRAWN: ABB/SR C/SC: 1.0 DISK: 775/9,3 DATE: 10/11/93 CHECK: B.G, DIVERTER DISCHARGE LINE AND VALVE LAYOUT PARKER DRILLING COMPANY RIG 141 AMERADA HESS CORPORATION NORTHSTAR NO. 5 PROJECT 0250-014--250 AIVIERADA HESS CORPORATION NORTHSTAR NO. 3 BOP DIAGRAM FILLUP LINE R-75 RING GASKET R-74 RING GASKET ~-------'"'~1 I 2,000 PSI WP ANNULAR PREVENTER I I 5000 PSI WP PIPE RAMS DOUBLE STUDDED ADAPTER (DSA) I I 5000 PSI WP BLIND RAMS / ,.._.[ I I ~-~~R-74 RING GASKET DOUBLE STUDDED ADAPTER vi --]-'"--"------R-75 RING GASKET I I I I I I H.C.R. F-~[T~ ~~DRILLING,,, ' , I I CHECK H.C.R. GATE VALVE 5" CHOKE LINE TO .5,000 PSI WP CHOKE MANIFOLD VALVE VALVE I I_.,~----~- R-74 RING GASKET '~"~ DOUBLE STUDDED ADAPTER (DSA) I I '~-"'~"'"-- R-75 RING GASKET GATE [I~~21 1{%W2'000~1-m VALVE CS'G HEAD ('"~-J'~.. BULL PLUG 1 , I "!! II:,l,l,l!llll'il 20" 94#, K-55 BTC CONDUCTOR PIPE TO 1000' ""' I ENSR CONSULTING & .ENGINEERING DRAWING, BBBPg'~K DRAWN, ABB/SR I C/SC, 1,1 ])ISK: 775/93 I DATE, 12/22/93 CHECK, 3.G. I 20" DOUBLE RAM BOP STACK WITH ANNULAR PREVENTER AMERADA HESS CORPORATION NORTHSTAR NO. PROJECT 0250-01 4-250 FILLUP LINE I 5,000 PSI WP ANNULAR PREVENTER ---~.-FLO~VLIN E BX 160 RING GASKET ----------_____~_I BX 160 RING GASKET I BX 160 RING GASKET I 5,000 PSI WP PIPE RAMS I I ,, KILL LINE ~ ~ ~,,,~q~__~DRILLING ( 5.000 PSI W~ PIPE RAMS ) BX 160 RING GASKET R-75 RING GASKET 15" CHOKE LINE TO 5,000 PSI WP CHOKE MANIFOLD I SECTION 21 1/4" 2,000 PSI FLANGE ENSR CONSULTING & ENGINEERING DRA~/ING: 3RAMSTK3 I)RA~/N: A]~B/SR I C/SC, 1,1 I)ISK: 775/93 I DATE, 18/82/93 CHECK: B.G. I 13 5/8" THREE RAM BOP :STACK WITH ANNULAR PREVENTER AMERADA HESS CORPORATION NORTHSTAR NO..3 PROJECT 0250-014-2,30 BLOWOUT PREVENTION EQUIPMENT PARKER DRILLING COMPANY, RIG 141 3 ea 1 ea 1 ea 1 ea 1 ea 1 ea 1 lot 13~5/8" x 5,000 psi wp ram type preventers (Hydril) 13-5/8" x 5,000 psi wp annular preventer (Hydril) 13-5/8" x 5,000 psi wp drilling spool with 2 ea 3-1/8" side outlets (choke and kill), HCR and manual valves on both choke and kill lines BOP accumulator, Koomey Model T-151003S, 3,000 psi with 12 bottles, 180 gallons, and one 80-gallon Valvcon accumulator. Accumulator pump, Gardner- Denver Triplex, Model PQ 172, air pump Model G7E. Eight bottles nitrogen backup Koomey, 6 station, remote control panel Schaffer automatic choke 3", 10,000 lb with control choke panel Hydraulic pipe and fittings from manifold to BOP stack AIVIERADA HESS CORPORATION NORTHSTAR NO. 3 DRILLING PROGRAM 1.0 AMERADA HESS CORPORATION NORTHSTAR NO. 3 EXPLORATION WELL (DIRECTIONAL HOLE) . PROGRAM BASIS INTRODUCTION AND DESCRIPTION OF PROJECT The Northstar No. 3 Exploration Well project consists of drilling an expendable exploratory well to approximately 10,521 feet measured depth from a surface location on an unnamed gravel island (ice drilling pad) in Section 17, T13N, R13E, UM, Beaufort Sea, Alaska. The well is programmed to be a directional hole. The principal objective is the evaluation of the Kuparuk "C" sand. The Kuparuk "A" sand is a secondary objective. The location of the primary target is the mid-point of the Kuparuk "C" zone. 2.0 HOLE SIZES, CASING, AND CASING POINTS Hole Size Casing Description Programmed Casing Points Driven 26" 17-1/2" 12-1/4" 8-1/2" 3.0 DRILLING RIG 30", 310 lb, X-52, welded 20", 94 lb, K-55, BTC 13-3/8", 68 lb, L-80, BTC 9-5/8", 47 lb, L-80, BTC 7", 26 lb, N-80, LTC Driven to minimum of 100' below original island surface 1,000' KB (1,000' TVD) 3,900' KB (3,900' TVD) 8,818' KB (8,452' TVD) 10,521' KB (10,000' TVD) liner Parker Drilling Company Rig 141 (OIME SL-2000) will be used to drill this well. A rig description is included in this APD submittal. 4.0 MAXIMUM ANTICIPATED PRESSURES The maximum anticipated pressure at TD (10,521' MD - 10,000' TVD) is 4,940 psi based on a normal gradient of 0.465 psi/ft plus a 0.029 psi/ft safety factor. Maximum anticipated surface pressure (worst case) is 3,790 psi based on a column of gas to the surface from TD, and an assumed gas gradient of 0.115 psi/ff. -1- The maximum anticipated mud weight is 10.0 to 10.2 ppg. 5.0 EXPECTED FORMATION TOPS AND KEY DEPTHS Formation VSS Depth Prince Creek/Schrader Bluff Seabee Shale Lower Seabee Silts HRZ Marker Top Kuparuk "C" Mid-Point Kuparuk "C" (target) Top Kuparuk "A" TD 6,0 DISPOSAL OF DRILLING FLUIDS MD TVD -4,600 4,642 4,637 -6,400 6,600 6,437 -7,700 8,031 7,737 -8,200 8,237 8,501 -8,380' 8,779 8,417 -8,675 9,104 8,712 -9,150 9,626 9,187 -9,963 10,521 10,000 Amerada Hess Corporation plans to dispose of drilling wastes_ ~ acc~o~_dance with NPDES Permit No. AKG284115, issued August 12, 1993. As a backup, the~, x ,@-,,),., annulus may be used for injection disposal. A General Wastewater Disposal Permit has been obtained from ADEC covering this annular injection activity. 7.0 PLAN OF OPERATIONS The Plan of Operations (Executive Summary) included herewith describes the key elements of the Northstar No. 3 project and gives a schedule of activities. -2- 1 PARKER DRILLING COMPANY -RIG 141 Pump 1.1 Data and Specifications #1 Pump: Engine/Motor: Liner Sizes Available: Operating Pressures: Maximum Operating SPM: Minimum Operating SPM: Maximum Deliverable HP: Pump Efficiency: 90% Make: Emsco Make: EMD Model: FB-1300 HP: 1,300 Model: D79MB4 HP: 1,300 6 in. 5-1/2 in. 3,400 psi 4,000 psi 120 SPM 120 SPM 35 SPM 35 SPM 1,300 HP 1,300 HP Mud Pump Efficiency: 90% 1.2 #2 Pump: Make: Emsco Engine/Motor: Make: EMD Liner Sizes Available: Operating Pressures: Maximum Operating SPM: Minimum Operating SPM: Maximum Deliverable HP: Pump Efficiency: 90% Model: FB-1300 HP: 1,300 Model: D79MB4 HP: 1,300 6 in. 5-1/2 in. 3,400 psi 4,000 psi 120 SPM 120 SPM 35 SPM 35 SPM 1,300 HP Mud Pump Efficiency: 90% 2.2 2.3 2.4 2.5 Mud System Data and Specifications 2.1 Number of Mud Pits: 3 Volume of each mud pit: 447 bbl No. of sections in each' mud pit: Trip Tank Description: Pill Tank Description: Number of surface guns on pits: Derrick Flowline Cleaners: No: 3 ea 2.6 Desander: Make: Pioneer Cones: Desander Pump: 2.7 Rated Throughput: Desilter or Mud Cleaner: Desilter Pump: Cones: Rated Throughput: Total Volume: 925 bbl 447 bbl 448 bbl 30 bbl 6 1 2 No. 2 ea, Volume: 32 bbl each No. 1 ea, Volume: 36 bbl 8-Brandt pit mixers Make: Derrick Model: FIo-Line Cleaner, Single Model: S2-12 Number: 2 Size: 12 in. Make: Mission, Model: Magnum Size: 5" x 6"x 11" 1,000 GPM at 10 ppg Make: Tri-FIo Model: Low Profile Make: Mission Model: Magnum Size: 5" x 6" x 11" Number: 16 Size: 4 in. 1,000 GPM at 10 ppg -1- 1 1 2.8 2.9 2.10 Centrifuge: Cellar Jet Pump: Reserve Pit Transfer pUmp: MaXimum Operating Pressure: MaXimum Discharge Rate: Efficiency of Annular Pump Motor: Make: Swaco GPM: 100 Marlo - 15 HP Make: Mission HP: 60 60 psi 500 GPM 90% - Rig Pump Model: 518 Volume: 100 CPM Model: Magnum Traveling Assembly Data and Capacities 3.1 Swivel' Make: Emsco 3.2 Block: 3.3 Hook: 3,4 3.5 3.6 Drilling Line: No: 1 Size: 1-1/4" Type: EIPS-iWC Sheave Number and Size: 5 ea - 42" Traveling Equipment's Weakest Point: Bails Model: LB-400 Capacity: 800 M lb Make: Ideco Model: UTB360 Capacity: 720 M lb MaXimum Lines: 10 Elevators MaXimum Load Capacity: 700 M lb Make: Ideco Model: UTB360 Capacity: 720 M lb Bail Lengths Available and Load Capacity: 130"x 3-3/16", 600 M lb Capacity: 648 M lb No. of Lines: 10 Power 4.1 4,2 4.3 Generating Data and Capabilities SCR Rig: SCR: Make: Ross Hill SCR Output: Total: 4,800 Amps MaXimum Operating Limit of SCR in KW: Maximum Power Available to Drawworks: Power Available to Pumps: Maximum Rotary RPM Available: Deliverable HP to Rotary: Maximum Deliverable Rotary Torque (ft. lb)' Prime Movers: Make: Caterpillar HP Per Unit: 1,200 Generators: Make: Kato Generator Unit Efficiency: Available KW/Unit: Total KW Available: TOtal HP Available: Model: 1200 No. of Bays: 3 DC 4,825 HP 1,200 KW @ 750 UDC 3,200 Amps 3,216 HP 3,200 Amps 3,216 HP 150 Maximum 1,000 35,000 Number: 3 Total HP Available: 3,600 Number: 3 95% 1,030 3,090 4,140 HP/Unit: 1,300 Available KVA/Unit: 1,287 Total KVA Available: 3,861 Power Factor of Units: .8% -2- 4.4 4.5 4.6 Additional Power Information: Maximum Deliverable HP to Rotary and Drawworks When Pumping 750 gpm at 3,000 psi Maximum Rotary HP: 1,608 Maximum Drawworks Hp: 1,608 Efficiency of Rotary Table Motor: 90% Efficiency of Drawworks Motor: 90% Drawworks: Make: OIME HP Rating: 2,000 Rig Capacities: Derrick Capacity: 750,000 lb Substructure Capacity: 750,000 lb Maximum Setback Load: 488,000 lb Maximum Hookload: 750,000 lb Maximum Combination Setback and Hookload' 750,000 lb Working Height (Ground to Rotary Beams)' 23' (Ground to Top of KB): 29 ' 6" (Ground to Top of Drill Floor): 28' 1 B.O.P.E. Data 5.1 Diverter System' Annular Preventer: Diverter Spool: No. Outlets: #1 #2 Diverter Valves #1: 5.2 Make: Shaffer Model: Bolted Bore: 20" W.P.: 2M Bore: 20" W.P.: 2M 1 Size: 14" W.P.: 150# Size: W.P.: Make: Familian, Model: KNIFE Hydraulic Diverter Lines(s): Size: 14", Flanged Series: MSD 21-1/4" Flg. Sz: Hub 21-1/4" Fig. Sz: Hub 21-1/4" Series: 15016 Length 120' Blowout Preventers: Annular Preventer: Make: Shaffer Model: GK Series: 1,500 Bore: 13-5/8" W.P.: 5M Fig. Sz: 13-5/8" Single Ram(s): Make: Hydril Model: Manual Lock Series: 1,500 Bore: 13-5/8" W.P.: 5M Fig. Sz: 13-5/8" Double Ram: Make: Hydril Model: Manual Lock Series: 1,500 Bore: 13-5/8" W.P.: 5M Fig. Sz: 13-5/8" Drilling Spool: Bore: 13-5/8" W.P.: 5M Fig. Sz: 13-5/8" No. Outlets: 2 #1 Size: 3-1/8" W.P.: 5M #2 Size: 3-1/8" W.P.: 5M -3- 5.3 5.4 5.5 5.6 Choke Line: Hydraulic Valve: Choke Line Valve: Make: OCT Bore: 3-1/8'' Make: OCT Kill Line Valve(s): Bore: 3-1/8" Check Valve: Make: LYND Bore: 3-1/8" Choke and Kill Manifold: Inlet Line: Size: 3-1/8" Choke Number: No: 2 ea Make: Shaffer Model: DB Bore: 3-1/8" W.P.: 5M Actuator Make: Shaffer Model: HYD Model: 75 W.P.: 5M Model: 75 W.P.: 5M Model: Check W.P.: 5M Series: HCR Fig. Sz: 3-1/8" W.P. 3M Series: Gate Fig. Sz: 3-1/8" Series: Gate Fig. Sz: 3-1/8" Series: Gate Fig. Sz: 3-1/8" Flange: 3-1/8" 5M Size: 3-1/8" W.P.: 5M/10/M Hook up for remote hydraulic choke available? Yes Handwheel Valves: No: 9 Make: Shaffer Number of lines exiting manifold: 3 Straight/thru Panic Line: Gas Buster/Mud Gas Separator: Size: 3-1/8" Model: Type B W.P.' 5M Size: 3", Anchored Height: 17 ff Inlet Line Size: 6" Gas Exit Line Size: 6" Mud Exit Line Size: 4" W.P.: 100 psi Height above G.L.: 41 ft Accumulator is Drill Floor Valves: TIW type full opening lower Kelly valve: TIW type full opening valve on drill floor: With hand wrenches: Inside BOP valve on drill floor: X-overs on floor safety valves to drill collars: Closing Unit Accumulator: Closing unit equipped with a minimum of six (6) stations. Width: 48" capable of closing all ram preventers and the annular preventer, opening the hydraulic choke line valve while maintaining a minimum of 200 psi over precharge pressure. Make of Unit: Koomey Model: T-151003S Distance from wellbore: 60' No. of Stations: 5 Location of remote unit: Rig Floor -4- RECEIVED DEC U~I .& Gas Cor~s. Commlssl.on 6, Rig Electrical Loads Total maximum rig electrical load, excluding drawworks, rotary, and mud . pumps: 500 KW Other electrical motors in operation while drilling, including centrifuges, boilers, shakers, etc. Motor Type Purpose HP Rating Efficiency nduction nduction nduction nduction nduction nduction Induction · .Induction Shale Shakers 1-1/2 x 4 95% Agitators 10 x 7 95% Water Pumps 20 x 2 95% Fuel Pumps 20 x 2 95% Charger Pumps 100 x 2 95% Mixer Pumps 100 x 2 95% Degasser Pump 60 x 2 95% Desander Pump 60 x 2 95% m Drill String 7.1 Drill Pipe: Size/Grade: 5"/E 5"/G Footage: 4,000 6,000 Wt/Ft: 19.50 19.50 Range: II II Connection: 4-1/2" IF 4-1/2" IF Hardbanding Grit: Fine Fine Class: Premium Premium 7.2 Drill Collars: Size/Grade: 8" 6.25"- 6.5" Footage: 250' 360' OD: 8" + 1/4" 6.5" + 1/4" ID: 2-13/16" 2-1/2" -Connection: 6-5/8" Req. 4-1/2" X.H. 5"/S 5" HWDP 4,000 9OO 19.50 49.60 II II 4-1/2" IF 4-1/2" None Course Premium Premium -5- SUMMARY DRILLING PROGNOSIS , . . . . . . . 10. 11. Mobilize and rig up Parker Drilling Company Rig 141 over previously set 10ft by 10ft insulated corrugated steel cellar and 30" structural casing (driven). 30"casing will have a 30" flange installed prior to rig mobilization. Perform complete rig and support facilities inspection. Correct any problems before accepting rig. - Nipple up 30" 500 psi diverter system as per diagram in Operating Procedures manual. Notify AOGCC sufficiently in advance of anticipated spud so AOGCC representative can witness functional test of diverter system, if necessary. Rig up mud loggers prior to spud: Pick up 16" bit and BHA. Wash out structural pipe. Drill 16" pilot hole to 1,000 ft M.D., maintain straight hole conditions. (a) Run all solids control equipment. Control drilling rate so as to not exceed capacity of solids control equipment to handle drilled solids. (b) Maintain lowest practicable mud weight as per mud program. (c) Maintain optimum hydraulics. Condition hole and run openhole wireline logs as directed. Open 16" hole to 26". Observe same precautions as in paragraph 6 above. Circulate and condition mud to run casing. Run and cement to surface 20", 94 lb, K-55 BTC casing as per detailed program in Operating Procedures manual. (a) Use float shoe and stab-in float collar. (b) Use permafrost cement as per cementing program. Maintain slurry weights as Iow as practicable. (c) If slurry will not circulate to surface after pumping 100 percent excess, do top job as directed. WOC as directed. Nipple down diverter system. Cut off 30" conductor at base of cellar. Install 20" SOW X 21-1/4" 2M casing head and 21-1/4" 2,000 psi wp x 20-3/4" 3,000 psi wp double studded adapter flange. Nipple up SRRA 3,000psi BOP stack in · accordance with Operating Procedures manual. AOGCC representative must witness test of BOPE prior to drill out of 20" shoe. (a) Test casing head to 260 psi, and test BOPs to 250/1500 psi minimum. (b) Pick up 16" Bit and BHA. Trip in hole and pressure test casing to 1,500 psi before drilling out float shoe. Drill out float shoe with 16" bit, clean out rathole, if any, and drill 10 ft of new hole. 12. 14. 15. 16. 17. 18. 19. 20. 21. 22. Drill 16" hole to 3900 ft M.D. Maintain straight hole conditions. (a) Run all solids control equipment. Control drilling rate so as to not exceed capacity of solids control equipment. (b) Maintain lowest practicable mud weight as per mud program. (c) Maintain optimum hydraulics. Upon reaching 3,900 ft, make wiPer trip and condition hole for wireline logs. Log as directed. Make wiper trip and condition hole for casing. Run and cement 13-3/8", 68 lb, L-80, BTC casing to maximum depth as per detailed program in Operating Procedures manual. Cement casing to surface. (a) Use top and bottom .wiper plugs, float collar, and float shoe. (b) If no cement returns after pumping and displacing calculated excess, do top job as directed. (c) Use friction reducing and retarding agents to provide 4-hour thickening time. WOC as directed. Land casing in 20"SOW x 21-1/4" 2,000 psi casing head. Install 13-5/8" 5,000 psi wp x 21-1/4" 2,000 psi wp casing spool and install and test 5,000 psi BOP equipment. (a) Run multi-shot gyro inside 13-3/8" casing while nippling up BOP's. (b) Run walkway VSP as directed. Run cement evaluation/cement bond log. Squeeze as directed, if necessary. Run in hole with 12-1/4" bit and BHA. Pressure test casing to 2,000 psi before drilling out float collar. Drill out float collar and float shoe with 12-1/4" bit, clean out any rathole and drill 10 ft of new hole. Perform formation competency test to 12.5 ppg equivalent-go slow! Drill 12-1/4" to 4,000' (kick-off point). Circulate and condition mud. Pull out of hole. Pick up 12-1/4"x 7-3/4" steerable system with MWD. Trip in hole. Drill 12-1/4" hole building 2°/100'to 24.7° at 5235' MD, (5197'TVD). Maintain 24.7°to 8818' MD, (8452' TVD) (_+50' below bottom of HRZ marker). Circulate and condition mud. Pull out of hole. (a) Observe same precautions as in Paragraph 12 above. Upon reaching 8818 ft, make wiper trip and condition hole for wireline logs. Log as directed. Run and cement 9-5/8", 47 lb, L-80, BTC casing to maximum depth as per detailed program in Operating Procedures manual. (a) Use top and bottom wiper plugs, float collar, and float shoe. (b) Using slurry volumes calculated from caliper log plus 15 percent, place sufficient slurry for a minimum 2,550 ft fill-up above casing shoe. (c) Use friction reducing and retarding agents to provide 7-hour thickening time. 23. 24. 25. 26. 27. 28. 29. 30. 31. 33. WOC as directed. ~and casing and install 13-5/8,. 5,000 psi x 11" 5,000 psi tubing head. Nipple up 11" 5,000 psi x 13-5/8" 5,000 double-studded adapter and reinstall BOP. Make complete BOPE test after nipple up. (a) Test tubing head to 2380 psi. Run walkway VSP as directed. Run cement evaluation/cement bond log to bottom of free pipe (top of cement). .. Squeeze as directed, if necessary. Run in hole with 8-1/2" bit. Pressure test casing to 3,000 psi before drilling out float collar. Drill out .float collar and float shoe. Clean out any rathole and drill 10 ft of new hole. Perform leak-off test. Expect approximate 14.0 ppg equivalent. Drill 8-1/2" hole maintaining 24.7° to top of Kuparu~, "C" Sand (estimated to be at 8857' MD, 8487' TVD). Circulate and condition mud. Pull out of hole. Pick up 8-1/2" coring assembly and trip in hole. Core entire Kuparuk interval (+_680' TVD, _750' MD). Pick up 8-1/2" hole opener and BHA. Trip in hole to 8857'. Ream hole through cored interval. Circulate and condition mud. Pull out of hole. Directionally drill 8-1/2" hole to 10,521 ft MD maintaining 24.7° as per directional program. (a) Run all solids control equipment. (b) Maintain optimum drilling fluid properties and lowest practicable mud weight in accordance with mud program. (c) Maintain optimum hydraulics. Upon reaching 10,521 ft or other depth as directed, make wiper trip to shoe of 9-5/8" casing. Condition hole and mud for open hole logs. Log as directed, and run walkway VSP as directed. A decision as to running a 7" liner and testing will be made after an analysis of log, conventional and sidewall core data. If a liner is run, it will be 26 lb, N-80, LTC and have a 400-ft lap inside the 9-5/8" casing. Cement volumes will be determined from the caliper log plus 15 percent plus 150 sacks. (a) A testing program will be issued based on an analysis of the geological data. (b) A supplementary program will be issued covering P&A procedure. This drilling prognosis is in summary form. A detailed Wellsite Operations manual and Operational Plan will be issued prior to the startup of drilling operations. PLAN OF OPERATIONS (EXECUTIVE SUMMARY) AMERADA HESS CORPORATION NORTHSTAR NO. 3 EXPLORATION WELL 1.0 INTRODUCTION AND STATEMENT OF PURPOSE The project consists of drilling one or more exploratory wells to evaluate the oil and gas Potential of Amerada Hess Corporation operated leases in the south part'of the Northstar Unit area. The initial exploratory well, hereinafter called Northstar No. 3, will be drilled on State of Alaska Oil and Gas Lease No. ADL 355001 in State waters in the Long Island area in the - Beaufort Sea. The Northstar No. 3 well will be directionally drilled to sufficient depth to test the Kuparuk formation. After completing the evaluation of the Kuparuk objective, the operator may elect to plug back and sidetrack the Well to a different bottom hole location to test the Ivishak formation. If this option is selected, the operator will file a separate APD covering this activity. -. This drilling activity will take place entirely within the boundaries of the State-approved Northstar Unit and is scheduled for the 1992-1993 winter drilling season. A bermed ice drilling pad will be constructed on a natural barrier island near the eastern end of Long Island. The well will be expendable and plugged and abandoned, regardless of any commerciality demonstrated during testing. Additional exploration/delineation drilling in the area is dependent on the outcome of the Northstar No. 3 well and further review of geologic and geophysical data. Amerada Hess Corporation (AHC) of HOuston, Texas, acting for itself and partners is planning to operate these wells and will be the permittee of record. The activities proposed in this Plan of Operations conform with Alaska's Coastal Zone Management Program and will be conducted in a manner consistent with the terms of permits that have been obtained by the operator. 2.0 DESCRIPTION OF THE AREA COVERED BY THE NORTHSTAR UNIT The Northstar Unit lies entirely offshore, north of the Prudhoe Bay Oil Field. The unit area includes both OCS and State Tidelands leases. A group of barrier islands trend northwest- southeast through the southern part of the Unit Area and are identified on published charts as the "Return Islands." The islands are of Iow relief (< 1 to 4 feet above sea level) and form the northern boundary of Gwydyr Bay. Water depths in Gwydyr Bay range between 1 and 8 feet and winter ice is typically grounded on the seafloor. Water depths increase northward of the Return Islands with depths in excess of 40 feet being typical of the area near the northern boundary of the Unit Area. Two artificial drilling islands have been constructed in the Unit Area north of the Return Islands. Exploratory wells drilled fr°m these artificial islands (Seal Island on the east and Northstar Island on the west) have confirmed an accumulation of oil in the Ivishak formation. -1- Figure 1 shows the geographic setting of the Northstar No. 3 exploration program and outlines the lands included in the Northstar Unit. 3.0 SITE LOCATION AND DESCRIPTION The Northstar No. 3 well will be drilled from a surface location situated on a small unnamed gravel island approximately 1,400 feet east of the eastern tip of Long Island, in the Return Islands chain. The Return Islands lie approximately 20.5 miles northwest of Deadhorse, Alaska. The drillsite lies within the boundaries of Alaska State Oil and Gas Lease No. ADL 355001. Ice roads will be used for access to the drilling location. The ice drilling pad is designed to accommodate a North Slope land drilling rig (Parker Rig 141). A reserve pit will not be used at the drillsite. At the conclusion of drilling operations, all equipment will be removed from the site, and all waste materials and trash will be disposed of in an approved manner. The ice pad will be left clean and all ice road markers recovered. When the ice pad melts in summer, the drilling location will be revisited to recover the well cellar and restore the island surface to original condition. This work will be carried out either from a barge or will be helicopter supported. In either case, the work will be coordinated with the U.S. Fish and Wildlife Service (USF&WS) and the Alaska Department of Fish and Game (ADF&G) to minimize any impacts on nesting waterfowl on the islands. 4.0 PROJECT SCHEDULE The project schedule is shown in Figure 2. The startup date for field operations is dependent on how early ice road construction to the site can be started. Based on historical perspective, this is estimated to be in early to mid-December 1993. 5.0 DRILLING PROGNOSIS The well will be drilled to a total depth of approximately 10,521 ft MD. Total vertical depth at TD will be approximately 10,000 ft. Maximum hole angle will be approximately 25 degrees and horizontal displacement will approach 2,652 feet. Preliminary directional information is contained in the Directional Information section of this APD. Hole sizes and casing data has been described earlier herein. -2- B EA UF O t~ T SEA THETIS 0 30 60 SCALE IN NAUTICAL MILES 0250-014 AMERADA HESS 9/11/92 Figure 1. PRUDHOE Geographic Setting of Northstar Unit Area. Figure 2. Project Schedule-Northstar No. 3 Exploratory Well 1992 1993 1994 Task Name Aug Sep' Oct Nov Dec Jan Feb Mar Apr May Jun Jul' Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug S Permit Applications Preparation ~ [] Permit Review by, Agencies - ;Engineering & Project Planning _ _ II _ _ ' ContraCting for Services ' ' Archaeological & Biological Surveys [] ~ Ice Road & Ddlling Pad Construction ===~ Rig Mobilization lw Drilling & Possible Testing a~ ~ P&A and Demobilize Equipment from Site . i · Monitor Breakup ~~=~ Final Site Cleanup and Restoration N · , Printed: Oct/11/1993 Page 1 5.1 Wellhead and BOP Equipment .- The following wellhead components and.associated BOP equipment will be utilized. Casing Size Wellhead. Section BOPE Description 30" Structural - 20" Conductor 13-3/8" Surface 9-5/8" Intermediate 30" Weld-on flange 21-1/4" SOW casing head, 2,000 psi wp 13-5/8" x 20" casing spool 13-5/8" x 11" 5,000 psi tubing spool 29-1/2", 500 psi wp diverter 20" 3,000 psi wp BOP, SRRA 13-5/8" 5,000 psi wp BOP, RSRRA DSA to 13-5/8" 5,000 psi wp BOP, RSRRA 7-5/8" Liner As above As above 5.2 Drilling Fluid Program A drilling fluid system containing polymers and co-polymers of cellulose, acrylamide-AMPS and glycol with specialty additives, including surfactants, will be used. This is a water-based system that has the properties required to drill a deviated hole over the required course deviation. A detailed drilling fluid program is included in this APD. 5.3 Formation Evaluation A mud logging unit will be employed for cuttings and drilling fluid analysis from spud to TD. Open hole wireline logs will be run at each casing point. The wireline logging program will be kept flexible to accommodate the specific formation evaluation objectives of the operator. The following logging program is representative of the wireline log data desired. Conductor Hole: 20" casing point (approximately 1,000 ft MD to shoe of 30" structural casing. Run 1' Dual Induction/Spontaneous Potential/Gamma Ray/ Borehole Compensated Sonic -5- .. Surface Hole: · 13-3/8" casing point (approximately 3,900 ft MD to 20" casing shoe. Run 1: Run 2: Dual Induction/Spontaneous Potential/Gamma Ray/ Borehole Compensated Sonic Litho DensitY/Compensated Neutron / Caliper/Gamma Ray Intermediate Hole: 9-5/8" casing point (approximately 8,818 ft MD to 13-3/8" casing shoe. Run 1: Run 2: Dual Induction/Spontaneous Potential/Gamma Ray/ Borehole Compensated Sonic Litho Density/Compensated Neutron/Caliper/Gamma Ray Run 3: Dipmeter (SHDT) Walkaway VSP (after casing) Total Depth: TD back to 9-5/8" casing shoe. Run 1: Dual Induction/Spontaneous Potential/Gamma Ray/ Borehole Compensated Sonic Run 2: Litho Density/Compensated Neutron / Caliper/Gamma Ray Run 3: EPT/Microlog Run 4: Formation Micro Scanner or Dipmeter Run 5: Repeat Formation Tester Run 6: Sidewall Cores (= 90) Walkaway VSP (after liner) 5.3.1 Conventional Cores Conventional cores may be cut in intervals of interest. The amount of actual coring attempted is dependent upon drilling progress and lithology penetrated and is at the discretion of the operator. Portions of any reservoir section recovered will be preserved for further analysis. The operator plans to core the Kuparuk "C" section, subject to downhole conditions. -6- 6.0 QUALIFICATIONS OF KEY PERSONNEL All wellsite operations will be under the direct' supervision of the on-site drilling foreman or engineer. A wellsite geologist will also be on-site to supervise mud logging, sample collection, and core recovery. Both the engineer and the geologist will assure quality control in wireline logging operations. Additional operations personnel will be at the wellsite as specific specialized activities dictate. Daily reports will be transmitted to the offices of AHC and frequent telephone and data fax communications will monitor activities at the wellsite. 6.1 Training and Drills Company and contractor personnel involved directly in drilling operations (including rotary helpers and derrickmen) will be trained in well control methods and in detection of abnormal pressures. Such training will be completed in approved company or industry schools before drilling is commenced. Blowout prevention drills will also be conducted as required by the AC)GCC. A list of personnel and their completed training will be maintained on the drilling rig and will be available on request. ~-. All AHC supervisory drilling personnel will be MMS certified as operator's representatives both in surface and subsea applications. All personnel engaged on the project will receive Oil Spill Containment and Cleanup training as specified in the Oil Discharge Prevention and Contingency Plan. In addition, all project supervisory and managerial personnel will receive Environmental Orientation Training as required by State of Alaska Oil and Gas Lease Sale No. 39 stipulations. Fire Drills: Procedures for emergencies such as fires will be posted on the rig and in the crew quarters. Specific emergency responsibilities for crew members will also be posted at appropriate and conspicuous places on the drilling rig. Fire, well kick, and H2S drills will be conducted periodically for all crew members. Safety Meetings: Safety meetings will be conducted periodically to make crews aware of safety procedures and to review potential sources of accidents, and the means of preventing them. Accident causes and corrective measures to be taken in the event of accidents will be discussed. An EMT/Radio Operator/Environmental Monitor person will be on the rig at all times and will coordinate the safety program with supervisory personnel. -7- Fuel Transfers: Fuel quantities will be' monitored daily. Fuel transfers from trucks to the rig-storage tanks are estimated to occur bi-weekly. A fuel transfer plan has been developed which addresses fuel flow diagrams, valving sequences, safety precautions, and transfer procedures. One man will have the responsibility for all fuel transfers and he will be thoroughly trained in the above procedures. No fuel transfers will be' made without this responsible party in attendance. 7.0 EMERGENCY SITUATIONS PROVISIONS AND CRITICAL OPERATIONS Plans for reacting to emerg ..eccy situations are covered in this section, as are critical operations and curtailment plans. Any drilling operation will be critical when the weather conditions approach the design limits of the drilling rig or can prevent emergency support equipment from reaching the rig. Potential critical operations are drilling below threshold depth, coring, running casing, logging or other wireline operations, and drill stem testing. 7.1 Critical Operations and Curtailment Plans The most probable factors that could result in the curtailment of operations while drilling in the Beaufort Sea area will be winds, and extreme storm conditions. Wind Factors: As a general rule, no operations will commence when the wind velocity exceeds 70 knots. Specific limits for critical operations at the Northstar No. 3 location are: Activity Wind Velocity Drilling 75 kts Tripping Pipe 75 kts Running Casing 70 kts Wire Line Logging 70 kts Drill Stem Testing 45 kts Other Factors: As a general rule, no drilling operations will commence or be continued when any of the following conditions exist: -8- Drilling will not begin until the AHC Drilling Supervisor is satisfied that the rig is properly rigged up to begin operations and ali required materials and third-party equipment are on location. When there is an insufficient supply of drilling fluid materials on location required for presSure control. When sufficient emergency containment and cleanup equipment is not on location or inoperative. When the manpower required to safely conduct the drilling operation is not available. When any critical equipment needed to assure a normally safe operation is not operative. . IMPORTANT: The above list is only a guideline. The decision as to what action to take during a given emergency, no matter what the cause, must be based on the judgement of the AHC Drilling Supervisor and the Drilling Contractor Toolpusher. The person in charge of the overall drilling operation is: E. Clyde Crouch U.S. Production Vice President Amerada Hess Corporation 1201 Louisiana, Suite 936 Houston, Texas 77002 (713) 752-5900 (office) (713) 824-4129 (mobile) (713) 360-8657 (home) -9- AMERADA HESS CORPORATION NORTHSTAR NO. 3 DRILLING FLUID PROGRAM Baker Hughes lnteq has been selected to furnish the drilling fluid services and materials for the Northstar No. 3 well. The following section'defines the mud program that will be used. O lo I! I?_.. ,,,,,,, ,,,IIIiIii MUD .,:IGHT VS. DEPTH ~,, ,, ' ' , I I LEASE ,,, I " ' ' ' WELL NO ,., , .... ,,,, ,-~,,, , . i J I JJ II11~ ! I I II i i~ I i II x I DATE BY . ,, ,, ....,~,,,,,~. ,, ,~,,,~,~ ',~1 ,, , II. ,, I , I \' I.\ III I I\ I I i I1 . . . t i I ! ,~,, I I ~ I I ~ ~ ~-~r' !1 , ,-~ ,, ~ , , .. ,, ,, IIi ,,, MUD WEIGHT (PPG.) AHEP-3065-A AMERADA HESS CORPORATION HOR1}ISTAR #3 STATE TRACT ~39-01 MUD 'PROGRAM DEPTH - (TVD) O' - 1000' 1000' - 3900' 3900' - 8452' 8452' - 10000' MUD WEIGHT VISCOSITY PV YP FILTRATE API HT-HP 8.6- 9.0 50- 150 10- 20 25- 50 <20* --- 9.0- 9.2 45- 55 8- 15 10- 15 <15' --- 9.2- 9.8 40- 48 10- 20 12 - 25 3-8 10-12 9.8 - 10.4 45 - 50 20 - 25 12 - 14 3-5 8- 10 *<12 for logging Amerada Hess Corporation The Northstar #3 INDEX 26" Interval For 20" Casing Page 1 17-1/2" 12-1/4" Interval For 13-3/8" Casing Interval For 9-5/8" Casing Page 4 Page 7 8-1/2" Interval For 7" Casing Page 16 Summary and Discussion Page 19 Amerada Hess Corporation The The Northstar #3 ..