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Home My WebLink About202-037 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase, They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. cQQ~ - 037 Well History File Identifier 0 Two-Sided (Rescan Needed OVERSIZED (Scannable) Organizing 1,lnll ,\ 7E AN \ Color items: ~ Grayscale items: 0 Poor Quality Originals: DIGITAL DATA Diskettes, No. 0 Maps: 0 Other. Noffype 0 Other items scannable by large scanner 0 0 OVERSIZED (Non-Scannable) 0 Other: Logs of various kinds NOTES: B (' BEVERL'( ROBIN VINCENT SHER'(LA WINDY Other r ,'.:L6ü" DATE: Iq- T,sl , , D. Project Proofing B(: BEVERL'( ROBIN VINCENT SHERYL~ WINDy' ~'''''''~J ¡ f DAlE:1 ¡;ydfs¡ I , 01--9 vn!J Scanning Preparation A fçn + ~z; = TOTAL PAGES ~ ç- x 30 = B(: BEVERL y ROßIN VINCENT SHER'(L ~IND ( 1 DA1E11J.: Ô£þsi Production Scanning bš ~ I b "CLf Stage 1 PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: B(: BEVERL'( ROBIN VINCENT SHE RY6)NlND'( DATE Ç{ Stage 2 IF NO IN STAGE 1 PAGE(S) DISCREPANCIES WERE FOUND: m!) _NO ~1V1 P B(: BEVERL 0( ROBIN VINCENT SHER'(L MARIA WIND'( /s/ - YES - NO DATE. (SCAPJIIIIJG 15 COMPLETE A T THIS POINT urJlE$S SPECiAl A IIENTlON IS REOulRED orJ ArJ INDIVIDUAL PAGE BASIS DuE TO OUAlITY. GP."YSCALE OR COLOR IMAGES) ReScanned 11'1//' ¡,;¡' '/1' ''1- ('",ï" ,- ',1( .,Ir.. '1fI'I'I/ ','- ,',n.,,,,, ", '11"/:'/1,;,'(1) RESCANNED BO(: BEVERLY ROBIN VINCENT SHERYL MARIA WINm' DATE: /s/ General Noles or Comments lIoout this file: Quality Checked ¡,'hIII'I 12/1 Q/02Rev3NOTScanned wpd e e ........,................. . . ~ -, - -- iT \_', >__ ..'~,-<, MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc ~;~~! ~ -¡ru~ 1: , :1 !Æ~!Æ~~'~!Æ f / / , / / I TONY KNOWLES, GOVERNOR ALASIiA OIL AND GAS CONSERVATION COMMISSION Tommy Thompson Drilling Superintendent Anadarko Petroleum Corporation 3201 C Street, Ste 603 Anchorage AK 99503 333 W, T" AVENUE, SUITE 1 00 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Re: Altamura #2 Anadarko Petroleum Corporation Pe1l11it No: 202-037 Sur. Loc. 1883' FSL, 1339' FWL, Sec. 19, T9N, R2E, UM Btmhole Loc. 2503' FSL, 3797' FWL, Sec. 19, T9N, R2E, UM Dear Mr. Thompson: Enclosed is the approved application for pennit 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 fTom 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. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where sanlples are rust caught and 10' sample intervals through target zones. A full suite of well logs (GR/resistivity/density/neutron) must be obtained from conductor shoe to T.D. Annular disposal has not been requested as part of the Pennit to Drill application for Altamura #2. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on form 10-403 prior to the start of disposal operations. 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, h7c(}r Cammy Oechsli Taylor Chair ORDER OF THE COMMISSION DATED this z.stf'&ay of February, 2002 jjcÆnclosures cc: Department of Fish & Game. Habitat Section wlo encl. Department of En\'ironmental Conservation w/o encl. STATE OF ALASKA ALASKP 'JIL AND GAS CONSERVATION CO~I~ISSION ) PERMIT TO DRILL ' 20 MC 25.005 [ ] Service [ ] Development Gas [ ] Single Zone [X] Exploratory [ J Stratigraphic Test [ ] Development Oil 5. Datum Elevation (DF or KB) 10. Field and Pool 29' RKB 6. Property Designation AA-081736 .I 7. Unit or Property Name Altamura 8. Well Number if.l' 9 Approximate spud date 2/15/02 14. Number of acres in property 15. Proposed depth (MD and TVD) 5,744 If) -W2.-~TVD, 1~D 1«7%2 17. Anticipated pressure ./ {s~ 20 AAC 25.035 (e) (2)} Al 32 degrees Maximum surface 3,578 psig, At total depth (TVD) 4,705 pSlg Setting Depth Top Bottom MD TVD MD TVD 29' 29' 80' 80' 29' 29' 3000' 2779' 29' 29' 9059' 8379' 8907' 8227' 10962' 10282' 1a. Type of work [X] Drill [J Redrill 1b. Type of well [ ] Re-Entry [ ] Deepen 2. Name of Operator Anadarko Petroleum Corporation 3. Address 3201 C Street, Ste. 603, Anchorage, Alaska 99503 4. location of well at surface 1883'FSl.1339'FVVL,Sec. 19,T9N, R2E,UM At top of productive interval 2503'FSl,3797'FVVL, Sec. 19, T9N,R2E,U.M. At total depth 2503'FSl,3797'FVVL,Sec. 19, T9N,R2E,U.M. ""'f2:'"" Distance to nearest property line 113. Distance to nearest well 3,797' E. of lease line 3.3 miles S. of Rendezvous #2 16. To be completed for deviated wells Kick Off Depth: 1,000' 18 Casing Program Size Casing 16" 9-5/8" 7" 4-1/2" [X] Filing Fee [X] Property Plat [X] BOP Sketch [X] Diverter Sketch [X] Drilling Program [X] Drilling Fluid Program [X] Time vs Depth Plot [ ] Refraction Analysis [ ] Seabed Report [ ] 20AAC25.050 Req. Contact Engineer Name/Number: Tommy Thompson 273-6300 Prepared By Name/Number: Bill Penrose 258-3446 21. I hereby certify that the fO~i~9 is true and correct to the best of my knowledge Signed .J~' \.r') ~. .'._~ ... ..., J I - - ~,~- \'. ~.r' r- Title Dnlhng ~u~nntendent Date \ L.f ,2. 'cl .---..-.J ."-- Commission Use Only Permit Number IAPI Number '2ö~- Ö37 5O-/L")3- ~c..¡/2 -o() Conditions of Approval: Samples Required: KVes [] No Hydrogen Sulfide Measures: DcfYes [] No Required VVorking Pressure for BOPE: [] 2M, [] 3M, [] 5M, Other' T e ~ t- ßo f é to c.¡c Ot f' &i. \:.1 r:,A- 1:,,\\."\ Co. \ ~f.:)Ç> ~~ -\~ sc(:)a~-;\ -~ ~/~ Commissioner Maximum Hole Angle: Hole 20" 12-1/4" 8-1/2" 6-118" Specifications Grade Coupling H-40 N/A L-80 BTC L-80 BTC L-80 IBT-mod VVeight 65# 40# 26# 12.6# 19. To be completed for Redrill, Re-entry, and Deepen Operations Present well condition summary Total depth. measured true vertical Effective depth: measured true vertical feet feet feet feet Casing Length Structural Conductor Surface Intermediate Production liner Perforation depth: measured true vertical 20 Attachments Approved By Form 10-401 Rev. 12-01-85 VJý/t l/Z'C/O'L k-;J-r ~ (, 1'f'Jd t J \ l,- tèJ, \, tAt' Ü [ ] Multiple Zone VVildcat 11. Type Bond \See 20 AAC 25 025) Blanket JX-8726 Number Amount $200,000 length 51' 2971' 9030' 2055' Quantity of Cement (include stage data) 235 sxAS1 Stage 1: 580 sx G, Stage 2: 575 sx AS3 380 sx G 228 sx G Plugs (measured) Junk (measured) Size Cemented MD TVD RECEIVED DEC 1 2 2001 Alaska Oil & Gas Cons. Commission .Anchorage I See cover letter for other requirements Mud Log Required kt Yes [ ] No Directional Survey Req'd b(ýes [ ] No [ ] 1 OM, [] 15M . Approval Date by order of the commission Date Submit In Triplicate n r: I (" \ ~ I 1\ L j t- ! \ - '; : -- ......... .' .-.," I , STATE OF ALASKA ALASKÞ fJlL AND GAS CONSERVATION COMMISSION ) PERMIT TO DRILL '} 20 AAC 25.005 [ ] Service [ ] Development Gas I ] Single Zone [X] Exploratory [ ] Stratigraphic Test [ ] Development Oil 5. Datum Elevation (DF or KB) 10. Field and Pool 29' RKB 6. Property Designation AA-081736 7. Unit or Property Name Altamura 8. Well Number #2 9. Approximate spud date 2/15/02 14. Number of acres in property 15. Proposed depth (MD and TVD) 5,744 17. Anticipated pressure Maximum surface 1 a. Type of work [X] Dnll [] Redrill 11 b. Type of well [ ] Re-Entry [ ] Deepen 2. Name of Operator Anadarko Petroleum Corporation 3 Address 3201 C Street, Ste. 603, Anchorage, Alaska 99503 4. Location of well at surface 1883' FSL, 1339' FWL, Sec. 19, T9N, R2E, U M. At top of productive interval 2503'FSL,3797'FWL,Sec. 19, T9N, R2E,U.M. At total depth 2503'FSL.3797'FWL, Sec. 19, T9N, R2E, U.M. 1r Distance to nearest property line 113. Distance to nearest well 3,797' E. of lease line 3.3 miles S. of Rendezvous #2 16. To be completed for deviated wells Kick Off Depth: 18. Casing Program Size Casing Maximum Hole Angle: l ] Multiple Zone Wildcat 11. Type Bond (See 20 MC 25.025) Blanket JX-8726 Number Amount $200,000 {see 20 AAC 25.035 (e) (2)} pSlg, At total depth (TVD) Hole Setting Depth Specifications Top Bottom Weight Grade Coupling Length MD TVD MD TVD Quantity of Cement (include stage data) PUBLIC INFORMATION COPY [X] Filing Fee [X] Property Plat [X] BOP Sketch [X] Dlverter Sketch [X] Drilling Fluid Program [X] Time vs Depth Plot [ ] Refraction Analysis [ ] Seabed Report Contact Engineer Name/Number: Prepared By Name/Number: 21. I ~ereb. 3ify that the foregoing is true and correct to the best of my knowledge Slgn~. t,-~~\r'':>~ ~"':::~ Title Drilling Superintendent . - '_../ Commission Use Only Permit Number I Number . 2 .., :J-OZ- -C~7 çO - /0 "3 ' 20'// - c.., L:J Conditions of Approval: Samples Required. DC) Yes [] No Hydrogen Sulfide Measures: [;<) Yes [] No Required Worki.ng P~ur~ for BOPE: [ ] 2M, [] 3M, [] 5M, Other. 'I c' c; t- f;c P t- fc tf DOt r.Lt'. V-L 4 ¡\- ~IGINAL SIGNED BY 1 T avlor Seamount 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Approved By Form 10-401 Rev. 12-01-85 Plugs (measured) Junk (measured) Size Cemented MD TVD RECEIVED DEe 1 2 2001 Alaska Oil & Gas Cons. Commission Anchorage [X] Dnlling Program [ ] 20AAC25.050 Req. Date, ¿ , ,2/ ~-, \ ~ )roval D~t~ I See cover letter ., ~ ') C,- for other requirements Mud -og R uired [xl Yes [ ] No Directional Survey Req'd [xl Yes [ ] No [ ] 10M, [] 15M Commissioner by order of the commission I')t~~~~ -:J Date ~ '\ . y.. Submi . lcate ORIGINA,L. Altamura Shallo\\" Gas Hazard Evaluation Stratigraph~' and Log Indicators: In this area~ the inter\'al from zero to approxilTIately 4000. 1\leasured Depth (1\.ID) consists of sands and shales fronl the Brookian 1\.'egasequence. They were deposited at a \"ery low angle and ha\"e since undergone very little defonnation. Correlation and mapping of l11arkers within this inten'al in nearby wells indicate that there will be less than 100. 1\10 ditference in between the proposed wells and the Phillips Alaska Rendez\'ous #2 (See 6~ T9N R2E) which is less than 6 mi. from the proposed locations. In the Rendez\"ous #2 welL base of Pennafrost is at approximately 600"1\ 10. From 600. 1\.10 to 2250' 1\,10. sands are less electrically resisti\'e than the sUlTounding shales and only methane gas is detected in the mudstream. These are interpreted to be water-\\'et sands \\'ith some biogenic gas present. The potential exists for natural gas hydrates to be stable at these depths and telnperatures: howe\'er: there ha\'e been no unusual conditions or problems in nearby wells. Fronl 2250'1\.10 to 3000. 1\.10~ sands are less electrically resistive than the surrounding shales and only methane and ethane (C 1 &C2) gas is detected in the mudstream . These are interpreted to be water-wet sands with some biogenic gas and thermogenic gas present in snlall percentages. No significant problems or conditions were encountered in nearby \\"ells. From 3000. 1\,10 to 4150' 1\,10 the sands gradually transition to being nlore electrically resisti\'e than the sunounding shales. and density porosity in excess of 20% is recorded. These sands are interpreted to be \vater-wet in the upper depths (note sands at 3050. and 3335.) but increasing in hydrocarbon saturation with depth. The sand at 3900.1\ 10 has a poor oil sho\\'o No significant problerTIs or conditions were encountered in nearby wells. Seismic Indicators: RA.P (relati\'e amplitude preser\"ed) processed seismic lines highlight areas of anomalously high amplitude. which could be an indication of natural gas drilling hazards. Ele\"en ( 11 ) 2-D RAP seismic I ines in close proximity to the proposed wells \\'ere used for this evaluation (Figure 1). One (1) 2-D line (line 27-74) runs within 200 feet of proposed location Altanlura 2. Proposed location Altamura 1 is 2.870 feet from the closest 2-0seismic line (line NPR96-14). 2-D seismic data (rather than 3-D data) were utilized as the primary evaluation tool because they contain the most near otTset infomlation to provide a more accurate image of the shallow depths that are the focus of this e\'aluation and RAP processed data \\'ere readily a\'ailable. Con\"entiOlRECEIVED JAN 1 1 Z002 '\Iask.a Oil & Gas t,;0..