£ HO,LE SIZE: CASING SIZE: .MUD TYPE: MUD PARAMETERS Weight: 26" (Spud- 1,000') 20" Spud Mud 8.5 - 9.O ppg Viscosity: 50 - 100 sec/qt pH: 8.5- 9.5 PV: 10- 20 cps YP: 25 - 50 lb/100 ft2 Fluid Loss: < 20.0 cc/30 min < 12.0 cc/30 rain for logging The surface interval should be drilled with a simple bentonite/Ben- Ex spud mud. For purposes of this program, a 500 barrel active system will be used for all calculations. Fill the pits with fresh water, and check both chloride and hardness levels. Treat out excessive hardness with small additions of Soda Ash ( 1/2 - 3/4 ppb) until < 40 ppm hardness remains. Do not overtreat. Prior to spud, mix the surface system to maximum capacity, adding Milgel of sufficient quantity (20-25 ppb) to yield a viscosity in excess of 90 sec/qt. Page 1 Amerada Hess Corporation The Nodhstar #3 Interval' 26" Drill ahead maintaining volume while keeping sufficient yield point for good hole cleaning. Maintain high funnel viscosities (minimum of 120 sec/qt) throughout any gravel sections. - Keep mud weight at desired levels (as Iow as possible) with water additions and solids control equipment. A sand content below 1% will improve the quality of mud as well as reducing wear on the rig pumps. Milgel may be supplemented by Ben-Ex, added at a sack ratio of 5 : 1 to act as a bentonite extender and secondary viscosifier. Adjust funnel viscosities as needed to maintain good hole cleaning characteristics. Prehydration of the bentonite will improve the rheological properties of the drilling fluid. If it is not possible to properly prehydrate, small additions of Mil-Lime will act to quickly flocculate the bentonite, aiding in its yield. if a logging program is planned, additions of Ligco throughout the interval will lower the APl filtrate to less than 12.0 cc/30 min. This will help stabilize the borehole wall and maintain a tough, thin filter cake to improve the quality of the logs that are obtained. Drispac could also be used to control the filtrate, but the potential for undesired viscosity increases would exist. For the hole opening operations, Milgel additions to return the funnel viscosity to 120 sec/qt should be more than adequate to ensure proper hole cleaning for the initial stages. Mud viscosities should be adjusted as hole conditions dictate. Past work shows a funnel viscosity of 60 to 80 sec/qt sufficient. XCD Polymer will aid in hole cleaning capabilities without causing undesired density increases. Page 2 Amerada Hess Corporation The Northstar #3 Interval: 26" At casing point, properly condition the hole by completing a wiper trip, followed by circulation of a high viscosity sweep to ensure complete removal of cuttings, cavings, etc. Prior to pulling out for the casing, spot a high viscosity pill (normally to fill the lower 500') on bottom to reduce the risk of any solids settling on bottom. ANTICIPATED PRODUCT USEAGE --26" Hole Mil-Bar Milgel Ben-ex XCD Polymer Soda Ash Mil-Lime Ligco Barite (for pills) 110 sx Bentonite 475 sx Co-Polymer 40 sx Xantham Gum 10 sx Soda Ash 5 sx Lime 10 sx Lignite 10 sx Page 3 _.. Amerada Hess Corporation The Northstar #3 HOLE SIZE: CASING SIZE: MUD TYPE: MUD PARAMETERS Weight: 17-1/2" (1,000' - 4,900') 13-3/8" LSND 9.O- 9.5 ppg Viscosity: 40- 50 sec/qt pH: 8.0- 9.0 PV: 8 - 15 cps YP: 10 - 15 lb/100 ft2 Fluid Loss: < 15.0 cc/30 min < 12.0 cc/30 min. for logging This section will be drilled with a basic-Iow solids, non-dispersed mud system. The pH of the fluid should be kept bland to reduce reaction of susceptable clays in the Eocene sections. Before drilling out the cement, the spud mud from the previous interval should be evaluated to determine the percent Iow gravity solids and active bentonitic clays. If the mud is found to have a Iow gravi6ty solids content of less than 6.0 %, the 20" shoe should be drilled with the old mud. As this would eliminate the necessity of building a new mud system from scratch, both time and direct cost savings would result. If the low gravity solids are too high and it is determined some dilution is needed, dump returns, adding fresh water. In order to Page 4 Amerada Hess Corporation The Northstar #3 Interval: 17-1/2" '"maintain a homogeneous "system, it would be preferable to accomplish this over at least one full circultation. Commence drilling the cement and float equipment, treating as required with Bicarb and/or SAPP. Prior to drilling formation, obtain the anticipated pump rates, and increase the Yield Point as necessary to ensure good hole cleaning properties. The on-site mud engineer will calculate the relevant rheological flow-regime and cuttings transport parameters on a daily basis to aid in determining the optimum hydraulic characteristics for the drilling fluid system. This will help ensure the hole is cleaned properly, while maintaining the laminar flow needed to reduce the chances of washouts. Add sufficient volumes of Milgel to obtain funnel viscosities in the range of 45 - 55 sec/qt. Additions of 0.1 - 0.3 ppb XCD Polymer will supplement the bentonite in providing hole cleaning capabilities. Again, light treatments of Mil-Lime will aid the yield of any fresh bentonite that is added. Since this well is planned as a straight hole through this section, particulate settlement and cuttings bed formation should not be a problem. Rheological properties can be regulated using Sodium Pyrophosphate (SAPP) or CF Desco in very small quantities (less than 0.25 ppb). These products, unlike other organic thinners, do not require Caustic Soda to solubilize or activate. It has been demonstrated hydroxyl ion (OH-) content exerts a highly dispersive effect on reactive formations on the North Slope. if it is desired to reduce the fluid loss to the 6 - 8 cc/30 min range Page 5 Amerada Hess Corporation The Northstar #3 Interval: 17-1/2" in order to facilitate logging, Drispac Lo-Vis can be used at a Iow concentration. At casing point properly condition the hole by wiper trips and circulation of-a Iow viscosity sweep (YP<8) followed by high viscosity fluid (YP>25). Again, spot a high viscosity pill over the last 500' of open hole to eliminate settlement of cuttings. ANTICIPATED PRODUCT USEAGE --17-1/2" Hole Mil-Bar Milgel Mil-Lime Bicarb SAPP CF Desco Drispac Barite 450 sx Bentonite 120 sx Lime 10 sx Bicarb of Soda 12 sx Sodium Acid 15 sx Pyrophosphate CF Tannin 30 sx Cellulosic Polymer 15sx Xantham Gum 8 sx Page 6 Amerada Hess Corporation The Northstar #3 HOLE SIZE: CASING SIZE: ,MUD TYPE: MUD PARAMETERS: Weight: 12-1/4" (4,900' - 8,642') 9-5/8" LSND/New Drill HP Polymer 9.0- 11.0 ppg .Viscosity: 40 - 48 sec/qt pH: 8.0'- 9.0 PV: 10 - 20 cps YP: 12 -25 lb/100 ft2 Fluid Loss: < 10.0 cc/30 min reduced to < 6.0 cc/30 min before the HRZ This section can be drilled with a basic LSND as long as the APl and HTHP Filtrate levels are tightly controlled prior to entering the HRZ (Torok Formation), and are controlled throughout the rest of the interval. The shale sections of the HRZ and Kalubik (if present), f ormations present high degrees of water sensistivity, therefore water loss should be kept to a minimum. Additions of Soltex (asphalt) and Bore-Plate (gilsonite) will aid in maintaining borehole stability. The pH should be moderate, but at such a level (>9.0) to permit effective use of any lignites or lignosulfonates as required. Moderate pH (<9.5) will not increase the tendency of interbedded clays hydrate, which could lead to the eventual sloughing of the shale sections. Page _7_ Amerada Hess Corporation The Northstar #3 Interval: 12-1/4" Mud weight will normally depend on the stability of the shales, i.e. the more-inhibitive and effective the fluid is in stabilizing this formation, the less mud weight that will be required. The alternative fluid we recommend utilizing through this portion of the Northstar #3 is a properly maintained New Drill polymer fluid, as this will provide an excellent fluid for the control of these sensistive formations at a relatively economic cost. Baker Hughes INTEQ has used the New Drill System very successfully on numerous wells similar to the North Star operation. The basic principal of this polymeric fluid being significant inhibition from the fluid, combined with minimal chemical re~¢ti0n with the form~,tion and encapsulation of formation solids. The primary additive for the system is New Drill HP, which is Baker Hughes INTEQ's proprietary PHPA polymer. The chemical makeup of the polymer helps impart improved borehole stability by limiting the reactivity of the drilling fluid to the exposed formations. This is accomplished by combining the actual inhibition obtained from the additive, which contains potassium chloride, with the solids encapsulation properties obtained from the active PHPH polymer. Treatments with Drispac type polymers combined and Bio-Lose, a non-fermenting starch, will iimprove the filtrate control of the fluid, therefore further reducing the potential for the formation reacting with the drilling fluid. Additions of a 1:1 blend of Soltex (asphalt) and Bore-Plaste (gilsonite) further enhance the stabilization of the borehole. Page 8 Amerada Hess Corporation The Northstar #3 Interval' 12-1/4" Typically, the entire drilling fluid system is either broken over to the polymer system, or completely changed out prior to entering the potentially reactive sections. While the HRZ Shale is the primary formation of concern, the upper shales' should also be considered. The inhibitive nature of the New Drill System is especially recommended when the drilling program calls for extensive long intervals of open hole through potentially reactive areas. Some of the basic comparative factors between the two systems are listed below. LSND -Lightly Dispersed Solids control by dispersion Filtrate has hydrative and dispersive nature Higher pH levels to activate New Drill HP (PHPA) Solids control by inhibition and encapsulation Filtrate is chemically inhibitive (KCI) Moderate pH which reduces chemical reaction By assisting rig equipment in controlling solids contamination primarily by inhibition, the New Drill HP system helps improve the overall efficiency of that equipment. By acting to encapsulate any solids that start to become incorporated in the mud, the "first cut" removal of solids is improved. By eliminating these solids before they degrade, later control is considerably inhanced. As dilution is reduced, disposal costs are reduced, lowering the overall well cost. While either the LSND or New Drill systems can be treated to obtain any desired levels of filtrate control,we recommend the New Drill HP system'for these primary reasons: Page _9_ Amerada Hess Corporation The Northstar #3 Interval' 12-1/4" * The inhibitive nature will help stabilize any formation that could be invaded through fractures, faults, or other means. * The low pH level associated with the polymer will also reduce dispersive reactions between the fluid and the formation. * The amount of dilution, therefore disposal, would be dramatically reduced with the use of the proper inhibitive fluid. Mud cost would also be lowered by the reduction in daily maintenance. The Baker Ht~ghes INTEQ New Drill System Bump the plug on the 13-3/8" casing with old mud or water, then prepare to build the new New Drill HP polymer system. Isolate one suction pit and fill with fresh water to use for drill out. Line up returns to create a one-pit circulating system, and if necessary treat lightly with Bicarb of Soda while drilling the cement. The drilling out cement with a new polymer system should be avoided, although the calcium and pH generated by the cement will produce significantly less adverse rheological effects than when using a conventional mud. To ensure proper formation stability and integrity, displace with the New Drill HP system prior to drilling the float shoe and exposing any formation. To build the New Drill HP mud, dump and clean the remaining pits, and fill with fresh water to capacity. Approximately 900 barrels will be required to completely displace the hole while keeping Page _10_ Amerada Hess Corporation The Northstar #3 Interval: 12-1/4" adequate circulating volume in the surface pits. Because of this volume, some of the mud from the previous interval will be incorporated into the new polymer fluid. This should not produce any adverse effects if the fluid was kept clean throughout the past section, and the Iow gravity solida level is less than 5.0 %. The quality of the mud should be evaluated to determine if there would be any problems or dilution needed before using as make-up. If the pits are full at the start, enough mud will be left after displacement for drilling operations to commence without delay. Check the fresh water, treating with Soda Ash as required for hardness (<100 ppm), then add 8.0- 10.0 ppb Milgel and allow time to properly hydrate. This time will depend on ther quality of the water, but should eb no longer than 1 hour. To this volume add 0.75 ppb New Drill HP and allow to roll in the pits. Mil-Bar additions are not necessary as of yet, and by holding off on barite additions at this time, the polymer "hump" will not be as severe. When circulation is resumed, displace the fluid in the hole, discarding as much of the old mud as possible. Continue New Drill HP additions until the complete system is treated with 0.75 ppb New Drill HP. On the subsequent two to three circulations, add sufficient New Drill HP polymer until the whole mud yields 0.4-0.6 ppb of available polymer, as determined by the Clapper Polymer Test. Since the system should be relatively solids-free at this point, it may take less than the usual amount. Because of the expected wellbore trajectory, in addition to the Page _11_ Amerada Hess Corporation The Northstar #3 Interval: 12-1/4" anticipated mud weights, particle settlement and cuttings bed formation is a possible problem. Initial gel strengths should be in the order of 7 - 15 lb/100ft2 to help retard "cuttings slip", with the 10 and 30 minute gels in the 25 - 30 Ib/100ft2 range, indicative of non- progressive gel structure. There may be a fairly significant increase in the viscosity of the fluid as the polymer initially reacts with the bentonite and native solids, but additions should continue until you the system is completely broken over. Slight additions of CF Desco or SAPP will reduce the viscosity somewhat. Drill ahead maintaining proper New Drill HP concentration. To help decide the correct concentration of the polymer, inspect the drilled cuttings regularly. Cuttings that are sticky or visibly hydrated are indicative of low polymer concentration. If the amount of cuttings has visibly decreased for a given ROP, then further additions are advisable. The Clapper Polymer Test is the most accurate method to ensure proper polymer concentrations, and was developed specifically for the New Drill System. It is recommended this test be run at least every 2 days, and preferably more often. The New Drill HP co-polymer itself should provide more than adequate viscosity to properly clean the hole, but if more is desired, XCD Polymer can be added to supplement the system. Utilize Iow viscosity-high viscosity sweeps to help completely remove all cuttings. The lower yield point from the Iow viscosity Page _12_ Amerada Hess Corporation The Northstar #3 Interval: 12-1/4" . . portion will promote turbulent flow, thereby scouring the bottom and letting the chase fluid (high viscosity) remove the cuttings. The high viscosity sweeps should contain at least 15-20 ppb fresh gel. Use of Drispac R and New Drill HP will increase the viscosity of the sweep to 150 sec/qt. Drill ahead maintaining acceptable New Drill properties. If the fluid loss is to be reduced, add Bio-Lose at 2.0-3.0 ppb combined with Drispac at 0.5-1.5 ppb. Each of these products has functions that are desirable in this type of Well, so a combination of the two is desired. Drispac, a polyanionic cellulosic polymer, will assist the bentonite and native clays in formulating good gel structure to ensure suspension when not circulating. Bio-Lose, a chemically modified non-fermenting starch and will work synergistically with the New Drill HP to provide an extremely lubricative fluid. Monitor the HTHP filtration to give an indication of cake formation and compressibility. Pyro-Trol, which is an acrylamide and alkali salt, will help stabilize the APl filtrate, and improve the HTHP values, which are more indicative of down-hole conditions. Pyro- Trol characteristically will reduce the HTHP levels to less than 12.0 cc/30 min at temperatures aS high as 250 degrees, but these levels usually do depend on the amount of bentonite in the mud. Lab tests have shown a proper blend of New Drill HP/Bio-Lose/Pyro-Trol will also provide for excellent lubricity,.in addition to the firm filtrate cakes associated with tight filtrate control. New Drill HP will impart basic inhibition of the formation clays and shales, but'supplementing this with 4.0 ppb of a blend of Soltex and Page _13_ Amerada Hess Corporation The Northstar #3 Interval' 12-1/4" BOre-Plate will provide maximum shale stabilization. Experience on other wells, using a fluid very similar to this, has demonstrated the benefits of the two products working together, especially if fractured or otherwise reactive areas are encountered. If it is desired to smooth out rheological properties, New Thin D can be added. New Thin D is a Iow molecular weight polyacrylate thinner that works well in this system, as it does not have the dispersing effects of lignosulfonates or other comparable products. Caustic is not required to solubilize or activate it, which could exert a highly dispersive effect on reactive formations. Mud weights should be kept at levels acceptable with sound drilling practices throughout the interval. Run all solids control equipment to their maximum efficiency. Add all water below the shakers to avoid washing in unwanted drill solids through the shaker screens. Run a minimum of 200 mesh screens on the mud cleaners to give maximum cut. Increases in torque and/or drag should not be a problem. We feel the New Drill System itself will be effective in controlling normal torque. However, slight additions of Pyro-Trol and/or Bio-Drill, a glycol based lubricant can be added if any torque increases become evident. Bio-Drill can be added initially at 1% by volume, and increaSed. Levels' higher than 4% have not provided any noticeable improvement on torque or drag, with 3 % to 4 % being accepted as the most efficient. Solids analysis should be done at least daily, and evaluated by the Page _14_ Amerada Hess Corporation The Northstar #3 Interval' 12-1/4" mud engineer. required for content could dilution or A Iow gravity solids content of less than 5 % is optimum performance of this system, Any higher adversely effect all properties. In this case, either complete displacement should be considered. ANTICIPATED PRODUCT USAGE --12-1/4" Hole Mil-Bar Barite 1750 sx Milgel Bentonite 48 sx New Ddli HP PHPA 60 sx Co-Poloymer New Thin Sodium 15 sx Polyacrylate CF Desco Tannin Thinner 35 sx Bio-Lose Modified Starch 80 sx Drispac Cellulosic Polymer 50 sx Soda Ash Soda Ash 6 sx Bicarb Bicarb of Soda 12 sx Soltex Asphalt Resin 45 sx Bore-Plate Ground Gilsonite 45 sx CONTINGENCY PRODUCTS --12-1/4" Hole Pyro-Trol Acrylamide & 20 sx Alkali Salt Bi o - D rill Glycol Lubricant 10 dr Page _15_ Amerada Hess Corporation The Northstar #3 HOLE SIZE: CASING SIZE: MUD TYPE: MUD PARAMETERS: Weight: 8-1/2" (8,642' - 10,966') 7 ~' LSND/New Drill HP Polymer 8.8 - 10.4 ppg Viscosity: 40 - 55 sec/qt pH: 11.0 - 11.5 PV: 20- 25 cps YP: 10 - 25 lb/100 ft2 Fluid Loss: < 5.0 cc/30 min As with the 12-1/4" interval, this section could be drilled with a basic LSND system, however we recommend a New Drill HP system similar to the one previously described. After setting the 9-5/8" casing at the desired depth, pre-treat the active system with either SAPP and/or Bicarb to offset the effects of cement contamination. Once drilling has commenced, there are two primary objectives. First will be to lower the pH to the desired level (8.0 - 9.0) as quickly as possible. This will reduce the chances of any reactive formations starting to swell and run. Secondly, raise the' mud weight to the desired levels, as dependent on pore pressure estimates and safe drilling practices. As drilling resumes continue with the system as in the previous interval, again utilizing low viscosity-high viscosity sweeps to Page _16_ Amerada Hess Corporation The Northstar #3 Interval: 8-1/2" ensure hole cleaning. Keep the New Drill HP concentration at a level slightly higher than before, as the formations that will be exposed have been-shown to have an extremely hydrative and reactive nature. Control filtrate with the Bio-Lose/Drispac blend, while monitoring the HT'HP filtration .to determine the necessity of Pyro-Trol additions. By having the 4.0 ppb blend of Soltex and Bore-Plate in the system the stability of the entire section will be improved. Run mud weights at levels sound drilling practices will allow. Carefully monitoring all mud pits and flow equipment is paramount to keeping the proper mud weight conducive to safe drilling operations. Weights of up to 11.5 ppg may be required, but we are confident the inhibitive nature of the New Drill System will permit lower weights to be maintained. During this interval, accurate daily solids analysis is extremely important. The 7% Iow gravity level should be carefully monitored to maintain optimum polymer efficiency. Page _17_ Amerada Hess Corporation The Northstar #3 Interval' 8-1/2" ANTICIPATED PRODUCT USAGE --8-1/2" Hole Mil-Bar Milgel XCD Polymer New Drill HP New Thin D CF Desco Bio-Lose Drispac Soda Ash Bicarb Soltex Bore-Plate Barite 1450 sx Bentonite 80 sx Xantham Gum 15 sx PHPA 75 sx Co-Poloymer (proprietary) SOdium 20 sx Polyacrylate (proprietary) Tannin Thinner 90 Modified Starch 80 Cellulosicic Polymer 60 Soda Ash 6 Bicarb of Soda 12 Asphalt Resin 40 Ground Gilsonite 40 SX SX SX SX SX SX SX Pyro-Trol Bio-Drill CONTINGENCY PRODUCTS --8-1/2" Hole Acrylamide & Alkali Salt Glycol Lubricant 50 sx 16 dr Page _18_ Amerada Hess Corporation The Northstar #3 SUMMARY & DISCUSSION Drilling operations during The Northstar #3 will expose large sections of extremely reactive formations, some for an extended time. The geometric configuration of this well amplifies some of the potential problems that could occur as a result of leaving these formations open for any length of time. For this reason, a highly inhibitive system of drilling fluid was the paramount consideration of this program. Different polymeric systems on the market all have different levels of inhibition, along with other benefits that could be realized. However, each system also has some down-side considerations, of which the susceptability to solids contamination being the most apparent in the field. Also, each system is usually based on its association with one or more inhibitive salts added, KCI (potassium chloride) being the most commo/Q.~.... ~ ./ ) While reviewing the needs of this well, the anticipatedformations indicated the New Drill HP, With its PHPA polymeric base and inhibitive KCI carrier, shouldprovide the appropriate fluid for this well. Sensitive and reactive formations are expected throughout both the 12-1/4" and 8-1/2' sections. As these intervals are the prime Page _19_ Amerada Hess Corporation The Northstar #3 Summary & Discussion _ source of drilling problems expected, all options should be reviewed to eliminate these potential problems. On some operations in the past, mud weight had been the primary method to control or reduce any adverse effects from these shales. For The Northstar #3, we feel the system as designed with its Iow ph levels (8.0 - 9.0) will reduce any chemical reaction of the formation, therefore reducing the tendencies to swell and start degrading. A secondary consideration when encountering these zones is the addition of Soltex and Boreplate to help in sealing them off. Soltex is an asphalt resin, and Boreplate a sized gilsonite, which together have been effective 'in controlling the tendencies of reactive formations to hydrate and start reacting and swelling. Our work in other areas has shown this is accomplished by the combination of asphalt (water soluble) and-gilsonite (water. dispersible) which impart a wider range of particle size distribution for better fracture sealing. Another consideration that could be used in conjunction with the aforementioned chemical treatment, could be the manipulation of pump rates, to minimize mechanical degradation of the formation's structure. Adjusting nozzle sizes and raising the Yield Point and Gel Strengths will maintain effective hole cleaning. A last alternative is to increase the mud weight before entering the sections. Amerada's The Northstar #3 operations represent a rather ambitious project, with many concerns involving formation evaluation and directional work, as well as the normal drilling and environmental aspects. We are confident of our peoples' abilities to work with Amerada to reach a safe and satisfactory conclusion within an appropriate time frame. Page _20_ AIVIERADA HESS CORPORATION NORTHSTAR NO. 3 CASING AND CEMENTING PROGRAM CASING AND CEMENTING PROGRAM - SUMMARY AMERADA HESS CORPORATION NORTHSTAR NO. 3 EXPLORATION WELL Hole Casing Casing Depth, Depth, Length Float Cement Slurry Size Size Description Shoe (KB) Top (ft) Equipment Class Wt. Notes 26" 20" 194 lb, 1,000 MD 0 1,000 F.S. Permafrost 13.5 - 13.7 Cement to surface. If no cement (1,000 TVD) (surface) F.C. Maximum returns to surface after 100 percent K-55, BTC (Stab-in) excess, do top job. 17-1/2" 13-3/8" 68 lb, 3,900 MD 0 3,900 F.C. Permafrost 15.5 - 16.0 Use top and bottom wiper plugs. L-80, BTC (3,900 TVD) (surface) F.S. Lead Determine slurry volume from caliper log. Add 15 percent excess. Slurry Class G volume should cement casing to Blend Tail surface. Friction reducer and retarder will be used to produce a minimum 4- hour thickening time. 12-1/4" 9-5/8" 47 lb, 8,818 MD 0 8,818 F.C. Class G 16.0 Use top and bottom wiper plugs. L-80, BTC (8,452 TVD) (surface) F.S. Blend Determine slurry volume from caliper log. Add 15 percent excess. Slurry volume should equal 2,550 ft fill-up above casing shoe. Friction reducer and retarder will be used to produce a minimum 6-hour thickening time. 8-1/2" 7" 26 lb, 10,521 MD 8,452 MD 2,069 F.C. Class G 16.0 Slurry volume to be based on caliper N-80, LTC (est.) (8,120 TVD) F.S. Blend log data plus 15 percent plus 150SX. (10,000 TVD) Supplementary program will be provided covering liner running and cementing procedures if decision is made to run liner. Note to Casing Design Calculations The casing setting depths used in the design calculations for collapse and burst are the measured depth rather than the TVD's. This approach provides two advantages: By not reducing the additional margin of calculations, and depth to the TVD's, an safety is added to the · The program does not have to be run twice. K-55 OPERATOR: AMERADA HESS CORPORATION DATE: 22-DEC-93 LEASE: NORTHSTAR NO. 3 FIELD: NORTHSTAR UNIT SEC. 20 TWP. 13N RNG. 13E COUNTY: NSB STATE: ALASKA SURFACE CASING CASING DESIGN DATA DESIGN CODE: 1 CASING STRING DESIGN CODE ............................ = **************************** DESIGN FACTORS: 2 BURST DESIGN FACTOR ................................... = 1.100 3 COLLAPSE DESIGN FACTOR ............................... = 1.100 4 TENSION DESIGN FACTOR ................................ = 1.600 50VERPULL IN EXCESS OF THE STRING WEIGHT ......... (LBS) = 100000.000 CASING BURST DESIGN DATA: 7 FRACTURE GRADIENT AT THE CASING SHOE + YOUR SAFETY FACTOR .............................. (PPG) = 8 GAS GRADIENT ................................. (PSI/FT) = 10 WEIGHT OF BACKUP FLUID .......................... (PPG) = 12.500 .115 9.500 CASING COLLAPSE DESIGN DATA: 11 MUD WEIGHT CASING IS SET IN ..................... (PPG) = 12 TOP OF CEMENT ......................... · ........... (FT) = 13 WEIGHT OF CEMENT ................................ (PPG) = 14 WEIGHT OF COLLAPSE BACKUP FLUID ................. (PPG) = 9.500 .000 13.500 9.500 CASING DESIGN DATA: 15 CASING SIZE, O.D ................................. (IN) = 16 CASING (MIN. ACCEPTABLE) DRIFT DIAMETER .......... (IN) = 17 SETTING DEPTH .................................... (FT) = 18 MINIMUM SECTION LENGTH ..... - ...................... (FT) = 20.000 17.500 1000.000 .000 CALCULATION CONTROL DATA: 24 UPGPJUDE BURST FOR TENSION ............... (0=YES;i=NO) = 25 UPGRADE COLLAPSE FOR COMPRESSION ........ (0=YES;i=NO) = 26 CONSIDER EFFECT OF BOUYANCY ON TENSION...(0=YES,i=NO) = 27 MAXIMUM LOAD;MAXIMUM STRAIN ENERGY.. (0=LOAD;i=STRAIN) = CASING TABLE NAME: 28 CURRENTLY SELECTED CASING TABLE ............ (CAS.BIN) = C:CAS.BIN OPERATOR: AMER3tDA HESS CORPORATION LEASE: NORTHSTAR NO. 3 SEC. 20 TWP. 13N RNG. 13E COUNTY: NSB FIELD: DATE: 22-DEC-93 NORTHSTAR UNIT STATE: ALASKA SURFACE CASING ___ CASING DESIGN -- 20.000 DEPTH LENGTH WEIGHT GPJtDE JOINT PRICE (FT) (FT) (LB/FT) ($/FT) .0 1000.0 94.00 K-55 BTC STRING COST = $ STRING WEIGHT ** INTERNAL YIELD UPGRADED FOR TENSION ** ** COLLAPSE LOAD UPGRADED FOR COMPRESSION ** FORMULA USED: MAXIMUM LOAD THEORY ** 94000. LBS BURST PIPE BURST DEPTH WEIGHT/GRADE/JOINT LOAD (FT) (PSI) .0 94.00/K-55 /BTC 534. 1000.0 94.00/K-55 /BTC 156. PIPE IN TENSION PIPE DESIGN BURST FACTOR (PSI) NOT IN TENSION PIPE DESIGN BURST FACTOR (PSI) 2154. 4.03 2110. 3.95 2099. 13.47 2110. 13.54 COLLAPSE PIPE COLLAPSE DEPTH WEIGHT/GRADE/JOINT LOAD (FT) (PSI) .0 94.00/K-55 /BTC 0. 1000.0 94.00/K-55 /BTC 208. PIPE IN TENSION PIPE DESIGN COLLAPSE FACTOR (PSI) NOT IN TENSION PIPE DESIGN COLLAPSE FACTOR (PSI) 504. 515. 518. 2.49 515. 2.48 TENSION PIPE TENSION DEPTH WEIGHT/GR3tDE/JOINT LOAD (FT) (1000 LBS) .0 94 ..00/K-55 /BTC 75.1 1000.0 94.00/K-55 /BTC -18.9 JOINT/BODY STRENGTH (1000 LBS) 1476.0 1476.0 TENSION DESIGN FACTOR 19.65 -78.20 OPEtLATOR: AMER_ADA HESS CORPORATION DATE: 22-DEC-93 LEASE: NORTHSTAR NO.~3 FIELD: NORTHSTAR UNIT SEC. 20 TWP. 13N RNG. 13E COUNTY: NSB STATE: ALASKA I 1 1 I 500 + * 1000 +* 1500 + 2000 + · 2500 + I I I 3000 + 3500 + I · · 4000 + .... 0 1000 + + + + + + + + + + SURFACE CASING BURST PRESSURE VS. DEPTH + .... + .... + .... + .... + .... .... + .... + .... + .... + I I I I + I I l I + I I l 1 + I l I I + I I I 1 + I I 1 I + I I I I + I 1 I I .... + .... + .... + .... + 6O0O 700O 2000 + .... + .... + .... + .... + .... + 3000 4000 5000 BURST DESIGN LINE (PSI) * PIPE BURST (PSI) + OPERATOR: AMERADA HESS CORPORATION DATE: 22-DEC-93 LEASE: NORTHSTAR NO. 3 FIELD: NORTHSTAR UNIT SEC. 20 TWP. 13N PANG. 13E COUNTY: NSB STATE: ALASKA SURFACE CASING 0 * .... + .... · + * · + · + 500 +* + I ~ + 1000 + * + 1500 + 2000 + 2500 + · 3000 + 3500 + · 4000 + .... + .... 0 1000 2000 COLLAPSE PRESSURE VS. DEPTH + .... + .... + .... + .... + .... 4 ..... 3000 4000 5000 6000 I I I I + 1 I I I + I I I I + I I I I + I I I I + I 1 I I + I I I I + I I I I 700O COLLAPSE DESIGN LINE (PSI) * PIPE COLLAPSE (PSI) + 0PEPJ~TOR: AMER_ADA HESS CORPORATION DATE: 22-DEC-93 LEASE: NORTHSTAR NO. 3 SEC. 20 TWP. 13N RNG. 13E FIELD: NORTHSTAR UNIT COUNTY: NSB STATE: ALASKA SURFACE CASING 500 1000 1500 2000 2500 3000 3500 4000 200 TENSION VS. DEPTH + .... + .... + .... + .... + .... + .... + .... .... + .... + .... + .... + .... + .... + .... + 400 600 800 1000 TENSION DESIGN LINE (1000 LBS) * JOINT/BODY STRENGTH (1000 LBS) + 1200 + + + + + + + + + + I l l I + l I I I + I I I l + I l I I + I I I I + I I l l + 1400 1 ?--3/8" L-80 0PERATOR: AMERADA HESS CORPORATION LEASE: NORTHSTAR NO. 3 SEC. 20 TWP. 13N RNG. 13E COUNTY: NSB FIELD: DATE: 22-DEC-93 NORTHSTAR UNIT STATE: ALASKA SURFACE CASING CASING DESIGN DATA DESIGN CODE: 1 CASING STRING DESIGN CODE ............................. ***************************** DESIGN FACTORS: 2 BURST DESIGN FACTOR ................................... 1.100 3 COLLAPSE DESIGN FACTOR ............................... = 1.100 4 TENSION DESIGN FACTOR ................................ = 1.600 50VERPULL IN EXCESS OF THE STRING WEIGHT ......... (LBS) = 100000.000 CASING BURST DESIGN DATA: 7 FRACTURE GRADIENT AT THE CASING SHOE + YOUR SAFETY FACTOR (PPG) 8 GAS GRADIENT (PSI/FT) 10 WEIGHT OF BACKUP FLUID .......................... (PPG) 14.500 .115 9.500 CASING COLLAPSE DESIGN DATA: 11 MUD WEIGHT CASING IS SET IN (PPG) = 12 TOP OF CEMENT (FT) = 13 WEIGHT OF CEMENT ................................ (PPG) = 14 WEIGHT OF COLLAPSE BACKUP FLUID ................. (PPG) = 9.500 .000 13.100 9.500 CASING DESIGN DATA: 15 CASING SIZE, O.D ................................. (IN) = 16 CASING (MIN. ACCEPTABLE) DRIFT DIAMETER .......... (IN) = 17 SETTING DEPTH (FT) = 18 MINIMUM SECTION LENGTH ........................... (FT) = 13.375 12.250 3900.000 .000 CALCULATION CONTROL DATA: 24 UPGRADE BURST FOR.TENSION ............... (0=YES;i=NO) = 25 UPGRADE COLLAPSE FOR COMPRESSION ........ (0=YES;I=NO) = 26 CONSIDER EFFECT OF BOUYANCY ON TENSION... (0=YES,i=NO) = 27 MAXIMUM LOAD;MAXIMUM STRAIN ENERGY..(0=LOAD;i=STRAIN) = CASING TABLE NAME: 28 CURRENTLY SELECTED CASING TABLE ............ (cAS.BIN) = C:CAS.BIN OPERATOR: AMERADA HESS CORPORATION DATE: 22-DEC-93 LEASE: NORTHSTAR NO. 3 FIELD: NORTHSTAR 1/NIT SEC. 20 TWP. 13N RNG. 13E COUNTY: NSB STATE: ALASKA SURFACE CASING CASING DESIGN -- 13.375 DEPTH LENGTH WEIGHT GRADE JOINT PRICE (FT) (FT) (LB/FT) ($/FT) · 0 3900.0 68.00 L-80 BTC STRING COST = $ STRING WEIGHT = ** INTERNAL YIELD UPGRADED FOR TENSION ** ** COLLAPSE LOAD UPGRADED FOR COMPRESSION ** ** FORMULA USED: MAXIMI/M LOAD THEORY ** 265200. LBS BURST PIPE IN TENSION NOT IN TENSION DEPTH (FT) .0 3900.0 PIPE WE I GHT/GRADE / JO INT 68.00/L-80 /BTC 68.00/L-80 /BTC BURST PIPE DESIGN LOAD - BURST FACTOR (PSI) (PSI) PIPE DESIGN BURST FACTOR (PSI) 2489. 5298. 2.13 5020. 2.02 1013. 4944. 4.88 5020. 4.96 COLLAPSE PIPE IN TENSION NOT IN TENSION DEPTH (FT) PIPE WE I GHT/GRADE / JO INT · 0 68.00/L-80 /BTC 3900.0 68.00/L-80 /BTC COLLAPSE PIPE DESIGN LOAD COLLAPSE FACTOR (PSI) (PSI) PIPE DESIGN COLLAPSE FACTOR (PSI) 0. 2109. 2260. 729. 2293. 3.14 2260. 3.10 TENSION DEPTH ' (FT) PIPE WE IGHT/GRADE / JO INT .0 68.00/L-80 /BTC 3900.0 68.00/L-~80 /BTC TENSION LOAD (1000 LBS) 213.6 -51.6 JOINT/BODY STRENGTH (1000 LBS) 1545.0 1545.0 TENSION DESIGN FACTOR 7.23 -29.94 OPERATOR: AMERADA HESS CORPORATION LEASE: NORTHSTAR NO. 3 SEC. 20 TWP. 13N RNG. 13E DATE: 22-DEC-93 · FIELD: NORTHSTAR UNIT COUNTY: NSB STATE' ALASKA 0 + .... + .... + .... + .... + .... I I I I 500 + I 1 1000 + 1500 + 2000 + * 2500 + 3000 + * 3500 + · 4000 + .... + .... + .... + .... + .... 0 1000 2000 SURFACE CASING BURST PRESSURE VS. DEPTH + .... + .... + .... + .... + .... + .... + .... 3O00 4000 +-+--+ .... + .... + .... + + I + I + + + + + 1 + I + + I + + + + I + I + I + + + I + I + + 1 + + + I + I + + I + + + I + I + I + 1 + + + I + I + + + + + I + I + + 1 .... + .... + .... + .... + .... + 5000 6000 7000 BURST DESIGN LINE (PSI) * PIPE BURST (PSI) + OPERATOR: AMERADA HESS CORPORATION DATE: 22-DEC-93 LEASE: NORTHSTAR NO. 3 FIELD: NORTHSTAR UNIT SEC. 20 TWP. 13N RNG. 13E COUNTY: NSB STATE: ALASKA SURFACE CASING 500 +* -I~ 1000 + * 1500 + * 2000 + · 2500 + I · I I 3000 + I I 3500 + I · · 1 I · 4000 + .... 0 + .... + .... + .... 1000 COLLAPSE PRESSURE VS. DEPTH ++---+ .... ~ ..... ~ ..... + .... + .... + + + + + + + + + + + + + + + + + + + + + + + + + + + + + + + + + + + + + + + 2000 + .... + .... + .... + .... 3000 4000 + .... + .... + .... 5000 6000 COLLAPSE DESIGN LINE (PSI) * PIPE COLLAPSE (PSI) + I 1 I I + I t I I + 1 I I + I I I + I I I I + I I I I + I I I I + .... -I- 7000 OPERATOR: AMERADA HESS CORPORATION DATE: 22-DEC-93 LEASE: NORTHSTAR NO. 3 FIELD: NORTHSTAR UNIT SEC. 20 TWP. 13N RNG. 13E COUNTY: NSB STATE: ALASKA 500 + 1000 + 1500 + 2000 + · 2500 + * · · · . 3000 + * · · · 3500 + * · 4000 + .... 0 SURFACE CASING + .... +* - __ -+ .... + .... + .... + .... + .... + .... 300 600 TENSION VS. DEPTH + .... + .... + .... + .... 9OO 1200 + .... ++---+ .... + .... + + + + + + + + + + + + + + + + + + + + + + + + + + + + + + + + + + + + + + + + .... + .... + .... + .... 