&. (;omr¡800 Ancl1of'aqF' processed 3-D data is, howe\'er, a\'ailable o\"er the proposed locations, and both full- otÌset and near-otÌset nligrated stack \'olumes \\"ere examined. No anomalously bright a.tl1plitudes \\"ere obsen"ed at the proposed well locations a.tld no other indirect indications of shallo\\" gas (\'elocity sags. "chimneys," frequency shado\\". etc.) were noted. A.nlplitude minima and maxima were highlighted on each 2-D line. Anornalously high arnplitude minima were tlagged as indications of potential drilling hazards and their t\\"o- way tra\'el times (T,\\,'T) were recorded. The T,\\'Ts were con\'erted to an equi\'alent depth using a tilne to depth function from the nearest well, the Phillips Alaska Rendez\'ous 2, \\"hich is less than 6 miles away in Sec 6, T9N R2E (Figure I). This tinle to depth function is a result of a Vertical Seismic Protile sur\'ey conducted 21 APRO 1. Fi\'e (5) seismic lines exhibited areas of anomalous anlplitude: NPR95-06. NPR 96-1-1-. NPR95-10. NPR95-19, and 29-7-1-. Snapshots of these areas are included in Figures 2 - 6. The largest anomalous e\'ent appears on t\\"o tie lines (NPR95-19 and 19-7-1-). All other anOlnalies are only obser\'ed on single seismic lines. as SI10\\11 in Figure I. Interpretation of the SeiS111ic data suggests \'ery low potential for drilling hazards at proposed locations Altamura 1 and Altamura 2. as the nearest anomalies to the west are tàirly small and do not appear to extend east\\"ard onto line 27-7-1- or the eastern paI1 of line NPR96-1-I-. Summary: 500'I\'ID -2-1-00' 1\-10 Potential for Natural Gas Hydrates. Low Potential for signiticant accumulation/drilling hazard 2150'1\ 10-2900'1\10 ,\\'ater wet sands with \"ery lo\\" potential for natural gas drilling hazard 2900'1\10--1-200'1\,10 Partially to fully hydrocarbon charged porous sa.tlds. Low potential for natural gas drilling hazard REj~ L: .I'''~ .' ~(,,-, :¡ V\--, \J "0 ~ , '1 (JOt. ,J A f\ I '" hJ¡8IiIit&~1!' 1'':':'-':' I ",' \ '. . ," ' ~\II g,v,,;;J _'~~II ... Äl1(:nono¡.: c w > ¡¡¡¡Ø!II!I ~.1J 0 W cr a 'w rr; .~ -- c ,4) ~::. ~ :ô ~~f ~ Oð ~ rni3 . ..e'I .~ c ~ (!1 ~ ~s ~ . 0 <Ø ~ ~ r.a ~ ¡ ¡ I ., r."~, I s:.. ~ ~ 0 ~ ~ S 0 s::: C\S ~ 0 ~ ~ C\j ~ 0 ~ ~ . ....... ;> ~ ~ ~ I I .~~--, .t;. ¡ \ \ '," - - '-- .. ....'" Ç~ti) ~ I ,.../ \'-:''''4-J ,~/ ,..1 .° .i/" ..~. ."! rÌ'q) . . ~ ~ $-c ::s OJ) . ....-I ~ 1-41~.l11 :>4 1),1 "..4J~ -:"".J r"'l - -J.".'L.............J./ ~..j 1S ::..~. , .' J"" <0 //~ ! . ¡/~f t'\ , ' .~ - - , I - '" ./ ~ ¡ / ~ --....,!<:' f / ..:"!'.'''< i" Allall1urJ 2 t! / II / J, .,~ I"" /' II.' I / ' , AI" I / .s¡, I 'I" . ,mum I i / "0 / i./ / I ,~ -.- " .T., .R 1 I / i'Þ .' / " ..,/ / '- / / -.... /. 1 / . ,~/ - , II I :'r / . .' /' j¡' ,,I '1 / / ,/ /- ! /~¿I / ~/,/' ?r:? ; j // ~4, .~"" , ~/ If¡ ... . 1 .k,. .' / / .' 1./ ~ I //~¿~ I !/ ./! ì/ ( " \ if/./ I ì........... - " .J" /,j/ \ ~ ~~ ~ _/~ . .. ì~ - ~ -- '-¡'''" I:, .\;1'-'.""1] :!/ //~ / I /~ f,/~ ~ ~ ,.1_~'..JII......~.3":I )'\I....~¡ (1 ........:r ~ 1"...uJ~' l_-/ ~./ ~:J ~~"~ /' 'I ~. ¡ ..(::;. I . /,/'~ -...\ '1(, . .~-- ..: ..' ./l ./ t. ~ L~ 127 112 96 80 64 48 32 16 0 -16 -32 ~8 -64 -80 -96 -112 -128 TWT - l~ß 190 200 210 220 230 240 250 260 270 280 290 300 310 320 330 340 350 360 370 380 390 400 410 420 430 440 450 460 470 480 490 500 - 510 - 520 - 530 - 549 Figure 2: Anomalous amplitudes and approximate depths L i -:;;¡. tI.) 52 i CD ~ Š¡ i.' ~ ," ~ ïÇI .- 0 5 '- (-::¡. 5' ca = S' m L ~ Ii. š" :::s - 0 "CII' tI' ¡; ftai5. s: ... :::s ::a !I .- cg 1/ ~ I ~ ~ 8-CO) C2x) D "'-, ~ I "T' ~ ¡¡: S' 0 ~ 1< =' I ñr ij I :e ~I ;1 ,ø; !. I .~.~ - I 1,' ,I" .\ . .~[' ()V' ,,'"0~"'V ,#~~ .~ .~ '\. ' ~' L ¡' ~' .(f:' I \~.... -,~ÝJ~ ... #':~~'- .~i .....~~- ~ \'" .~"I) ,~. ~ ~ ~ ~ Q) ~ Q) ~ ro S . ...-4 ~ 8 ~ ~ ro ~ 0 ro r.n Q) '"'C ;::::S ~ . ...-4 ~ ~ S ro ~ 0 ~ ro S 0 0 ~ ("fj ~ =s OJ:) . ...-4 ~ Va; .~ ,~1-, -~tJ, ~r, .J 'a ~';.~ ..> '-'l "'U. (: - "Î /) t'1/~ ~iiL Cot:.> \ ..~ 'v ~' '-. .. /'" "".~p;'.v";'. ~ .. ~, r. .c , cO !' .'1/' , 'þ),. '-?'~ .. ~ I,' /"' .'~. . .., . .'~,.. "<f" .' '~ ? ~- Oi,-<!... ~. :~ j ,-I Color Bar: JCl_shallhaz . ~ [lie I?TI~@D~ = Display Range Start Interval lþ74 IÞo Mode: Global ..J I ..J Martœr II End I 1548 I . I Set Range I Pf1nolaUon II .~~ ~"':t .,..- ",-, . fJ--4.~:J" ""j~ Æ ," ~. ~~I t-\-' .~\.' .:J..'i .¡::;,.. .~ e>- .~J " l' " ~)-' "., ~~ # .\ A:" ~. ~.' ~u .¡.. !,'" . ~ ,,\~,- - ,. ,.' '-' .~> ..l)~ì e>.VI G-CO) (C J) D QCR) ~ ~ ~ 1:/ ~ I &11 ~ ! ~ '8J s "'" ~ ~ i 'æ ! CI ' &.5~~1I ~ 6.. i;' 1:: ~ .. I Is ,.., .. Q~~2 , sq¡dap a¡em!xoldde pue sapn¡!ydme snoyernouv :17 aln~!d Figure 5: Anomalous amplitude and approximate depth ~~ ~ ~ (dO) @]U 0 ", (dO) Š" = - Q ell '1:1'1' ~ i ~ & Do g ! II.!. I' 1"T1 - ~ S' Q , IS i' "'~ nI, -(' 'v ::e .. ,.,~. J" c... . .~ '. -::.' p "'....,~ ~'.~.' ~.~ . f"\~ -siP" ( 1\' ,\,. .~ {(~J, "..., .,'~ 15 '.. ::...;... - ,;:,.' ,.~C:. fê "0~ - ,,;~~~¿) .::;-'~-' 1~0"'" ' ~'>:!~ ~f L I'~'~I I.. S~ ., i ::a 1I1~=cI ell Ii CD L :æ e!. Figure 6: A110malous amplitude and approximate depth L ~~tJ)o I: 8. ~ ~.i ¡CD :1 - .. ~ ~ :::c II c ! I: -::¡: 5' ca Q S' CD l ~ I!!. ! ::s - CI '01' rTI ¡ f ~ ::s £: ... co c. CI :::c ::s ! - II c¡ ß (§) D ~ ~ e- n I~ I Q, .".<;9 . . . "";'.. . ~ ," -::i'-) -2~" :~~ . - \ ". ", '0. ';......... ....- .~\ ' ,'.' .:: . '. I . . , '.' ;. =."{" ',. ..~:.I" Anadarko Altamura #2 Overview and Timetable Anadarko Petroleum Corporation plans to drill two exploratory wells, Altamura #2 and # 1, in NPRA this winter. AJtamura #2, the first to be drilled, will be located approximately 19 mules southwest of the viUage of Nuiqsut. The well \vill be driUed trom ./' a temporary ice pad with spudding estimated to occur approxinlately F7bruary 15, 2002. The weU will be drilled directionaBy with a maximum hole angle of 32°. If tUlle perm.its, a second weB, Altamura # I, wiU be drilled. The well \-vilJ be accessible by ice roads and rolligon across the trozen tundra. A map showing details of the ice road routes and lengths as weB as the drilling location are enclosed in this application. Ice road and pad construction wiU begin as soon as the necessary pemlÍts and approvals are available and weather conditions allow. It is planned that the Altamura ice road \vill be a 3.7-mile extension off of Phillips Alaska's (PAl's) planned ice road to PAl's Rendezvous #2 welJsite. Anadarko anticipates using rolligons to transport water to the well site as soon as tundra travel is aUowed and the necessary permits and approvals are in place. Construction of the ice road and ice pad will occur concurrently. While it is planned to use rolligons to transport Nabors' Rig #14-E to the wellsite. a backup plan involves using trucks to transport the rig if al1 ice roads, including PAl's road trom 2P Pad to the Rendezvous #2 exploratory wel1 site, are completed in time. WeB testing may be performed. Current plans are to plug and abandon the well prior to " the end of the 2001/2002 winter dri11ing season; however, the well may be temporarily / suspended if weU evaluation cannot be completed prior to the closing of tundra travel in the spring of 2002. Any weU suspension will be performed in accordance with applicable BLM and AOGCC regulations. Operational Considerations Pennafrost Based on offset wells. permafrost is assumed to be present from the surface to approximately 620'. 'The permatrost is not expected to present any drilling difficulties as neither thawing nor gas hydrate problems were encountered in any of the off:set wells. Lost Circulation Some of the offsetting weUs encountered lost circulation in and near their target horizons. The Altamura #2 casing and mud programs have been designed to take this possibility into account. Intermediate casing will be set just above the target horizon and the mud weight cut to avoid lost circulation. When TD is reached, the target interval \\ill be cased with a production liner. Pressures Anticipated pore pressw'es are derived primarily ITOll1 the histories of offsetting wells. These wells, referenced in the Pressure section of this application. were all drilled in the past tèw years and are well-documented. As shown on the attached pore pressure plot and maximum anticipated surtàce pressure (MASP) calculations, the expected pressure at TD is 4,576 psi (8.8 ppg EMW) pnd will result in a maximun1 pressure at the surface, with, a full column of gas. of 3,480 psi. A 5,000 psi WP BOP and wellhead system will / theretore be used on this well. l Shallow gas is not anticipated. The Pressure section of this application contains a Shallo\v Gas Hazard Evaluation that reviews offsetting stratigraphy and log indicators as well as seismic indicators. Drilling Within Annular Blowout Preventer Limitations As ShO\Vl1 in the MASP calculations, no surface pressures are expected above the surface casing setting depth that will exceed the 2,000 psi working pressure rating of the diverter. Below the surface casing, BOPs will be used in lieu of a diverter. Again, the MASP calculations show that aU anticipated surface pressures are well below the 5,000 psi /' working pressure rating of the annular preventer. '1 --/~1 e . BOP System and BOPE Testing ~'.' The BOP system on Nabors Rig #14-E is rated at 5.000 psi working pressure and is described in the BOPE section of this applicatiqn-:--- ¡Since the calculated I1laximum anticipated working pressure at TD in this well is 3"48Q 'psi. it is planned to routinely test all BOPE to 800/0 of its rated working pressure (i.e., 4:600 psi). / / The BOP systen1 will be tested initially (before spudding the \Nen) and w'eekly thereafter to a low pressure of 200 psi and a high pressure of 4,000 psi (800/0 of rated working pressure ). Directional Well The Altamura #2 wiU be directionally drilled to a bottomhole location located approximately 2.535' to the ENE of the surface location. A directional well plan is included with this application. Directional surveys will be recorded a minimum of every 100' ITom the surface to TD. Wellbore proximity calculations are not included with this application because the nearest wellbore is 3.3 miles away. H2S , None of the offsetting wells encountered measurable amounts of H2S and it is not expected that Altan1ura #2 \\iill encounter any. However. the drilling rig \\iill be \vired with operating sensors. enhanced by additional sensors tied into the mud logging system. to continuously monitor tor the presence of H2S Drilling Waste Handling / Drilling nlud and cuttings &001 the well wi11 be pumped down the T' X 9-5/8"" annulus or will be hauled to an approved disposal facility. An average of 20.000 gallons of liquid waste &001 the well may require processing or disposal. Prior to on-site disposal or hauling, nlud and cuttings will be temporariJy stored in a bermed storage cell on the ice pad. Diagrams are included with this application that show the ice pad layouts with the proposed location of the storage cell and cross-sectional layouts of the storage cell. Approximately 15,000 ~bic feet of cuttings will be generated by drilling the priInary wellbore and a sidetrack. If disposed on-site, drill cuttings and gravel from the well will be ground in a portable ball nu11. After grinding, the nlud and cuttings will be pumped into subsurface fomlations below 3,000' via the 9-5/8" surface casing X T' intermediate casing romulus. Included with this application is a Shallow Sand Study in the Rendezvous Area by Anadarko's J.D. Kilgore. This study uses log analysis to show that the fornlations into which waste fluids will be injected are not of aquitèr quality. Additional Infomlation Additional information on operations such as formation tops, logging, mud logging, etc. can be found on the attached Altamura #2 Well Prognosis. Certified Location Plat An as-built location plat, certified by a Registered Land Surveyor, will be submitted shortly after construction of the drilling location is completed and the conductor set. Contacts The contacts \~rithin Anadarko for information are: Reporting and Technical Infomlation T onmlY Thompson (907) 273-6300 Geological Data and Logs John Hartner (907) 273-6300 Anadarko Altamura #2 Well Pro2nosis Well Natne: Anadarko AJtamura #2 Surface Loc.: ./ 1883' FSL, 1339'FVVL,Sec. 19, T9N,R2E,~ Target Loc.: 2503' FSL,3797' FVVL.Sec 19. T9N,R2E, ~ Bottomhole Loc.: 2503' FSL,3797'FVVL.Sec 19, T9N,R2E,~ Elevations: Ground Level 125' AMSL RKB 29' AGL Planned TD: 10,000' TV 0, 10,680 l\ID Formation Tops: TOPS Base Permaftost K - 3 Marker Base Brookian Shelf Sands F.C. Slumps (Top) F.C. Slumps (Base) HRZ (Top) HRZ (Base) K-l LCU Upper Jurassic UJU Nuiqsut A J-3 TD DEPTHS (l\ID) 654' , \ 3,1 77' - '?