1500 1800 TENSION DESIGN LINE (1000 LBS) * JOINT/BODY STRENGTH (1000 LBS) + I I I I + I I I I + I I I I + I I I + I · l I l + I l l I + l I l l + l I · I l , ib .... + 2100 OPERATOR: AMERADA HESS CORPORATION LEASE: NORTHSTAR NO. 3 SEC. 20 TWP. 13N RNG. 13E L-80 COUNTY: NSB DATE: 22-DEC-93 FIELD: NORTHSTAR UNIT STATE: ALASKA INTERMEDIATE CASING CASING DESIGN DATA DESIGN CODE: 1 CASING STRING DESIGN CODE ............................ = ***************************** DESIGN FACTORS: 2 BURST DESIGN FACTOR .................................. = 1.100 3 COLLAPSE DESIGN FACTOR ............................... = 1.100 4 TENSION DESIGN FACTOR ................................ = 1.600 50VERPULL IN EXCESS OF THE STRING WEIGHT ......... (LBS) = 100000.000 CASING BURST DESIGN DATA: 6 SURFACE EQUIPMENT WORKING PRESSURE .............. (PSI) = 7 FRACTURE GRADIENT AT THE CASING SHOE + YOUR SAFETY FACTOR .............................. (PPG) = 8 GAS GRADIENT ................................. (PSI/FT) = 9 MAXIMUM ANTICIPATED MUD WEIGHT .................. (PPG) = 10 WEIGHT OF BACKUP FLUID .......................... (PPG) = 5000.000 16.000 .115 9.800 9.5OO CASING COLLAPSE DESIGN DATA: 11 MUD WEIGHT CASING IS SET IN ..................... (PPG) = 12 TOP OF CEMENT .................................... (FT) = 13 WEIGHT OF CEMENT (PPG) = 14 MINIMUM BACKUP .................................. (PPG) = 9.800 6268.000 15.800 9.500 CASING DESIGN DATA: 15 CASING SIZE, O.D ................................. (IN) = 16 CASING (MIN. ACCEPTABLE) DRIFT DIAMETER .......... (IN) = 17 SETTING DEPTH .................................... (FT) = 18 MINIMUM SECTION LENGTH ........................... (FT) = 9.625 8.500 8818.000 .000 CALCULATION CONTROL DATA: 24 UPGRADE BURST FOR TENSION ............... (0=YES;i=NO) = 25 UPGRADE COLLAPSE FOR COMPRESSION ........ (0=YES;i=NO) = 26 CONSIDER EFFECT OF BOUYANCY ON TENSION... (0=YES,i=NO) = 27 MAXIMUM LOAD;MAXIMUM STRAIN ENERGY.. (0=LOAD;i=STRAIN) = CASING TABLE NAME: 28 CURRENTLY SELECTED CASING TABLE ............ (CAS.BIN) = C:CAS.BIN OPERATOR: AMERADA HESS CORPORATION DATE: 22-DEC-93 LEASE: NORTHSTAR NO. 3 FIELD: - NORTHSTAR UNIT SEC. 20 TWP. 13N RNG. 13E COUNTY: NSB STATE: ALASKA INTERMEDIATE CASING CASING DESIGN -- 9.625 DEPTH LENGTH WEIGHT GRADE JOINT PRICE (FT) (FT) (LB/FT) ($/FT) · 0 8818.0 47.00 L-80 BTC STRING COST = $ STRING WEIGHT = ** INTERNAL YIELD UPGRADED FOR TENSION ** ** COLLAPSE LOAD UPGRADED FOR COMPRESSION ** ** FORMULA USED: MAXIMUM LOAD THEORY ** 414446. LBS BURST PIPE IN TENSION NOT IN TENSION DEPTH (FT) .0 8818.0 PIPE WEIGHT/GRADE/JOINT 47.00/L-80 /BTC 47.00/L-80 /BTC BURST PIPE DESIGN LOAD BURST FACTOR (PSI) (PSI) PIPE DESIGN BURST FACTOR (PSI) 5000. 7628. 1.53 6870. 1.37 2977. 6659. 2.24 6870. 2.31 COLLAPSE PIPE IN TENSION NOT IN TENSION DEPTH (FT) .0 8818 0 PIPE WE I GHT / GRADE / JO INT 47.00/L-80 /BTC 47.00/L-80 /BTC COLLAPSE PIPE DESIGN LOAD COLLAPSE FACTOR (PSI) (PSI) PIPE DESIGN COLLAPSE FACTOR (PSI) 0. 3941. 4750. 932 . 4883 . 5.24 4750. 5.10 TENSION DEPTH (FT) .0 8818.0 PIPE WE I GHT / GRADE / JO INT 47.00/L-S0 /BTC 47.00/L-80 /BTC TENSION LOAD (1000 LBS) 342.7 -71.7 JOINT/BODY STRENGTH (1000 LBS) 1085.8 1085.8 TENSION DESIGN FACTOR 3.17 -15.14 OPERATOR: AMERADA HESS CORPORATION .. DATE: 22-DEC-93 LEASE: NORTHSTAR NO. 3 FIELD: NORTHSTAR UNIT SEC. 20 TWP. 13N RNG. 13E COUNTY: NSB STATE: ALASKA 1500 + · 3000 + 4500 + 6000 + 7500 + 9000 + 10500 + · 12000 + .... + .... 1000 + .... + .... + .... 2000 INTERMEDIATE CASING BURST PRESSURE VS. DEPTH + .... + .... + .... ~ ..... . .... + + + + + + + + .... ++- - _ + + + + + + + + + + + + + + + + + + + 3000 4000 5000 6000 BURST DESIGN LINE (PSI) PIPE BURST (PSI) 7OOO + l l I I + I I I I + I I I I + I I I I + I I I I + I I I I + l l I l + l l l l · 8000 OPERATOR: AMERADA HESS CORPORATION DATE: 22-DEC-93 LEASE: NORTHSTAR NO. 3 FIELD: NORTHSTAR UNIT SEC. 20 TWP. 13N RNG. 13E COUNTY: NSB STATE: ALASKA INTERMEDIATE CASING 0 * .... + .... + .... + .... I* · 1500 +* · 3000 +* 4500 +* 6000 +* 7500 + * 9000 + · 10500 + · · 12000 + .... + .... + .... + .... 0 1000 COLLAPSE PRESSURE VS. + .... + .... + .... +- - _ + + + + + + + + + + + + + + + + + DEPTH + + + + + + + + + + + + 2000 + .... + .... + .... + .... 3000 4000 COLLAPSE DESIGN LINE PIPE COLLAPSE (PSI) (psi) + .... + .... + .... + .... 5000 6000 + I I + I + I I + I I + I I I + I I I I + I I + I I · + 7000 OPERATOR: AMERADA HESS CORPORATION DATE: 22-DEC-93 LEASE: NORTHSTAR NO. 3 FIELD: NORTHSTAR I/NIT SEC. 20 TWP. 13N RNG. 13E COUNTY: NSB STATE: ALASKA 0 + .... + .... I I I I 1500 + 3000 + 4500 + 6000 + * I . 7500 + * · . 9000 + · 1 10500 + · I 12000 + .... + .... 0 200 + .... + .... + .... TENSION VS. DEPTH +-~- -+ .... + .... + .... INTERMEDIATE CASING .... +- - -++ .... + .... + .... + + I + l + l + I + + + I + I + I + l + + + l + I + I + I + + + I + I + t + 1 + + + I + l + I + I + + + I + I + I + I + I I I I · + l I I I .... + .... + .... + .... + 1200 1400 .... + .... + .... + .... + .... + .... + .... + 400 600 800 1000 TENSION DESIGN LINE (1000 LBS) * JOINT/BODY STRENGTH (1000 LBS) + OPERATOR: AMERADA HESS CORPORATION N-80 DATE: 22-DEC-93 LEASE: NORTHSTAR NO. 3 FIELD: NORTHSTAR UNIT SEC. 20 TWP. 13N RNG. 13E COUNTY: NSB STATE: ALASKA LINER CASING DESIGN DATA DESIGN CODE: 1 CASING STRING DESIGN CODE ............................. ***************************** DESIGN FACTORS: 2 BURST DESIGN FACTOR .................................. = 1.100 3 COLLAPSE DESIGN FACTOR ............................... = 1.100 4 TENSION DESIGN FACTOR ................................ = 1.600 50VERPULL IN EXCESS OF THE STRING WEIGHT ......... (LBS) = 100000.000 LINER BURST DESIGN DATA: 6 SURFACE EQUIPMENT WORKING PRESSURE .............. (PSI) = 7 FRACTURE GP3~DIENT AT THE LINER SHOE + YOUR SAFETY FACTOR .............................. (PPG) = 8 GAS GRADIENT ................................. (PSI/FT) = 9 MAXIMUM ANTICIPATED MUD WEIGHT .................. (PPG) = 10 WEIGHT OF BACKUP FLUID .......................... (PPG) = 5000.000 16.600 .115 10.400 10.000 LINER COLLAPSE DESIGN DATA: 11 MUD WEIGHT CASING IS SET IN ..................... (PPG) = 12 TOP OF CEMENT .................................... (FT) = 13 WEIGHT OF CEMENT ................................ (PPG) = 14 MINIMUM BACKUP .................................. (PPG) = 10.000 8452.000 15.800 10.000 LINER DESIGN DATA: 19 LINER SIZE, O.D .................................. (IN) = 7.000 20 LINER (MIN. ACCEPTABLE) DRIFT DIAMETER ........... (IN) = 6.000 21 LINER HANGER DEPTH ............................... (FT) = 8452.000 22 LINER SETTING DEPTH .............................. (FT) = 10521.000 23 MINIMUM SECTION LENGTH ........................... (FT) = .000 CALCULATION CONTROL DATA: 24 UPGP3JDE BURST FOR TENSION ............... (0=YES;i=NO) =. 25 UPGRADE COLLAPSE FOR COMPRESSION ........ (0=YES;i=NO) = 26 CONSIDER EFFECT OF BOUYANCY ON TENSION...(0=YES,i=NO) = 27 MAXIMUM LOAD;MAXIMUM STRAIN ENERGY.. (0=LOAD;i=STRAIN) = CASING TABLE NAME: 28 CURRENTLY SELECTED CASING TABLE ............ (CAS.BIN) = C:CAS.BIN OPERATOR: AMERADA HESS CORPORATION LEASE: NORTHSTAR NO. 3 SEC. 20 TWP. 13N RNG. 13E COUNTY: NSB FIELD: DATE: 22-DEC-93 NORTHSTAR UNIT STATE: ALASKA LINER CASING DESIGN -- 7.000 DEPTH LENGTH WEIGHT GRADE JOINT PRICE (FT) (FT) (LB/FT) ( $/FT) 8452.0 2069.0 STRING COST ** INTERNAL YIELD ** COLLAPSE LOAD ** FORMULA USED: 26.00 N-80 BTC = $ STRING WEIGHT = UPGRADED FOR TENSION ** UPGRADED FOR COMPRESSION ** MAXIMIIM LOAD THEORY ** 53794. LBS BURST DEPTH (FT) 8452.0 10521.0 PIPE IN TENSION PIPE BURST PIPE DESIGN WEIGHT/GRADE/JOINT LOAD BURST FACTOR (PSI) (PSI) NOT IN TENSION PIPE DESIGN BURST FACTOR (PSI) 26.00/N-80 /BTC 4443. 7281. 1.64 7240. 1.63 26.00/N-80 /BTC 3607. 6983. 1.94 7240. 2.01 COLLAPSE DEPTH (FT) 8452.0 10521.0 PIPE WE IGHT/GRADE/JO INT 26.00/N-80 /BTC 26.00/N-80 /BTC PIPE IN TENSION COLLAPSE PIPE DESIGN LOAD COLLAPSE FACTOR (PSI) (PSI) 43. 5379. 125.12 623. 5584. 8.96 NOT IN TENSION PIPE DESIGN COLLAPSE FACTOR (PSI) 5410. 125.86 5410. 8.68 TENSION DEPTH (FT) PIPE WEIGHT/GRADE / JO INT TENS ION LOAD (1000 LBS) JOINT/BODY STRENGTH (1000 LBS) 8452.0 10521.0 TENSION DESIGN FACTOR 26 . 00/N-80 /BTC 7 . 8 603 . 9 77 . 07 26.00/N-80 /BTC -46.0 603.9 -13.14 OPERATOR: AMERADA HESS CORPORATION DATE: 22-DEC-93 LEASE: NORTHSTAR NO. 3 SEC. 20 TWP. 13N RNG. 13E FIELD: NORTHSTAR UNIT COUNTY: NSB STATE: ALASKA 8000 + .... + .... + .... 8500 + · · I 9000 + 9500 + · 10000 + 10500 + I · 11000 + I 11500 + · 12000 + .... + .... + .... 1000 20O0 3000 LINER BURST PRESSURE VS. DEPTH + .... + .... + .... . .... + .... .... + .... +--+-+ .... + + + + + + + + + + + + + + + + + + + + + + + + + .... + .... + .... + .... 700O 4000 5000 6000 BURST DESIGN LINE (PSI) PIPE BURST (PSI) + I I 1 I + I 1 1 + I I I I + I I I I + I 1 I I · + I I I I + I I I I + I · I I I + 8000 OPERATOR: AMEP_ADA HESS CORPORATION LEASE: NORTHSTAR NO. 3 SEC. 20 TWP. 13N RNG. 13E DATE: 22-DEC-93 FIELD: NORTHSTAR UNIT COUNTY: NSB STATE: ALASKA 8000 * .... + .... 8500 * I* 9000 + * I * 9500 + * 10000 + * I * 10500 + * I I . 11000 + I 11500 + 12000 + .... + .... 0 1000 + .... + .... + .... 2000 LINER COLLAPSE PRESSURE VS. DEPTH + .... + .... + .... + .... + .... +- -+-+ .... + + + + + + + + + + + + + + + + 3000 + .... + .... + .... + .... 4000 500O COLLAPSE DESIGN LINE (PSI) * PIPE COLLAPSE (PSI) + 6000 .... + .... + I I I I + I I I I + I I I I + I I I I + I I I I + I I I I + + I -t- .... -I- '7000 OPERATOR: AMERADA HESS CORPORATION DATE: 22-DEC-93 LEASE: NORTHSTAR NO. 3 FIELD: NORTHSTAR UNIT SEC. 20 TWP. 13N RNG. 13E COUNTY: NSB STATE: ALASKA 8000 + .... + .... t I · I I 8500 + I I 1 · 1 9000 + 1 I I 1 9500 + I I I I 10000 + 10500 + 11000 + 11500 + 12000 + .... + .... 0 100 TENSION VS. DEPTH .... + .... + .... + .... + .... + .... + .... + .... LINER 200 300 400 500 TENSION DESIGN LINE (1000 LBS) * JOINT/BODY STRENGTH (1000 LBS) + + .... + .... + + + + + + + + + + I + + + + + I + + + + + + I + + I + + + I + + + I + + I I I I + I + I I I I .... + .... + ....+ 600 7OO BJ Services has been selected to perform the Cementing work on the Northstar No. 3 well. The following pages define the cementing program that will be used for each casing string. BJ SERVICES AMEFLADA HESS CORPORATION CEMENT SERVICES - NORTHSTAR //3 NORTH SLOPE, ALASKA WELL DATA CONDUCTOR CASING DEPTH 1000'MD, TVD VOLUME HOLE SIZE 26" EXCESS PIPE SIZE 20"OD, 94# VOLUME REQUIRED MUD WEIGHT 9 PPG TOP OF CEMENT BHST 26° F PREFLUSH BHCT 40° F 1670 CF 100 % OH 2969 CF SURFACE WATER CEMENT RECOMMENDATION Slurry;-3100 Sks (2976 cf) COLDSET II + 1 ghs FP-6L Top Out: 200 Sacks (192 cf) COLDSET II + 1 ghs FP-6L CEMENT PROPERTIES PREFLUSH SLURRY TOP OUT DENSITY - PPG 14.95 14.95 YIELD - CF/SK 0.96 0.96 MiX WATER - GALS/SK 3.89 3.89 THICKENING TIME - HRS:MINS 4:00 4'00 FLUID LOSS - CC's /30 MINS FREE WATER - ML's COMPRESSIVE STRENGTH - PSI 0 0 12 HOURS @ OF 500 500 24 HOURS @ °F 1500 1500 REMARKS Volume includes a42' float joint. Base of Permafrost@ ~ 1300'- 1700' MD 30" OD casingw/1" WTat 100' ss (rkb = 37'). Stab-In equip used w/5"OD 19,50 ppf Drill Pipe. BJ SERVICES AMERADA HESS CORPORATION CEMENT SERVICES - NORTHSTAR #3 NORTH SLOPE, ALASKA WELL DATA SURFACE CASING DEPTH HOLE SIZE PiPE SIZE MUD WEIGHT BHST BHCT 3900 'MD, TVD VOLUME 2310 CF 16" EXCESS 100 % OH 13 3/8"0D, 68# VOLUME REQUIRED 3530 CF 9.5 PPG TOP OF CEMENT SURFACE 50° F PREFLUSH 50 bbls Water 40° F CEMENT RECOMMENDATION Lead: Tail: 1585 Sks (3043 cf) BJ COLD SET 111 + 1 ghs FP-6L .- 430 Sks (494~f) Class G + 2% A-7, CaCI + I 9hs FP-6L'(500' fill) Top Out: 200 Sacks (192 cf) COLDSET II + 1 ghs FP-6L CEMENT PROPERTIES PREFLUSH LEAD TAIL , DENSITY - PPG 12.2 15.8 YIELD - CFISK 1.92 1.15 10.53 MIX WATER - GALS/SK THICKENING TIME - HRS:MINS 5:30 FLUID LOSS - CC's / 30 MINS FREE WATER - ML's COMPRESSIVE STRENGTH - PSI 1 2 HOURS @ OF 50 100 24 HOURS @ OF 4.95 4:00 0.4 1000 240O REMARKS Volume includes a 85' Float Joint I~J SERVICES AMERADA HESS CORPORATION CEMENT SERVICES - NORTHSTAR//3 NORTH SLOPE, ALASKA INTERMEDIATE CASING WELL DATA DEPTH 8818'MD, 8452'TVD VOLUME 833 CF HOLE SIZE 12 1/4" EXCESS 40% OH PiPE SIZE 9 5/8"OD, 47// VOLUME REQUIRED 1153 CF MUD WEIGHT ' 10 PPG TOP OF CEMENT 6268 MD BHST 1 80° F PREFLUSH BHCT 125o F CEMENT RECOMMENDATION Preflush: Lead: Tail: - CEMENT PROPERTIES i i i 50 Bbls Water containing 1% MCS-A 270 Sks (894 cf) Class G + 3% A-2 + 0.3% FL-52 + 0.4% CD-32 + 1 ghs FP-6L 225 Sks (256 cf) Class G + 0.3% FL-52 + 0.5%CD-32 + 0.05%A-2 + 1 ghs FP-6L (5O0' fill) PREFLUSH LEAD TAIL DENSITY - PPG 8.4 11.0 15.8 YIELD - CF/SK 3.31 1.14 MIX WATER - GALS/SK THICKENING 'TIME - HRS:MINS FLUID. LOSS - CC's / 30 MINS FREE WATER - ML's COMPRESSIVE STRENGTH - PSI 20.92 4.85 5'00 4:30 75 - 50 0 0 12 HOURS @ °F 100 1400 24 HOURS @ °F 200 2800 REMARKS Slight additive adjustments are expected to meet desired properties. Volume includes a 85' Float Joint. Actual volume required based on calipier plus 15% excess. E~J SERVICES AMERADA HESS CORPORATION CEMENT SERVICES - NORTHSTAR #3 NORTH SLOPE, ALASKA PRODUCTION LINER WELL DATA DEPTH 10521 'MD, 10000'TVD VOLUME HOLE SIZE 8 1/2" EXCESS PIPE SIZE 7"OD, 26// VOLUME REQUIRED MUD WEIGHT 10.5 ppg TOP OF CEMENT BHST 210° F PREFLUSH BHCT 145o F 374 CF 1 OO% OH 590 cf 8218' MD Pre flush/Spacer CEMENT RECOMMENDATION Preflush: 20 Bbls Water containing 1% MCS-A 50 Bbls MCS-4 spacer Slurry: 500 Sks (590 cf) Class G + 0.4% FL-33 + 0.25% CD-32 + 0.1%R-1 + 1 ghs FP-6L CEMENT PROPERTIES PREFLUSH SLURRY DENSITY - PPG 8.4 / 12.0 15.7 YIELD - CF/SK 1.18 MIX WATER - GALS/SK THICKENING TIME - HRS:MINS FLUID LOSS - CC's /30 MINS FREE WATER - ML's COMPRESSIVE STRENGTH - PSI 1 2 HOURS @ °F 24 HOURS @ °F FANN 35 READINGS @ RPM REMARKS 5.03 4:00 < 5O 0.0 @ 450 angle est 1900 est 3500 600 300 200 100 6 3 164 94 66 38 6 4 Top of Liner @ 8418'MD, 8052'TVD. Slight additive adjustment should be expected to achieve the desired results. Actual Volume required to be based on calipier plus 25%. AMERADA HESS CORPORATION NORTHSTAR NO. 3 DIRECTIONAL PROGRAM AMERADA HESS Corporation North Star #3 NS #3 slot #1 Exploration North Slope, Alaska PROPOSAL L I ST I N G by Baker Hughes INTEQ Your ref : North Star #3 Version #2 Our ref : prop820 License : Date printed : 30-Nov-93 Date created : 19-Jun-93 Last revised : 30-Nov-93 Field is centred on nTO 28 24.450,w148 49 2.487 Structure is centred on n70 28 24.450,w148 49 2.487 Slot location is n70 28 29.384,w148 50 5.410 Slot Grid coordinates are N 6024643.292, E 642634.180 Slot local coordinates are 502.00 N 2140.00 W Reference North is True North AMERADA HESS Corporation North Star #3,NS #3 Exploration,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : North Star #3 Version #2 Last revised : 30-Nov-93 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 0.00 0.00 196.39 0.00 0.00 N 0.00 E 0.00 0.00 500.00 0.00 196.39 500.00 0.00 N 0.00 E 0.00 0.00 1000.00 0.00 196.39 1000.00 0.00 N 0.00 E 0.00 0.00 1500.00 0.00 196.39 1500.00 0.00 N 0.00 E 0.00 0.00 2000.00 0.00 196.39 2000.00 0.00 N 0.00 E 0.00 0.00 2500.00 0.00 196.39 2500.00 0.00 N 0.00 E 0.00 0.00 3000.00 0.00 196.39 3000.00 0.00 N 0.00 E 0.00 0.00 3500.00 0.00 196.39 3500.00 0.00 N 0.00 E 0.00 0.00 3900.00 0.00 196.39 3900.00 0.00 N 0.00 E 0.00 0.00 4000.00 0.00 196.39 4000.00 0.00 N 0.00 E 0.00 0.00 13 3/8" Casing Point KOP 4100.00 2.00 196.39 4099.98 1.67 S 0.49 W 2.00 1.74 4200.00 4.00 196.39 4199.84 6.69 S 1.97 W 2.00 6.98 4300.00 6.00 196.39 4299.45 15.06 S 4.43 W 2.00 15.69 4400.00 8.00 196.39 4398.70 26.75 S 7.87 W 2.00 27.88 4500.00 10.00 196.39 4497.46 41.75 S 12.28 W 2.00 43.52 4600.00 12.00 196.39 4595.62 60.06 S 17.66 W 2.00 62.60 4700.00 14.00 196.39 4693.06 81.64 S 24.01 W 2.00 85.10 4800.00 16.00 196.39 4789.64 106.47 S 31.31 W 2.00 110.98 4900.00 18.00 196.39 4885.27 134.52 S 39.56 W 2.00 140.21 5000.00 20.00 196.39 4979.82 165.75 S 48.75 W 2.00 172.77 5100.00 22.00 196.39 5073.17 200.13 S 58.86 W 2.00 208.60 5200.00 24.00 196.39 5165.21 237.61 S 69.88 W 2.00 247.67 5234.70 24.69 196.39 5196.82 251.33 S 73.92 W 2.00 261.98 5500.00 24.69 196.39 5437.87 357.66 S 105.20 W 0.00 372.81 6000.00 24.69 196.39 5892.14 558.06 S 164.14 W 0.00 581.70 End of Build 6500.00 24.69 196.39 6346.42 758.46 S 223.08 W 0.00 790.58 7000.00 24.69 196.39 6800.70 958.86 S 282.02 W 0.00 999.47 7500.00 24.69 196.39 7254.97 1159.25 S 340.96 W 0.00 1208.35 8000.00 24.69 196.39 7709.25 1359.65 S 399.90 W 0.00 1417.24 8500.00 24.69 196.39 8163.52 1560.05 S 458.84 W 0.00 1626.12 8815.31 24.69 196.39 8450.00 1686.42 S 496.01W 0.00 1757.85 9 5/8" Casing Point 9000.00 24.69 196.39 8617.80 1760.44 S 517.78 W 0.00 1835.01 9103.68 24.69 196.39 8712.00 1802.00 S 530.00 W 0.00 1878.32 TARGET #1 9500.00 24.69 196.39 9072.08 1960.84 S 576.72 W 0.00 2043.90 10000.00 24.69 196.39 9526.35 2161.24 S 635.66 W 0.00 2252.78 10500.00 24.69 196.39 9980.63 2361.64 S 694.60 g 0.00 2461.67 10521.32 24.69 196.39 10000.00 2370.18 S 697.11W 0.00 2470.57 TD - 7" Casing Point All data is in feet unless otherwise stated Coordinates from slot #1 and TVD from wellhead (37.00 Ft above rkb). Vertical section is from wellhead on azimuth 196.39 degrees. Declination is 0.00 degrees, Convergence is 1.11 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ AMERADA HESS Corporation PROPOSAL LISTING Page 2 North Star ~3,NS #3 Your ref : North Star #3 Version #2 Exploration,North Slope, Alaska Last revised : 30-Nov-93 Comments in wellpath MD TVD Rectangular Coords. Comment 3900.00 3900.00 0.00 N 0.00 E 13 3/8" Casing Point 4000.00 4000.00 0.00 N 0.00 E KOP 5234.70 5196.82 251.33 S 73.92 W End of Build 8815.31 8450.00 1686.42 S 496.01W 9 5/8" Casing Point 9103.68 8712.00 1802.00 S 530.00 W TARGET #1 10521.32 10000.00 2370.18 S 697.11W TD - 7" Casing Point Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOE 3900.00 3900.00 O.OON O.OOE 13 3/8" Csg 0.00 0.00 O.OON O.OOE 8815.31 8450.00 1686.42S 496.01W 9 5/8" Casing 0.00 0.00 O.OON O.OOE 10521.32 10000.00 2370.18S 697.11W 7" Casing Targets associated with this wellpath Target name Position T.V.D. Local rectangular coords. Date revised Target #1 not specified 8712.00 1802.00S 530.00W 19-Jun-93 All data is in feet unless otherwise stated Coordinates from slot #1 and TVD from wellhead (37.00 Ft above rkb). Bottom hole distance is 2470.57 on azimuth 196.39 degrees from wellhead. Total Dogleg for wellpath is 24.69 degrees. Vertical section is from wellhead on azimuth 196.39 degrees. Declination is 0.00 degrees, Convergence is 1.11 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ AMERADA HESS Corporation North Star #3,NS #3 Exploration,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : North Star #3 Version #2 Last revised : 30-Nov-93 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 0.00 0.00 5OO.0O 0.00 1000.00 0.00 1500.00 0.00 2000.00 0.00 196.39 0.00 502.00 N 2140.00 W 0.00 0.00 196.39 500.00 502.00 N 2140.00 W 0.00 0.00 196.39 1000.00 502.00 N 2140.00 W 0.00 0.00 196.39 1500.00 502.00 N 2140.00 W 0.00 0.00 196.39 2000.00 502.00 N 2140.00 W 0.00 0.00 2500.00 0.00 3000.00 0.00 3500.00 0.00 3900.00 0.00 4000.00 0.00 196.39 2500.00 502.00 N 2140.00 W 0.00 0.00 196.39 3000.00 502.00 N 2140.00 W 0.00 0.00 196.39 3500.00 502.00 N 2140.00 W 0.00 0.00 196.39 3900.00 502.00 N 2140.00 W 0.00 0.00 196.39 4000.00 502.00 N 2140.00 W 0.00 0.00 13 3/8" Casing Point KOP 4100.00 2.00 196.39 4099.98 500.32 N 2140.49 W 2.00 1.74 4200.00 4.00 196.39 4199.84 495.30 N 2141.97 W 2.00 6.98 4300.00 6.00 196.39 4299.45 486.94 N 2144.43 W 2.00 15.69 4400.00 8.00 196.39 4398.70 475.25 N 2147.87 W 2.00 27.88 4500.00 10.00 196.39 4497.46 460.24 N 2152.28 W 2.00 43.52 4600.00 12.00 196.39 4595.62 441.94 N 2157.66 W 2.00 62.60 4700.00 14.00 196.39 4693.06 420.36 N 2164.01 W 2.00 85.10 4800.00 16.00 196.39 4789.64 395.53 N 2171.31 W 2.00 110.98 4900.00 18.00 196.39 4885.27 367.48 N 2179.56 W 2.00 140.21 5000.00 20.00 196.39 4979.82 336.25 N 2188.75 W 2.00 172.77 5100.00 22.00 196.39 5073.17 301.87 N 2198.86 W 2.00 208.60 5200.00 24.00 196.39 5165.21 264.39 N 2209.88 W 2.00 247.67 5234.70 24.69 196.39 5196.82 250.67 N 2213.92 W 2.00 261.98 5500.00 24.69 196.39 5437.87 144.34 N 2245.20 W 0.00 372.81 6000.00 24.69 196.39 5892.14 56.06 S 2304.14 W 0.00 581.70 End of Build 6500.00 24.69 196.39 6346.42 256.46 S 2363.08 W 0.00 790.58 7000.00 24.69 196.39 6800.70 456.86 S 2422.02 W 0.00 999.47 7500.00 24.69 196.39 7254.97 657.25 S 2480.96 W 0.00 1208.35 8000.00 24.69 196.39 7709.25 857.65 S 2539.90 W 0.00 1417.24 8500.00 24.69 196.39 8163.52 1058.05 S 2598.84 W 0.00 1626.12 8815.31 24.69 196.39 8450.00 1184.42 S 2636.01W 0.00 1757.85 9 5/8" Casing Point 9000.00 24.69 196.39 8617.80 1258.44 S 2657.78 W 0o00 1835.01 9103.68 24.69 196.39 8712.00 1300.00 S 2670.00 W 0.00 1878.32 TARGET #1 9500.00 24.69 196.39 9072.08 1458.84 S 2716.72 W 0.00 2043.90 10000.00 24.69 196.39 9526.35 1659.24 S 2775.66 W 0.00 2252.78 10500.00 24.69 196.39 9980.63 1859.64 S 2834.60 W 0.00 2461.67 10521.32 24.69 196.39 10000.00 1868.18 S 2837.11W 0.00 2470.57 TD - 7" Casing Point All data is in feet unless otherwise stated Coordinates from SE corner of Sec. 17, T13N, R13E, UM and TVD from wellhead (37.00 Ft above rkb). Vertical section is from wellhead on azimuth 196.39 degrees. Declination is 0.00 degrees, Convergence is 1.11 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes [NTEQ AMERADA HESS Corporation North Star #3,NS #3 Exploration,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : North Star ~3 Version #2 Last revised : 30-Nov-93 Comments in wellpath MD TVD Rectangular Coords. Comment 3900.00 3900.00 502.00 N 2140.00 W 13 3/8" Casing Point 4000.00 4000.00 502.00 N 2140.00 W KOP 5234.70 5196.82 250.67 N 2213.92 W End of Build 8815.31 8450.00 1184.42 S 2636.01W 9 5/8" Casing Point 9103.68 8712.00 1300.00 S 2670.00 W TARGET #1 10521.32 10000.00 1868.18 S 2837.11W TD - 7" Casing Point Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 502.00N 2140.00W 3900.00 3900.00 502.00N 2140.00W 13 3/8" Csg 0.00 0.00 502.00N 2140.00W 8815.31 8450.00 1184.42S 2636.01W 9 5/8" Casing 0.00 0.00 502.00N 2140.00W 10521.32 10000.00 1868.18S 2837.11W 7" Casing Targets associated with this wellpath Target name Position T.V.D. Local rectangular coords. Date revised Target #1 not specified 8712.00 1300.00S 2670.00W 19-Jun-93 All data is in feet unless otherwise stated Coordinates from SE corner of Sec. 17, T13N, R13E, UM and TVD from wellhead (37.00 Ft above rkb). Bottom hole distance is 2470.57 on azimuth 196.39 degrees from wellhead. Total Dogleg for wellpath is 24.69 degrees. Vertical section is from wellhead on azimuth 196.39 degrees. Declination is 0.00 degrees, Convergence is 1.11 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ I I V 700 1050 140,0 _ 1750 _ 2450 -- 2800 _ 3850 4200 4550 4900 5250 56/'.43 _ _ 5950 _ _ 6300 _ _ 6850 _ _ 70¢/3 _ _ 735O _ _ 7700 _ _ 8050 _ _ 8400_ 9100 945O 9800 AMERADA HESS Corporation RKB ELEVATION: $7' Structure : North Stor //3 Field : Explorotion :,Created by jones For: R SA,MONTE iDote plotted ' 30-Nov-93 ,~iPlot Reference is North Star #5 Version #2.!' iCoordinotes ore in feet reference slot #1. : (True Vertical Depths ore reference wellhead. Baker Hbghes INTEQ '. S 16.39 DEG W 1878' (TO TARGET) [ 13 3/8' Casing Point KOP 4.00 8.00 BUILD 2 DEG / 100' 12.OO 16.00 20.00 24.00 End of Build ~~9 5/8 Co mg Point \ ~X~ 10 - 7' ¢osing Point I I I I I I / I I I I I I I I I O 550 700 1050 1400 1750 2100 2450 2800 Sco~ 1 : 175.o0 Vedical Section on 196.3,9 azimuth with reference 0.00 ti. 0.00 E from slot Well: NS #3 Location : North Slope, Alaska Point .... !~e on iKOP ;Er~ of Build Target iEnd of HCd WELL PROFILE DATA MD Inc D;r ~ N~th 0 0.00 196.39 0 0 4000 0.00 196.39 4000 0 5235 24.69196.39 3197 -251 -74 9104 24.69196.59 8712 -1802 -5~0 10521 2~.6g196=39___ _10000 750 I I <-- West 600 450 300 1500 150 I I I f I I I I I I 0 End of Build 9 5/8~ Casing Point TD - 7 Casing Point ._ EoM 0 0.00~, 2.00i 0,00~, 150 ~ 1050 ('~ 1200 135o I 1800 2100 - _2250 . .2400 - _2550 AIVIERADA HESS CORPORATION NORTHSTAR NO. 3 TllVIE vs. DEPTH PLOT 1000 2OOO 3000 4000 5000 6000 7000 SO00 9OOO 10,000 11,OOO 12,000 DRILL 18" HOLE LOG. OPEN HOLE TO 26" I UN/CEMENT 20", NIPPLE UP 20" BOP STACK DRILL 16" HOLE ~-,,,, LOG. RUN/CEMENT 1.3 5/8", NIPPLE UP 1,$ 5/8" BOP CK. RUN CBL. KOP: 4000' BUILD 2'/100' TO 24.7' DRILL 12 1/4" HOLE MAINTAINING 24.7' LOG. RUN/CEMEMT 9 5/8". NIPPLE UP BOP STACK. RUN CBL. ORE KUPARUK "C" ZONE MAKE 8 1/2" HOLE PENER RUN DRILL 8 1/2" HOLE MAINTAINING 24.7' I LOG. RUN/ CEMEMT 7" LINER AND TEST WELL OR P&A I I I I I I I I I I 1 0 20 30 40 50 DAYS E...NSR .CONSULTING & ENGINEERING DRAWING: PDC2 DRAWN: ABEl C/SC: 1:20 DISK: 775/93 DATE: 12/2,3/93 CHECK: B.O. ESTIMATED DRILLING CURVE i"AMERADA HESS CORPORAT-ION I NORTHSTAR NO. 3 ...~ PROJECT 0_.!_5__t.7014-250 E & P SERVICES, INC, January 13, 1994 Mr. David Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ATT: Robert Crandall, Senior Petroleum Geologist RE: APD, Amerada Hess Corporation, Northstar No. 3 (Geophysical Analysis for Shallow Gas) Dear Mr. Crandall: Please find attached three (3) copies of a geophysical analysis for shallow gas for the above referenced well. This analysis has been prepared by Jeffe Ready of Amerada Hess Corporation in order to comply with 20 AAC 25.061(a). Shallow gas concerns have also been addressed in the well design. A 20" casing string will be cemented to surface from 1000 ft. MD and a 20" BOP stack (SRRA) installed prior to drilling below permafrost. In the unlikely event that gas is encountered beneath the permafrost, well control will be more secure than if this section were drilled using only a diverter. This submittal should complete all outstanding APD requirements. If you have any questions, please call at your convenience. ~Ri U Gardner Agent for Amerada Hess Corporation RCG/js Attachements cc: John Simon, Amerada Hess Corporation Jeffe Ready, Amerada Hess Corporation RECEIVED JAN 1 3 1994 Alaska Oil & Gas Cons. Commission Anchorage 715 L Street Anchorage, Alaska 99501 (907) 258-3446 FAX (907) 258-5557 '~ ~-~ i ~!~ ;~ii''/!~ SEISMIC ANALYSIS FOR SHALLOW GAS The high quality NOrthstar Unit seismic grid (red and purple lines on Figure 1), acquired or reprocessed in 1991-92 was analyzed for any evidence of shallow gas anomalies at or near the base of permafrost. The Northstar No. 3 will be drilled vertically to a depth of 4000' before kick off as shown on the seismic lines. The base of permafrost is expected at about 1600 feet as indicated by the pick in the Sohio Long Island well on the west end of Long Island, four miles west of the Northstar No. 3. Mud logs in the Sohio Long Island have no shows of gas in that interval. Anomalies due to gas should show up as either a bright spot (high amplitude), a dim out {low amplitude) or a sag in the data due to low velocity. No shallow anomalies attributable to gas were noted on the data near the well. LOW VELOCITY SAGS A sag in the data was noted on g2ANS16 between VP 220 and VP 280. The velocity gathers demonstrate an increase in velocity toward VP 130 above 1.0 seconds. This is indicative of thicker permafrost toward shore and is commonly found in the area. There is no pull up to the north indicating the other side of the sag, which would be expected if there were a restricted gas anomaly. BRIGHT SPOT (ABNORMAL HIGH AMPLITUDE) No bright spots were noted in the shallow data. The highest amplitude shallow reflection~ is at about .300 seconds on the data. This reflector has been ipenetrated by nearby wells, the Sohio Long Island, the Seal Island wells and the Northstar Island wells, and no significant gas was encountered. DIM SPOTS No dimming of individual reflectors was noted on the data set. Although dimming of all the shallow reflectors was noticed in several places, for example, VP 468 on SF84-401 and VP 280 on 92ANS16, these areas of data degradation are due to noise from the flexure wave generated at the bottom of the ice layer when shooting on ice. This noise severely affects the data shallower than 2.0 seconds on the records near the wellsite and anywhere where data is acquired on ice. WELLSITE SURVEYS Transition zone data along the shoreline, acquired during the summer, has been of poor quality and in the winter it will be strongly affected at shallow depths by the flexure wave. Therefore, acquiring a high quality shallow hazard survey such as those routinely done offshore would not be possible in the transition zone with present technology and methods. The above analysis of the conventional data sets and nearby wells reveals no indication of shallow gas. Shallow hazard data has not been acquired in the transition zone here and would likely be unusable for detecting shallow gas sands above 2000 feet. We request, therefore, that the wellsite survey requirements be waived. ~ ~. C E!V E D ,'~ :!:-~,~ Oii& Gas" ,' uOno. Commission Anchoragn Dril 1 ing procedures will be adopted to maximize safety while dril ling through this part of the section. P ECEI~,IED .Al',' C h o~ arjr'., FIGURE 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION $001 Porcupine Drive Anchorage Alaska 99501-3192 Re; THE APPLICATION OF AMERADA ) HESS CORPORATION for an order ) granting an exception to the spacing ) requirements of Title 20 AAC 25.055 ) to provide for the drilling of the ) Amerada Hess Corporation Northstar ) No. 3 exploratory oil well. ) Conservation Order No. 322 Amerada Hess Corporation Northstar No. 3 November 4, 1993 IT APPEARING THAT: Amerada Hess Corporation submitted an application dated Oct~)ber 11, 1993 requesting exception to 20 AAC 25.055(a)(1) to allow drilling the Amerada Hess Corporation Northstar No. 3 exploratory oil well to a bottom-hole location that is closer than 500 feet to a drilling unit boundary. , Notice of an oppommity for public heating was published in the Anchorage Daily News on October 20, 1993 pursuant to 20 AAC 25.540. 3. No substantive protests to the applications were received. FINDINGS: o . The Amerada Hess Corporation Northstar No. 3 well as proposed will be a deviated hole ckilled from a surface location 502' from the south line (FSL) and 2140' from the east line (FEL) of Section 17, T13N, R13E, Umiat Meridian (UM) to a proposed bottom-hole location 3235' FSL and 2889' FEL Section 20, T13N, R13E, UM. Amerada Hess Corporation is the owner and operator of all governmental quarter sections directly and diagonally offsetting the proposed bottom-hole location of the well. . An exception to 20 AAC 25.055(a)(1) is necessary to allow drilling of this well. Conservation Order No. 32. November 4, 1993 Page 2 CONCLUSION: Granting a spacing exception to allow drilling of the Amerada Hess Corporation Northstar No. 3 exploratory oil well as proposed will not result in waste nor jeopardize correlative rights. NOW, THEREFORE, IT IS ORDERED: Amerada Hess Corporation's application for exception to 20 AAC 25.055 for the purpose of drilling the Northstar No. 3 well is approved as proposed. DONE at Anchorage, Alaska and dated November 4, 1993. Ala~s'kd~~rvation CommisSion Russell A. Douglass, oner Alaska Oil and Gas Conservation Commission ennan A. Babcock, Commissioner Alaska Oil and Gas Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for reheating. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court hms from the date on wlfich the request is deemed denied (i.e., 10th day after the application for rehearing was filed). ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE (1) Fee (2) Loc '-" · ['2 thru 8]' (4) Casg ~u22] Company~/~/~ .~:' /' / · ,~ ..... :. ~, / YES /.:. Lease S Well NO [23 thru 28] 1. Is 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 undo. dicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... (6) Other 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ (7) Contact ,,~'/%¢ ' [~32 ]: ...... (8) Addl ~ /~,NT/f~..~ . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28 '['29 thrQ 3'1] 30 3!. 32. 33. geo 1 ogy' en~i n9: DWJ ~_ RAD~ I~l? "' REMARKS rev 6/93 jo/6.011 Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease ncrnber appropriate .......................................... Does well have a unique name & nLrnber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Wi]] cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wel]bore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to~4-~-~3 psig ..... Does choke manifold comply w/API RP-53 ~tay 84) ...................... Is presence of H2S gas probable.~ ./;~-~.~.~? FOR EXPLORATORY & STRATIGRAPHIC WELLS' Are data presented on potential overpressure zones ................... ~ Are seismic analysis data presented on shallow gas zones ............. ~!-~, / If offshore loc, are survey results of seabed conditions presented ,,Cz -': Name and phone nLrnber of contact to supply weekly progress data ~ · · · · · · . , , ., ? Additional requirements . . ' .......... Additional remarks' INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE ,,, J //.~' ./1~ ~,,~// ~-r,. UM >~ (.~/Dev ,~ Inj MERIDIAN' SM WELL TYPE' Redrill Rev Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. LIS VERIFICATION LISTING FOR: AMERADA HESS CORPORATION NORTHSTAR #3 WILDCAT AMERADA HESS ¢ORPOP&TION Date_. BELOW, J~E THE MNEMONICS THAT CAN BE FL .~D ON THE LIS TAPE GENERATED FOR AMERADA HESS CORPORATION NORTHSTAR #3 AZT CADE CPDE DCCM GRAM INC PDCM PDDC PDEM PDIM RACM RADE ROPA ROPS RPCM RPDE TCDM TVD Azimuth - True (Posted) Conductivity (AT) Corrected for Dielectric Effect [RWD] Conductivity (PD) Corrected for Dielectric Effect [RWD] Calculated Dielectric Constant Gamma Ray Memory (APl) [RWD] Inclination - True (Posted) Phase Difference Borehole Corrected [RWD] Phase Difference Dielectric Corrected [RWD] Phase Difference Elapsed Time [RWD] Phase Difference Data Density Integrated [RWD] Resistivity (AT) Borehole Corrected [RWD] Resistivity (AT) Corrected Dielectric Effect [RWD] Rate of Penetration Averaged Rate of Penetration Resistivity (PD) Borehole Corrected [RWD] Resistivity (PD) Corrected for Dielectric Effect [RWD] CDS Temperature [RWD] True Vertical Depth deg mmho/m mmho/m MWD-API deg deg deg mins pts ohm-m ohm-m fi/hr ft/hr ohm-m ohm-m deg F ff Note: AT is Attenuation PD is Phase Difference RWD is Recorded While Drilling Copyright 1987,1988,1989,1990,199', By WESTERN ATLAS INTERNATIONAL, INC. All rights reserved. PROGRAM: TAPESCAN REVISION: 2.64 Start of execution: Mon 25 APR 94 11:44a ECHOING INPUT PARAMETERS= INPUT PARAMETER FILE: TAPESCAN.INP 1 2 3 4 5 6 7 123456789012345678901234567890123456789012345678901234567890123456789012 1 AUTOCURV = 0 , ! Automatic Curve renaming: 0=OFF, I=ON 2 AUTOFILE = 0 , ! Automatic FILE= generation: 0=OFF, I=ON 3 COMMENTS = 1 , ! Decode LIS Comment records: 0=OFF, I=ON 4 INFORECS = 1 , ! Decode LIS Information records: 0=NO,I=YES 5 LISTMETHOD -- 0 , ! Listing Method: 0=depth units 1=tape units 6 LISTFREQ = 100, ! Listing Frequency: Every n units 7 LISTMAX = 0 , ! Listing Maximum (0=no limit, value=list limit) 8 STATS -- 0 , ! Statistics generation: 0 = OFF, 1 = ON 9 FORCETYP = 0 , ! (I=BIT,2=LIS ... thru 35=Array Accoustic) (see table) 10 WRITEASCII = 0 , ! If 1, all ascii files will be written (file0001.dat,etc.) 11 WRITETAP = 1 , ! Write Tape-Image File: 0=NO,I=YES 12 SPLITLIS = 1 , ! If 1 and WRITETAP on, split LIS logical files to physical 13 SUBFILES = /0/, ! Tape Subfile write selection (WRITETAP must be on) 14 INTERPOLATE='YES' ! Set up for TAPE2WDS to interpolate datums ~"YES'oCNO') 15 END != = USER INPUT PARAMETERS AUTOCURV = 0 , AUTOFILE = 0 , COMMENTS = 1 , INFORECS = 1 , LISTMETHOD = 0 , LISTFREQ = 100, LISTMAX = 0 ,. STATS = 0, FORCETYP = 0 , WRITEASCII = 0 , WRITETAP = 1 , SPLITLIS = 1 , SUBFILES /0/, INTERPOLATE ='YES' END !-- PROCESSING INTERVAL FROM 0.000 TO 0.000 ............. !-- CONSTANT PARAMETERS ........................................... AUTOCURV= O.O00000E+O0 AUTL _E= O.O00000E+O0 COMMENTS= 1.00b~ FORCETYP= O.O00000E+O0 INFORECS= 1.00000 LISTFREQ= 100.000 LISTMAX = O.O00000E+O0 LISTMETH= O.O00000E+O0 SELFTEST= O.O00000E+O0 SPLITLIS= 1.00000 STATS = O.O00000E+O0 WRITEASC= O.O00000E+O0 WRITETAP= 1.00000 dpcoef = 1.00000 dpcte = 1.00000 drlength= O.O00000E+O0 listwave= O.O00000E+O0 maxrecln= O.O00000E+O0 minrecln= O.O00000E+O0 nsamples= O.O00000E+O0 numcurvs= O.O00000E+O0 numdatar= O.O00000E +00 numrecfl = O.O00000E +00 tfendep = O.O00000E +00 fflevsp = O.O00000E+O0 tfstdep = O.O00000E+O0 wcrbot = O.O00000E+O0 wcrlevsp= O.O00000E+O0 wcrtop = O.O00000E+O0 !-- ARRAY PARAMETERS .............................................. SUBFILES(1) = O.O00000E+O0 SUBFILES(2) = -9999.00 SUBFILES(3) =-9999.00 SUBFILES(4) =-9999.00 SUBFILES(5) =-9999.00 SUBFILES(6) =-9999.00 SUBFILES(7) =-9999.00 SUBFILES(8) =-9999.00 SUBFILES(9) = -9999.00 SUBFILES(10) = -9999.00 SUBFILES(11) = -9999.00 SUBFILES(12) = -9999.00 SUBFILES(13) = -9999.00 SUBFILES(14) = -9999.00 SUBFILES(15) = -9999.00 SUBFILES(16) = -9999.00 SUBFILES(17) = -9999.00 SUBFILES(18) = -9999.00 SUBFILES(19) = -9999.00 SUBFILES(20) = -9999.00 SUBFILES(21) = -9999.00 SUBFILES(22) = -9999.00 SUBFILES(23) = -9999.00 SUBFILES(24) = -9999.00 SUBFILES(25) = -9999.00 SUBFILES(26) = -9999.00 SUBFILES(27) -- -9999.00 SUBFILES(28) = -9999.00 SUBFILES(29) = -9999.00 SUBFILES(30) = -9999.00 SUBFILES(31) = -9999.00 SUBFILES(32) = -9999.00 SUBFILES(33) = -9999.00 SUBFILES(34) = -9999.00 SUBFILES(35) = -9999.00 SUBFILES(36) = -9999.00 SUBFILES(37) = -9999.00 SUBFILES(38) = -9999.00 SUBFILES(39) = -9999.00 SUBFILES(40) = -9999.00 SUBFILES(41) = -9999.00 SUBFILES(42) = -9999.00 SUBFILES(43) = -9999.00 SUBFILES(44) = -9999.00 SUBFILES(45) = -9999.00 SUBFILES(46) = -9999.00 SUBFILES(47) = -9999.00 SUBFILES(48) = -9999.00 SUBFILES(49) = -9999.00 SUBFILES(50) = -9999.00 SUBFILES(51) = -9999.00 SUBFILES(52) = -9999.00 SUBFILES(53) = -9999.00 SUBFILES(54) = -9999.00 SUBFILES(55) = -9999.00 SUBFILES(56) = -9999.00 SUBFILES(57) = -9999.00 SUBFILES(58) = -9999.00 SUBFILES(59) = -9999.00 SUBFILES(60) = -9999.00 SUBFILES(61) = -9999.00 SUBFILES(62) = -9999.00 SUBFILES(63) = -9999.00 SUBFILES(64) = -9999.00 SUBFILES(65) = -9999.00 SUBFILES(66) = -9999.00 SUBFILES(67) = -9999.00 SUBFILES(68) = -9999.00 SUBFILES(69) = -9999.00 SUBFILES(70) = -9999.00 SUBFILES(71) = -9999.00 SUBFILES(72) = -9999,00 SUBFILES(73) = -9999.00 SUBFILES(74) = -9999.00 SUBFILES(75) = -9999.00 SUBFILES(76) = -9999.00 SUBFILES(77) = -9999.00 SUBFILES(78) = -9999.00 SUBFILES(79) = -9999.00 SUBFILES(80) = -9999.00 SUBFILES(81) = -9999.00 SUBFILES(82) = -9999.00 SUBFILES(83) = -9999.00 SUBFILES(84) = -9999.00 SUBFILES(85) = -9999.00 SUBFILES(86) = -9999.00 SUBFILES(87) = -9999.00 SUBFILES(88) = -9999.00 SUBFILES(89) = -9999.00 SUBFILES(90) = -9999.00 SUBFILES(91) = -9999.00 SUBFILES(92) = -9999.00 SUBFILES(93) = -9999.00 SUBFILES(95) ---9999.00 SUBFILES(97) = -9999.00 SUBFILES(99) = -9999.00 SUBFILES (101 ) = -9999.00 SUBFILES(103) = -9999.00 SU BFILES (105) = -9999.00 S U B FILE S (107) ---9999.00 SUBFI LES (109) ---9999.00 SUBFILES(111) = -9999.00 SUBFILES(113) ---9999.00 SUBFILES(115) ---9999.00 SUBFILES(117) = -9999.00 SUBFILES(119) = -9999.00 SUBFILES(121) = -9999.00 SUBFI LES (123) ---9999.00 SUBFILES(125) = -9999.00 SUBFILES(127) = -9999.00 SL ,LES(94) = -9999.00 SUBFILES(96) = -9999.00 SUBFILES(98) = -9999.00 SUB FILES (100) -- -9999.00 SUBFILES(102) = -9999.00 SUBFILES(104) = -9999.00 SUBFILES(106) = -9999.00 SUBFILES(108) = -9999.00 SUBFILES(110) -- -9999.00 SUBFILES(112) = -9999.00 SUBFILES(114) = -9999.00 SUBFILES(116) = -9999.00 SUBFILES(118) = -9999.00 SUBFILES(120) -- -9999.00 S U B FI LES (122 ) -- -9999.00 SUBFILES(124) = -9999.00 SUBFILES (126) -- -9999.00 SUBFILES(128) = -9999.O0 !-- STRING PARAMETERS ............................................. INTERPOL-- YES Input Tape Device, LU (1) is: TAPEC: Output Tape-Image file, LU (2) is: J:\1316\1316.TAP (Output Tape-Image file will be created) Listing Method ("LISTMETH") - 0, Depth Unit oriented listing. Listing Frequency ("LISTFREQ") is every ( 100) units of Depth. Listing output limiting (LISTMAX) not enabled... (to enable list limiting set LISTMAX positive) Data Statistics reporting ("STATS") has not been enabled. (Specify STATS = 1 to enable this feature) Automatic curve renaming has been disabled by user input (AUTOCURV=0). Automatic "FILE= n" card generation is disabled. ('rhis is the program default, AUTOFILE=0) (Specify AUTOFILE = 1 to enable this feature) LIS comment record decoding (COMMENTS= 1) has been enabled by user input. LIS information record decoding (INFORECS=I) has been enabled by user input. The WRITEASC option has not been enabled... (to write ASCII subfiles specify WRITEASC= 1) Tape Subfile 1 is type: LIS **** REEL HEADER **** LIS 94/04/25 TELECO 01 ** LIS CUSTOMER LIBRARY TAPE BAKER HUGHES INTEQ **** TAPE HEADER **** LIS 94/04/25 00001316 01 TELECO DPR DATA FROM AMERADA HESS'S NORTHSTAR #3 Tape Subtile: 1 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Tape Subtile 2 is type: LIS **** FILE HEADER **** MAIN .001 1024 CN : The Amerada Hess Corp. WN : The Northstar #3 FN :WILDCAT COUN : NORTH SLOPE STAT :ALASKA LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS THE DATA FROM NORTHSTAR #3. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 1213141516 0001 00000001 0001 Rep Code Count Bytes 68 18 72 Sum: 18 72 72 fndun a [FT ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F-I' 18 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ CIs Mod 1 AZT MAIN 68 1 DEG 4 2 CADE MAIN 68 1 MMHO 3 CPDE MAIN 68 1 MMHO 4 DCCMMAIN 68 1 4 5 GRAM MAIN 68 1 GAPI 4 6 INC MAIN 68 1 DEG 4 7 PDCM MAIN 68 1 DEG 4 8 PDDC MAIN 68 1 DEG 4 9 PDEM MAIN 68 1 MINS 4 10 PDIM MAIN 68 1 PTS 4 11 RACM MAIN 68 1 OHMM 4 12 RADE MAIN 68 1 OHMM 4 13 ROPA MAIN 68 1 FPH 4 14 ROPS MAIN 68 1 FPH 4 15 RPDE MAIN 68 1 OHMM 4 16 RPCM MAIN 68 1 OHMM 4 17 TCDM MAIN 68 1 DEGF 4 18 TVD MAIN 68 1 FT 4 72 4 45 35O 01 1 4 45 350 01 1 4 45 35O 01 1 4 45 350 01 1 4 95 580 03 1 4 95 800 03 1 4 95 181 03 1 4 95 181 03 1 4 95 181 03 1 4 95 181 03 1 4 95 181 03 1 4 95 181 03 1 4 95 970 01 1 4 95 970 01 1 4 95 181 03 1 4 95 181 03 1 4 95 980 01 1 4 95 980 01 1 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 13 FRAMES * DATA RECORD (TYPE# O) 994 BYTES * Total Data Records: 1901 Tape File Start Depth = 3824.000000 Tape File End Depth = 10000.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 59968 datums Tape Subtile: 2 1906 records... Minimum record length: 62 bytes Maximum record length: 994 bytes Tape Subtile 3 is type: LIS **** TAPE TRAILER **** LIS 94/04/25 OOOO1316 01 **** REEL TRAILER **** LIS 94/04/25 TELECO 01 Tape Subtile: 3 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 25 APR 94 11:46a Elapsed execution time -- 1 minute, 43.6 seconds. SYSTEM RETURN CODE = 0 Tape Subtile 1 is type: LIS Tape Subtile 2 is type: LIS DEPTH AZT CADE CPDE DCCM GRAM INC PDCM PDDC PDEM PDIM RACM RADE ROPA ROPS RPDE RPCM TCDM TVD 3824.0000 153.1300 -999.2500 -999.2500 -999.2500 14.7679 0.6400 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 10.5569 12.3862 -999.2500 -999.2500 55.9203 3823.9048 3824.2500 153.1300 -999.2500 -999.2500 -999.2500 13.3979 0.6400 -999.2500 -999.2500 -999.2500 -999.2500 0.2836 -999.2500 10.5569 11.1667 -999.2500 5.8001 55.3524 3824.1548 3900.0000 153.1300 -999.2500 -999.2500 -999.2500 21.1885 0.6400 -999.2500 -999.2500 221.9167 -999.2500 0.1771 -999.2500 318.6774 315.0279 -999.2500 353.5269 61.7051 3899.8999 4000.0000 147.1583 458.1412 40.5299 1.2333 18.9354 326.5000 2.2880 2.1827 1.8665 1.8129 57.6219 4100.0000 187.5505 563.0265 75.1910 4.7621 21.4354 990.0000 1.8498 1.7761 1.5014 1.4613 59.1875 4200.0000 188.8957 372.7717 39.0694 7.8128 17.1386 1323.5000 2.8337 2.6826 2.2194 2.1497 62.1781 4300.0000 188.9755 221,5577 67.2247 8.2170 12.9979 1909.0000 4.9045 4.5135 3.5304 3.3993 64.6250 4400.0000 187.5258 437.9454 35.6529 9.0871 18.8417 2374.0000 2.3981 2.2834 1.8838 1.8284 66.6500 4500.0000 187.4234 236.2004 70.0908 10.8021 13.3104 2933.5000 4.5780 4.2337 3.3943 3.2709 69.9687 4600.0000 193.2305 583.0677 29.2215 12.0011 21.1542 -999.2500 1.7836 1.7151 1.5369 1.4962 72.8375 535.7512 18.6249 212.9322 3999.8848 666.0609 21.1157 73.5623 4O99.6885 450.5772 16.8304 173.3348 4199.0273 283.2545 12.7105 81.5040 4298.0488 530.8481 18.5279 203.4661 4396.9150 294.6073 13.0214 68.4988 4495.4O92 650.6608 2O.8344 247.4248 4593.4336 166.7775 110.0664 177.1942 185.0213 38.7333 77.0096 153.6896 129.2833 135.5803 123.5616 113.6667 85.1653 166.0947 33.3833 236.1808 125.8364 54.7500 68.7071 182.9247 27,3944 221.4026 DEPTH GRAM PDIM RPDE AZT INC RACM RPCM .ADE PDCM RADE TCDM CPDE PDDC ROPA TVD DCCM PDEM ROPS 4700.0OOO 27.8144 -999.2500 1.2138 4800.0000 39.4798 4164.0000 1.4816 4900.0000 49.9893 4641.0000 2.4311 5000.0000 27.7606 5157.5000 3.6225 5100.0000 44.9091 5645.OOOO 1.2529 5200.0000 56.9468 6133.5000 1.8359 5300.0000 57.0749 6633.0000 1.1370 5400.0000 71.8652 7333.5000 3.0109 5500.0000 69.1089 -999.2500 2.4684 5600.0000 77.3815 8511.0000 2.2272 57oo.ooo0 64.5239 9075.00O0 2.8924 194.4602 13.8989 1.4837 1.1876 193.1326 16.2821 1.3612 1.4427 194.7426 17.0808 2.9578 2.3524 197.1226 19.5613 2.6120 3.4869 194.0526 21.6947 1.4189 1.2221 187.6505 24.2659 2.O089 1.7907 187.5806 24.6774 1.2148 1.1100 188.3333 24.9333 4.2038 2.9061 188.8000 25.1652 2.9580 2.3890 188.4538 25.4989 2.7685 2.1584 187.7095 25.7116 3.3189 2.7938 698.3263 24.1386 1.4320 73.5125 756.2743 21.5917 1.3223 73.9625 357.3362 16.2479 2.7985 73.3437 398.2668 12.7948 2.5109 71.9375 728.5465 23.7167 1.3726 73.8781 518.5265 19.1185 1.9285 74.0750 847.7250 25.O292 1.1796 68.8875 256.4946 14.3104 3.8987 74.2437 357.3091 16.1004 2.7987 77.1687 381.1779 17.0990 2.6234 80.1781 319.4213 14.6566 3.1307 84.0312 823.8450 23.8143 212.2228 4690.9033 674.9346 21.2747 209.7097 4787.4590 411.3397 15.9430 102.7770 4883.2539 276.0538 12.5071 69.8371 4978.1777 798.1438 23.3938 28O.0220 5071.7227 544.6871 18.8059 131.9178 5163.7480 879.4916 24.7026 253.4835 5254.7549 332.1285 14.0148 47.1773 5345.5244 405.1204 15.7987 48.6783 5436.1221 449.0019 16.7942 37.0385 5526.5010 345.7320 14.3609 61.7048 5616.6797 204.5203 56.5250 192.7426 186.1627 29.9667 305.1758 147.2087 150.3000 140.7949 122.0827 72.1667 86.4362 201.7056 31.6500 289.9279 167.7664 38.5000 107.9684 211.3244 70.5996 254.4179 133.1011 78.1167 46.3558 146.1252 119.3583 46.9501 153.3927 96.5500 37.2889 135.6198 60.3167 58.O376 DEPTH GRAM PDIM RPDE AZ'F INC RACM RPCM .,ADE PDCM RADE TCDM CPDE PDDC ROPA TVD DCCM PDEM ROPS 5800.0000 53.7476 9601.5000 1.5142 5900.0000 89.8337 1O248.00OO 2.7373 6000.0000 23.2698 10880.0000 0.8280 6100.0000 39.2743 11468.5OOO 1.4939 6200.0000 32.9451 12078.0000 1.0064 6300.0000 54.1660 12750.5000 1.9731 640O.OOOO 69.9380 13477.00O0 2.4332 6500.0000 57.9972 14169.OO0O 3.3234 6600.0000 43.8186 14843.0000 1.4875 6700.0000 50.1422 15443.500O 2.8847 6800.0000 83.4226 16156.0O00 2.7219 189.0111 25.6711 1.6332 1.4741 191.9695 25.O826 3.3201 2.6458 192.134O 25.0617 0.9561 0.8110 191.6473 25.4527 1.7796 1.4543 192.2699 25.8828 1.0109 0.9838 193.9128 24.6712 1.8748 1.9160 194.1710 24.6054 2.5418 2.3548 194.1000 25.3710 3.7359 3.2041 193.0837 25.7772 1.7995 1.4485 193.3916 24.6253 3.7069 2.7861 193.4000 25.4316 3.2057 2.6306 634.5131 21.3291 1.5760 86.6609 319.9125 15.1460 3.1259 88.0531 1074.5671 29.7649 0.9306 91.6893 584.7588 21.4949 1.7101 95.1125 1015.3320 26.7656 0.9849 98.8250 554.6205 18.3450 1.8030 98.3750 412.2159 16.2378 2.4259 92.3000 284.9653 13.4802 3.5092 97.5875 578.4279 21.5427 1.7288 101.1875 288.2528 14.6788 3.4692 103.4600 330.4517 15.1967 3.O262 103.9250 660.4124 21.0123 81.1021 5706.7891 365.3224 14.8461 38.3829 5797.1289 1207.6765 29.4341 222.6915 5887.7168 669.4055 21.1740 94.7273 5978.1650 993.6750 26.4383 116.6850 6068.3057 506.8099 18.0328 38.8687 6158.8437 410.9780 15.9327 47.3334 6249.7119 300.8986 13.1898 64.0264 6340.3643 672.2855 21.2258 93.3434 6430.5723 346.6617 14.3824 89.0350 6521.0303 367.3862 14.8956 66.6650 6611.6279 184.2390 51.0167 48.7871 139.1802 69.2496 32.5127 246.1313 75.6333 192.7426 185.4501 57.9833 60.0109 224.0646 78.5833 118.1326 162.4067 84.0167 34.2118 147.1363 55.7000 37.3040 127.0736 65.4666 71.2999 185.8054 49.2167 88.5971 135.7968 46.6833 105.1672 139.5616 58.4820 71.8061 DEPTH GRAM PDIM RPDE AZT INC RACM RPCM .,ADE PDCM RADE TCDM CPDE PDDC ROPA TVD DCCM PDEM ROPS 6900.0000 84.0345 16891.5000 2.3762 7000.0000 74.4148 17612.5000 2.6373 7100.0000 75.3162 18369.5000 2.7759 7200.00OO 72.8327 19O52.500O 3.4113 7300.0000 72.3595 19741.5000 3.4461 7400.0000 90.4271 20528.0000 2.3588 7500.0000 97.3434 21334.5O00 2.4377 7600.0000 87.5369 22167.0000 2.8470 7700,0000 111.3910 22993.5000 2.8333 7800.0000 83.0632 23796.5000 1.2970 7900.0000 138.3070 24533.0000 1.5667 193.9022 25.7087 2.7583 2.3004 198.0245 23.9362 3.1674 2.55O6 200.0763 22.3118 3.2801 2.6827 201.2391 22.0087 4.3584 3.2882 201.0319 22.783O 4.2082 3.32O5 200.9622 23.6578 2.6O43 2.2843 202.1087 24.1826 2.8065 2.3599 202.5000 24.5043 3.0360 2.7509 202.2766 24.6OOO 3.6318 2.7378 202.4452 24.7634 1.4837 1.2651 202.6570 24.7108 1.7296 1.5243 381.8948 16.4647 2.6185 104.7312 334.5410 15.4813 2.9892 107.4312 323.3597 15.0174 3.0925 109.9062 247.1322 13.2657 4.0464 116.2625 255.1074 13.1859 3.9199 118.7375 403.1566 16.5314 2.4804 121.3250 375.3669 16.2147 2.6641 110.3000 347.3755 14.7901 2.8787 116.3750 293.9877 14.8326 3.4015 120.8750 697.6866 23.2596 1.4333 124.7000 599.9641 20.9225 1.6668 125.2625 42O.845O 16.1588 42.7629 6701.8193 379.1815 15.1819 40.3518 6792.6104 360.2434 14.7186 35.2757 6884.5957 293.1469 12.9767 60.8366 6977.2256 290.1854 12.8955 55.0172 7069.6777 423.9492 16.2280 25.5093 7161.5771 410.2163 15.9127 21.2796 7252.9805 351.2481 14.4937 27.0668 7344.0908 352.9432 14.5361 20.1556 7435.0469 771.0243 22.9397 35.4806 7525.9150 638.2812 20.6034 32.9203 7616.7354 148,7871 62,6167 43.7516 141.6328 77.1167 41.6927 138.2651 80.5000 34.7440 125.5220 57.4000 6O.O346 124.9414 61.5333 53.6952 149.2877 1079.0000 26.2510 146.9846 97.3167 2O.3290 136.6218 105.9333 22.0609 136.9312 116.4833 21.4781 198.3656 75.1167 38.1169 181.2889 61.1333 35.7968 DEPTH GRAM PDIM RPDE AZT INC RACM RPCM ~,ADE PDCM RADE TCDM CPDE PDDC ROPA TVD DCCM PDEM ROPS 8000.0000 106.0996 25288.5000 1.1637 8100.0000 128.7416 26069.0000 0.8864 8200.0000 183.9374 26861.5000 2.2355 8300.0000 122.7322 27639.5000 1.3583 8400.0000 117.1815 28419.0000 1.7628 8500.0000 122.0625 29193.5O00 1.9906 8600.0000 144.7841 29949.5OO0 2.5480 8700.0000 229.3157 30639.0000 2.1687 8800.0000 146.0023 31386.5000 5.3440 8900.0000 131.6270 32156.0000 1.9483 9000.0000 57.6018 32816.5O00 -999.2500 202.2298 24.1255 1.1831 1.1360 201.8478 23.8739 1.1538 0.8675 202.9383 23.3383 2.8179 2.1664 203.2774 23.5226 1.5007 1.3241 203.8717 23.2000 2.00O7 1.7140 205.0863 23.2347 2.3847 1.9318 207.2936 23.3000 2.8957 2.4646 208.8723 23.1128 2.3641 2.1020 2O8.2849 22.9000 3.0838 5.1173 210.9193 22.8387 2.3682 1.8928 213.2500 22.4500 0.0940 13.2922 869.2465 24.7081 1.1504 126.3875 894.3856 28.6870 1.1181 127.5125 374.7013 17.0579 2.6688 128.7500 689.2999 22.6680 1.4507 131.7875 522.3517 19.5670 1.9144 132.4625 439.9126 18.2465 2.2732 113.7875 364.1735 15.8008 2.7459 119.4125 442.6892 17.3650 2.2589 120.8750 337.4534 10.0308 2.9634 122.7875 444.0918 18.4720 2.2518 125.6000 -999.2500 5.2010 -999.2500 126.9500 859.2920 24.3816 30.4713 77O7.7783 1128.1294 28.3543 18.0349 7799.1328 447.3211 16.7532 20.9914 7890.7822 736.1980 22.3490 41.3580 7982.5283 567.2711 19.2512 30.1139 8074.3389 502.3605 17.9364 36.0219 8166.2412 392.4610 15.4974 32.7467 8258.1094 461.1039 17.0562 39.2090 8350.0156 187.1243 9.7633 7.9764 8442.0664 513.2581 18.1629 25.2692 8534.2090 -999.2500 4.9931 28.0094 8626.5371 208.9738 70.1143 30.2896 238.1891 106.0979 17.9515 153.1216 93.3667 21.1516 194.0390 62.0333 43.7516 171.3341 1504.0000 30.0085 161.7680 72.4667 36.9910 143.9696 59.4000 33.1204 155.3498 46.2000 24.0739 101.9264 79.6833 6.5818 163.3586 67.5500 21.2746 -999.2500 8390.0000 27.9550 DEPTH GRAM PDIM RPDE AZT INC RACM RPCM ,,ADE PDCM RADE TCDM CPDE PDDC ROPA 'rVD DCCM PDEM ROPS 9100.0000 153.8562 33685.5000 2.7184 9200.0000 124.3365 34549.5000 2.7065 9300.0000 121.4306 35417.5000 2.64O8 9400.O0OO 129.1013 36296.5000 3.2320 9500.0000 69.5151 36910.OOOO 4.9777 9600.0000 107.2388 37344.5000 5.3883 9700.0000 105.4123 38119.5O0O 5.1588 9800.0000 107.3247 38921.5000 4.0986 9900.0000 115.5385 39775.5000 3.1617 10000.0000 -999.2500 -999.2500 -999.2500 214.8839 21.7516 3.0825 2.6293 218.3761 2O.9663 2.8772 2.6184 221.5641 20.7000 2.7530 2.5545 223.5098 20.4623 2.995O 2.5711 225.2329 20.4523 5.0952 4.7764 225.6548 20.3301 5.7990 5.1655 225.O596 20.5745 6.1383 4.9453 226.0882 20.9957 4.3089 3.942O 229.8000 21.7333 3.4303 3.0515 232.0000 22.1000 -999.2500 -999.2500 344.OO95 15.1859 2.9O69 131.1125 366.9707 15.2221 2.7250 142.1938 382.6140 15.4482 2.6136 144.7250 347.4287 13.7142 2.8783 151.0250 212.3623 10.4710 4.7089 127.4281 188.3418 9.9539 5.3095 127.5125 179.2451 10.2339 5.579O 135.9500 249.1164 11.8278 4.0142 141.4625 310.0051 13.8653 3.2258 151.0250 -999.2500 -999.2500 -999.2500 -999.2500 367.8578 14.8848 15.2650 8719.1465 369.4838 14.9236 15.3999 8812.2852 378.6765 15.1475 19.7695 8905.7578 309.4018 13.3942 11.0664 8999.3535 200.8972 10.1985 95.7792 9093.0742 185.5867 9.6865 64.3813 9186.8008 193.8447 9.9642 30.6505 9280.5020 243.9872 11.5465 26.0229 9374.0039 316.2883 13.5727 19.1613 9467.13O9 -999.2500 -999.2500 13.2682 9559.8555 139.5954 98.8667 14.9531 139.8716 86.1138 15.8533 141.5295 90.7464 22.6482 141.0915 99.6333 11.2680 105.2692 8.2556 92.5687 101.4812 9.4000 59.0647 103.5702 21.9833 29.5331 115.2114 35.7333 27.4720 130.0498 44.8000 19.5835 -999.2500 -999.2500 13.2682 Tape File Start Depth = 3824.000000 Tape File End Depth = 10000.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subtile 3 is type: LIS * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA, INC. WELL NzV4E : D.S.4-47 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : AK API NUMBER : 500292243900 REFERENCE NO : 98355 OCT '/5 1998 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 10:46 PAGE: **** REEL HEADER **** SERVICE NA~E : EDIT DATE : 98/10/ 5 ORIGIN : FLIC REEL NAME : 98355 CONTINUATION # : PREVIOUS REEL : COMgfEAFP : ARCO ALASKA INC., PRUDHOE BAY, D.S. 4-47, API# 50-029-22439-00 **** TAPE HEADER **** SERVICE NA~E : EDIT DATE : 98/1 O~ 5 ORIGIN : FLIC TAPE NAME : 98355 CONTINUATION # : 1 PREVIOUS TAPE : COF~fENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 4-47, API# 50-029-22439-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D. S. 4-47 API NUMBER: 500292243900 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 5~0CT-98 JOB NUMBER: 98355 LOGGING ENGINEER: BAILY OPERATOR WITNESS: G. SARBER SURFACE LOCATION SECTION: 26 TOWNSHIP: 1 iN RANGE: 1SE FNL: FSL: 649 FEL : FWL: 311 ELEVATION(FT FROM MSL O) KELLY BUSHING: 53.80 DERRICK FLOOR: GROUND LEVEL: 32.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 10. 750 3845.0 45.50 2ND STRING 7. 625 12090.0 29.70 3RD STRING 4. 500 11339.0 12. 60 PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(FiEASURED DEPTH) LIS Tape VerificatiOn Listing Schlumberger Alaska Computing Center BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 26-JAN-94 LOGGING COMPANY: WESTERN ATLAS BASELINE DEPTH 88888 0 11911 0 11910 0 11904 5 11899 0 11898 5 11877 0 11876.0 11862 5 11859 5 11847 5 11847 0 11844 5 11843 0 11840 0 11828 5 11811 0 11797 0 11779 5 11779 0 11754 5 11726 5 11703 0 11682 0 11649 0 11629.5 11628.5 11608.0 11603.5 11574.5 11571.0 11557.5 11556.0 11554.0 11551.5 11538.5 11537.5 11531.5 11517.0 11508.5 11507.5 11494.5 11491.5 11486.5 11485.0 5-0CT-1998 10:46 ...... ~- - -EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG 88889.0 88889.0 11912.0 11911.0 11911.0 11905.5 11905.5 11900.0 11877.0 11864.0 11861.0 11849.0 11846.0 11842.5 11828.5 11811.5 11798. 0 11780. 0 11755. 0 11727. 0 11703. 0 11682.5 11649.5 11631. 0 11604. 0 11574. 0 11572. 0 11557.0 11551.5 11539.0 11532.0 11518.0 11508.5 11495.5 11492.0 11486.5 11900.0 11877.0 11864.0 11861.0 11849.0 11846.0 11842.5 11828.5 11811.5 11798.0 11780.0 11755.0 11727.0 11703.0 11682.5 11649.5 11631.0 11608.5 11604.0 11574.0 11572.0 11557.0 11554.5 11551.5 11539.0 11532.0 11518.0 11508.5 11495.5 11492.0 11486.5 PAGE: LIS Tape Verificati~on Listi'ng Schlumberger Alaska Computing Center 5-0CT-1998 10:46 11470.5 11470.5 11469.5 11470.5 11458.5 11459.5 11449.5 11452.0 11452.0 11446.0 11447.0 11445.5 11447.0 11442.5 11443.5 11443.5 11439.5 11440.5 11439.0 11440.5 11424.0 11425.0 11425.0 11410.5 11411.5 11411.5 11401.0 11402.0 11402.0 100.0 101.0 101.0 $ RE~ZARKS: CONTAINED HEREIN IS THE CNTG DATA ACQUIRED ON ARCO ALASKA, INC. WELL D.S. 4-47 ON 2-NOV-97. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CNTG PASS #1 GRCH TO THE BASELINE GAMMA RAY PROVIDED BY THE CLIENT (GR.BCS) ; AND CNTG PASS #1 NPHI TO GR.BCS. ALL OTHER CNTG CURVES WERE CARRIED WITH THE NPHI SHIFT. **NOTE: ALL OF THE DATA PRESENTED IN THESE FILES WAS DIGITIZED FROM THE BLUELINE. NO FIELD TAPE OF THE ORIGINAL RAW DATA WAS RECEIVED. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .00i SERVICE : FLIC VERSION : O01CO1 DATE : 98/1 O~ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUM~ER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUM~IARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11914.0 11396.0 CNTG 11924.0 11396.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: LIS Tape Verificati'on Listi~g Schlumberger Alaska Computing Center 5-0CT-1998 10:46 PAGE: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNTG REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR CNTG PASS #1. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1173647 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTG PU-S 1173647 O0 000 O0 0 1 1 1 4 68 0000000000 ENPH CNTG PU-S 1173647 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTG 1173647 O0 000 O0 0 ! 1 1 4 68 0000000000 ENRA CNTG 1173647 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTG CPS 1173647 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTG CPS 1173647 O0 000 O0 0 1 1 1 4 68 0000000000 CNEC CNTG CPS 1173647 O0 000 O0 0 1 1 1 4 68 0000000000 CFEC CNTG CPS 1173647 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNTG GAPI 1173647 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verificati'on Listi'ng Schlu_r~erger Alaska Computing Center 5-0CT-1998 10:46 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TENS CNTG LB 1173647 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 1173647 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 12007.500 NPHI.CNTG -999.250 ENPH. CNTG -999.250 CRAT. CNTG ENRA.CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS.CNTG -999.250 GR.BCS DEPT. 11300. 000 NPHI. CNTG -999. 250 ENPH. CNTG -999. 250 CRAT. CNTG ENRA. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999. 250 GRCH. CNTG -999. 250 TENS. CNTG -999. 250 GR. BCS -999.250 -999.250 149.112 -999.250 -999.250 236.848 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION : O01CO1 DATE : 98/10/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION · O01CO1 DATE : 98/10/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NI]MBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS1FUMBER: 2 DEPTH INCRE~!ENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 10:46 PAGE: GRCH 11916.0 11402.0 CNTG 11926.0 11402.0 $ CURVE SHIFT DATA - PASS TO PASS (FIEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUM~ER: 1 BASELINE DEPTH 88888.0 11922.0 11911.5 11908.5 11906.5 11901.0 11900.5 11895.5 11880.0 11878.0 11864.0 11854 5 11851 5 11845 0 11844 0 11832 0 11829 5 11821 0 11820 0 11811 0 11806.5 11803.5 11799.5 11797.5 11785.0 11783.0 11779.5 11777.5 11759.5 11755.0 11752.0 11742.0 11740.5 11733.5 11732.5 11724 5 11719 0 11717 5 11714 0 11704 5 11696 0 11690 5 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNTG 88887.0 88889.0 11905.5 11900.5 11895.5 11877.0 11852.5 11846.0 11828.5 11820.0 11811.5 11797.5 11780.0 11755.0 11751.0 11741.5 11731.5 11703.5 11691.5 11923.0 11910.5 11908.5 11900.0 11880.5 11864.0 11855.0 11846.0 11831.5 11820.0 11806.0 11804.0 11799.5 11785.5 11782.5 11778.0 11760.0 11739.5 11734.0 11723.5 11717.0 11715.0 11713.0 11696.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 10:46 PAGE: 11683.0 11667.0 11661.5 11654.0 11646.0 11630.5 11629.0 11610.0 11608.5 11602.5 11590.0 11587.0 11580.0 11574.5 11568.5 11563.5 11561.5 11558.0 11552.5 11551.0 11549.0 11548.5 11543.0 11539.5 11529.0 11519.0 11518.0 11509.5 11508.5 11497.0 11495.0 11488.0 11478.0 11471.5 11466.0 11460.0 11452.5 11451.0 11449.0 11440 5 11439 5 11430 5 11428 0 11427 0 11424 5 11420 5 11416.0 11412.0 11411.0 11407.0 11405.5 100.0 $ 11631.0 11608.5 11589.0 11574.0 11562.5 11557.5 11551.5 11548.0 11543.5 11539.0 11518.0 11509.0 11495.0 11486.5 11478. 0 11470.5 11465.0 11461.0 11452.0 11440.5 11430.0 11428.5 11425.0 11411.5 11406.0 99.0 11684.0 11669.5 11661.0 11653.0 11647.0 11630.0 11609.0 11602.0 11587.5 11578.5 11573.5 11568.5 11560.5 11557.5 11550.0 11547.5 11539.0 11529.5 11518.0 11509.0 11496.5 11487.0 11471.0 11459.5 11454.0 11450.0 11439.5 11427.0 11420.5 11416.0 11412.0 11405.5 100.0 REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA LIS Tape Verificati'on Listi'ng Schlumberger Alaska Computing Center 5-0CT-1998 10:46 PAGE: FOR CNTG PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT PASS #2 GRCH TO PASS #i GRCH; AND PASS #2 NPHI TO PASS #1 NPHI. ALL OTHER CNTG CURVES WERE CARRIED WITH THE NPHI SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD~ SAMP ELEM CODE (HEX) DEPT FT 1173647 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTG PU-S 1173647 O0 000 O0 0 2 1 1 4 68 0000000000 ENPH CNTG PU-S 1173647 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNTG 1173647 O0 000 O0 0 2 1 1 4 68 0000000000 ENRA CNTG 1173647 O0 000 O0 0 2 1 1 4 68 0000000000 ClTTC CNTG CPS 1173647 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTG CPS 1173647 O0 000 O0 0 2 1 1 4 68 0000000000 CNEC CNTG CPS 1173647 O0 000 O0 0 2 1 1 4 68 0000000000 CFEC CNTG CPS 1173647 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTG GAPI 1173647 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNTG LB 1173647 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape VerificatiOn Listing Schlurt~erger Alaska Computing Center 5-0CT-1998 10:46 PAGE: ** DATA ** DEPT. 11927.000 NPHI.CNTG 30.400 ENPH. CNTG 46.565 ENRA.CNTG 6.233 CNTC. CNTG 1686.331 CFTC. CNTG 531.808 CFEC. CNTG 419.153 GRCH. CNTG -999.250 TENS.CNTG 1701.847 DEPT. 11401.000 NPHI.CNTG -999.250 ENPH. CNTG -999.250 ENRA.CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CFEC. CNTG -999.250 GRCH. CNTG 146.441 TENS.CNTG -999.250 CRAT. CNTG CNEC. CNTG CRAT. CNTG CNEC. CNTG 3.078 2592.271 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : OOiCO1 DATE : 98/10/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUM~ER: 3 DEPTH INCREMeNT: 0.5000 FILE StC4~ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11914.0 11400.0 CNTG 11924.0 11400.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASUEED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NOW~ER: 1 LIS Tape VerificatiOn Listing Schlumberger Alaska Computing Center 5-0CT-1998 10:46 PAGE: 10 BASELINE DEPTH 88888.0 11917.5 11909 5 11905 0 11900 0 11887 5 11885 0 11878 0 11876.0 11869.5 11864.5 11863.0 11850.5 11846.5 11843 0 11839 0 11831 5 11817 0 11811 5 11797 0 11789 5 11779 0 11777 0 11771 5 11766.0 11762 0 11760 5 11758 5 11755 5 11751 0 11733 0 11732 0 11721 5 11703 5 11700 0 11676 0 11653 5 11636 5 11634 5 11629 0 11614 5 11612.0 11611.5 11609.5 11609.0 11605.0 11602.0 11594.0 11591.5 11587.0 11580.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNTG 88888.5 88889.0 11905.5 11900.5 11877.0 11861.0 11852.5 11846.0 11840.5 11817.5 11798.0 11789.5 11780.0 11765.5 11760.0 11757.0 11755.0 11751.0 11733.5 11722.0 11703.0 11615.0 11611.5 11608.5 11605.0 11594.5 11918.5 11910.5 11887.0 11884.0 11877.0 11868.0 11864.0 11848.5 11831.5 11811.5 11776.0 11769.0 11760.0 11732.5 11700.0 11676.0 11653.0 11637.5 11635.0 11630.0 11612.5 11608.5 11601.5 11592.0 11587.5 11578.5 LIS Tape VerificatiOn Listing Schlumberger Alaska Computing Center 5-0CT-1998 10:46 PAGE: 11574.5 11573 5 11558 0 11554 0 11552 0 11551 0 11550 5 11547 5 11539 5 11539 0 11529 5 11525 0 11518 0 11517 5 11510 0 11508 5 11506 0 11496 5 11494 5 11487 0 11474 5 11471 5 11470 5 11463 5 11459 5 11450 5 11448 5 11443 0 11429 5 11427 0 11416.0 11411.5 11409.0 11405.5 11405.0 11404.0 11402.0 100.0 $ 11574 11554 11551 11548 0 11539 5 11524 5 11518.0 11508.5 11505.5 11495.0 11486.5 11470.5 11461.0 11452.0 11442.5 11430.0 11411.0 11403.5 11574 0 11557 5 11552 0 11549 5 11539 0 11529 5 11518.5 11509.0 11496.0 11486.5 11474.5 11471.0 11463.0 11450.0 11427.0 11416.0 11409.5 11405.5 11404.0 11402.0 11402.5 100.0 100.5 REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR CNTG PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT PASS #3 GRCH TO PASS #1 GRCH; AND PASS #3 NPHI TO PASS #1 NPHI. ALL OTHER CNTG CURVES WERE CARRIED WITH THE NPHI SHIFT. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-i998 10:46 PAGE: 12 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUFiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1173647 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTG PU-S 1173647 O0 000 O0 0 3 1 1 4 68 0000000000 ENPH CNTG PU-S 1173647 O0 000 O0 0 3 1 1 4 68 0000000000 CRAT CNTG 1173647 O0 000 O0 0 3 1 1 4 68 0000000000 ELTRA CNTG 1173647 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTG CPS 1173647 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTG CPS 1173647 O0 000 O0 0 3 1 1 4 68 0000000000 CNEC CNTG CPS 1173647 O0 000 O0 0 3 1 1 4 68 0000000000 CFEC CNTG CPS 1173647 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNTG GAPI 1173647 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTG LB 1173647 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 11925.000 NPHI.CNTG 28.790 ENPH. CNTG 41.890 CRAT. CNTG ENRA.CNTG 5.689 CNTC. CNTG 1842.333 CFTC. CNTG 651.338 CNEC. CNTG CFEC. CNTG 475.874 GRCH. CNTG -999.250 TENS.CNTG 1709.318 DEPT. 11400.000 NPHI.CNTG -999.250 ENPH. CNTG -999.250 CRAT. CNTG ENRA.CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCH. CNTG 104.889 TElVS.CNTG -999.250 2.974 2752.016 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 10:46 PAGE: 13 ** EArD OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE : 98/10/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE~ER **** FILE NA~IE : EDIT .004 SERVICE : FLIC VERSION : 001 CO1 DATE : 98/10/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SOWk/~ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11914.0 11396.0 CNTG 11924.0 11396.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NO?~BER: 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH CNTG 88888.0 88888.5 88892.0 11914.5 11918.5 11905.0 11905.5 11904.5 11908.5 11900.5 11900.0 11900.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 10:46 PAGE: 14 11896.0 11889.5 11884.0 11878.0 11877 5 11860 5 11852 0 11845 0 11844 5 11832 0 11828 5 11818 0 11812 0 11807 0 11803 0 11800 5 11797 5 11796.5 11783.0 11780.0 11776.5 11766.0 11764.5 11760.5 11756.0 11755 0 11753 5 11751 0 11732 5 11724 0 11718 0 11677 0 11661 5 11654.5 11651.0 11638.0 11631.5 11624.0 11615.0 11610.0 11603.0 11591.0 11580.5 11573.5 11559.0 11556.5 11553.0 11549.0 11540.5 11540.0 11519.0 1151 O. 5 11498.0 11495.5 11488.0 11877.0 11852.5 11846.0 11828.5 11818.5 11811.5 11797.5 11780.0 11765.5 11755.0 11722.0 11649.5 11631.0 11615.0 11591.0 11572.0 11557.5 11551.5 11548.0 11539.5 11495.0 11486.5 11895.5 11890.5 11884.0 11877.0 11862.0 11846.0 11831.5 11811.5 11806.0 11804.0 11800.0 11796.0 11782.5 11774.5 11763.0 11760.0 11754.5 11752.5 11749.5 11732.5 11716.5 11676.0 11661.0 11653.0 11650.0 11637.5 11623.0 11609.0 11602.0 11578.5 11554.5 11539.0 11518.0 11508.5 11496.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 10:46 PAGE: 15 11487.5 11486.5 11480.0 11478.0 11473.0 11471.0 11472.5 11471.0 11451.0 11452.0 11449.0 11450.0 11447.5 11447.0 11440.0 11439.5 11436.5 11436.5 11430.0 11430.5 11427.5 11428.5 11426.5 11425.0 11421.5 11420.5 11417.0 11418.0 11415.0 11414.0 11412.5 11411.0 11405.5 11405.5 11402.0 11402.0 11401.5 11401.0 100.0 100.0 99.5 $ REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR CNTG PASS #4. THE DEPTH SHIFTS SHOWN ABOVE REFLECT PASS #4 GRCH TO PASS #1GRCH; AND PASS #4 NPHI TO PASS #1NPHI. ALL OTHER CNTG CURVES WERE CARRIED WITH THE NPHI SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 10:46 PAGE: 16 TYPE REPR CODE VALUE 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELEM CODE (HEX) DEPT FT 1173647 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNTG PU-S 1173647 O0 000 O0 0 4 1 1 4 68 0000000000 ENPH CNTG PU-S 1173647 O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNTG 1173647 O0 000 O0 0 4 1 1 4 68 0000000000 ENRA CNTG 1173647 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNTG CPS 1173647 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNTG CPS 1173647 O0 000 O0 0 4 1 1 4 68 0000000000 CNEC CNTG CPS 1173647 O0 000 O0 0 4 1 1 4 68 0000000000 CFEC CNTG CPS 1173647 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTG GAPI 1173647 O0 000 O0 0 4 1 1 4 68 0000000000 TENS CNTG LB 1173647 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 11928.000 NPHI.CNTG 36.590 ENPH. CNTG 31.090 CRAT. CNTG ENRA.CNTG 4.752 CNTC. CNTG 1964.173 CFTC. CNTG 675.375 CNEC. CNTG CFEC. CNTG 555.040 GRCH. CNTG -999.250 TENS. CNTG 1665.622 DEPT. 11395.500 NPHI.CNTG 56.751 ENPH. CNTG 53.890 CRAT. CNTG ENRA.CNTG 6.757 CNTC. CNTG 1402.479 CFTC. CNTG 332.175 CNEC. CNTG CFEC. CNTG 344.840 GRCH. CNTG -999.250 TENS.CNTG 1623.428 2. 974 2626. 279 4.518 2298. 259 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION : O01CO1 DATE : 98/10/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 10:46 PAGE: 17 **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/ 5 M_AX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 5 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT O. 5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS .......................... 