~\-\c..~ C"S~ ~ ~~~O 4.471' 7.221' 7,972 . 8,093' 8,168 ' 8.320' 8,400' - ,\,. ~ ~(jS" . 9, 1 09' 9,228' 9,318' 10,714 ' 10,962' _\-\1( 1\ \) Two (2) 60' cores are planned in the 6-1/8" hole I Cores: Planned Logs: 12 '14 Surface Hole, 80'-3,000' L WD Only - GR, Res, DenslNeutron, Sonic 8-1/2" Intermediate Hole, 3,000' - 9,180.tvID: L WD OnJy - GR, Res, DenslNeutron. Sonic 6-1/8"" Production Hole, 9,180' - 1 O,680'MD, TD: L WD - GR. Res. DenslNeutron, Sonic E-line - RFT. NIvlRL Side Wall Cores Mud Logging: Contingent Logging: Mud logging will be in operation from the base of the 16 conductor to TO. Service will include sample collection~ ROP. lithology- show description. hot \vire, gas analysis of cuttings, gas chromatography. and drilling parameters. ThÏ11y-foot (30') san1ples will be collected from the base of the surface casing, and 10-toot (10') samples will be coUected in zones of interest. The wellsite geologist will adjust the interval or sample frequency as required. Planned San1pling 1 set unwashed each: Anadarko 3 sets washed and dried: Anadarko 1 set washed and dried: Partners (2), State of AK, BLM 1 set canned ditch samples for geochen1Ïcal analysis collected at 30' intervals from base of the structural casing to TO. If conditions dictate, electric line confirmation of the L WD logging suite is planned. Shallow Sand Study in the Rendezvous Area 1. D. Kilgore Anadarko Petroleum A study has been undertaken to understand the shallow lithologies in the Rendezvous area. The purpose of this study is to determine the proper casing programs to use in upcoming wells that will protect ftesh water aquitèrs. The Rendezvous A well has been studied and few sands were found above 3.000 teet. In addition all of the sands and shale below 600 feet appear to be saline with total dissolved solids (TDS) approaching 9,000 ppm. Above 600 feet the resistivity data seems to indicate hard permafrost. In the study of Rendezvous A wireline well logs were used to examine the lithologies and water chemistries. The gamn1a ray~ resistivity~ sonic. shear, density, and neutron logs were utilized. Various calculations were made to obtain porosity and salinity estinlates ITom these logs. The gamma ray was affected by an enlarged bore hole. The gamn1a ray tool measures natural gamma radiation that is present in the rocks. Proper measurement of the natural gamma radiation requires that the tool is close to the formation. In larger holes the tool is often far away ITom the íormation and the gamma ray tool undercounts the formation galruna rays. The muds in larger bore holes act as a shield absorbing the ganuna rays before they can be read by the tool. To correct this problem gamma ray tools are environn1entally corrected for the large bore hole effect. The gamma ray in this well was corrected using the reported drill bit sizes. Shale volumes were calculated from gamma-ray and density/neutron where available. The sonic was logged over the entire bore-hole and was used for porosity calculations. The ""Hunt-Raymer" algorithm was used to obtain porosity fron1 the sonic. ø = 0.6 * (IJ.T - 56) / IJ.T ./ Salinities were calculated using the R W A or "Rw Apparent" technique. In this technique it is assumed that all sands are 1 000/0 water bearing and that no excess conductivity from the shales in the systen1 are pre~ent. The Humble coefficients were used tor values of a and m (ie:a=0.62 and m=2.15)." The temperature gradient was taken from the bottom hole temperature measured by the wireline tools. All R W A values are converted to 75° F for easy comparison. Salinities have been converted to total dissolved solids, TDS, in units ofppm at 75° F. R1va = aR1V / øm Based on the results of this study we conclude that there are no fresh \vater aquitèrs below the planned casing point at 2600 feet. I Raymer, LL., Hunt ER., & Gardner JS., "An Improved Sonic Transit Time-to-Porosity Transtonn", Transactions of the SPWLA 21 Sf Annual Logging Symposium( 1980). Rendezvous A: The Rendezvous A well logs over the shallow section are displayed in Figure 1. The well encountered few sands above 3,000 tèet. Most of the thin sands encountered appear to have low porosities based on the sonic. There is no density or neutron data above 2700 feet. The gamma ray is displayed in track one with an environmentally corrected gamma ray. The increase in resistivity above 600 feet occurs mainly in shales and probably indicates hard permafTost and perhaps a reduction in salinity. A resistivity curve, a calculated R W A curve and the TDS curve are presented in track two. Density and neutron logs are presented in track three. Sonic and shear logs are presented in track four. A calculated porosity curve is given in track five and shale volume is presented in t rac k seven. Rendezvous A well logs from su rface to 4000 feet. ~Íllm~\l'''..:.'~I[']9.:l:tlDJr.I_.'.tll.:JlIIll']=r'''''IU'j.~"fI".:.'~'.:.'.''Æ~".t~III"..:.~'l'J[IiI.! Well Layout Edit Insert Format Tools Petrophysics corEVAL Geophysics VIew OptIons "f,] E'3 Help I I tl:~~.':.!:,I. -" ---------- --._---------- ~ I.... rë.JI.,.!!kII.vQ)8 ìiò3Ñ.1- Formation Water Salinities: A histogram of the shales is presented in Figure 2. The histogran1 of the RW A curve in the shales shows a mean value of 0.6446 ohm-meters. Converting ohm-n1eters to total dissolved solids yields a value of about 9~000 ppm. Sbale salinities at RendeZ\o'ous A d.".,," ... ',"'iii' .. ..um.. ,,".,.. ,..., ." ,. ""'.'...' ..,."...."., """"', "'. ", "., ""'......' .,. ... ',....",',."..".... . ..,. (3' Frequency Edit Insert Fonnat VIew' Options , [j~,[i1J:JØ%~,~~e.~Q.~~tO ' '-,,' " 01 "[ , 21 31 .f 41 !II 81 71 III 91 '°1 ' 111 121 ' ddl .!d.l. ddd, d,I.l1 ltd. I .Idd! d.lIl,,"..IrI, dild. lid.!. d,l.l, ,ld.l, dddl ,d¡~ 6 - Help II , ,II '3 - - rI1lQ~""C:V .IlsIogrom 01 I<'WA In Shein Well: R[~2\lUI.JS...A ti2.0 - B~I.~ F[[T mtrr: C[PTH< ~OOO ðc 115'" 1> ~ - !": -= :r: ::: 0.045. , -= 0.040 - ~ 0.035. -..----..--.. ..",,---""-' 1.0 'O.iI . all -0,7 .0.8 'O.