1, 2, 3, 4, CNTG REMARKS: THE ARITH~IETIC AVERAGE WAS CALCULATED AFTER CLIPPING AND DEPTH CORRECTIONS WERE APPLIED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 10:46 PAGE: 18 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1173647 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI CNAV PU-S 1173647 O0 000 O0 0 5 1 1 4 68 0000000000 CRATCNAV 1173647 O0 000 O0 0 5 1 1 4 68 0000000000 ENPH CNAV PU-S 1173647 O0 000 O0 0 5 1 1 4 68 0000000000 EATRA CNAV 1173647 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC CNAV CPS 1173647 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC CNAV CPS 1173647 O0 000 O0 0 5 1 1 4 68 0000000000 CNEC CNAV CPS 1173647 O0 000 O0 0 5 1 1 4 68 0000000000 CFEC CNAV CPS 1173647 O0 000 O0 0 5 1 1 4 68 0000000000 GRCH CNTG GAPI 1173647 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 11925.000 NPHI.CNAV 31.083 CRAT. CNAV 3.049 ENPH. CNAV ENRA.CNAV 5.208 CNTC. CNAV 1845.544 CFTC. CNAV 631.513 CNEC. CNAV CFEC. CNAV 526.903 GRCH. CNTG -999.250 DEPT. 11397.000 NPHI.CNAV -999.250 CRAT. CNAV -999.250 ENPH. CNAV ENRA.CNAV -999.250 CNTC. CNAV -999.250 CFTC. CNAV -999.250 CNEC.CNAV CFEC. CNAV -999.250 GRCH. CNTG 73.676 35.854 2733.443 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAlViE : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 10:46 PAGE: 19 FILE HEADER FILE NU~ER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUM~ER: 1 DEPTH INCREMENT: 0.5000 FILE SU~ff4ARY VENDOR TOOL CODE START DEPTH CNTG 11948.0 $ LOG HEADER DATA STOP DEPTH 11394.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 2-NOV-97 CP 44.2 1443 2-NOV-97 11950.0 11931.0 11400.0 11946.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VEIVDOR TOOL CODE TOOL TYPE GR GAMMA RAY CNTG COMP. NEUTRON $ TOOL NUMBER ........... SGTL CNTG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 11339.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) '. CRUDE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EP I THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 10:46 PAGE: 2O TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 14000 TOOL STANDOFF (IN): REMARKS: TIED INTO SWS CBL DATED 15-FEB-94. THE PURPOSE OF THIS LOG WAS TO MONITOR GOC. VOLUMES PUMPED: CRUDE 270 BBLS PRIOR TO LOGGING @ $ BPM, 180 BBLS @ 3 BPM WHILE LOGGING. WITHOUT A BHC PRINT IN THE FIELD AN ACCURATE PICK IS DIFFICULT. A ROUGH PICK OF NEAR/FAR COUNT RATES WOULD PLACE THE GOC AT 11644'. THIS FILE CONTAINS THE RAW CNTG DATA FOR PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 10:46 PAGE: 21 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CI_~SS MOD NUMB S~IP ELi~ CODE (HEX) DEPT FT 1173647 O0 000 O0 0 6 1 i 4 68 0000000000 NPHI PS1 PU 1173647 O0 000 O0 0 6 1 1 4 68 0000000000 ENPH PS1 PU 1173647 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS1 1173647 O0 000 O0 0 6 1 1 4 68 0000000000 ENRA PSI 1173647 O0 000 O0 0 6 1 1 4 68 0000000000 CFEC PS1 CPS 1173647 O0 000 O0 0 6 1 1 4 68 0000000000 CNEC PS1 CPS 1173647 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PS1 CPS 1173647 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PS1 CPS 1173647 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS1 GAPI 1173647 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS1 LB 1173647 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 11948.000 NPHI.PS1 37.540 ENPH.PS1 48.770 TNRA.PS1 ENRA.PS1 6.364 CFEC. PS1 528.448 CNEC.PS1 3367.175 CNTC. PS1 CFTC. PSi 473.779 GR.PS1 13.788 TENS.PSi 1038.883 DEPT. 11394.000 NPHI.PS1 52.500 ENPH. PS1 68.310 TNRA.PS1 ENRA.PS1 7.763 CFEC. PS1 374.943 CNEC.PS1 2698.630 CNTC. PS1 CFTC. PSi 325.703 GR.PS1 65.831 TENS.PSI 1609.137 3.463 1596.225 4.359 1398.009 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEA~ER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION · O01CO1 DATE : 98/10/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 10:46 PAGE: 22 FILE HEADER FILE NUM~ER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE S~Y VENDOR TOOL CODE START DEPTH CNTG 11950.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIM~ LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO) : STOP DEPTH 11400.0 2-NOV-97 CP 44.2 1443 11950.0 11931.0 11400.0 11946.0 1800.0 NO 2-NOV-97 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY CNTG COMP. NEUTRON $ TOOL NUMBER SGTL CNTG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 11339.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): E P I THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 10:46 PAGE: 23 TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 0 FAR COUNT RATE HIGH SCALE (CPS): 5000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 14000 TOOL STANDOFF (IN): REMARKS: TIED INTO SWS CBL DATED 15-FEB-94. THE PURPOSE OF THIS LOG WAS TO MONITOR GOC. VOLUPiES PUMPED: CRUDE 270 BBLS PRIOR TO LOGGING @ 5 BPM, 180 BBLS @ 3 BPM WHILE LOGGING. WITHOUT A BHC PRINT IN THE FIELD AN ACCURATE PICK IS DIFFICULT. A ROUGH PICK OF NEAR/FAR COUNT RATES WOULD PLACE THE GOC AT 11644'. THIS FILE CONTAINS THE RAW CNTG DATA FOR PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 10:46 PAGE: 24 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1173647 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PS2 PU 1173647 O0 000 O0 0 7 1 1 4 68 0000000000 ENPH PS2 PU 1173647 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PS2 1173647 O0 000 O0 0 7 1 1 4 68 0000000000 ENRA PS2 1173647 O0 000 O0 0 7 1 1 4 68 0000000000 CFEC PS2 CPS 1173647 O0 000 O0 0 7 1 1 4 68 0000000000 CNEC PS2 CPS 1173647 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PS2 CPS 1173647 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PS2 CPS 1173647 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS2 GAPI 1173647 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS2 LB 1173647 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 11950.000 NPHI.PS2 -999.250 ENPH. PS2 -999.250 TNRA.PS2 ENRA.PS2 -999.250 CFEC.PS2 -999.250 CNEC.PS2 -999.250 CNTC. PS2 CFTC.PS2 -999.250 GR.PS2 -999.250 TENS.PS2 -999.250 DEPT. 11400.500 NPHI.PS2 38.050 ENPH. PS2 59.009 TNRA.PS2 ENRA.PS2 7.121 CFEC.PS2 409.160 CNEC. PS2 2873.639 CNTC. PS2 CFTC.PS2 471.083 GR.PS2 119.762 TENS.PS2 1630.522 -999.250 -999.250 3.494 1558.609 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE · FLIC VERSION · O01CO1 DATE : 98/10/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~fE : EDIT .008 SERVICE : FLIC VERSION · O01CO1 DATE : 98/10/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 10:46 PAGE: 25 FILE HEADER FILE NUMBER 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUM~ER: 3 DEPTH INCREMENT: 0.5000 FILE S~Y VENDOR TOOL CODE START DEPTH CNTG 11940.0 $ LOG HEADER DATA STOP DEPTH 11398.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 2 -NOV- 97 CP 44.2 1443 2-NOV-97 11950.0 11931.0 11400.0 11946.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~IA RAY CNTG COMP. NEUTRON $ TOOL NUMBER ........... SGTL CNTG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) '. LOGGERS CASING DEPTH (FT) : 11339.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): E P I THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-I998 10:46 PAGE: 26 TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 14000 TOOL STANDOFF (IN): REMARKS: TIED INTO SWS CBL DATED 15-FEB-94. THE PURPOSE OF THIS LOG WAS TO MONITOR GOC. VOLUFiES PUMPED: CRUDE 270 BBLS PRIOR TO LOGGING @ 5 BPM, 180 BBLS @ 3 BPM WHILE LOGGING. WITHOUT A BHC PRINT IN THE FIELD AN ACCURATE PICK IS DIFFICULT. A ROUGH PICK OF NEAR/FAR COUNT RATES WOULD PLACE THE GOC AT 11644'. THIS FILE CONTAINS THE RAW CNTG DATA FOR PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 10:46 PAGE: 27 ** SET TYPE - C~ ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1173647 O0 000 O0 0 8 1 1 4 68 0000000000 NPHI PS3 PU 1173647 O0 000 O0 0 8 1 1 4 68 0000000000 ENPH PS3 PU 1173647 O0 000 O0 0 8 1 1 4 68 0000000000 TNRA PS3 1173647 O0 000 O0 0 8 1 1 4 68 0000000000 ENRA PS3 1173647 O0 000 O0 0 8 1 1 4 68 0000000000 CFEC PS3 CPS 1173647 O0 000 O0 0 8 1 1 4 68 0000000000 CNEC PS3 CPS 1173647 O0 000 O0 0 8 1 1 4 68 0000000000 CNTC PS3 CPS 1173647 O0 000 O0 0 8 1 1 4 68 0000000000 CFTC PS3 CPS 1173647 O0 000 O0 0 8 1 1 4 68 0000000000 GR PS3 GAPI 1173647 O0 000 O0 0 8 1 1 4 68 0000000000 TENS PS3 LB 1173647 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 11940.000 NPHI.PS3 32.910 ENPH. PS3 47.320 TNRA.PS3 ENRA.PS3 6.239 CFEC. PS3 358.218 CNEC. PS3 2205.836 CNTC. PS3 CFTC.PS3 457.301 GR.PS3 24.803 TENS.PS3 1293.971 DEPT. 11398.000 NPHI.PS3 45.060 ENPH. PS3 49.860 TNRA.PS3 ENRA.PS3 6.468 CFEC. PS3 357.719 CNEC.PS3 2284.045 CNTC. PS3 CFTC. PS3 386.074 GR.PS3 74.930 TENS.PS3 1617.539 3.211 1411.973 3.835 1452.782 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE · FLIC VERSION : O01CO1 DATE : 98/10/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 10:46 PAGE: 28 FILE HEADER FILE1VO?4~ER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS ~ER: 4 DEPTH INCREMENT: 0.5000 FILE SU~ff~ARY VENDOR TOOL CODE START DEPTH CiTTG 11948.0 $ LOG HEADER DATA STOP DEPTH .......... 11394.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT) .' BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 2-NOV-97 CP 44.2 1443 2-NOV-97 11950.0 11931.0 11400.0 11946.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR G~ RAY CNTG COMP. NEUTRON $ TOOL NUMBER ........... SGTL CNTG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 11339.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL MATRIX'. MATRIX DENSITY: HOLE CORRECTION (IN): E P I THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-~9~8 10:46 PAGE: 29 TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 14000 TOOL STANDOFF (IN): REMARKS: TIED INTO SWS CBL DATED 15-FEB-94. THE PURPOSE OF THIS LOG WAS TO MONITOR GOC. VOLUMES PUMPED: CRUDE 270 BBLS PRIOR TO LOGGING @ 5 BPM, 180 BBLS @ 3 BPM WHILE LOGGING. WITHOUT A BHC PRINT IN THE FIELD AN ACCURATE PICK IS DIFFICULT. A ROUGH PICK OF NEAR/FAR COUNT RATES WOULD P~ACE THE GOC AT 11644'. THIS FILE CONTAINS THE RAW CNTG DATA FOR PASS #4. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 10:46 PAGE: 3O ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE ~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1173647 O0 000 O0 0 9 1 1 4 68 0000000000 NPHI PS4 PU 1173647 O0 000 O0 0 9 1 1 4 68 0000000000 ENPH PS4 PU 1173647 O0 000 O0 0 9 1 1 4 68 0000000000 TNRA PS4 1173647 O0 000 O0 0 9 1 1 4 68 0000000000 ENRA PS4 1173647 O0 000 O0 0 9 1 1 4 68 0000000000 CFEC PS4 CPS 1173647 O0 000 O0 0 9 1 1 4 68 0000000000 CNEC PS4 CPS 1173647 O0 000 O0 0 9 1 1 4 68 0000000000 CNTC PS4 CPS 1173647 O0 000 O0 0 9 1 1 4 68 0000000000 CFTC PS4 CPS 1173647 O0 000 O0 0 9 1 1 4 68 0000000000 GR PS4 GAPI 1173647 O0 000 O0 0 9 1 1 4 68 0000000000 TENS PS4 LB 1173647 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 11950.000 NPHI.PS4 -999.250 ENPH. PS4 44.140 TNRA.PS4 ENRA.PS4 5.993 CFEC. PS4 377.617 CNEC.PS4 2238.771 CNTC. PS4 CFTC. PS4 -999.250 GR.PS4 32.789 TENS.PS4 1032.726 DEPT. 11394.000 NPHI.PS4 54.700 ENPH. PS4 60.570 TNRA.PS4 ENRA.PS4 7.169 CFEC. PS4 316.386 CNEC.PS4 2283.090 CNTC. PS4 CFTC.PS4 300.263 GR.PS4 75.477 TENS.PS4 1636.375 -999.250 -999.250 4.402 1268.082 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE · FLIC VERSION · O01CO1 DATE : 98/10/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/10/ 5 ORIGIN : FLIC TAPE NAME : 98355 CONTINUATION # .. 1 PREVIOUS TAPE : COAE~IT · ARCO ALASKA INC., PRUDHOE BAY, D.S. 4-47, API# 50-029-22439-00 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0CT-1998 10:46 PAGE: 31 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/10/ 5 ORIGIN : FLIC REEL NAME : 98355 CONTINUATION # : PREVIOUS REEL : COf~EJFT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 4-47, API# 50-029-22439-00 I I PLAN OF OPERATIONS I NORTHSTAR NO. 3 EXPLORATORY WELL I 61 3- ao 3 Prepared for I AMERADA HESS CORPORATION I I I I tri dt I 1 • *h al se 4 ' k • . . ,. t., J sls a �'- -- :,,mo - r.- ....... c:r :''K;a'" tviiiht. 0 ININ if f . . I I I NORTE C July, 1987 A DIVISION OF ERT 1 I I I • PLAN OF OPERATIONS l NORTHSTAR NO. 3 EXPLORATORY WELL I I I Prepared for AMERADA HESS CORPORATION NORTEC, A DIVISION OF ERT ANCHORAGE, ALASKA July, 1987 RiciATED j M 4 71 ors u ✓Ydb' §d:`: I TABLE OF CONTENTS Page 1.0 STATEMENT OF PURPOSE 1 1.1 Coastal Zone Consistency Certification . . . 2 1.2 Authorization 2 I I 2.0 SITE LOCATION 2 3.0 SITE DESCRIPTION 4 3.1 Sea Ice and Oceanographic Considerations . . 6 4.0 SHALLOW GEOHAZARD ASSESSMENT (Stand Alone Volume) 11 4.1 Bottom Founded Structures 14 4.2 Future Investigations 15 5.0 PHYSICAL ENVIRONMENT 16 5.1 Meteorology 16 5.2 Currents, Tides and Storm Surges 17 5.3 Sea Ice 19 6.0 BIOLOGICAL ENVIRONMENT 21 6.1 Primary Productivity 21 6.2 Zooplankton 22 6.3 Benthos 23 6.4 Fish 28 6.5 Marine Mammals 30 6.6 Coastal and Marine Birds 37 6.7 Threatened or Endangered Species 40 6.8 Effects of Proposed Activities 44 7.0 PROPOSAL DEVELOPMENT SCENARIO 45 1 WED a 'm'ea c Ni e TABLE OF CONTENTS (CONT'D) Page 8.0 DRILLING VESSEL DESCRIPTION 48 8.1 Marine Specifications 50 8.2 Drilling Specifications 56 8.3 Wastewater, Cuttings and Drilling Fluids Disposal 66 8.4 Solid Waste Disposal 68 8.5 Air Emissions 6 8.6 Communications 68 8.7 Food Service 69 9.0 SUPPORT SERVICES AND TRANSPORTATION 69 10.0 DRILLING PROGNOSIS (Public Information) 71 10.1 Geological 72 10.2 Mud Logging and Collection of Cuttings Samples 72 10.3 Wireline Logging Program and Velocity Survey . 73 10.4 Conventional and Sidewall Coring 74 10.5 Geochemical and Paleontological Program. . . 75 10.6 Drilling Mud Program 75 10.7 Casing and Cementing Program 76 10.8 Testing Program, Disposal of Produced Test Fluids 77 10.9 Qualifications of Key Personnel 78 11.0 BLOWOUT PREVENTION PROGRAM AND EQUIPMENT 80 12.0 OIL DISCHARGE CONTINGENCY PLAN (Stand Alone Volume) 84 ii TABLE OF CONTENTS (CONT'D) Page 13.0 HYDROGEN SULFIDE CONTINGENCY PLAN 84 14.0 CRITICAL OPERATIONS CURTAILMENT PLAN 85 15.0 ENVIRONMENTAL TRAINING PROGRAM 88 16.0 RELIEF WELL DISCUSSION 89 17.0 REFERENCES CITED 91 111 LIST OF ILLUSTRATION PLAN OF OPERATIONS NORTHSTAR NO. 3 Page Figure 1: Location Map 3 Figure 2: Exploratory Well Location and Adjoining Lease Blocks 5 Figure 3: Ice Thickness, North Coast of Alaska 8 Figure 4: Unconfined Compressive Strength of Ice. . . 9 Figure 5: Ice Strength vs. Depth From Top of Ice. . . 10 Figure 6: Location of Bird Colonies and Nesting Sites in Vicinity of Project Area 39 Figure 7: Locations of Bowhead Whale Sightings in Project Area 42 Figure 8: Schedule of Activities, Northstar No. 3. . 46 Figure 9: Conceptual Drawing, CIDS Rig 49 Figure 10: Proposed Ice Road Routing 70 Figure 11: 21 Diverter System 81 Figure 12: 13 10,000 psi wp BOP Stack 82 iv LIST OF TABLES PLAN OF OPERATIONS NORTHSTAR NO. 3 Page Table 1: 10 -year Westerly storm, Northstar No. 3 Location 12 Table 2: List of Benthic Species Collected in Prudhoe Bay and Simpson Lagoon Areas 24 Table 3: Estimated Quantities of Waste Materials Generated from Northstar No. 3 Exploratory Well 67 V AMERADA HESS CORPORATION NORTHSTAR NO. 3 PROJECT PLAN OF OPERATIONS 1.0 STATEMENT OF PURPOSE The Northstar No. 3 project consists of drilling up to three (3) exploratory wells from a bottom - founded mobile offshore drilling unit for the purpose of evaluating the hydrocarbon potential of the Ivishak and other formations in the Northstar -Seal Island area, north of Long Island, Beaufort Sea, Alaska. The initial well (Northstar No. 3) will be drilled as a straight hole to a true vertical depth of approximately 11,350 feet. Bottom hole locations and depths of any subsequent wells will be determined following evaluation of test results from the initial well. The proposed activity lies within the boundaries of State of Alaska lease No. 312799 (Tract BF -47), Joint Federal -State Beaufort Sea Oil /Gas Lease Sale Area. The exploration activities proposed herein are directed toward a further evaluation of the same structural trend that has been previously explored from wells on Northstar Island and Seal Island. Recent drilling from these two man -made islands have shown potentially commercial accumulation of oil and gas in that area. The proposed exploratory well(s) will further assess reservoir characteristics in the area between the two islands. The exploratory well(s) will be operated by Amerada. Hess Corpor- ation (AHC) of Tulsa, Oklahoma and New York City, New York. AHC is undertaking this project acting for themselves, without partners. AHC will be the permittee of record for all activities described in this Plan of Operations. -1- The drilling contractor will be Applied Drilling Technology, Inc. (ADTI), based in Houston, Texas. ADTI is a wholly owned sub- sidiary of Global Marine Incorporated. The contactor will use the Concrete Island Drilling System KIDS) "GLOMAR BEAUFORT SEA I" rig for this project. 1.1 Coastal Zone Consistency Certification The activities proposed in the Plan of Operations conform with the State of Alaska Coastal Zone Management Program and will be conducted in a manner consistent with the objectives of that program. Consistency has been certified in the application for a permit from the U.S. Army Corps of Engineers. 1.2 Authorization The requirement and authorization for this Plan of Operations is contained in Alaska Administrative Code (AAC) 83.158 and Alaska Statute (AS) 38.05.020, 38.05.130, 38.05.145 and 38.05.180. 2.0 SITE LOCATION The proposed Northstar No. 3 exploratory well is located in the Beaufort Sea approximately 3 miles northeast of the central portion of Long Island and 15 miles northwest of the community of Deadhorse, Alaska (Figure 1). Water depth at this location is approximately 42 ft MLLW. Two additional directional exploratory wells may be drilled from this same surface location. The coordinates of this surface location are shown below: GEODETIC POSITION UTM ZONE 6 (IN METERS) Lat. = 70 ° 30'41.87" y = 7,823,756.55 Long. = 148 ° 46'02.20" x = 434,105.73 -2- �NORTHSTAR ISLAND 148 ° 30'� I �� Proposed Location O ' Northstar No. 3 !TRACT BF -47 SEAL ISLAND REINDEER ISLAND I LADE 312708 LONG ISLAND 8 E A up,., R T ARGO ISLAND Q `V y \ ,, o y A seA EGG ISLAND 0 4 I a I I n 1r S ISLAND GJ r - � POINT STORKERSEN 70°25 I , Of I I / a ' POINT � C MCINTYR a WEST DOCK C� GULL ISLAND NIAKUK \ , ,0 I ��Q. Q ISLANDS I ., ( 3 C:)) C.) 0 c oc) a) I v, )--- ,... ' PRUD HOE BAY (i C3 t (3* EAST DOCK a - OHIO BASE CAMP (::: a. 1 4 I < (j % Z9 I 144, , ,.. .01 , ARCO BASE n L � CAMP v v� 0 op ../ • SCALE IN MILES 2 (APPROX.) - V r iQ Q � J NORTHSTAR NO. 3 'C) CD BEAUFORT SEA, ALASKA i �° a o o'� LOCATION MAP DEADHORSE f . , 4 , I -ss G� o� Figure l Y O a y I NORTEC, A DIVISION OF ERT JULY 1587 - 3 - I ASPC ZONE 4 (IN FEET) LEASE LINE REFERENCE I y = 6,038,273.87 ft 11,012.84 ft NSL x = 650,630.26 ft 4,284.09 ft EWL Lease block BF -47 (ADL 312799) The bottom hole location of the first well to be drilled (North - star No. 3) will be approximately the same as the surface location, as the well is programmed to be a straight hole. The bottomhole location will be well in excess of the required 500 ft distance from the closest lease line. The bottom hole locations of possible subsequent wells, (Northstar 4 and 5) will be approximately 5,000 ft to the SW and SE of the surface location. These bottomhole locations will be further refined following evaluation of data from Northstar No. 3. Both the surface and all bottomhole locations fall within the boundaries of State of Alaska Oil and Gas Lease No. ADL 312799 (Figure 2). I 3.0 SITE DESCRIPTION The proposed drilling location lies approximately halfway between Northstar Island and Seal Island. Both of these islands are man -made gravel structures from which drilling has been carried out in the past. Due to the distance from both Seal and North - star (approximately 2.5 miles) it is not practical to direction- ally drill to the desired target from either island. II ML Water depth at the Northstar No. 3 location is 42 ft LW. The bottom is relatively flat, but NOAA published bathymetry in- dicates the sea floor slopes up to 5 feet per mile to the North. Amerada Hess Corporation will run a detailed bathymetric survey (50 ft grid) over the proposed site prior to mobilizing the drilling unit. I -4- RI 3E ' I I � Shell et al AMOCO ; I EXXON AMOCO I I Y-0176 • -- -- -- -' -- r_O175 — — — ---- T 31 NORTHSTAR NO.i 1 ' AMOCO ; 36 31 AMOCO I NORTHSTAR \ ' r- 0179 r -018C IS-AND y.OBTtl..� — — — —r- EAL NO4 6' PROPOSED I T 6 T ! NORTHSAR• j AMERADA HESS NO SEAL I Shell et al Na., ' I IN / BF -46 r -0181 I ■ I I 1 —C -- r�----- t----- T- - - - - +— AMERACA HESS \ / I I BF -47 , \ , I I I SEAL \ 1 ISLAND I I I AOL- 312798 i — I I ADL 312799 I SEAL NO.2 I \ 3 Mile Limit e \ ! <0 I i ■ , 4, - t -- - - - - - - - - 1 - - - - - -- — TXAS EASTERN • I , BF -56 ' S E A - I I TEXAS EASTERN -- - - - - L - - - - ADL 312808 I - --- I ` AOL- 312804 II • Q I 1 I 1 , one mile NORTHSTAR NO. 3 BEAUFORT SEA, ALASKA EXPLORATORY WELL LOCATION, ADJOINING LEASE BLOCKS AND WELLS PREVIOUSLY DRILLED IN THE AREA NORTEC, A DIVISION OF ERT JULY 1987 Figure 2 - 5 - 3.1 Sea Ice Oceanographic Considerations Since operations at the Northstar No. 3 location will be carried out continuously during the winter months, an understanding of the formation and movement of sea ice in the area is fundamental to the integrity of the operation. Water depth at the Northstar No. 3 location is 42 feet. The location is well within the landfast ice zone, since the seaward extent of the floating fast ice is typically near the 65 foot bathymetric contour (Reimnitz et al., 1977; Kovacs and Mellor, 1974). The landfast ice zone comprises primarily seasonally formed ice that is bounded by either the shear zone or grounded fast ice (stamuki zone) at its seaward side, and by bottom fast ice at its shoreward side (Reimnitz et al., 1977). Occasional multiyear ice features can be contained within the seasonal ice, although their distribution is typically sparse. Grounded ice ridges are commonly located within the floating fast ice near the 30 foot bathymetric contour (Kovacs and Mellor, 1974). These ridges are formed through shearing and crushing movements at the landfast ice edge. Grounded ridges help to stabilize the landfast ice zone, preventing invasion by moving pack ice and limiting velocities of shoreward ice (Agerton, 1981; Agerton and Kreider, 1979). Ice movements were monitored at three stations during May, 1984 by Arctec Inc. for Amerada Hess Corporation. Two of the stations were located within Tract BF -46, the third station was situated approximately 2 miles north of Tract BF -46. There were no major ice movements during the period of observation. Maximum recorded movement during a five minute sampling period was less than 0.1 feet and maximum recorded movement during the period of obser- vation was 3.4 feet. - 6 - The thickness of the landfast ice is dependent upon the time of year. The rate of ice growth has been documented by Tomas (1980). Generally, the maximum thickness of first year landfast ice is about six feet (Figure 3). The most important property of first year ice is its compressive strength. The design crushing strength is dependent upon the rate of loading and the temperature and salinity within the ice. Typical first -year ice has a top surface temperature of approxi- mately -10 ° C and a salinity of about five parts per thousand. Compressive strength test results for these conditions are presented in Figure 4. It is evident from this figure that the compressive strength of the ice increases substantially with strain rate up to a maximum of 540 psi at a strain rate of about 5x10 -4 sec -1 , after which there is no further increase in strength regardless of strain rate. The compressive strength over the full thickness of the ice sheet has been compared with the compressive strength of the top of the ice sheet by Schwarz and Weeks (1977). Data pertinent to strength variations within ice sheets that are 0.7, 2.6, and 9.8 feet thick are presented in Figure 5. It can be deduced from this figure.that the average compressive strength of an ice sheet is approximately 75 percent of the top surface strength, regard- less of ice sheet thickness. Therefore, an average compressive strength through the ice sheet of 405 psi (0.75x540 psi) has been used for design purposes. For late winter ice conditions (six foot thick first year ice sheet) the maximum ice force per foot of width of structure has been calculated to be 350 kips /foot. f 4 The oceanographic conditions expected at the Northstar No. 3 g location have been estimated using previous work performed by Shell Development Company for the Seal Island site. Because the Northstar location is only 2.5 miles northwest of Seal Island and lies in a comparable water depth, the findings of the Seal Island oceanographic study may be applied directly to the Northstar - 7- 8 • GO • f 6— •0 e o — cu • • • O c •• • w - 00 O• Z O U 4 - w • u . 2 — • HARRISON BAY • SIMPSON LAGOON — O ELSON LAGOON - DEASE INLET t l t t 1 t t t OCTOBER DECEMBER FEBRUARY APRIL JUNE NOTE: Adapted from Thomas, 1980 Figure 3 Fast Ice Thickness, North Coast of Alaska 1970 - 1973 -8- I . I I . - 1000 I 0 . • • o I — 0 : • • A 9 1 a • 1 500 — • • — i i • I— • a z • I • • us • cc _ • • I— • • • I w w > cii • •• w w I a 0 • • REPRESENTITIVE COMPRESSIVE U STRENGTH 0 • • I z 1Z- • • • 0' A.P.I. . 0 100 — • C.) 0 Schwarz and Weeks I Z • • 1 Si 1 I I W4 10-6 10 10 10 10 I STRAIN RATE (1/sec) I , I NOTE: Adapted from American Petroleum Institute, 1982 I . . • and Schwarz and Weeks, 1977 I I I Figure 4 Unconfined Compressive Strength of Ice vs. Strain Rate. I I -9- A ,,js STRENGSTRENGTH TH L FRESH OF SA WATER INE ICE 0 0 0.2 0.4 0F 0.6 ICE 0.8 1.0 I I I r r I r I 0.7 FOOT THICK ICE SHEET • 2 _ • 2.6 FOOT THICK ICE SHEET m ar • w 4 — U _ u . O a. 0 _ I- 0 cc u _ I a 6 - ui 0 - 8 • • 9.8 FOOT THICK ICE SHEET 10 I I I I I I CE J NOTE: Adapted from Schwarz and Weeks, 1977 Figure 5 Ice Strength vs. Depth from Top of Ice. site. The previous studies by Shell (Reese, 1981a, Reese, 1981b; Ward and Reese, 1979) have utilized numerical modeling techniques to determine the expected wave conditions within the area. Table 1 summarizes the oceanographic conditions during a 10 year westerly storm event. Sea ice, oceanographic, and meteorological conditions at the site are further discussed in Section 5.0 (Physical Environment) herein. 4.0 SHALLOW GEOHAZARD ASSESSMENT (Stand Alone Volume) EBA Engineering, Inc. (EBA) conducted a geotechnical investi- gation of the proposed site, as well as three alternative locations, in April 1987. The investigation was carried out from the ice and involved four (4) sampled borings at each site. In situ core penetrometer testing (CPT) was performed as well as comprehensive laboratory testing of recovered samples. An interim report covering the geotechnical conditions at the proposed location (EBA referenced "Site B ") is submitted herewith as in a stand alone volume and entitled "Geotechnical Investigation Site B, Northstar -Seal Area Beaufort Sea, Alaska ". P The conclusion drawn from this interim report is that the proposed site is suitable for the deployment of a gravity structure such as the CIDS Beaufort Sea I. The dense sands and gravels present at the site will offer good frictional resistance to lateral ice loading, and vessel mud skirt penetration and withdrawal can be accomplished with the limits of available ballast and buoyancy forces. Stratigraphic conditions on the inner Beaufort Sea shelf in the area of the proposed location have been influenced by a complex 1, series of sea level fluctuations occurring during the Pleisto- cene. During these fluctuations, in which the sea level may have reached elevations of 300 feet above and 400 feet below present -11- ,, Table 1. Ten Year Westerly Storm, Northstar No. 3 Location. l Oceanographic Condition Design Criteria Water Depth (MLLW) 42.0 feet Storm Surge 2.7 feet Astronomical Tide 0.7 feet Significant Wave Height 12.0 feet Maximum Wave Height 22.8 feet Significant Period (T 9.6 seconds Mean Period (T) 8.7 seconds -12- I levels, the shelf has been subjected alternately to continental and marine deposition and subaerial exposure. Most of the Quartenary deposits in the area comprise alluvial and fluvial materials deposited during sea level regressions. Surficial Holocene materials comprise marine sediments deposited during the most recent transgressions, together with reworked Pleistocene soils and present day deltaic and littoral deposits. Surficial soil conditions at Site B comprise two distinct units: a thin mantle of soft or loose Holocene silts and silty sands, overlying dense Pleistocene sands and gravels. Detailed in- formation is presented in the Stand Alone Volume. The strati - graphy is summarized in the following table: SOIL DESCRIPTION DEPTH RANGE TO RANGE OF TOP OF LAYER THICKNESS (feet) (feet) SILTY SAND, fine, loose; and 0 4.5 - 8.0 SANDY SILT, soft to medium; trace of organics, trace of gravel SAND, medium dense 5.0* 0 - 2.5 SANDY GRAVEL, clean, dense 4.5 - 8.0 >25 to very dense, up to 2.5" sizes; frozen below 54 feet °! NOTE: * where present A thin veneer of loose silty sand appears to exist at the seabed surface across the entire site. The soft sandy silt was en- countered at all boring locations, but in general was thinner in the eastern portion of the site. The surface of the sandy gravel is closest to the seabed surface in the eastern portion, occur- ring at a depth of approximately 4.5 feet. -13- Gravelly sand layers exist within the Pleistocene strata and a frozen gravel encountered at 54 feet is well bounded with no excess ice. A shallow geologic hazard survey was conducted in the area by Harding- Lawson Associates (HLA) in summer of 1980, and an over - the -ice geotechnical investigation carried out by the USGS and HLA in 1978 acquired data in the area as well (Borings 4 & 5, HLA /USGS). An additional shallow hazard survey was con- ducted in 1984 by HLA for Amerada Hess Corporation which centered on the NORTHSTAR " A " Island location. In general, the HLA shallow hazard surveys indicate that the seabed at the proposed site is fairly regular and slopes upward to the south toward Long Island. Numerous ice gouges were detected on earlier side scan sonar records. The proposed location lies in the floating fast ice zone and rafting of floes during freezeup and breakup can produce keels which can gouge the seafloor to a depth of one to two meters. The depth of incision of all gouges observed was interpreted to be less than one meter. High resolution seismic reflection records in Tracts BF -46 and BF -47 indicate only one small area of signal attenuation indi- cative of acoustically turbid sediments having a high compres- sibility due to the presence of interstitial gas bubbles. This area is located over 6 miles to the southeast of the proposed location. No signal attentuation indicative of hydrocarbon presence was observed in the area of the proposed location. N Seismicity of the area is very low. 4.1 Bottom - Founded Structures A major issue governing the design of bottom - founded structures for the Beaufort Sea is the provision of adequate lateral resistance against ice loading. The lateral resistance is a function of the shear strength of the seabed soil at the govern- 1011 -14- I ing potential failure surface. Depending on whether the soil behaves in a frictional or cohesive (undrained) manner, the sliding resistance may also depend on the on- bottom weight, base area, and the efficiency of the contact between base and soil. The efficiency of contact depends to some extent on the nature of the seabed surface and, for a structure with base shear (mud) skirts, such as the CIDS, on the mode of action of the skirts. The latter is also influenced by the resistance to penetration of the skirts. For bottom - founded structures designed for the Beaufort Sea, bearing capacity is seldom a problem, due to the small thickness of potentially weak material in relation to the width of the structure. The near - surface Pleistocene soils present in the Seal - Northstar area will provide adequate assurance against bearing failure. Settlements may occur, however, particularly if the applied load exceeds the preconsolidation pressure of the surficial sediments. The most critical layer with respect to sliding resistance at the proposed site is the soft sandy silt. This material displays an in situ undrained shear strength in the range of 400 to 600 psf. Under loading by a structure, this value will increase somewhat due to consolidation, a process that would be reasonably rapid due to the relatively permeable nature of the soil. 4.2 Future Investigations Prior to mobilizing the CIDS Beaufort Sea I to the drilling location, Amerada Hess Corporation will conduct a detailed bathymetric and side scan sonar survey. Any significant anom- alies discovered by these surveys will be further investigated by divers. The results of these further site investigations will be made available to the Alaska Oil and Gas Conservation Commission and the Department of Natural Resources. -15- a 5.0 PHYSICAL ENVIRONMENT 5.1 Meteorology Long -term temperature data are available for Barrow, Barter Island, and Prudhoe Bay. Air temperatures at all three locations are very similar with mean annual temperatures in the range of -12 to -13 (10 to 9 F). All stations show mean monthly temperatures below freezing except in June, July and August. July temperatures (3.7 to 4.6 ° C [39 to 40 ° F]) are the warmest and February ( -28 to -31 ° C ( -18 to - 24 ° F)) is the coldest month. Precipitation is minimal in the project area. The annual precipitation (including the water content of the snow) and snowfall data for Barrow and Barter Island have been obtained by the National Weather Service for the last 40 and 26 years, respectively. These data indicate a mean precipitation in the range of 12 to 18 cm (5 to 7 inches) annually. The prevailing winds along the Beaufort Sea coast are from the east and west (Selkregg, 1975). The mean annual wind speed for Barrow, Barter Island, and Prudhoe Bay is 10.3, 10.5 and 11.5 kts, respectively. The mean annual direction is easterly for all locations. There is some seasonal variation in both wind speed and direc- tion. Mean monthly wind speeds are generally highest in winter and lowest in summer. Although wind directions vary somewhat, they are generally from either the east or the west. During the summer, the prevailing direction is from the east. Highest winds on record (fastest mile) for Barrow, Barter Island and Prudhoe Bay are 50.5, 80.5, and 50.5 kts, respectively. Highest winds, unlike the prevailing winds, are generally from the west and are more common in the fall and early winter than in the spring and summer months. -16- I Currents, Tides, and Storm Sur 5.2 Cur r , d , Surges g Winter current measurements by NORTEC (1981) in Stefansson Sound in water depths of 5.5 to 8.2 m (18 to 27 ft) indicated average currents of less than 2 cm /s (0.04 kts) with occasional pulses to 10 cm /s (0.2 kts) or greater. The duration of these pulses generally ranged from several hours to several days. Current directions were generally either easterly or westerly for both the normal and extreme currents and did not appear to correlate with either winds or tides. Woodward -Clyde (1979) measured below -ice currents at six locations in water depths of 4.0 to 7.5 m (13 to 25 ft) in the vicinity of the West Dock at Prudhoe Bay. Although current speeds were similar to those reported by NORTEC (1981), their data suggested a tidal dominance in currents. It is expected that these tidal effects are more predominant in nearshore areas, particularly in the vicinity of passes between barrier islands or at bathymetric constrictions. Currents and circulation patterns in the nearshore areas during the open water periods are primarily wind induced (Kinney et al., 1972, 1975; Britch et al., 1983; NORTEC, 1983). Prevailing easterly and westerly winds, in combination with the general east -west orientation of the shoreline and bathymetric contours result in a predominance of westerly or easterly currents along most of the nearshore areas. Based on current measurements in Stefansson Sound (Mangerella et al., 1979; Britch et al., 1983), mean currents would typically range from 10 to 15 cm /s (0.2 to 0.3 kts) with maximum currents typically in the order of 50 to 60 cm /s (1.0 to 1.2 kts). Although open water currents have not been measured at the drilling site, it is expected that they would be similar to those indicated above. -17- Tides in the area include both astronomical and meteorological components. Astronomical tides are the result of a complex interaction of gravitational forces of the sun and the moon and hydrodynamic responses imposed by the basin geometry on these forces. Storm surges, or meteorological tides, result as shear stresses imposed by strong winds move near - surface water masses at a greater rate than can be counterbalanced by gravitational forces less shear forces at the seafloor. Storm surges may either be positive (above normal sea level) or negative (below normal sea level) and generally produce greater water level changes in the area than the astronomical tides. The following sections describe astronomical tides and storm surges documented for the project area. Astronomical Tides - Tidal data are available for a number of locations along the Beaufort Sea in the vicinity of the drilling site. Based on these data the astronomical tides in Stefansson Sound are classified as mixed (and mainly semidiurnal) and are characterized by two unequal high and low water levels occurring over a lunar day (24.8 hours). All stations report mean and diurnal ranges of 12 and 18 cm (4.7 to 7.1 inches), respectively. Storm Surges - While astronomical tides are of academic interest, the largest variations in water levels in the study area, at least during the open water periods are attributed to storm surges. Perhaps the most dramatic storm surges on record occurred in September, 1970. Low -lying tundra plains and deltas as far as 5.0 km (3.0 mi) inland were inundated and a driftwood line was left as much as 3.4 m (11.2 ft) above the normal sea level (Reimnitz and Maurer, 1978, 1979). Surge elevations measured along the coast near the study area ranged from 2.3 m (7.5 ft) near Spy Island to 2.6 m (8.5 ft) southwest of Oliktok Point. Although winds from the 1970 storm of 45 kts, gusting to 70 kts, were reported to have a return period ranging from 25 to 50 years, the actual surge has been estimated to have a recur -18- sea surface downward and achieves a normal maximum ice thickness of 1.8 to 2.1 m (6 to 7 ft) by April. Thicker ice may be found 4 locally because of ice rafting or ridging. In May, melting begins at the ice surface and melt ponds appear on the sea ice surface. These ponds increase in area and depth as spring continues, eventually draining through cracks and holes in the sea ice (Barns and Reimnitz, 1974). By late May or early June, melting rivers in the area usually reach the Arctic coastline. River channels and nearshore areas near the Colville River, the Kuparuk River, and the Sagavanirktok River are generally shallow and intermittently frozen to the bottom by late winter, and river floodwaters in part, spread out on top of the sea ice. The outer limit of overflooding typically extends only a short distance seaward of the outer edge of the bottomfast ice edge. Walker (1974) indicates that overflow from the Colville River normally forms an arch nearly parallel with the delta front over the 3 to 6 m (10 to 20 ft) contours. River over - flooding from either the Kuparuk or Colville Rivers is not expected to be present at the proposed island site. Open water along the Arctic coast begins with the river over- flooding, and as summer progresses, sea ice breakup proceeds normally from the shore in a seaward direction. This breakup process can be accelerated by summer storms. Although remnants of the melting and broken ice can be absorbed into the seaward retreating ice pack, the area is rarely completely ice free, and floes consisting of multiyear ice, or ice ridge fragments can persist throughout the summer. Ice road construction over floating sea ice can begin as early as mid - December. Weakening of the sea ice as breakup approaches usually forces the road to be abandoned by mid -May. -20- 6.0 BIOLOGICAL ENVIRONMENT The Beaufort Sea supports numerous coastal and marine species whose distribution varies temporally. Most animals are absent from the Beaufort Sea area from freeze -up to the following ice breakup. In the spring, most marine mammals are found several miles offshore along the transition zone between the landfast and moving pack ice. Most birds, fish, and mammals show a high degree of mobility and specialized adaptations to survive in an environment characterized by extremes of physical and biological parameters. General descriptions of the biological resources of the Beaufort Sea are provided in the following sections. 6.1 Primary Productivity I Primary production in the Beaufort Sea is furnished by phyto- plankton, ice algae, and benthic algae. Annual production in the Beaufort Sea is relatively low, i.e., less than 20 grams of carbon per square meter per year (gC /m /yr) (Carey et al., 1978). By comparison, annual production in the Bering Sea is estimated at 121 gCm /yr (McRoy and Goering, 1974). Phytoplankton blooms generally occur in the photic zone (upper water column) in late spring and early summer as a result of ice breakup and lengthening daylight. Phytoplankton abundance appears to be greatest in nearshore waters with decreasing numbers further offshore. Nearshore communities are dominated by both pennate and centric diatoms, and flagellates. Peak abun- dance occurs in late July and early August due to increased light levels (Bursa, 1963; Horner et al., 1974). The phytoplankton bloom accounts for an estimated 31 percent of Prudhoe Bay's annual primary production (Horner et al., 1974). I Ice algae blooms occur in March and April on the bottom of ice and continue until early June when ice breakup begins (Horner and Schrader, 1982). Pennate diatoms predominate while centric I -21- diatoms, flagellates, and cryptomonads occur in lesser numbers (Griffiths and Dillinger, 1981). Ice algae account for less than 10 percent of carbon fixed annually in the Beaufort Sea (Horner et al., 1974), but the timing of the bloom provides an early spring food supply for zooplankton and benthic organisms (Horner and Alexander, 1972; Horner et al., 1974; Carey et al., 1978). Benthic macroalgae (commonly associated with boulders) are sparsely and patchily distributed, and make a negligible contri- bution to primary production in the Beaufort Sea (Schell et al., 1982; Dunton et al., 1982). However, kelp do provide important substrate for the attachment of a diverse assemblage of other marine organisms (Dunton et al., 1982). Benthic microalgae generally include diatoms, flagellates, and blue -green algae (Bursa, 1963). Habitats which may be important for benthic microalgae are in clear water in the lee of spits and islands. The overall contribution of benthic microalgae to primary production in the Beaufort Sea remains unknown (MMS, 1984). Project activities are not expected to impact primary production in the Beaufort Sea since effects will be localized and short- term in nature. 6.2 Zooplankton Over 100 species of zooplankton have been identified for the Beaufort and Chukchi Seas. Zooplankton densities are highest in summer when they graze on phtyoplankton. Copepods are the dominant group in terms of total biomass and numbers of species. Other planktonic organisms include amphipods, mysids, euphausids, and the larval stages of many benthic invertebrates (e.g., barnacles, polychaetes, hydrozoans, snails, and starfish) (BLM, 1979; MMS, 1984). -22- Project activities are not expected to impact zooplankton populations in the Beaufort Sea since efforts will be localized and temporary in nature. 6.3 Benthos 1 The distribution, abundance, and species composition of the Beaufort Sea benthos are strongly influenced by the physical - chemical environment. Carey et al. (1978), Feder and Schamel (1976), and Crane and Cooney (1973) considered the following factors to be of particular importance to organisms that live on or in the bottom sediments (the benthos) of the Beaufort Sea. 1 1. ice scour and wave action 2. salinity 3. sediment type and distribution 4. availability of food. Ice scour, wave action, and sedimentation seaward of the barrier islands preclude the establishment of benthic communities similar to the Boulder Patch of Stefansson Sound. Numerous studies have investigated the benthic infauna and epifauna of the Beaufort Sea. NORTEC (1981) investigated the inshore benthic infauna shoreward of the Midway Islands at water depths of 4.9 to 8.2 m (16.0 to 26.9 ft) in 1979. Greater numbers, biomass, and diversity of benthic fauna were noted than in the shallower nearshore areas examined by Feder in 1974 and e4 1975 (Feder et al., 1976). During the sampling, 165 invertebrate taxa in 13 phyla were collected (Table 2). Polychaetous annelids (71 taxa) dominated the fauna, while molluscs (36 taxa) and crustaceans (31 taxa) were subdominants. Mean biomass was 55 g /m wet weight, and the Shannon function of diversity ranged from 2.4 to 3.0. -23- I Table 2 List of Benthic Species collected in the Prudhoe Bay and Simpson Lagoon Areas (NORTEC, 1981; Griffiths and Dillinger, 1981). TAXA TAXA PROTOZOA ANNELIDA Unidentified species Polychaeta Anaitides aroenlandica PORIFERA Etoene onga Unidentified species Me aenLS oveni Phloe minuta CNIDARIA ycin�e sp. HydrozOa Neph ciliata Unidentified species Neoncys ounctata Anthozoa Aglaoonomus ma1 Euneohyta rubiformis Exoaone naidina Nereimyra apnroditoides RHYNCHOCOELA Nereis zonata Unidentified species aZ` ottel a o caLtata er etomastus filitormis ASCHELMINTHES Capitellidae, unid. species Nematoda Scalibrecma inflatum Unidentified species Praxillelia sp. Praxtlieila oraetermissa - ECTOPROCTA Clymenura sp. Unidentified species Maldanidae, unid. species TravesLa sp. rnao tesis scutata MOLLUSCA Spio sp. Gastropodao filicornis CLnaula sp. Solocn eru aetoots sp. aFt tics clausa PrLonosoio sp. Polinices pallida Prionospio cirriferra Neotunea neros Spionudae, unid. species Retusa sp. Aricidea suecica - Oenopota sp. AricL ea leffreysii Oenopota imoressa Tauoeria aracilis e n000ta pyr Lmi3alis ApLstoorancnus tullberai J. Oenopota bicarLnata Apistoorancnidae, unidspecies enopota retu ata Lumbrineris sp. en000ta TTFITOFFEa Lumorineris fragilis e n000ca novalasmeliensis Ninoe sp. en000ca cinerea Ainoe aemmea y Lonna occu to DorvLl eL ae, unid. species nL entified• species Spinther sp. Pelecypoda Hap oscoloous elonqatus Nucula tenuis Scoloolos armiger 4 Portlan La sp. Chaetozone setosa Portlandia erotica Tharyx sp. Liocyma tluctuosa traTEulidae, unid. species sepni a lordi Owenia fusiformis Muscu us niger Ampnarete sp. uscu us sp. Ampharete goes.i A starte borealis Ampnarete vega sx Carte montequL Am�cteis sp. starte ens nectLi Lysipoe Iabiata s esquLmau i Am rettdae . unid. species s7�taite sp. Terebellides stroemi yF�seLla sp. Piste cristata TT vrasl.ra aouldi anassa venusta xtda oroLculata Proclea sp. Axinoosida sp. Talc araffii D Lpl000nta aleuttca ereoe 1L ae, unid. species Become moesta alaskana Brada aranulata Panaora q acla Ls Sabelludae, unid. species LyonsLa arenosa Chone duneri yonsLa sp. , pnaerOodoroDSis minuta • rac a dae, unid. species unidentified species Unidentified species , . . . . Oligochaeta Unidentified species '::::::::'--'!:-.'-- -24- . ,,,1',Is'',-&:,'',:',::...- ABE 1 Table 2 List of Benthic Species collected in the Prudhoe Bay and Simpson Lagoon Areas (NORTEC, 1981; Griffiths and Dillinger, 1981) (Cont'd). 1 • 1 TAXA TAXA III ARTHROPODA PRIAPULIDA Cruscacea Halicrvotus soinulosus Unidentified species Podo Priaoulus caudatus III Mysidacea SIPUNCULA Mvsis littoralis Golfinaia margaritaeea MVS iS reiLCtd Mv51S so. Cumacea Lamoroos so. ECHINODERMATA III Dlascv Ls sp. Holothuroidea Dlascvlls rathkei Myriotrochus rinkii Dlascvlls su csca Unidentified species Bracnvdiasty is cesima Tanaidacea CHORDATA III Unidentified species Unidentified species Is000da Teleostei Saduria entomon Unidentified species Saduria sa ini Cottidae, unid. species - Ampniooaa III Bvblis aaimardi Hao 000s so. Hao 000s sibirica Leotocnelrus so. Pont000reia Femora I Iscnvrocerus sp. Anonvx sp. Anonvx nuaax Boeckosimus sp. Boeckosimus brevis II Boeckosimus a 1n1 Toecxosimus =Fr Hl000medon Sp. tnlsimus oirulai niO s rnus a aria is II n1�simus itT" oraiLs Batnymedon sp. Monoculoides sp. Unidentified species Atvlus car'inata II rcnonene sp. Oedicerotids II . 1 1 1 1 1 -25- 1 AMEMMOMMOMONI Griffiths and Dillinger (1981) conducted extensive studies of benthic epifauna in the Simpson Lagoon, Jones Island, and Spy Island areas. Mysids and amphipods were the most abundant invertebrates during the open -water season. Mysis littoralis and M. relicta were the most common mysids while Onisimus glacialis and Boeckosimus affinis were the key amphipods present. B. affinis was the dominant amphipod on the ocean side of the barrier islands while 0. glacialis was most abundant on the lagoon side. 0. littoralis was also found to be abundant in deeper offshore waters (9 to 11.5 m; 30 to 38 ft). Seasonal calculations of biomass showed that mysid species migrated from the lagoon areas to deeper water during freezup while O. glaci- alis overwintered in the shallow areas. Both mysid species R recolonize the lagoon areas immediately after breakup. Species present in studies by both NORTEC (1981) and Griffiths and Dillinger (1981) were nearly identical. A combined list of all benthos for these two studies is presented in Table 2. Densities and biomass of benthic invertebrate species vary widely in the open -water season. Benthic invertebrates are either filterfeeders (feeding on molts, carcasses, detritus, and living organisms suspended in the water column), or bottom feeders (feeding on organics in the sediments). The quantity and distribution of food and nonfood particles has a major effect on the abundance and distribution of benthic species. Primary production by phytoplankton is probably of major importance ,; (Carey et al., 1974) and epontic algae are also likely to be an important early food source (Horner and Alexander, 1972) . The , dependence of primary productivity on the ice cover and the turbidity, temperature, salinity, depth, and nutrient supply of the surface waters further ties the success of benthic communi ties to these physical and chemical factors. -26- ,' Potential effects on benthic communities from placement of the rig on location and exploratory drilling activities include: mortal- "' ity or physiological stress from physical disruption of the sea bottom including burial of benthic organisms; lethal or sublethal effects as a result of sedimentation from mud and cuttings discharges; altered rates or recolonization in disturbed areas; or changes in community structure as a result of habitat alterations. 1 Turbidity resulting from mud and cuttings dischrages from the rig would reduce light penetration and would interfere to some extent with the operation of gills and filtering organs of filter feeders. Benthic organisms are normally associated with mud or silt and are highly tolerant of most suspended sediment con- ditions caused by construction activities (Hirsch et al., 1978). Studies conducted by the U.S. Army Corps of Engineers as part of the Dredged Material Research Program have demonstrated that concentrations of suspended sediments that are lethal to most marine species are higher than concentrations observed in . the field by an order of magnitude or more. Ambient levels of suspended sediments are relatively high in the Beaufort Sea as severe storms, winds, and currents prevent rapid deposition of sediments and suspended surface sediments. Polychaetes and other annelids are generally successful at burrowing through sediment accumulations. Surface dwelling crustaceans do not fare well under heavy sedimentation; however, many species are adapted to the shifting or gradual accumulation of sediment (Masse, 1972). Bivalves vary in their ability to exhume themselves from sediment accumulation. Some can escape from 50 cm burial (Kranz, 1972) while others are unable to escape from 1 cm accumulation. Habitat alterations will be very localized and will occur primarily in deposition areas. Alterations would consist of changes in sediment grain size, changes in water depth, and possible changes in current, temperature, and salinity. 1 • -27- r Some impacts may result from the associated ice road which may be constructed to resupply the rig. Infauna would be lost along the corridor where the road's ice thickness allowed contact with the bottom (excluding the corridor in 2 m or less of water, which naturally freezes to the bottom). Mobile epifauna would move away from the affected area. This area is periodically scoured by natural ice, thereby relieving the magnitude of impact. In summary, sedimentation and burial resulting from the proposed drilling operation is expected to have an insignificant impact on the arctic benthic community due to its localized nature. 6.4 Fish The Beaufort Sea and its arctic coast support freshwater, anadromous, and marine fish species. Excluding freshwater species, there have been 43 fish species documented in the _ Beaufort Sea. The relatively low species diversity, when compared to more than 300 species in the Bering Sea and Gulf of Alaska, has been attributed to low temperatures, low produc- tivity, and harsh ice conditions which prevent extensive use of coastal habitat during winter months (MMS, 1984). Freshwater species distribution is sporadic in coastal waters of the Beaufort Sea, with peak abundance occurring during or immediately after spring breakup. These species are almost exclusively associated with the extension of fresh or brackish waters off major river deltas. Freshwater species include arctic grayling, round whitefish, and ninspine stickleback (MMS, 1984). Anadromous species found in nearshore waters of the Beaufort Sea include arctic char, arctic cisco, least cisco, Bering cisco, boreal smelt, humpback whitefish, and broad whitefish. Pink and chum salmon are also occasional occupants of Simpson Lagoon and numerous coastal rivers (Craig and Haldorson, 1981). -28- With the first sign of breakup (June 5 - 20), adult and juvenile anadromous fish move into coastal waters to feed on an abundant epifaunal food supply of mysids and amphipods. During the open water months, anadromous species typically occur along the mainland shore (within 100 m) and along the edges and lee sides of the barrier islands. Spawning occurs in river deltas or further upstream in the fall (except for boreal smelt which spawn in spring or early summer). Overwintering areas probably occur in large river deltas (Bendock, 1977; Craig and Haldorson, 1981; Galloway et al., 1982). Anadromous fish are the focus of fisheries along the Beaufort Sea coast. Most subsistence fishing occurs in inland lakes and I streams. The only continuous commercial fishing operation on the North Slope is operated by a single family during the summer and fall months in the Colville River Delta. Subsistence catch in the Colville River Delta area is probably similar to the area's commercial catch. Of four species harvested commercially, arctic cisco is the most important. Average annual commercial catch data (1964 - 1981) is as follows: Species Number Harvested* Arctic cisco 32,548 Least cisco 20,863 Broad whitefish 2,030 Humpback whitefish 1,677 11 *Source: MMS, 1984. 1 It is estimated that about 9 percent of the arctic ciscos and 5 percent of the least ciscos are harvested by commercial fisheries each year. It is assumed that the subsistence fisheries harvest a similar portion of the fish population (MMS, 1984). 11 1 -29- Marine fish species are widely distributed throughout the Beaufort Sea in low densities; although, patchy distributions can occur with schooling species. The most abundant marine species include arctic cod, fourhorn sculpin, saffron cod, capelin, several species of snailfish, arctic flounder, and starry founder. Arctic cod has been described as a "key species" of the ARctic Ocean because of its abundance, widespread distribution, and trophic importance to marine mammals, birds, and other fish. Species such as arctic cod and capelin, periodically enter nearshore areas to feed on epifauna or to spawn. Other species, such as fourhorn sculpin, saffron cod, and founder, remain in coastal waters throughout the open -water months and move further offshore during winter months. Spawning by marine fish species occurs nearshore (or offshore) during winter months; however, capelin spawn in late July or early August (BLM, 1979; Craig and Haldorson, 1981; MMS, 1984). Harvesting of marine fish species by subsistence fishermen is traditional in Beaufort Sea coastal communities (e.g., Barrow, Kaktovik). Arctic cod is fished through the ice during late fall and winter while capelin is harvested in July and August (MMS, 1984) . Project activities are not expected to impact fish resources in the Beaufort Sea since effects will be localized and short -term in nature. No impacts to subsistence or commercial fishing are expected since these activities do not occur at the project location or along routes that project support vessels would utilize. 6.5 Marine Mammals Several species of marine mammals occur in the central Beaufort Sea region. Ringed seals (Phoca hispida) are year -round resi dents. Bearded seals (Erignathus barbatus) and spotted seals (Phoca lar ha) are present during the open -water period, and a -30-- 1 very few of the former may overwinter in the Beaufort Sea. During the open -water period, a small number of walrus (Odobenus rosmarus) may also enter the area. Polar bears (Ursqs maritimus) are present near the coast during the winter, but they move north with the ice pack during summer. Bowhead (Balaena mysticetus) and beluga whales (Delphinapterus leucas) make a far offshore, eastward migration during the spring and a westward return migration in the fall. Gray whales (Eschrichtius robustus), whose normal summer range extends as far north as the Point Barrow area, very occasionally are found as far east as the central Alaskan Beaufort Sea. Non - endangered marine mammal species are discussed below. Bowhead and gray whales are dis- cussed in Section 6.7, Threatened or Endangered Species. Ringed Seal The ringed seal is the most abundant marine mammal in the project area. The Beaufort Sea population is estimated at 80,000 ringed seals in the summer and 40,000 during the winter (Frost and Lowry, 1981) . Ringed seals do not congregate into large herds; however, loose aggregations of tens and hundreds of animals do occur. Densities within the project area depend on a variety of factors such as food availability, proximity to human distur- bance, water depth, and ice stability. Ringed seals are year -round residents in the Beaufort Sea. In winter and spring the animals are associated with landfast ice or stable pack ice, and the shear zone nearshore. During breakup and the retreat of ice form the coast during the summer, ringed seals concentrate along the ice edge. Some seals may remain behind and more may move into the open water during late summer. Breeding ringed seals overwinter in areas of landfast ice, where they are territorial and maintain breathing holes through the ice. In later March and early April, females give birth to a single pup in lairs hollowed out of snow drifts on the ice -31- surface. The pups are weaned at about six weeks of age. Additional ringed seals, mainly sub - adults and non - breeding adults, are found in the transition zone pack ice seaward of the landfast ice. Ringed seals molt during May, June, and early July. During this time, seals commonly haul out to bask and rest on the ice for long periods of time. Ringed seals feed on a variety of prey depending on season and location. Food items include cod, mysids, amphipods, and euphausids. Important predators of ringed seals include polar bears and arctic foxes. Bearded Seal Bearded seals are abundant in the Bering and Chukchi Seas where an estimated 300,000 to 450,000 individuals exist (Braham et al., 1977). Bearded seals that are present in the Alaskan Beaufort Sea come mainly from the Chukchi Sea. The seals move into the Beaufort Sea during the summer open -water period and nearly all will leave before freeze -up. Adults are associated with the receding ice edge. Juveniles frequent the ice -free nearshore areas. Pupping takes place on top of the ice from late March through April" primarily in the Bering and Chukchi Seas. Some pupping does occur in the Beaufort Sea. Bearded seals do not form herds, although loose aggregations of animals do occur. Bearded seals feed primarily on benthic and epibenthic molluscs and crustaceans including isopods, amphipods, clams, and snails. Spotted Seal • The spotted seal is a seasonal visitor to the Beaufort Sea. Spotted seals move into the Beaufort Sea from the Chukchi Sea in low numbers (about 1,000). They appear along the coast in July -32- hauling out on beaches, barrier islands, and remote sand bars on the river deltas. The furthest east that spotted seals are regularly found is the Colville River Delta (Eley and Lowry, 1978). They migrate out of the Beaufort Sea in the fall as the shorefast ice reforms and the pack ice advances southward. 1 Walrus The north Pacific walrus population is estimated to be between 170,000 and 250,000 animals. Most of this population is asso- ciated with the moving ice pack year- round. Walrus spend the 111 winter in the Bering Sea and summer in the Chukchi Sea (MMS, 1984). A few walrus move into the Beaufort Sea during the summer open -water season. The majority of the Pacific population occurs west of Barrow, Alaska. Walrus are benthic feeders and rely primarily on bivalve mol- luscs. Other foods include polychaetes, snails, and crustaceans. Beluga Whale The beluga whale is a circumboral species and a summer seasonal visitor to the Beaufort Sea. An estimated 11,500 beluga whales migrate from the Bering Sea into the Beaufort Sea (Davis and Evans, 1982) during the summer open -water season. They enter the Beaufort Sea at Point Barrow, and from there they follow an almost due easterly course which takes them across the central ice pack to the southeastern Beaufort Sea region (Fraker, 1979). In summer, the beluga whales concentrate in the Mackenzie River estuary. The westward fall migration our of the Beaufort Sea occurs primarily in September. Davis and Evans (1982) showed that the fall migration in the Canadian Beaufort Sea occurred far offshore in 1981. The paucity of sightings of beluga whales near the Alaskan Beaufort coast (Johnson, 1979), despite the large amount -33- of research done there and the large numbers that have been seen offshore, strongly suggests that the majority of belugas migrate far offshore in the fall as they do in the spring. Beluga whales feed on a variety of marine vertebrates and invertebrates such as capelin, cod, herring, squid, and various crustaceans. Polar Bear The polar bear is a circumpolar species. The Beaufort Sea! population (from Point Barrow to Tuktoyaktuk Peninsula) is estimated to be 2,000 bears (Amstrup, 1983). The total Alaskan polar bear population is about 5,000 to 7,000. There is substantial annual variation in the seasonal distri- bution and local abundance of polar bears in the Alaskan Beaufort Sea. The two most important natural factors affecting distri- bution are sea ice and food availability. Drifting pack ice probably supports greater numbers of polar bears than either shorefast or polar pack ice, due to the abundance and availa- bility of subadult seals in this habitat (Smith, 1980). Except when females den on land, polar bears usually remain on the sea ice. Pack ice normally carries bears north of the Harrison Bay area during summer. During winter, males and sub - adults appear to be more mobile, and move relatively long distances, sometimes into Harrison Bay. Females may den on sea ice, particularly in the ridged ice zone. There is a growing body of information that suggests that many female polar bears dig maternal dens on the sea ice (S. Amstrup, pers. comm. and Lentfer, 1975). Lentfer and Hensel (1980) indicate that histori- cally, some important denning habitat existed in land in and adjacent to the Colville River Delta, but that current use of the area is apparently relatively low. -34- Detailed information on polar bears in the barrier island area is lacking; however, it is known that they tend to be attracted to areas where ringed seals, their principal prey, are abundant. Because seals are not particularly abundant in the project area, polar bears are probably relatively scarce as well. Polar bears off the Alaskan coast feed primarily on ringed seals and to a lesser extent, bearded seals and walrus. The polar bear is an opportunistic feeder occasionally frequently coastal areas to feed on carrion, especially whale carcasses. Bears will also scavenge through human refuse when it is available. Other less common marine mammal species that could occur in the area include the narwal (Monodon nonocerus), killer whale (Or- cinus orca), harbor sea (Phoca vitulina richardsi), harp seal (Phoca groenlandica), hooded seal (Cystophoca cristata), northern fur seal (Collorhinus ursinus), and northern sea lion (Eume- topias jubata) (Eley and Lowry, 1978). The major effect of the proposed activities on marine mammals will be the disturbance from noise generated by the project. Sources of noise disturbance will be from over -ice vehicles on the ice road, support vessels, support aircraft, and drilling activity. Mobile airborne sources of noise can disturb hauled -out seals and polar bears occurring within a few kilometers of the source. Seals are possibly more sensitive during molting in the spring. Polar bears can be especially sensitive to noise during maternity denning; however, preliminary results of noise measurements taken within a simulated polar bear den suggest that noise would only be detected by denning bears if the sources was very near the den. -35- Mobile sources of underwater noise primarily include support vessels, support aircraft, and drilling equipment. Fraker et al. (1981) reported that composite sounds from island construction activities from an artificial island were above ambient levels at a distance 4.6 kilometers (2.9 miles) north of the island. Malme and Mlawski (1979) recorded noise from drilling rigs on a natural and artificial island in shallow water (1 -12 m) (3.3 to 39.4 ft) near Prudhoe Bay during ice cover. Low frequency sounds were still recorded at a distance of 6.4 to 9.6 kilometers (4.0 to 6.0 miles) from the drilling area under quiet ambient noise con- ditions, although this disturbance was decreased to 1.6 kil- ometers (1.0 mile) under noisy ambient levels. Underwater sound propagation loss is higher in shallow water than in deep water. Underwater noise may affect marine mammals by disturbing or alarming the animals and causing them to flee the sound source. Underwater noise may interfere with or mask reception of marine mammal communication or echo - location signals. Noise may also interfere with the reception of other environmental sounds used by marine mammals for navigation. Frequent and /or intense noise that causes a flight or avoidance response in marine mammals could displace animals from important habitat areas. However, the monitoring of beluga whale behavior and distribution for the past 10 years in the Mackenzie River Delta estuary in association with marine traffic supporting Canadian oil and gas activities has not shown long -term or permanent displacement of whales from a PIM portion of the estuary with comparatively high levels of indus- trial activity. Due to the low levels of underwater and airborne noise, timing of drilling activities, and the relatively short duration of project activities no long -term displacement or disturbance of marine mammals is expected. -36- 6.6 Coastal and Marine Birds Several million birds, consisting of about 150 species of sea- birds, waterfowl, shorebirds, passerines, and raptors (including the endangered peregrine falcon, discussed in Section 7.7) occur on the North Slope (Pitelka, as cited by Schamel, 1978). The great majority of birds in the area are migratory. Only six species are present from September to May. These overwintering species are rock ptarmigan, willow ptarmigan, snowy owl, common raven, gyrfalcon, and black guillemot (BLM, 1979). The most abundant marine and coastal species include: red phalarope, oldsquaw, glacuous gull, common eider, king eider, spectacled eider, arctic tern, arctic loon, red - throated loon, yellow - billed loon, pintail, white - fronted goose, black brandt, Canada goose, lesser snow goose, whistling swan, pectoral sandpiper, dunlin, northern phalarope, semipalmated sandpiper, parasitic jaeger, pomarine jaeger, longtailed jaeger, Sabine's gull, Ross' gull, ivory gull, and blacklegged kittiwake (MMS, 1984). Major concentrations of birds occur in nearshore (water less than 20 m [65 ft] deep) and coastal areas such as Simpson Lagoon (MMS, 1984). Spring migration to the North Slope and western Beaufort Sea occurs from mid -May to June 20 (Richardson and Johnson, 1981). Coastal and offshore migration routes are greatly influenced by spring ice conditions; timing is influenced by wind direction and availability of open -water leads (Divoky, 1983). After arrival in the spring, most shorebirds and waterfowl disperse to nesting grounds located primarily on moist tundra and marshlands of the arctic slope. Species such as common eiders, arctic terns, glaucous gulls, and black guillemots nest on barrier islands. Timing of ice breakup surrounding a barrier island is critical for determining its importance as a marine bird nesting site. For this reason, islands near large river deltas receive the heaviest use (Divoky, 1978). -37- PI Cross and Egg Islands near Prudhoe Bay support small groups of several species (Divoky, 1978). MMS (1984) notes that the number of nests on these islands is low compared to the overall bird 0 1111 resources of the arctic slope, but these sites are considered more important than other barrier islands where nesting does not occur. Figure 6 shows locations of bird colonies or nesting sites (less than 10,000 individuals per colony) in the vicinity of the project site. Beginning in mid -July, large concentrations of 10,000 or more PI oldsquaw occur in coastal waters inshore of islands (e.g., Simpson Lagoon) where they feed intensively and molt prior to Ill fall migration. In late July, phalaropes and shorebirds also concentrate along the coast, feeding intensively at coastal beach habitats of barrier islands and along lagoon coastlines, marsh- lands, and mudflats (Conners et al., 1981). Fall migration in 1 late August and September is focused along the coast with molting and staging occurring in lagoons, coastal tundra lakes, ponds, and river deltas (MMS, 1984). Figure 6 shows highly sensitive III coastal bird habitat (i.e., major feeding and /or molting concen- tration areas) in the vicinity of the project site. ill Beaufort Sea avian species include both offshore and nearshore 0 111 feeders. Offshore feeders such as arctic terns and black guillemots feed primarily on fish, especially arctic cod. ill Near -shore coastal feeders re on various invertebrates n p y ario us invertebrate and emergent vegetation. Sea ducks (e.g., oldsquaw) feed on benthic crustaceans, particularly mysids. Other waterfowl and shorebirds IIII feed on various adult and larval insects, crustaceans, and molluscs inhabiting coastal salt marshes and tundra ponds (Connors et al., 1981). Although project activities may occur while bird populations are utilizing adjacent coastal areas, there will be no significant impact from the project or its support vessels. Support services M g 1U iii -38- � MIN JINN AN i i i i i i i i i i i i B E q u F a III MR ����� BARRIER ISLAND NESTING SITES MOLTING a NEARSHORE FEEDING CONCENTRATIONS 0 R T NORTHSTAR NO. 3 S 1 S/M . a / i �ip �� .