~ .o.~ -0.3 -0.2 .0.1 , 0.0 IX! <:) -:: 0.030. r: o.QZ::¡' ~ 0.020. I - ,I -: Q.CII'). r::: 0."10. - ~ ;.. ~,/ ~ ~~:. ~~liì !]""': .. - 0 -,11~~_~ In 0 ... 0 (I ,., 0 - 4<121 0 (}.(}OOOO 133.61138 133.B:?'738 (}.6.&460 5.2ssao .2 ..299D9 "9.BUOI 2707.2"9711 0.6:.'565 0.67700 ~ - - SI<rtrsll,,; - r: - POS'!lb'. .Ol~~ - IIlnlnQ ""!u.. IInlmum WCI'ue - 110-1........ ualUf - RolI(e ,-: "eon G~T1c Ueon -= I-tor",on~ r.leon y:: V(l'1an~ - Slal'((rd Dev'Dtlon - s~... ntn - kUl1~''5 - - LltdI'on r:: IlQOe .,. i - - . - :fISlartI ~ExploritL I.M,aosot~I1Geolog6 I Igeolog6..llwen Pr.-H~wellfren. ~\If8l1freq..1 6!oppeðrð.. !...F1J"!~0 7OS-N.i Figure 2 t'''" .- Unfortunately there are really no clean sands to examine in this well in the shallow section. Figure 3 displays the lack of sands with VSH used as the color bar displayed against the RW A curve. -- ..:.. -.. -... . 1'1.- -._.. -- $ well. Xplot UI::I-^Ul. I Well ¡~ ...~IIJ ...."DIIl:! Help I . -[j ~Ii}l ::JA% X ~',œ0.a.~[gJ ~ to " .., .'. .,. .,,_.. .. .' I - IN ~1.1111r.1,111.1'11, 1,1, r.I,III,I',l.lll, f.I,I,I,f.I,I,I, t.1,1,I, f.1,1111r.1,1,1,f.I,IIIIr.IIIIIIr.IIIII~r.III,I~~I,I,I~r.I,I, I~~I,III~ r.1,I,I~ ~1,111~r.U, al,l,l :r.I,I,t:r.I,II~I,III~I~III.r.r.I,IIr.~" I, f.r.I,I, ~I,II f.r.1, I, r.r tJb ~ ~ ~ DEPTH 'IS. RWA Cros9plol -= Well: RENDE2VOUS A ïrl 62.0 - 8351..5 r£[T : ::§ riller; . ~ c: .. .~ ~ ~ ~ ~ ~ ~ ~ ,~ ~ ~ 1 !ci ::§ ~ ~ ~. r.~.,-=I.~ .... -----,.1.... .. ~:::'~~,~~~~¡""',:"'¡'I'."i-':' ',I": ~1'.'-.'a.'~"'.~'''II~,..j,'!"''',,'I:',,~,,.},'11':'I''.I',,' 1".'';'" .Start' ~ExpI...I"Micr...II!IGeo...1.geol I 'weiLl f!]http;,..1 t1Abm.~1 ~Q¡Je,.US$weL ~ ~ .. .. ~ . Xplot Edit Inselt Format Toob VIew OpUons -~~ :- '0226 f:11.". ," .. .. ,',-" .. 1:,"11', , '." ~!I' ::: ~~\,-, :r: ..... ,fu~,I, 0 16 I~:'.' ~ '-.s',.',. . :: ~'I: , ....J'.' r ',{,rl . ... .. 1 .."~ tl.' . 0 ,'" 1 !~. <. .. '"JO:' ~ .1 ~h-" '-'.1" "-'fl.' I I~I _','IJ> ~ r ~\i : i"1 -- 0\' ,Þ"l~, ~~I~ ~~QJi~AU , t:%r: '"",' '\\., , ¡.~I."!~';'0iè(li1-3AM - REV DA.TE BY CK APP DESCRIPTION REV Dot. TE BY CK APP DESCRIPTION [J,JTES, ) --_..1,"-, fi\') !J';:;' 2a :' \fi -5'-').:0" '~:~ ~ \"'~ ~ ~fN- "'"')~t ~ J. J2 JJ V ~. ,/~~f~~~ ~~ ~ ~~. I. : f ;: ---- I 6Rt'cv:I~z~~us ~. . J ~ ~ ì' " ;¿¡( ~ c~. 7 " ~,V'vr;~ 9If,~ '<t-: ': '- , .(/¡-) - ,) - ç ~ ) A!;'~ ;; IJ 'ð '7 ~ ,~ .. '> I) } " L"- ./ AlT~A t-a. 2. ~ ~ "\.,---1. 23 24 lb'9;~ ~..r~ C), u ~J ;.0< ~ Si T[ -.. ~~- (>:;";1 .- --/-. , \ , ~ ~ 28 ~ ~..: ..-.,~ ~ 26 .~ AL TAM'JRA. tJO. 1 ?~ '",/" .15 / 1';,1~ \~ .. ,r J '-, l~. l ,-,: f:"- i " r' ~~ J~ ~), 3} 3J '0/ 3.1 T q 11 ?~J " ; 5 r }~1~ ~~ ~ I (~J 3 I \/1 C II'.J I TY SCALE: 1" = 3~ -r..' ,,,~ c~ ~ ~fí ~.~Jí, M AF' 3 ~.1 [ L E S ø 8/13/01 RLS CC I I~(}JRDINA.TES SHOWN ARE ALAShA STATE PLAtJE zor'.JE 4, NAD 27. :.: I,~EI)GRAPHIC: COORDINATES ARE r,JA[I 27 3 ,fI,Ll D I S T/\r~CES /\RE TRUE 4 ICE PAD [S ROTA TED 70' EAS T FROM rJORTH. 5 VERTICAL DATUM IS ASSUMED. N tr SCALE. I" = ~oø' - ,o.c;r""',~,-J 'ø~ AL TAMURA ~ð2 {-.I --I .. F L Ë v't)/) c.J/V I 12S A~L. I "i< "" (-/\',,~ ~'. \..1" /// C'i ~/... /' ':;).. D.Q.F ~I' (t)p) \----- co ) ~., ~ f,¡l 'l ( , ) V ;/' ,6, L TAM U R A f-.J 0. 2 lOCATED WITHIt~ PROTRACTEC SEC 19, T 9 r~. & R 2 E, UMIAT MERIDIAN. 1883' F S.L, 1339' F. W.L lA T = 70'07'04 77" LONG = 151'44'11.90" ï = :1,895,754.7 '/ = 283,695 6 I Anadarko S Petroleum Corporation CADD nLE NO, t DRAWING NO: UK6010431 08/12/01 AL TAMURA NO 2 DRILL RIG. WELL PAD CONFIGURATION AND SPILL TRAJECTORY NSK 6,Ø1-d431 t SHEET; 1 OF 1 1 REV: 0 i ... Dlk~ Di~e ~Jl R::.:.ve N6::.'o', '. ke p'JJ!6.0,1 ~ 16.0'\ Ri~?~~d. '~. [c:8~~0~ _f'_L20 IL - - - Tundr2- -""- - - - - - - - ~ - - _OS>=-- - - - - - - - - _.-J Tundr!! TYPICAL CROS~, SECTION (N,T.S) Dike c' Dike 0' Resc:rve -¡' Pit ~ ()1 160 ø' - 1 - ~37.0' , 6.0' '" t 6,0' I - 95,0". I J 1 0' Rlq Pad Csi Ice Pad 1 - . '0 5' -1-----~nd~-----------------T~ro-----~1-- TYPICAL CROSS SECTION (N,T's) Total Capacity = 44,800 cubic feet Free Board = 2 feet Usable Storage Volume = 19,200 cubic feet 3.0' ~ A. 80.0' Reserve Pit ~ 160,Ø' þ . TYPICAL RESERVE PIT (N.T.S.) Plan View Anadarko 1Z Petroleum Ccrporation CAOO F1lE NO, I DRAWING NO: LK601D429 8/02/01 RESERVE PIT PLAN AND PROFILE PERMIT EXHIBIT NSK 6,01 - d429 I SHEET: I RE~ ø 1 OF 1 ReVISIÜn O. , 3 August 2001 >~::,':,'~!-'..~,,'. ':- 'i.--.,'", ,.,' ~"l'!.-. -.:,'" -" ':' \ .:", _: I' "; ,- 1 ~Î.:" 4'1, ~:, ' ". -, I, , ..' ,. " ,-_'I,t"., i~, "',' "-'. .' ':. ..-'-,',-[',', ," i. 'i ,'"( "I'. \1, .1. ¡ .' "þ~' \" " \" I,..': '.' 1,-- \ II I""" ,-, '\" ~¡' ,. : ,-,\-,-,:~;j~:-~,,'~e'\ ',' " ,'"]-/ "',"")'rIl'~j;E I,' :'-,,' !I .., 1""'_- 'Jll~\ ~3È <,;,',{ì 'i" ,': I :''''~': ~ t\,'r.:""~~'~'~R~E' ,- \~\';,.l !:'- .' -'~~~i~;'-::~'i.['_:~' 1 ,.. ,l. "" I. ,,'-<,,'-'-' ,j, I .'- i. .-- ". -'1 ,-~ ~',I ~ I .>err' ... .', -,' '" -1' - - -. - .. -, , 1- - ,-,~O,_.. ' - - - -,' 1- 'I ..' - I - . - , ' .., , - .. .' , , '.! r' I I 'i.""" ,"'-,:-"",,_1,.'" :':.':"1 ,.-, ' '\'1..e. 1 I,' '. .-1 OIl....' ,_.-,,\ " " 1'1" \' -.."."."'.il I, '. .. , I ' I, '. . 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II, I :~:. - 4 Miles -- I 2 I ~. ," - - ---. r - , ' /,1, ,. "j ," , . .- ~ "-...'..- - - -- L - - -" Lr?ase Boundanes ~""""'\1 r::.. -:::.. -:::.. -::¡ NaTiOnal PetrOleum Reser"e - Alaska I" / / '" 1 L. ///.. I:~:~:::;:::~~~I ---------- ...... ------- . -9- PropüS;;d Water Source Lakr?s Pre, IOlJ!;I~ Permitted Lakes Fish Be.3nng U;kr? Proposed IC':> Road Pre",'OLJsl~ PHm,ltr?d Ice Roads Prüpljsed Rolhgon Routoõ' PrellloLJsl~' Permitted Exploration Wells Proposed E),ploratlon Well Horizontal Datum NAD27, coordinale syslem UTM Zone 5, Vertical Datum NGVD29, Hydrology derived from 1 :63360 USGS DLG Data. An..d..rI(p~ ., 11. '., - -t,- .:.'< AL TAMURA PROSPECTS, LEASES, PROPOSED WATER SOURCES, AND ACCESS FIGURE. SCALE: 1 inch equals 2 miles 2 Lynx apc127 mxd, December 10,2001, Rev 7 ~ g c ~ 6000 J: .. C. CD C 0 - I I I I I - Set 16" @ I 1000 2000 3000 ...r 4000 5000 7000 8000 9000 10000 11 000 12000 0 5 Altamura #2 Altamura # 2 Days vs Depth ~t Pt)troleun) Cûf~a!IO" ------r ----~ Iset 9-5/8" @ 3,000' 'l'-f.o.¡ I. ~, " I Set 7" @ ~1-1lí' 1 Icore @+/- 9250 , 0'."" ,0 .°' I Set 4-1/2" @ 1JMr19' I Run 3 1/2 Completion 1 10 15 20 25 30 35 Days from Spud ..... Altamura #2 i Alhlnlura Drilling Program NPRÞ. Alaska ~()O 1-2()O~ Drilling Scason ) ~! Petrolður"" Corpo''!ul~ Altamura #2 Drilling Procedure .I I. MIRU Nabors rig I~E. , 1. Install Slip-Lock starting flange on the pre-set conductor. /' 3. NU diverter system and test per AOGCC and BLM requirements. 4. MU 12 1/4"" BHA and MWD/L WD tools. .- 5. Drill 12 1/4" surtàce hole per directional plan to +/-3,000 MD'. Wiper trip as necessary. Circulate and condition hole for 9-5/S" casing. TOOH, LD BHA. 6. RU casing tools and run 9-5/S'" casing and accessories per casing program. Thread lock float equipment and 1st jt above float equipment. Verify circulation through float equipment. 7. MU casing mandrel. landing joint. and stack centralizer. S. Circulate and condition hole for cementing. 9. RU cementing equipment. Test lines to 3k psi. 10. Cement 9-5/S" casing per program. Slowly reciprocate the casing with I 0' to 15' strokes if possible. Land casing. Check floats. RD cementing equipment. Drain conductor. 11. woe. 12. Back out 9-5/S"landingjoint, ND diverter and (emove Slip-Lock starting flange. Prep and install 9- 5/S" x II"" 5M multi-bowl wellhead. / 13. NU BOP's. Test per AOGCC and BLM requirements. Pick up and stand back enough 4'" DP to drill to T' casing point. ;' 14. Install wear bushing. MU S ~'i '" BHA and test. TIH to TOC. Test casing to 3,000 psi. 15. Drill out float equipment and 20' of new formation. Circulate and condition mud for FIT. 16. Perform FIT to 13.S ppg EMW. ;-' 17. Drill to +/- S.350' TVD. Perform wiper trips as needed. Reference mud program for mud weight and properties. T' casing point is expected to be between S,350' - S.550 TVD. Drill ahead slowly, circulating up samples as needed. Note: Casing point of this hole section is critical. Contirm shoe depth with to\\11. IS. Circulate and condition mud for casing. TOOH. LD BHA. 19. RU casing tools and run T' casing and accessories per casing program. Pull wear bushing and install T' rams in the top gate BOP. Test accordingly. Thread lock float equipment and 1st jt above float equipment. Verify circulation through float equipment. :W. MU casing mandrel, landing joint and stack centralizer. 21. Circulate and condition hole for cementing. 22. RU cementing equjPment. Test lines to 5k psi. 23. Cement T' casing per program. Slowly reciprocate the casing 10' to IS'strokes if possible. Land casing. Test tloats. Drain stack. RD cement equipment and back out landing joint. 24. Run pack off assembly. Change out the T' rams for variables and test accordingly. Install wear bushing. 25. MU 6-I/S" rotary BHA.)Jse mill tooth rock bit for bette~ples. TIH to TOC. 26. Test casing to 4,000 psi. Perform LOT on 7" x 9-S/8'~ annulus. Freeze protect T~x 9-S/S" annulus by bullheading 2,700 gals of diesel into annulus. 27. Drill out float equipment and 20' of new formation. Circulate and condition mud for FIT. 2S. Perform FIT to 13.5 ppg EMW. .' 29. Drill ahead looking for core point. Reduce mud weight per program. Circulate up samples as necessary. Contìrm core point \\;th to\\11. 30. Circulate and condition as necessary and TOOH for coring tools. 31. MU coring BHA. TIH and cut core per procedure. TOOH and LD core barrel. Confirm recovery and wlo orders tTom town. 32. MU 6-1 IS'" BHA clw PDC bit and test. TIH and ream/log over core interval. v 33. Drill to +/- I 0.2S2' TVD. Confirm TD and if electric line logs are necessary. Short trip. circulate and condition. TOOH for liner. - I - ~ Altamun1 Drilling PI'ogrnm NPRA AJuska lOll 1-1002 Dri Iling Scason ~a POlroleur1r1 Cc..tpOt.:'lIIOl1 / 3..f. RU casing tools and run 4 I 'z" liner and accessories per program. AIIO\v for 150-200 ft of liner lap. Notet: RA pip to be run below liner hanger assy. Record exact distance tTom pip to landing area at top of PBR. Note2: Run short joint approximately 100 ft below pay zone, 35. MU liner hanger assembly. 36. TIH with liner and DP to liner setting depth. Circulate and condition for cement. 37. RU cementing equipment. Plan to reciprocate liner during job. Cement liner per recommendation. Set liner hanger per procedure. Note: Contact to\\l1 ASAP if returns are lost during job and/or cement is not circulated out after cement job. Do not set ZXP packer until approved by town. Sting out of liner hanger. stand back 2 stands and reverse out cement. TOOH. 38. MU liner clean-out BHA. TIH. 39. TEST liner top to 4,000 psi. / 40. Clean out 4 1/2" liner to PBTD. Do not drill out float equip. Circ clean. 41. Pump Hi-Vis sweep and displace well with inhibited, kill w1, 6% KCL packer fluid. Test casing to 4,000 psig. TOOH laying own DP. Circulate briefly while pulling through liner hanger assembly and PBR. . 42. MOVE TO COMPLETION PROCEDURE - 2 - ) Altamura Drilling Program NPRA !\Jaska 100 l-l00~ Drilling Sca~on ) ~~ Pûrroloi:Juln Corpor<1110n Altamura #2 Completion Procedure I. RU ElU. RlH w/ Gamma ray and CCl and log across short joint. pay zone and RA pip below liner hanger assy. Contirm exact distance tTom pay zone to RA pip. POOH and RD ElU. 2. MU perforating gun and spacer assembly per procedure and TIH. 3. MU gun drop and seal assemblies and TIH. Prep to run the electric cable for the Promore gauges. 4. MU Promore gauges and remainder of 3 ~/2" tubing string per procedure and TIH. Prep to run control line for the SCSSV and injection sub. 5. Circulate very slowly while the seal assembly is approaching the PBR. A circulating pressure increase indicates that the seals are entering the PBR. Note: the perforating guns have a back up firing head that is set @ approximately 4,000 psi. Be extremely careful not to trap any pressure in the tubing. 6. PU and space out to land 5M - 10M Ibs down weight on PBR. MU tubing hanger and landingjoint. MU TlW valve and pump-in sub. Lower tubing assembly until tip of seal assembly is +/-5 feet above PBR. 7. RU pump truck and nitrogen equipment. Pump 3,300 gals diesel down tubing. Immediately start displacing the tubing with nitrogen until 58 bbls of KCl water is recovered trom returns. 