� SOk y�_ i i � / mi G/ W - GOON i„ / t.0 C., I 1lLE OE1TA / , Jk PRUDHOE %% * BAY a P % / /// } Sr �/ v-1* 4,ySSON YQi SO 1 15 0 15 30 F- --I 11---1 I 1 SCALE IN MILES Figure 6 Location of Bird Colonies and Nesting Sites in Vicinity of Project Area. for the project will be based in the Deadhorse /Prudhoe Bay area. There will be no use of the adjacent barrier islands nor will crew members be allowed access to the islands for other than work related activities. Project activities are not expected to interfere with bird migration or flight patterns and no impact to the bird population is expected as a result of the project activities. 6.7 Threatened or Endangered Species There are two mammal species listed as endangered by the U.S. Fish & Wildlife Service that occur in the general project area They are the bowhead whale (Balaena mysticetus) and the gray whale (Eschrichtius robustus). One bird species, the arctic peregrine falcon (Falco peregrinus tundrius) listed by the U.S. Fish & Wildlife Service as threatened and by the State of Alaska Department of Fish & Game as endangered, may also occur in the general project area. No other federal or State of Alaska listed threatened or endangered animal or plant species are found in the project area. Bowhead Whale The bowhead is a large ice - associated baleen whale that inhabits Arctic waters. Only a few years ago, it was thought that the Western Arctic bowhead stock might have contained fewer than 1,000 individuals, but recent more accurate estimates have resulted in a much brighter picture. The Scientific Committee of the International Whaling Commission (IWC) has accepted 3,871 ( +254) as the current "best estimate" of the size of this stock (IWC, in press). Davis et al. (1982) arrived at an independent estimate of 3,842 for the surveyed area on the summer feeding grounds on the eastern Bering Sea. Recent research by Clark (1983) indicated that many whales are undetected in the routine annual census at Barrow, and that current estimates may be low by 15 to 40 percent. -40- Bowheads winter in the Bering Sea and summer in the Canadian Beaufort Sea. Beginning in late March and early April, bowheads start to move north in the Bering Sea, passing through the Bering Straits to enter the Chukchi Sea. From mid -April to early June they migrate through the coastal leads along the northwest Alaskan coast to Point Barrow (Krogman et al.,1982). From Point 1 Barrow, the whales move east and northeast through the offshore pack ice (Braham et al., 1980; Ljungblad, 1981; Ljungblad et al., 1980). The summer feeding range of the bowhead is mainly in the Canadian Beaufort Sea (Fraker and Bockstoce, 1980). The whales begin their activities on the eastern and northern parts of their summer range, and during the course of the summer the whales shift westward, with the first whales entering the eastern Alaskan Beaufort Sea in August or September (Ljungblad et al., 1983). The westward fall migration begins sometime after mid - September and continues into October. The data from 1979 to 1982 show that the vast majority of sightings have been in waters of 18 m to 20 m or deeper, and that the whales migrate across a broad front extending seaward to at least the 50 m isobath (Figure 7). Limited data suggest that some whales migrate even further offshore. The closest sighting of whales to the project area is approximately 11 km (7 mi) to the north. Bowheads have been reported to feed at certain locations in the Alaskan Beaufort (Braham and Krogram, 1977; Ljungblad et al., 1980, 1983; Lowry and Burns, 1980), particularly in the area just east of Kaktovik. Kaktovik is near the western extremity of the main feeding range, which lies mainly in Canadian waters (Fraker and Bockstoce, 1980). Outside of the area near Kaktovik, feeding in the Alaskan Beaufort is not predictable. Bowheads may feed anywhere that food is available in sufficient concentrations to make a feeding effort worthwhile. There have been scattered E observations of "possible feeding" made in the Alaskan Beaufort -41- 1 Ii ' `-- ' : - - - -- - , SEPTEMBER __ -_ ' ` SIGHTINGS ----- , X6 0 - - b OCTOBER - -_ - -_-_ �: - O `SIGHTINGS '4'4,:::: '.'. X ._- - __________.. _- 1200 - 1000'. _ _ - - ' cg0 40 - 30 1 20 0. \ 0, ``° • o _ 0 0 ., o & 0 0 • N 'l O./ � o j NORTHSTAR NO. 3 SIMPSO -- e LAG. lr ./- 1)� 7 -,-� 14) �,1+ RI V ER DELTA 0 �� 1 J 0 0 E ` (� 0 0 " i () O I I I 0 1 I p Q r o 0 3) I � � a p 0 4 0 O 10 20 m■ . 0 13‘,,e p 0 ; I I 1 I DEPTH IN METERS •s of bowhead whale sightings in the project area during September Figure 7 Location h 982. and October of 1979 throug ] Sea (D.K. Ljungblad, pers. comm.; Ljungblad et al., 1983). However, the distribution of food organisms is patchy and highly variable in these regions (Horner et al., 1974). The preferred foods for bowhead whales are pelagic arthropods such as euphausiids, mysids, copepods, and amphipods. Gray Whale The gray whale is a benthic feeding baleen whale occurring only in the North Pacific and adjacent waters of the Arctic Ocean. In the summer, gray whales range primarily in the Bering, Chukchi, and Western Beaufort Seas. Current population estimates place the gray whale at roughly 16,000 whales. The species may be approaching or may have exceeded pre - exploitation levels of abundance. The gray whales endangered status is currently under review and declassification is likely. There is a small but apparently regular movement of gray whales into the Western Beaufort Sea during the summer open -water period. Thirteen gray whales were landed by the Eskimos from Barrow in the 30 year period from 1950 -80; a single animal was taken at Cross Island, east of Harrison Bay, in 1933 (Marquette and Braham, 1982). Three gray whales were sighted in the Canadian Beaufort Sea in 1980 (Rugh and Fraker, 1981). It is possible that a few gray whales might be present in the project area during the summer. Arctic Peregrine Falcon The arctic peregrine falcon occurs in the Beaufort Sea area each year during late summer to early fall (mid - August to early September) as they migrate from nesting areas in the foothills of the Brooks Range down the Colville River to the outer coast. The falcons then fly eastward into Canada where they are thought to migrate south along the Mackenzie Valley to wintering areas -43- • further south. On some occasions during this autumn migration, arctic peregrines may linger at some coastal locations where they hunt waterfowl and shorebirds. 6.8 Effects of Proposed Activities Bowhead whales have been shown to be sensitive to noise generated by low flying aircraft. However, aircraft (fixed -wing) flying at 305 meters above sea level or higher appears to have little or no discernible effect on bowheads (Davis and Koski, 1980). Nearby boat activity also affects bowheads. Bowhead whales tend to move away from vessels which approach within one kilometer and have been known to react to boats as far away as 3.7 kilometers. In general, bowhead flight responses are somewhat tolerant of ongoing noise from boats and may habituate to continuous boat sounds. Drilling noise may be less disturbing to bowheads than boat noise. Richardson et al. (1983) reported seeing bowheads as close as four kilometers from an operating drillship and industry personnel report even closer sightings (MMS, 1984). There are no consistent indications of unusual behavior among whales observed within 20 kilometers of drillships. Fraker et al. (1981) frequently observed bowheads quite close to island construction sites during the summer months. The bowhead may habituate itself to the noises associated with island construction. Once in place, it is unlikely that temporary artificial islands will interfere with bowhead whale migration or other behavior (MMS, 1984). The proposed exploratory drilling activity will have a negligible impact on the Western Arctic bowhead stock. No measurable short -term or local change in numbers or distribution of indivi- duals is expected as a result of the project. The majority of activities will take place during the winter and summer when -44- 1 bowheads are not present in the project area. All support traffic will be kept to a minimum and will follow the most direct routes to and from the drilling vessel and Deadhorse /Prudhoe Bay. Support aircraft will maintain a minimum altitude of 457 m (1500 ft) when in flight to or from the project area. All drilling and other downhole activities will be undertaken in full compliance with the State of Alaska's Department of Natural Resources and Environmental Conservation Commissioner's decision of May 15, 1984. The proposed exploratory drilling activities are unlikely to have any significant effect on gray whales migrating through the Beaufort Sea. Very few, if any gray whales could be expected to be present in the area during the life of the project. The proposed exploratory drilling activities are not likely to have any significant effect on Arctic peregrine falcons. 7.0 PROPOSED DEVELOPMENT SCENARIO (Figure 8) On site project activities will begin in late July or early August, 1987 with detailed bathymetric and side scan surveys of the proposed site. Any deep ice gouges or other anomalous bottom features will be further investigated by divers. Following data analysis, the results of these surveys will be presented to the Alaska Oil and Gas Conservation Commission (AOGCC) and Department of Natural Resources (DNR). The Global Marine Concrete Island Drilling System (CIDS) "GLOMAR BEAUFORT SEA I" will be employed to drill the Northstar No. 3 well, and any subsequent wells from the same location. This drilling unit is currently stacked approximately 6 miles east of the proposed location. In mid - August, 1987 the rig will be de- ballasted and floated to the proposed location. The vessel will be towed by three (3) 9,000 hp (7,200 bollard hp) class 1 1 -45- 1987 1988 JUL AUG SEP OCT NOV DEC JAN FEB MAR APR MAY JUN JUL AUG 1 PERMIT ACQUISITION 2 ADDITIONAL SITE SURVEYS 3 MOBILIZE CIDS EMI BEAUFORT SEA 1 4 DRILL TEST, P&A NORTHSTAR NO. 3 (STRAIGHT HOLE) 5 BOWHEAD WHALE FALL MIGRATION 6 DRILL, TEST, P&A„ NORTHSTAR NO. 4 (DIRECTIONAL HOLE) 7 POSSIBLE ICE ROAD ••• •• • CONSTRUCTION 8 DRILL, TEST, P&A, NORTHSTAR NO. 5 (DIRECTIONAL HOLE) 9 RIG RE- SUPPLY •••••••••••••••• (AS REQUIRED) 10 DEMOBILIZATION MN • • JUL AUG SEP OCT NOV DEC JAN FEB MAR APR MAY JUN JUL AUG Northstar No. 3 SCHEDULE OF ACTIVITIES I s �,� FIGURE 8 e .. ... 1 ocean going tugs. The tugs will be in the Beaufort Sea /Prudhoe Bay vicinity as part of the 1987 sealift of production modules to Endicott. The drilling site will have been previously marked with buoys during the marine survey phase of the project, and mobilization will be timed to coordinate a favorable weather window and tug availability. The vessel will be positioned on site using electronic position- ing equipment. Ballasting operations will result in gravity load on the seafloor sufficient to resist ice pressures which will develop during the winter. An inspection dive may be made following ballasting to assess mud skirt penetration and general 1 seabed conditions with the rig in position. 1 Supplies of fuel, mud materials, cement, casing, wellhead equipment and other materials as required will be put aboard the rig from a supply barge operating out of West Dock at Prudhoe Bay. The consumable capacity of the CIDS is sufficient for up to four months of operation and major resupply will not be required until well into the winter months. Sufficient casing and other tangible equipment for two (2) wells will be loaded at this time. 1 Personnel, groceries and miscellaneous materials will be trans- ported on an as- needed basis by helicopter from Deadhorse. Approximately 35 days will be required to drill the Northstar No. 3 well to 11,350 ft TVD. Testing will consume an additional 25 or more days, depending on the amount of reservoir evaluation required (Figure 8). An additional 5 days are programed for plugging and abandonment. The possible second and third wells (Northstar No's 4 and 5) are programed as directional holes and will require approximately 85 to 90 days each to drill, test and P & A. 1 1 1 1 -47- Northstar No. 3, as well as any subsequent wells will be ex- pendable wells regardless of any commerciality demonstrated during testing. The wells will be abandoned in accordance with Alaska Oil and Gas Conservation Commission regulations. In February and March of 1988, an ice road may be constructed to the location from West Dock. This road would be used to resupply the CIDS with fuel and other materials to continue operations into late spring. Following the completion of drilling and testing operations and PRI release of the rig by AHC, the CIDS will remain on location until the open water season. At this time, it may be deballasted and floated to a new location. Lacking a contract for additional work, the vessel may remain stacked at the Northstar No. 3 PRI location. If the vessel is to remain on location, permits will be obtained for this activity. Pill 8.0 DRILLING VESSEL DESCRIPTION (Figure 9) The Glomar Beaufort Sea I, Concrete Island Drilling System (CIDS) will be used to drill the Northstar No. 3 well and any subsequent wells from the same location. The CIDS is a bottom founded modular concrete structure which supports a barge mounted drilling rig, camp and other facilities. The modules incorporate an efficient honeycomb structural system that provides great longitudinal, transverse and torsional strength. This structural design is based on a "brute mass" approach that obtains sufficient gravity load on the seafloor by ballasting with seawater and relies on passive crushing of the local ice sheet. No active ice defense mechanisms are required. When fully ballasted with seawater the structure provides both a sufficient gravity load to hold the CIDS on location when exposed to ice loads up to 460 kips /ft, as well as adequate freeboard to -48- p \ t 1 ‘ A . , I, • '• si,' cn \ ■ - ' .. N 11/4., 9- • ,.....1/4 A c lk t\ ) * I t, i ',,: t' - , ' '0. .,.., • , 10 , '1 \ I Sr % • St , .. : %P4 . • • , N.: . Ai•li • . S 1. ; '' %‘''' U.. 0 ',.. . ., :. \ i (4 .; ! ‘4,..4 .. 't .' . k , , \ •- : .. '. t . .•., • \\\.. t ■ ' , $e ' .‘ f . . ."' 0 . , , • , ‘ ■ 1, \ \ A s‘ 1 A. I 1,. \ . ki. ‘• 4 \ . 10; \ . , l • , , -A ..• ,• . 1 •i • 1 - i , . •,;,.. . • ,I !,,,. /A . , Ntl: ,,,, , . : t : ' t . i .. '..,' ',‘ iii • '.., '‘ 'L . A A ' 4 • . •'• 4, 0' ,..%, N :-.., •,,.. ', 2 it . • . • • .... „ 9., , ...... 1 .4: , • A .. I.4V`k - 1 x .• ,,L 0 „, ,..J.: k AL 4 ; , ) 4' • 1....t.:1 , • ., . 4 ,,,, ttl "Z. ttS CC. .d. vrs• 't , 'n's ,." ' .".: !' ' 't.: .. :,' ‘ • ' t .... ‘. 1 1 4.A • ' i :0.,, t t *4 : .= A . .t , •,.c, . :-.' OA' %. . - • : • Ai Ni , -, -it t , i' - 4'rvi ,,,. ••■• :A' „f ol 0- Ilf... 1-.. is , , 4.,, 4 '• . ".• A *Z. .1 . ‘,..., ., 11111111\ : .• , ‘ k ,, 1 • •'.‘ .: . • ?”" * . ■ . ....• 0 0 ') • 'i, ik 1 ■ 41 :, '' : 41 . ! P ' ',. . 64 a I : 44' 41P - 4 ■ 40 a. T\* • -- .' .:,,,. ,,..„..:::::.,'",-, , ., \, ' ' I iN • ‘ A '-• * I' A , ' .1 t ‘,116 f A . ' \. :‘,.... ':. ':. \ ■:‘ v *" sl. 'AV , : 4 1 \ ‘ % 0 0°1 . \ 011.11P 11 . : . 10 0 11° 0 111.1 10 11 01.6 ' O.. —.. keep the deck dry during summer storms. Movable concrete armor panels are placed at the ice line to transmit highly localized ice forces into the hull structure. The deck barges provide sufficient storage capacity, and deck space to support up to four months of operation without major resupply. Following the completion of operations the CIDS can be deballasted, floated and towed to a new locaiton. The CIDS GLOMAR BEAUFORT SEA I which has been contracted for the work described herein has previously been used successfully by Exxon in the Cape Hallket area through two complete ice season. 8.1 Marine Specifications • Classification: ABS Maltese Cross A -1 Caisson Drilling Unit. o County of Registry: USA o Operating Parameters: Maximum water depth: 50 ft. Minimum water depth: 35 ft. Minimum temperature (operate): -60 ° F Structural Design Ice Load: 460 kips /ft (diagonal width) Ice Control Pressure: 900 psi (5'x28'area) o PrinciRal Dimensions: Deck: Length Overall 290.5 Feet = Breadth 274 Feet Base: Length Overall 312.5 Feet Breadth 295 Feet Depth From Deck to Baseline: 95 feet o Loading and Towing Data: Average Towing Speed: 4.0 knots with Two (ocean transport) (2) 22,000 IHP Oceangoing Tugs -50- 1 Minimum Draft: 24 Feet without mud skirts 29 Feet with mud skirts Capacities: 11 Drill Water: 34,736 bbl Potable Water: 730 bbl Fuel Oil: 48,712 bbl Bulk Cement: 9,000 cu ft Bulk Mud: 27,000 cu ft 1 Liquid Mud: Reserve Tanks 2,750 BBL Tubular Storage Area (approx.): 4,050 sq ft. (enclosed) plus additional outside 1 storage Sack Storage: Mud & Cement 2,000 sacks open area (not enclosed) Cuttings Storage: 4,000 BBL 1 Heliport: 73 feet x 73 feet. Designed to support an S -61N helicopter in accordance with U.S. Coast Guard speci- fications. 1 Perimeter lighting system with alternating blue and amber lights. One (1) Mission Helicopter fire foam pump, centri- 1 fugal, 900 gpm. One (1) National Foam PPH 60 foam proportioner, 175 gallon tank with operating heads. Four (4) National Foam hose stations, 1 -1/2 inch hose, 50 ft. live hose reel w /PC -12 nozzles. Fireman outfit Helicopter rescue equipment per USCG requirements. 1 1 -51- 0 Quarters: Quarters for 83 men Hospital quarters for 7 men Galley and mess room Recreation room ° Meteorological Instrumentation: One (1) 1 Bendix -Friez anemometer One (1) OSI barometer One (2) OSI thermometer One (1) OSI hygrometer One (1) OSI precipitation indicator O 1 Ice Forces Instrumentation: Ailtech, stress /strain sensor system OSI concrete wall ice force stress panel monitoring system Two (2) Validyne embedment strain gauge readout panel O Navigation Equipment: Two (2) Kokoska, side lights. One (1) Kokoska, stern light One (1) navigational lighting panel Two (2) Carlisle & Finch, search lights One (1) portable signaling light Four (4) obstruction lights, Automatic Power One (1) fog signal system, 2 mile range, Automatic Power O Communications Equipment: One (1) Texas Instruments single side band radio telephone with antenna Two (2) Texas Instruments VHF marine radio telephones with antennas -52- One (1) Torishima emergency stepdown transformer, 75 KVA -Delta Wye, 480 VAC to 208/120 VAC. One (1) emergency quarters generator. • Air Compressors: Two (2) 60.2 CFM, 125 psi air compressors, electric One (1) 17.2 CFM, 125 psi air compressor, diesel o Fresh Water Supply Equipment: One (1) 15,000 gal /day rated reverse osmosis Three (3) 2,400 gal /day rated waste heat distillers. Firefighting and Safety Equipment: Kidde Halon fire extinguishing system in engine room, paint locker, emergency generator room, and water cannon pump house. Deluge system Portable dry chemical fire extinguishers Portable CO2 fire extinguishers Smoke detector installed in each crew accommodation ° Lifesaving Equipment: Life Rafts: Sufficient USCG approved inflatable life rafts to accommodate all personnel onboard suitable for Arctic service. Two (2) Whittaker arctic survival capsules, 54 -man, ' USCG approved, with launch system. Life Jackets: Sufficient to furnish all personnel with one (1) each plus excess as required by USCG. Life buoys: Eight (8), Cal June Work vests: Twenty -five (25) USCG approved, stearns. 0 Medical Facilities: First Aid supplies and equipment. Hospital with seven (7) berths Stretcher, Marine Safety -54- O Reserve Mud System: One (1) Mission, reserve pit transfer pump, 6 x 8, 100 psi discharge, driven by 100 HP motor. Four (4) Brandt, reserve pit agitators, 25 HP each. o Bulk System: Twelve (12) bulk storage tanks, 3,000 CF capacity, 12 foot diameter x 32 feet high, 40 psi operating pres- sure. One (1) tank to have weighting scales. One (1) blend tank, 500 CF capacity, 40 psi operating pressure with weighting scales. Two (2) dust collectors One (1) transfer air compressor, 450 cfm at 40 psi, diesel powered One (1) dry additive system for filling bulk storage tanks with sack material • Cranes and Loaders: One (1) Crawler Crane with 120 foot boom rated at 100 tons One (1) Wheeled Crane with 91 foot extended boom rated at 18 tons American pedestal crane with 140 foot boom rated at 100 tons One (1) caterpillar 966 -C front end loader with bucket and two (2) forks • Welding Equipment: One (1) 400 -amp Lincoln electric unit One (1) 300 -amp portable diesel electric unit • Lighting, Wiring, and Controls: Vapor -proof or explosion - proof, as required by USCG regulations o Sewage Treatment Plant: USCG approved sewage collection and treatment system certified to accommodate 100 persons -55- • Special Services and Equipment: Cementing Unit: Cementing unit with two (2) diesel engines • Well Testing Flare Equipment: (1) Two (2) each flare booms for well testing (2) Manifolding and piping as required to end of boom for gas (3) Test separators, including burner 8.2 Drilling Rig Specifications The drilling rig to be used for the proposed exploratory drilling operations will be Parker Drilling Company Rig No. 217. This rig is currently aboard the GLOMAR BEAUFORT SEA I. ° Depth Rating and General Description: Diesel - electric SCR Drilling Rig rated to 25,000 ft. Rig is designed and winterized to operate in arctic environments. ° Drawworks: One (1) OIME Model 2000E Drawworks complete with Baylor - Elmagco model 7838 electric auxilliary brake, 1 -1/2" lebus grooving, drum size 32" diameter by 56" wide x 58" x 12" hard -faced brake rims, and type K drum brake linkage, fully equalized. Drum drive chains 2" pitch quadruple, transmission chain 1 -3/4" pitch sextuple, high drum clutch - Twin Disc PO 336 and low drum clutch - Twin Disc PO 342. Foster 37AH and 24 AH air actuated catheads, rotary drive assembly using Twin Disc PO 318 clutch, and Duomatic crown block protector. Mast and Substructure: Parco, type Cantilever, static hookload capacity 1,250,000 lb strung with 12 lines, 650,000 lb set back capacity, racking platform capacity 25,000' of 5" drill pipe. Leveling shims and jack. Removable /adjustable stabbing board. Height of rig -56- 1 floor wind break: 60 ft. Height of derrickman wind break: 15 ft. Parco substructure, 34 ft high, 30 ft beneath rotary beams. ° Rotary Table: 37 -1/2" Oilwell rotary table with 650 Y Y ton load capacity. Traveling Equipment: Ideco, 525 ton, with 6 sheaves and Ideco 525 ton hook. ° Crown Block: Parco crown block, grooved for 1 -1/2" line, 60" sheaves with 72" fast line sheave with sand line, cat line, and tugger line sheaves. Capacity 650 tons. Crown -O- Matic: Duo -matic crown block installed • Rotary Hose: One 3-1/2" ID X 60', 5000 psi working pressure with 4" connections. • Prime Movers: Four (4) Caterpillar Model D -399 turbo charged after - cooled engines. Rated at 1000 HP con- tinuous at 1200 RPM. Four (4) Kato brushless generators, 1050 KW. Six (6) EMD79 -MB drilling motors complete with quick - disconnect junction box, explosion proof lockout device, high capacity 7.5 hp blower, and Hunt air cure vents. One (1) Ross Hill SCR Controls package completely housed with four (4) model 1201 SCR drive cubicles with bridge rated at 1600 AMPS. Cubicles are complete with AC alternator control section for alternators including AC control module (electronic- governor - voltage- -57- regulator) and power limit; one (1) model 1201 SCR drive cubicle, one (1) 1600 amps feeder breaker for the 600 volt distribution section; driller's console, driller's foot throttle; 225 KVA, 600/480 volt domestic type core and core transformer in NEMA III enclosure. ° Mud System: Mud Pumps: Two (2) National 12 -P -160 Triplex pumps, 1600 HP with pulsation and suction dampers, powered by four (4) EMD -79 1000 HP motors. Active tanks, compartmented with sand trap, slugging pit, with 1,100 BBL volume. Dual tandem Brandt shakers mounted on sand trap. Two (2) Brandt SRS -2, 2 cone desanders at 1,000 gallon each, mounted over a single screen shale shaker for closed system operations. Two (2) Brandt mud cleaners or equivalent, capable of 400 GPM each. Mud Agitators: (1) Each mud pit has individual bottom mud guns. (2) Each mud pit has individual agitators, Brandt MA 7.5 - 7.5 HP. OIME Mud Gas Separator: Two Centrifuges, equivalent to Pioneer Mark I. -58- Degasser: Swaco, capable of handling 1,000 GPM with independent pump and explosion -proof motor. Mud Testing Facilities: Baroid Offshore test kit. 1 Two mud mixing pumps driven 100HP electric motors. 5" x 6" x 11" Mission Magnum. Gas Detection System: Fixed combustible four -point monitor gas detection system complete with control modules, general alarms 1 and sensors; one each sensor located at central ventilation inlet for air ducts, on bell nipple, 1 shaker -pits and on drill floor to comply with regula- tory requirements. ° Drill String: Drill Pipe: 1 (1) 16,000' 5" OD, 19.5 lbs /ft. Range 2 grade E and G able to maintain 100,000# overpull. 1 (2) 1085' 5" OD, hevi -wate drill pipe. (3) Two pup joints, 5" OD X 5'. (4) Two pup joints, 5" OD X 10' 1 (5) 3 -1/2" drill pipe, 10,000 ft. 1 I! ' 1 -59- Drill Collars: (1) 18 - 8" OD zip grooved with stress relief grooved in box and pin. 6 -5/8" reg connections. (2) 18 - 6 -1/2" OD zip grooved with stress relief grooved in box and pin. 4 -1/2" XH connections. (3) Crossover subs, bit subs, XO subs and handling subs to fit all drill pipe and drill collars, and fishing tools. ° Drill String Handling Tools: Drill Pipe Slips: Two (2) sets Varco SDXL drill pipe slips, one set air operated Varco PS15 slips with accessories. Drill Collar Slips: Two (2) sets for 6 1/2" drill collars, Two (2) sets for 8" drill collars. POI Drill Pipe Elevators: Two (2) sets BJ GC 350 ton 5 ". Zip Lift Elevators. Elevator Links: One (1) set 2 -3/4" X 132" 350 ton links, One (1) set 3 -1/2" X 144" 500 ton links. Drill Pipe Tongs: Wooleys super B with lug jaws and hinge jaw spares. M Drill Collar Safety Clamps. Two (2) 5KUL Ingersol Rand Air Tuggers with 5000# pull. -60- ° Casing and Related Tools: Master casing bushings with split type insert bowls for 20 ", 13 -3/8 ", 9 -5/8 ", and 7-0". 1 Air impactor wrench with adjustable torque to fit all nuts on well heads and BOP's. ° Rig Floor Equipment: Drillers Console with the following Gauges and Instruments. Weight Indicator - Martin Decker - Hercules Type "E" 1 Pump Pressure Gauge - Cameron - Type "E" Rotary Torque Gauge (AMPS) 1 Pump Strokes Gauges (for Main Mud Pump) Rotary Tong Torque Gauge Martin Decker 7 Pin Recorder Kelly: 5 -1/4" Hex X 46 foot, 6 -5/8" LHR box X 4 -1/2" IF pin 1 Kelly Spinner: International Tool, Model A -6C 1 Wire Line Survey: Mathey electric drive surveyor II with 15 HP motor with 20,000' .092" steel line with circulation head and stuffing box. 1 Iron roughneck, Model 2000 "Big Foot ". Automatic Driller: Bear Industries 1 Air Compressors: Two electric screw Gardner Denver BESG. Heating Units: Two (2) Tioga 4,2000 BTU /HR. -61- Flo -Sho on flow line with alarm with recorder. Pit level indicators on all active tanks with totali- zers and recorders at drilling position. Totco Drift Indicator, 0 -8 degrees and 0 -16 degrees for Subcontractor - furnished equipment. Mud Bucket and Drain. Tong- Torque indicator on each set of tongs. Drill pipe lay down machine with manual back -up operation provided. ° Blowout Prevention Equipment: Diverter System: (1) One (1) - 21 -1/4" 2000 psi WP annular diverter with spare element on location. (2) One (1) - 21 -1/4" 2000 psi WP drilling spool with two 10" outlets. (3) Two (2) 300 psi WP hydraulically operated diverter ball valves. (4) Two (2) 10 diverter lines. 13 -5/8" X 10,000 psi WP blowout preventer system: (1) One single 13 -5/8" X 10,000 psi type U Cameron blowout preventer with H2S trim. -62- (2) One double 13 -5/8" X 10,000 psi Type U Cameron blowout preventer with H2S trim. (3) One double 13 -5/8" X 5,000 psi Cameron Type "D" annular preventer with companion flange to bell nipple. (4) Blowout preventers are certified for H2S. (5) Blowout preventer handling system. (6) Drilling spool - 13 -5/8" X 10,000 psi WP. 1 (7) Drill pipe test joints. (8) Ram blocks - 3 sets 3 -1/2" X 10,000 psi 3 sets 5" x 10,000 psi 2 sets blinds 1 (9) Annular Element: One spare. 1 BOP Choke and Kill Line System: 1 (1) Kill Line: Two 3- 1/16" X 10,000 psi full opening gate valves. One 3 -1/16" X 10,000 psi check valve. 1 (2) Choke Line: 1 One 3- 1/16" X 10,000 psi hydraulic full opening gate valve. One 3- 1/16" X 10,000 psi full opening 1 gate valve. (H2S certified) 1 I II 1 -63- Blowout Preventer Control System: PIN NL Sheaffer 3000 psi accumulator, Model 2016035 with electric hydraulic Tri -Plex pump, two air operated hydraulic pumps, hydraulic pump control panel on drill floor, one removed from drill floor and proper mani- folding valves and regulators for functioning BOP's, HCR valve, diverter control. Choke Manifold: 10,000 psi WP, H2S trim with two (2) 3- 1/16" hydraulic chokes with remote panels, on (1) manual adjustable choke, full control opening 4" bypass. Spare parts for rubber components of BOP system. 13-5/8" X 10 000 Type U casing and tubing rams for / . YP g 9 -5/8 ", 7" and 3 -1/2" pipe. Power trip tank with two 40 BBL minimum compartments. BOP Test Pump: 10,000 psi Tri -plex. Fishin g Tools: Overshots, packoffs, extensions and grapples to fish Contractor's drill pipe and drill collars. One (1) 10-3/4" OD full strength series "150" Bowen releasing and circulating overshot with complete accessories to include packoffs, extensions and grapples. -64- One (1) 8 -1/8" OD full strength series "150" Bowen releasing and circulating overshot with complete accessories to include packoffs, extensions and grapples. Taper taps with proper OD's to fit ID's of drill pipe and drill collars. One 8" OD X 20" stroke Bowen fishin g bumper er sub with 3 -1/2" ID circulating hole. One 6 -1/2" OD X 20" stroke Bowen fishing bumper sub, 1 with 2 -1/4" ID circulation hole. ° Downhole Tools and Equipment: Casing protectors: 324 ea 7 -1/4" X 5" Bettis Antelope. 1 Control Valves: 1 (1) Two (2) full opening safety valves for Kelly equivalent to Omsco lock open type, upper kelly cocks, 10,000 psi 1 WP. (2) One (1) test safety valve for 5 inch drill string equivalent to TIW type, lower kelly valves, 10,000 psi WP. 1 (3) Two (2) test drill pipe safety valves for 5 inch drill string with crossover subs to each connection in drill string. 1 1 -65- (4) Two (2) inside blowout preventers for 5 inch drill pipe, Gray Took Company or equivalent, 10,000 psi WP with crossover subs to each connection in drill string. Float Valve: Two (2) full -flow drill string to fit subs as follows: 7 -5 /8" API Regular 6 -5/8" API Regular 4 -1/2" API Regular 8.3 Wastewater Cuttings, and Drilling Fluids Disposal The GLOMAR BEAUFORT SEA I has three suitable methods for the disposal of non -oily waste fluids and cuttings: (1) Overboard discharge diluted with seawater, 10:1 minimum (2) Overboard discharge of undiluted cuttings Immo (3) Storage in holds of CIDS for later disposal mom Wastewater, as well as non -oily muds and cuttings from the proposed operation will be disposed of into the Beaufort Sea in accordance with the terms and conditions of the U.S. Environ- mental Protection Agency (EPA), Beaufort Sea General NPDES permit. Application for coverage under the General Permit has been made by Amerada Hess Corporation. Table 3 shows the estimated quantities of waste materials generated from the Northstar No. 3 exploratory well. Raw sewage will be treated in USCG approved marine sewage treatent unit. This equipment is a biological activation unit utilizing extended aeration and chlorination. Following treatment effluent and sludge will be discharged. -66- aswomm• AMINO= MINIM MM. NM/ MEM MINN MIN MIN 21111.1 MEI MN NM 11111 Table 3 Estimated Quantities of Waste Materials Generated from Northstar No. 3 Exploratory Well. (Based on 65 Day Drilling and Testing Program) WASTE QUANTITIES Per Day Per Well Disposal DriIIing Mud 15 bbl 3,550 bbl Discharge into Beaufort Sea in accord with general NPDES permit. If oiI contaminated, mud will be infected into subsurface disposal zone or transported to approved onshore disposal site. Cuttings 25 bbl 4,250 bbl Discharge into Beaufort Sea In accord with general NPDES permit. Any of contaminated cuttings will be transported to an approved onshore disposal site. Sewage and Gray Water 4,000 gal 280,000 gal Discharge into Beaufort Sea in accord with general cn I NPDES permit. Trash - Combustible materials - 1,000 Ib 70,000 Ibs Incinerate at site. wood boxes, paper, kitchen wastes, etc. Junk - Noncombustible items, 500 - 1,000 Ib 85,000 - 170,000 Transport to an approved onshore disposal site. such as oil drums, Junk metal, tires, batteries, etc. 1 Includes approximately 1,000 bbl of mud to be discharged or infected upon completion of the Iasi exploratory well. 2 Estimated well depth, 11,350 feet subsea. 3 Based on approximately 30 gal /day sewage and 30 gal /day gray water per person for average 60 to 70 persons. 4 Solid Waste Disposal - 10 Ib /trash /day /person plus drilling rig operation combustible wastes. 8.4 Solid Waste Disposal All combustible waste including trash from quarters, mud sacks, and garbage will be burned and reduced to ash in a diesel fired gun -fired burner incinerator. Incinerator residue and non- combustible waste will be backhauled to an approved onshore disposal site. Estimated quantities of solid waste are also shown on Table 3. 8.5 Air Emissions The prime movers on the drilling vessel will be standard items associated with contemporary drilling and marine equipment and are familiar to the Alaska Department of Environmental Conser- vation (DEC). / Application has been made to DEC for approval of open burning of hydrocarbons produced from flow testing. 8.6 Communications Private telephone circuits will be available on the CIDS rig when drilling operations are being carried out. These circuits will access the Arctic Slope Telephone Association Cooperative system IMO in Deadhorse through a microwave link. Both voice and data transmission will be able to occur simultaneously. VHF -FM communications will be maintained between the drilling vessel and the Deadhorse expediter. Marine radio communications will be maintained between the rig and all vessels enroute to and from the rig during open water periods. Aircraft VHF -FM communi- cations will be available for helicopter operations. A wind speed and direction indicator and a non - directional beacon will be maintained on the rig in support of VFR and IFR heli- copter flights. -68- 8.7 Food Service The drilling contractor will provide food service for the crew on 1 the drilling vessel. He will be responsible for ensuring that all food is from an approved source, is properly refrigerated, and 1 stored on shelves off the floor. Cleanliness will be maintained in the kitchen and dining facilities in compliance with applicable government regulations. The contractor will have a valid State of Alaska, Department of Environmental Conservation Food Service Permit. 9.0 SUPPORT SERVICES AND TRANSPORTATION Support of the drilling operation will utilize a variety of modes 1 of transportation dependent on the season, ice conditions and weather. The GLOMAR BEAUFORT SEA I is capable of storing fuel sufficient for up to four months of continuous operation, as well as consumables and tangibles sufficient for three (3) wells. Consequently, major resupply will not be required until December r 1987 or January 1988. 1 An ice road may be constructed to the CIDS location early in 1988. Prior to that time any major resupply that may be required 1 would be accomplished by Rolligon. If an ice road is not constructed to allow trucks access to the rig, Rolligon would remain the principal mode of resupply during the winter months. The approximate routing of the proposed ice road is shown in t Figure 10. Frequent helicopter flights to the rig will be maintained 1 throughout the operation period. An IFR equipped helicopter (Bell 412 class) will be contracted for support of the operation I and stationed at Deadhorse Airport. Compatible IFR instrumen- tation will be installed on the rig. This aircraft will be dedicated to the Amerada Hess drilling operation and will be available 24 hours per day. The adverse weather and light -69- SEA UFOR T SEA SANDPIPE R DRILLSITE 0 G –'-.��Y P ingokls. �l done. /siO^ds Skm L 0 900. p Oh ktpotk Milne C o % NORTHSTAR „A,. ISLAND Pt Ko orok NORTHSTAR 3 Pt. Beechey • (C I DS) *1 w Pt Bock pt, Lon Is Q SEAL ISLAND c oy /fi Cw DRILLSITE Reindeer Ism o� Cross I s yoy O Argo Is. B :99 /s. Q °j O at 0 5 10 et:2 1 t - . - 4 } — I K ( West Dock Score in Miles � °f � Gull k 09 . ,Niakuk Is. Figure 10 Pru dhoe Boy • H�� gt. PROPOSED ICE ROAD ROUTE NORTHSTAR NO. 3 o E Dock �� owls. Q Is. • t°" 4:49 5 °9 °4 °n1A Je t ' � 0� if O 0 \ Deodhorse Airstrip � i - U O Q �0 4 IFR capability essential. The helicopter will be backed up by a second IFR aircraft which will be available during times when the primary helicopter is undergoing maintenance. Amerada Hess will establish a Deadhorse base to recieve and forward cargo, coordinate flights, and arrange other modes of transportation. This facility will be staffed by experienced expeditors and materialsmen. During periods of freeze -up and break -up and the weeks both preceding and following these events, transportation to and from the rig will be almost exclusively limited to helicopter. A possible exception would be the use of an ACV (air cushion vehicle), either self - propelled or towed by heavy lift heli- copter, if heavy loads exceeding helicopter sling load capability were required. During the open water season the rig will be supported by tug and barge operating from West Dock in Prudhoe Bay, as well as continuous helicopter operations. Major fuel deliveries will be made during the open -water season. Fuel transfer will be governed by an SPCC Plan (required by USCG) which will be kept aboard the vessel. Detailed logistical planning will be required to assure that adequate supplies of fuel, mud material, and other consumables are on the rig prior to the freeze -up /break -up periods. 10.0 DRILLING PROGNOSIS (Public Information) The drilling program for the Northstar No. 3 exploratory well is covered in detail in the Application for Permit to Drill, filed with the Alaska Oil and Gas Conservation Commission. In the application the drilling mud program, casing design, formation evaluation program, cementing programs, hydraulics programs, and other engineering material is presented in detail. Much of the -71- information is of a proprietary nature. The following sections cover the drilling programs within the limits of public informa- tion. 10.1 Geological The Northstar No. 3 well will be drilled from a surface location approximately 11,013 ft NSL and 4,284 ft EWL of lease block ADL 312799 (Figure 2). The well is programmed as a straight hole and the total depth will be approximately 11,350 ft TVD. The Ivishak formation is the principal exploration target, estimated to lie at approximately 10,900 ft TVD. The Kuparuk formation may also be evaluated as a secondary objective. The well will bottom in the base of the Ivishak formation. Relict permafrost is expected in the upper 1000 feet of the well. 10.2 Mud Logging and Collection of Samples A qualified contractor will perform the mud logging service. A computerized mud logging unit will be employed which will supply drilling engineering data, formation gas and hydrocarbon moni- toring, and lithologic information on a continuous basis. The mud logging contractor will also collect, wash, and prepare cuttings samples as directed by the on -site geologist. A complete mud log and lithologic log will be prepared consisting of a detailed record and description of the sequence of strata penetrated, all shows of hydrocarbons, drilling penetration rate and other salient information. Drill cuttings will be collected every 30 ft from spud to the 13 -3/8" casing point, and every 10 ft thereafter. Both washed and unwashed samples will be collected in sufficient quantities to supply all parties designated by the operator. In addition, cuttings samples will be collected for both geochemical and paleontological analysis as required by the operator. A mud Pill sample will be collected at each casing point and at each significant change in the mud system. -72- A complete set of washed cuttings samples will be supplied to the State of Alaska in accordance with AOGCC regulations (20 AAC. 25.536.2). 1 10.3 Wireline Logging and Velocity Survey The wireline logging program will be kept flexible to accommodate the specific formation evaluation objectives of the operator. The following logging program is representative of the wireline log data desired: Conductor Hole: No. Logs 1 ° Surface Hole to approximately 3000 ft (through relict permafrost zone). Run 1: DIL /SP /SFL /LSS /GR combination tool ° 3000 ft to 9,700 ft TVD (top of Kingak Shale) Run 1: DIL /SP /BHC /GR 1 Run 2: CNL /LDT /GR Run 3: Sidewall cores (if Kuparuk not conventionally 1 cored) ° 9,700 ft to 10,700 ft Run 1: DIL /SP /BHC /GR Run 2: CNL /LDT /GR 10,700 ft to 11,350 ft Run 1: DIL /SP /BHC /GR Run 2: CNL /LDT /NGS Run 3: RFT (optional) Run 4: Gyro survey Run 5: Velocity survey 1 1 -73- All logs will be run on 2" and 5" scales. Log data will be taped (LIS format or equivalent) and a field computed interpretation (cyberlock or equivalent) may be made on location. Further log evaluation will be made from the taped data by Amerada Hess Corporation. At the election of the operator, a velocity survey may be run prior to running th'e 7" liner described in Section 10.7. This survey will use a vibratory or air gun energy source. 10.4 Conventional and Sidewall Coring Conventional cores may be cut in intervals of interest. The amount of actual coring attempted is heavily dependent upon drilling progress and lithology penetrated, and is at the discretion of the operator. Portions of any reservoir section recovered will be preserved for further analysis. The core will be slabbed vertically into two (2) parts. The slabbed core will be photographed and a core gamma log will be performed by a suitable contractor. Part "A" of the core will be reserved for description only. Part "B" will be available for analysis. Sidewall cores may be attempted in significant zones for reser- voir, lithological, paleontological, and geochemical analyses, at the option of the operator. Additional cores may be taken in massive reservoir beds or significant source bed sequences. An excess of sidewall cores will be planned in order to ensure full coverage. If conven- tional core recovery is good, the number of sidewall cores will be reduced over that interval. 1 A preliminary lithologic description of both conventional and sidewall cores will be made at the wellsite and distributed as directed by the operator. -74- At the operator's discretion, cores designated as potential reservoir lithologies will be subject to (1) porosity, permea- bility, and grain density measurements and /or (2) thin section 11 petrographic study. Those sidewall cores judged as non - potential reservoir lithologies will also be sampled for possible thin section petrography unless they are clay or coal. Argillaceous sidewall cores (shales, claystones, mudstones, marls, or other shaly or clayey lithologies), and coal sidewall cores may be subject to x -ray diffraction study. 10.5 Geochemical and Paleontological Program A basic geochemical well profile analysis may be carried out, at the option of the operator, particularly involving cuttings, sidewall cores, and conventional cores from the Kuparuk sands and Sadlerochit formations. The study, if performed, will be designed at a later date. The drilling fluid system will be kept as free as possible from contamination with organic and hydrocarbon materials to facili- tate any geochemical investigation. A paleontological study of drill cuttings and cores may also be made at the option of the operator. Age dating, determination of microfaunas and microfloras may be done with emphasis on foramin- ifera, palyomorphs and siliceaous nannofossils. Study of cuttings may be based on foraminifera determinations at appro- priate intervals, but should the foraminifera prove non- diagnostic, then either siliceous nannofossils or polynomorphs may be studied at increased intervals. 10.6 Drilling Mud Program 1 The drilling mud program will conform to the discharge regula- 1 tions set forth in the EPA General NPDES permit (No. AKG284000) covering waters of the Beaufort Sea. While the specific mud 1 1 -75- program is being developed at the time of this application, it will include only those generic muds described in the NPDES permit and those additives which have EPA approval. In general, an undispersed bentonite spud mud will be used through the 13 casing point (3000 ft TVD). Drilling the next hole section to approximately 9700 ft will use a low- solids non - dispersed mud system. This system will be weighted up to approximately 11.5 ppg through the Kingak shale section to approximately 10,700 ft. Additions of dispersants will be minimized. Below the Kingak shale a lightly dispersed low-solids mud system will be used, such as EPA approved Type 8 mud. Desired mud properties will be maintained under the direction of the on -site drilling foreman and a qualified mud engineer. Optimum solids control and fluid loss will be maintained, which is critical to successfully drilling the anticipated strati - graphic section. Contingency planning requires that a large inventory of barite and lost circulation material be maintained on the drilling vessel. These materials can be resupplied if required, but frequent adverse weather and sea conditions mandate that these products, as well as other backup mud materials be maintained on location. Sufficient materials will be available to completely rebuild the total circulating volume without resupply from shore. A non - freezing fluid (Arctic pack) may be placed in the 13 -3/8" x 9 -5/8" casing annulus prior to skidding the rig to the next location. 10.7 Casing and Cementing Programs The casing and cementing programs for the Northstar No. 3 well are described in detail in the Application for Permit to Drill. The design is consistent with good oilfield practice and all -76- casing weights and grades are sufficient to resist anticipated downhole pressure differentials and mechanical loading. Hole and casing sizes are described below: Depth (TVD -KB) Hole Size Casing Size 400 ft + 26" 20" conductor 3000 ft + 17 13 surface 10,700 ft + 12 9 Intermediate 11,350 + 8 7" liner The wellhead sections used to land each of the successive strings of casing are also described in the Application for Permit to Drill filed with the AOGCC. 10.8 Testing Program, Disposal of Produced Test Fluids If the liner is run and a decision made to flow test the well, a testing program will be written at that time based on the known downhole conditions. Annular pressure activated test tools will be employed. Recovered liquids will be stored in portable tanks brought to the site for that purpose and gas will be flared from flare booms on the rig. All required permits will be obtained in advance of flaring. Equipment is presently installed on the GLOMAR BEAUFORT SEA I to also burn oil produced from flow tests. Amerada Hess may desire to utilize this equipment during the testing program. Applications for permits for this activity are being prepared. If a permit to burn produced oil cannot be obtained, the fluid will be reinjected (bullheaded) back into the formation from which it originated, or it may be disposed of by injection down the 133/8" x 9 casing annulus. All permit restrictions and stipulations will be observed during any of these operations. 1 -77- 1 10.9 Qualifications of Key Personnel All wellsite operations will be under the direct supervision of the on -site drilling engineer. A wellsite geologist will also be on -site to supervise mud logging, sample collection, and core recovery. Both the engineer and the geologist will assure quality control in wireline logging operations. Additional operations personnel will be at the wellsite as specific special- ized activities dictate. Daily reports will be transmitted to the offices of Amerada Hess Corporation, and frequent telephone and datafax communications will monitor activities at the wellsite. Training and _Drills ° Drilling Company and contractor personnel involved directly in drilling operations (including rotary helpers and derrickmen) will be trained in well control methods and in detection of abnormal pressures. Such training will be completed in approved company or industry schools before drilling is commenced. Blowout prevention drills will also be conducted as required by the Alaska Oil and Gas Conservation Commission. A list of personnel and their completed training will be main- tained on the drilling rig and will be available on request. All supervisory drilling personnel will be MMS certi- fied as operator's representatives both in surface and subsea applications. All personnel engaged on the project will receive Oil Spill Containment and Cleanup training as specified in the Oil Spill Contingency Plan. -78- • Fire Drills: Procedures for emergencies such as fires will be posted on the rig and in the quarters. Specific emergency responsibilities for crew members will also be posted at appropriate conspicuous places on the drilling rig. Fire, abandon rig and H2S drills will be conducted periodically for all crew members. • Safety Meetings: Safety meetings will be conducted periodically to make crews aware of safety procedures and to review poten- tial sources of accidents, and the means of preventing them. Accident causes and corrective measures to be taken in the event of accidents will be discussed. An EMT /Radio Operator /Environmental Monitor person will be on the rig at all times, and will coordinate the safety program with supervisory personnel. • Fuel Transfers: Fuel quantities in all storage and day tanks will be monitored daily. Fuel transfers from trucks or Rolligons (winter) and barges (summer) to the rig storage tanks will occur as required. A fuel transfer plan has been developed which addresses fuel flow diagrams, valving sequences, safety precautions and transfer procedures. One man will have the responsi- bility for all fuel transfers and he will be thoroughly trained in the above procedures. No fuel transfers will be made without this responsible party in atten- dance. U.S. Coast Guard approval of the fuel transfer plan will be obtained prior to startup of operations. -79- 1 11.0 BLOWOUT PREVENTION PROGRAM AND EQUIPMENT 1 All drilling procedures employed on this project, whether automated or controlled by Company or Contractor personnel, are 1 specifically designed and operated to prevent a loss of well control. The primary method of well control utilizes hydrostatic 1 pressure exerted by a column of drilling mud of sufficient density to prevent an undesired flow of formation fluid into the well bore. In the unlikely event primary control is lost, the following surface blowout prevention equipment would be used for secondary control: A 21 2000 psi working pressure (wp) annular diverter system will be nippled up on a 21 weld -on flange on the conductor pipe prior to drilling the 17 surface hole (Figure 11). Two 10" diverter lines will run to discharge points downwind from the drilling rig. The diverter lines will be equipped with a hydraulically actuated valves which will open the diverter lines concurrently with the closing of the annular preventer. In the unlikely event that high pressure, low volume surface gas is encountered, the wellbore fluids can be diverted downwind and gas vented to the atmosphere. After drilling the 17 surface hole to approximately 3000 feet and cementing the 13 casing back to the surface, the con- ductor will be cut off and a API 5000 psi wp SOW casing head will be installed. A 13 10,000 psi wp BOP stack will then be nippled up consisting of two sets of drill pipe rams and one set of blind rams plus a drilling spool and 5000 psi wp annular preventer (Figure 12). Choke and kill lines will be hooked such that the well can be closed in and killed in the unlikely event primary control is lost while drilling the next section of hole. This BOP stack will remain in place throughout all remaining drilling and testing procedures. A 10,000 psi wp choke manifold will be used in all well control operations after the 21 diverter system has been removed. -80- FLOW LINE MIS u u 21 1/4" 2000 PSI WP ANNULAR, DIVERTER IMO • • - - !• 10' DIVERTER LINES �j'���i , - 10' DIVERTER LINES Immuri 300 PSI WP HYDRAULICALLY 10' 300 PSI WP HYDRAULICALLY OPERATED DIVERTER BALL VALVES OPERATED DIVERTER BALL VALVES -► CONDUCTOR PIPE Figure 11 21 1/4" 2000 psi wp Diverter System. -81- 1 1 t A I� 011 1 ' I� = —� FLOWLINE I i r I FILLUP LINE —I"- I I' ! ,fl 5,000 PSI WP I ANNULAR PREVENTER ' FnPln m ] , l IIii',,r, ,( . I 10,000 PSI WP PIPE RAMS 0 „it„ ,nil,',,,,, I I I fl',. `ii , iIIHA 10,000 PSI WP BLIND RAMS 0 3' KILL LINE mi 'Ifs III' 4' CHOKE LINE I n DRILLING' _ = �1I■r41' . ('� TO WP 10,CHOKE- POOL SI I �-1/ CHECK E GATE 111111IIlIII1I1lllfl GATE H.C.R. MANIFOLD VALVE V VALVE VALVE VALVE 1- 17 - 777 1 I. ilia j C 10,000 PSI WP PIPE RAMS P I I I I I I I 0 0 _IIII I �— 13 5/8' 10,000 psi x 13 5/8' 5000 ADAPTER • WELLHEAD 13 5/8' 5000 psi FLANGE —0 SECTION h o d I i . 0 1 0 Figure 12 13 5/8" BOP Stack 10,000 psi wp. 0 0 —82— , 1' The blowout preventers will be actuated by a 375 gallon 3000 psi accumulator system with both air and nitrogen backups. All blowout prevention equipment and testing procedures will meet specifications required in the American Petroleum Institute Recommended Practice #53. Testing of all blowout prevention equipment will be conducted at least weekly and prior to drilling out the shoe of each casing string. Function tests and crew drills will be conducted daily. Primary well control will be maintained by over - balancing formation pressure with the drilling fluid. Automatic and manual monitoring equipment will be installed to detect any abnormal variations in the mud system and drilling parameters. A mud logging unit, manned by experienced personnel, will be in continuous use throughout the drilling operations and will monitor formation pressure, hydrocarbon shows, and loss or gain in mud pits. In the event that the well kicks, the blowout preventers 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 pressure can be safely shut in at the surface. The drilling representatives assigned to the drill site will have extensive training, including MMS approved well control training, together with actual experience in controlling and killing kicks. Such training is an ongoing program of Amerada Hess Corporation and Applied Drilling Technology, Inc. These personnel will be further supported by well- trained rig crews approved by the operator. Pressure resulting from a kick will be circulated out using industry approved methods, and the well will be restored to its normal operating condition. Leakoff tests or formation competency tests will be made after running each string of casing, both for well control information and as an indicator of the depth at which the next string of casing will be required. -83- i In the unlikely event that secondary control of the well is lost and premature well flow occurs, the operator has at its disposal specially designed contingency equipment, experienced back -up personnel, and an emergency spill containment unit which will be on location at all times. Section 14.0 describes Emergency Situation Procedures and Critical Operations in detail, and addresses the loss of well control. 12.0 OIL DISCHARGE CONTINGENCY PLAN (Stand Alone Volume) The prevention of pollution is given a high priority, exceeded only by the protection and safety of personnel. Proper equipment is provided on the rig, and at onshore facilities, so as to avoid the possibility of pollution. Personnel are trained in the use of this equipment and made aware of the potential consequences of spills. Good housekeeping practices will be emphasized and cleanup equipment will be provided at all stations to handle spills. The equipment and procedures for responding to oil spills at Northstar No. 3 location are detailed in the Oil Discharge Contingency Plan. The Oil Discharge Contingency Plan for the Northstar No. 3 well is a stand -alone volume and has been prepared and submitted to the Alaska Department of Environmental Conservation for review and approval. The Contingency Plan includes notification procedures, cleanup equipment inventories, spill trajectory analyses, response and cleanup techniques, and description of environmentally sensitive areas. 13.0 HYDROCARBON SULFIDE CONTINGENCY PLAN The area in which the Northstar No. 3 well is being drilled is not known to contain hydrogen sulfide gas in any formation above the Lisburne Formation. Since the subject well will bottom in the Ivishak Formation and not penetrate the Lisburne Formation hydrogen sulfide risk is considered extremely low. Nevertheless - I I a Hydrogen Sulfide Contingency Plan is being prepared as a separate Stand Alone document. Personnel safety is the prime concern of this plan. In the remote possibility that H2S gas is encountered, procedures will be in place to handle the situation. The Hydrogen Sulfide Contingency Plan will thoroughly familiarize all personnel with the following: o Training for H2S emergencies including identification of safe briefing areas, o Visible H2S Warning System. o H2S Detection and Monitoring System. • Personnel Protective Equipment. • Ventilation Equipment. • Metallurgical Equipment Considerations and Adjustments in the Mud Program. o Flare Systems. o Rig Evacuation Procedures. The basic premise for the protection of both personnel and the environment is containment. In the event of accidental release of H2S gas all safeguards and control procedures will be adhered to by all personnel. The rig will be positioned on location with the bow pointing at approximately 270 (due west). This will place the quarters upwind during prevailing weather conditions. 14.0 CRITICAL OPERATIONS CURTAILMENT PLAN Any drilling or marine operation will be critical when the weather and /or sea ice conditions approach the design limits of the drilling rig or a drilling vessel. Potential critical operations are ballasting /deballasting, drilling, coring, running casing, logging or other wireline operations and drill stem testing. As a general rule no drilling or drilling related -85- operations will commence or be conducted when wind gusts exceed 80 knots. These conditions are unusual for the subject area, with peak gusts in the 50 to 60 knot range being the extreme. As part of the contingency planning, the operator and /or con- tractor will implement an ice movement monitoring program which will supply real time data on ice loads against the drilling platform. In the unlikely eventuality that ice loads ever approach the design limits of the rig or the failure limits of the underlying soil, immediate action can be taken to secure the well until the condition(s) has improved. The drilling contractor has developed a manual of critical procedures (Global Marine Drilling Company - Critical Procedures, 1985) which detail operating and emergency procedures to be followed during ballasting /deballasting, towing, drilling and emergency operations. This manual is considered company propri- etary information, but can be made available for review by authorized regulatory personnel. No drilling operations will commence or be conducted when any of the following conditions exist: 1. Operations will not begin until the Amerada Hess Corporation Drilling Representative is satisfied that the rig is properly rigged up to begin operations. The Drilling Representative will make an entry in the IADC Report stating his satisfaction to the above. 2. When there is an insufficient supply of drilling fluid materials on location to control the well. 3. When sufficient emergency containment and cleanup equipment is not on location or is not maintained in good working order. -86- 4. When the manpower required to safely conduct the drilling operation is not available. 5. When any critical machinery needed to assure a normally safe operation is not operative. 6. When the ice load on the drilling vessel approaches design limits. IMPORTANT: The above list is only a guideline. The decision as to what action to take during a given emergency, no matter what the cause, must be based on the judgement of the Amerada Hess Corporation Drilling Representative and the Drilling Contrac- tor's Supervisor. The persons in charge of the overall drilling operation is: C. R. Richard Jon Marshall Manager, Engineering & Technical Operations Manager Services Glomar Beaufort Sea I Amerada Hess Corporation 510 "L" St., Suite 411 550 West 7th Street, Suite 1340 Anchorage, Alaska 99501 Anchorage, Alaska •99501 Tel: (907) 279 -5449 Tel: (907) 277 -0873 If the drilling unit becomes partially or totally disabled while under contract to Amerada Hess Corporation, the priorities for action in all cases will be: 1. Personnel safety and evacuation, if required 2. Prevention of pollution from well in progress 3. Minimize property and rig damage 4. Regulatory agency and Amerada Hess management notification. All contingency plans are developed with these priority objec- tives in mind. If the drilling rig is damaged to the point where it cannot be repaired on location, then, after evacuation of personnel (if necessary) and suspending the well in progress, the rig would most likely be repaired or replaced with the CIDS -87- remaining on location. A new rig could be brought in by barge, Rolligon or truck depending on the time of year and ice con- ' ditions, to continue drilling or plug and abandon the well in progress. Any debris that may have reached the seafloor would be removed in accordance with Coast Guard regulations and other agency requirements. Loss or Damage to Support Craft The same priorities for emergency response in the event of a boat or helicopter accident will be followed as for a rig mishap. Since there are several barges, tugs, and helicopters routinely working in the coastal area of the Beaufort Sea (dependent on the season) there will be strong back -up capability to provide assistance in the event of one of these craft requires help. Assistance for search and rescue operations would be expected to come from other operators' boats and helicopters, other commercial vessels based in Prudhoe Bay, and the USCG along with other military organizations. If any support craft is lost from service to our operation, a suitable replacement for the support craft will be acquired before preceeding with any segment of the operation which depends on that support for its safety. 15.0 ENVIRONMENTAL TRAINING PROGRAM State /Federal Lease Stipulation No. 2 requires that any Plan of Operations include a proposed environmental training program for all personnel involved in exploration activities (including the personnel of contractors and subcontractors). This training program is subject to review and approval by the Director, Division of Oil and Gas. Amerada Hess Corporation has parti- cipated in the cost of the videotape presentation prepared by Mobil, Sohio, and Exxon. This training presentation has been -88- riew reviewed and found satisfactory by the Joint Federal /State Biological Task Force. The program will be given to all person- nel involved in the exploration activities. These tapes have been edited for industry -wide application under guidance from the Alaska Oil and Gas Association. The tapes are narrated by qualified instructors to insure that personnel understand and use techniques necessary to preserve archaeological, geological and biological resources. The program is designed to increase the sensitivity and understanding of personnel to community values, customs, and lifestyles in areas where such personnel will be operating. The required continuing technical environmental briefing program for supervisory and managerial personnel involved, including those of Amerada Hess Corporation, its agents, contractors, and sub - contractors has also been videotaped for industry -wide use. 16.0 RELIEF WELL DISCUSSION In the unlikely event that primary and secondary well control was lost, and a blowout occurred which could not be contained, the rig may have to be abandoned to prevent loss of life. This is an extremely remote possibility due to the extensive precautions taken to prevent such an occurrence. Fundamental to these precautions is the training required of all personnel involved in exploratory drilling operations and the safety equipment on the rig itself. All crew and supervisory personnel will be trained in accordance with OCS Order No. 2 (GSS- OCS -T1). A list of personnel and training received will be available in the rig. If subsequent efforts to control the well failed, a relief well would be spudded from Seal or Northstar Island. The equipment and method used to transport a rig and supplies to either island would be dependent on the season and weather. Contractors capable of reacting to such an emergency are listed in the Alaska Clean Seas manual and are located in the Deadhorse - Prudhoe Bay -89- ,.� Area. In cases of a blowout emergency, it is customary for all operators and contractors in the area to cooperate in making equipment and labor available. Sufficient drilling rigs, tubulars, wellhead equipment and materials (i.e., mud, cement, bits, fuel, etc.) are available on the North Slope to spud a relief well on an emergency basis. The rig and the aforementioned supplies would be transported to the relief island as soon as possible. Transportation during the ice season would be over ice roads or by Rolligon and by boat and /or barge during the open -water season. During freeze -up and breakup transportation would be by helicopter or possibly by an air - cushioned vehicle. The relief well drill site will be determined by consideration of meteorological forecasts, directional survey data from the blowout well and the indicated required depth of intersection of the relief wellbore with the blowout wellbore. The relief well would always be located away from the blowout at a distance adequate for the protection of personnel and equipment. -90- 17.0 REFERENCES CITED Agerton, D., 1981. 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