8. Sting seals into PB~ lan<i¡tubing and lock dO\\l1 mandrel. Bleed nitrogen off tubing. 9. Test annulus to 4.000 psi. Remove landing joint. 10. Install BPY in tubing hanger. II. ND BOP's and NU THA and tree. Test wellhead equip per procedure. 12. RDMO Nabors 14E. - I - Potr'l)lðUfn Corporation B/ Permafrost @ 620' ! 20" Hole 12-1/4" Hole Altamura No.2 NPRA - North Slope, Alaska Planned Well bore Sketch 8-1/2" Hole 6-1/8" Hole Rig: s: Nabors 14-E I T: R: GR: I KB: 16", 65ppf, H-40 @ 80' Cmt to surf L. ~ z ~ ¡,' l- TAM port collar @ 900' (contingency) 'V ,-- SCSSV c/w 2.81 X-nip @ 1800' Injection sub @ 2000' ¿ ~ 9-5/8", 40ppf, L-80, BTC @ 3,000' Cmt to surf J - -- Side Pocket Mandrel @ +/- 3200' --- - 31/2,9.3 ppf, EUE 8rd-mod, L-80 tubing - (Q!H'11 \J.I('; t'\" j--- Side Pocket Mandrel @ +/- 8,659' ~7 Pressure Gauge Mandrels@ 8,783',8,721' - Baker BX 2.750 XN-nip @ 8,845 0 -- Promore Surface Read Out Pressure Guages @ 8,876' ~ ~ - Baker 7x4 1/2 Lnr Hngr c/w ZXP Packer and 10' PBR @ 8,907' ... ~ 2 7/8" Seal Extension, flow sub, and GDAlWLEG .i. 0 r ~ 7" , 26ppf, L-80, BTC-mod @ +/- 9,059' , - - 60' perfs @ +/- 9133-9183' (TCP- dropped) Dropped TCP perf gun '- ~ ~ 4-1/2", 12.60ppf, L-80, IBT -mod, Liner @ 10,961' . ~DIV[JITER ~£AD ~S:;,.16 :;l,P'LOI: BN III fS SlAI.S X 21-1/~ ,~ ~~f~.,ð'~l~, 2' LP oUrlE T 80.41' 120H.9 mtn, ~3..W 11100.1 """I S.!l9' 1111.1 ""'" ?(,.44' .1'>11,6 ...,,1 S1.18' (1461.& ",",,,", ~~ ~:J ¡~~- =oji - 13.1'" .:!~8.0 ,TW",I n.1;' IS/I,6 ,T,") 'l.IJ' 12 Jr.~ ,T'II',I DIVERT£.R H~A(I t IS.." n~l.o ......, 0 C J I 8 . 50'}" ,Ii. :,S, '. ::T,;, ('(;M[C'~;¡ ---_/~ -~-~"--r 3 1,6-~0ü':, 101(,.:, 120 (V -;}If I;_u ']a- - -1- ~ ~- I~~:~å ~ ?".W 1011,S ......', -------- 3 '''6-':,QOO We'D 120 G-~ 111/ l,crl.JAi~ 2.B.}.' r7roj.1 rTl""U ~...--.> I' õ' 50:'J "!)'J I¡':' C V ! q.~ .~4 '1 ""T,' , 6 -S~"'}-; ~. JS' -I,IONITOR pc,' 10 LOC.C-Q(I ~CPE.:; ':(~"...J E:<I[ 10 l()(.r'~WI. ,':1>£":' ¡ I j.~I'. 43"¥ JVi11 "-U"j''''': Rrtf:, };.O 4.00' ItI)t,e. trWTIl , /~ f AN ADARKO .lli!!:L!. r\') C. ~~;~oOOIIIlI:n.:'~i'= ~ g-~~5;~ði~ C. íl~~lü~ 71ia13 -J ~.=:.~~~~.J~-::' t~.J\.¡C;i- E.CI~~ .L~'-n'E.AC ~.,. LJ..I ~:.~~~=¡::=: ,:',~'~ (~:I;,~7 ~~. :=I~ ~: ~.:.~-:I::=i;~ L'IIS'''''tõ ':¡"úGRlI.U ~-;: ~lo"'hJrJ.o;o!.i r.) U-SCIO( THROUGH BORE SYSTEM l' X q 5/8 X 7 X ¡ 1/2 --- ------------ ----- 1000 2000 3000 4000 5000 g "'::I ) ; 6000 . .r:. ë. () c 7000 8000 9000 10000 11 000 80 12000 0 - - . . . / . ~ 90 1C.O 11.0 ....... Planned Mud Wt Altamura # 2 . . 8-- 12.0 13.0 16.0 1'--,0 17.0 18.0 15.0 Mud Weight (ppg) ---- Est Frac Gradient ---.- Est Pore Pressure ~ 1000 2000 3000 - 4000 g c > '": 5000 .r:: ë. CD C 6000 7000 8000 9000 ---- 10000 8.0 Offset Well Data Mud Weight vs Depth 0- III : ':"",...,1 . ......................... ...,................"....... ~'"'''''' ....~....,. ,.'1 ¡ - ..... )IC .;: . ""--""""---.:1... ~~\l" - ,,-=, ! x "' ,,( X .n ~ ~OI(Ä . \ -. - ---- . - -- - - - - -. -. - - ..- - -- - - - --.--- .---- --- 9.0 100 11.0 Mud Weight (ppg) --.- Rendezvoos#2 ---Lookout #1 ---- Rendezvous-A- --..- Nanuk #3 Clover -A- -t- Nigliq #1 ~!' PðTtQIÖ"urn Corpor.rulo/'\ 12.0 13.0 14.0 ---...: '---- Moose's T oath -Spark #1 S:\Alaska\Drilling\Welllnfo AltamuraPlannedTvsD.xls Offset MW vs Depth Maximum Anticipated Surface Pressures The following presents data used tor calculation of maximum anticipated surface pressures (MASP) during drilling for the Altan1ura #2 well: Casing Pore Casing Sett ing Fracture Pressure Pore MASP Size Depth Gradient Gradient Pressure Drilling (in.) (ft TVD RKB) (lbs/gal) (lbs/gal) Ú2ill Ú2ill 16~' 80~ 11.0 8.3 35 892 9-5/8" 2~ 779~ 14.8 8.3 I, 1 99 1 ~834 T' 8~3 79' 17.6 8.8 3~834 3~578 4- 1/2" 1 0,282 ~ 17.6 8.8 4,705' N/A Procedure for Calculating Maximum Anticipated Surface Pressure (MASP) 1. Drilling Below Conductor Casing MASP while drilling below the 16'~ conductor shoe \vill be the lesser of the formation pore pressure (less a full gas column to the surface) at the next (9-5/8~") casing shoe. Based on offset well data, the highest tormation pressure expected in the 12-1/4" hole section is L 199 psi at the 9-5/8'~ casing setting depth of 2,779' TVD (or 0.431 psi/ft). Complete evacuation of the wellbore, except for a 0.11 psi/ft gas gradient, is assumed. MASP Calculation for Drilling 12-1/4" hole section MASP (pore pressure) (2~ 779 ft)(0.431 - 0.11) = 892 psi ~/ Thus, MASP in the 12-1/4" hole section is below the diverter's 2,000 psi rated working pressure. 2. Drilling Below Suñace Casing MASP while drilling below the 9-5/8"" casing shoe ,^,ill be the lesser of the formation pore pressure (less a full gas column to the surface) at the next (7") casing shoe or the formation fracture pressure at the last (9-5/8"") casing shoe, less a full gas column to the surface. Based on offset well data~ the highest formation pressure expected in the 8-1/2" hole section is 3,834 psi at the T' casing setting depth of 8,379' TVD (or 0.458 psi/ft) and the formation tTacture pressure at the 9-5/8"" shoe depth of2,779' TVD is a minimum of 14.8 ppg EMW (0.770 psi/ft). Complete evacuation of the wellhore, except for a 0.11 psi/ft gas gradient. is assumed. MASP Calculations for Drilling 8-1/2"" hole section , MASP (pore pressure) = (8~379 ft)(0.458 - 0.11) = 2~916 psi ./ MASP (fill breakdown) (2~ 779 ft)(0.770 - 0.11) = 1 ~834 psi Therefore~ MASP in the 8-1/2" hole section is 1.834 psi. It is planned to routinely test the BOPE to 4.000 psi. 3. Drilling Below Intermediate Casing MASP while drilling below the 1" casing shoe will be the lesser of the formation pore pressure (less a full gas column to the surface) at TO or the formation tÌ"acture pressure at the last (1") casing shoe, less a full gas column to the surface. Based on offset well data~ the highest formation pressure expected in the 6-1/8" hole section is 4,705 psi at the TO of 1 0~282' TVD (or 0.458 psi/ft) and the formation fracture pressure at the 7" shoe depth of 8,379' TVD is a minimum of 17.6 ppg EMW (0.915 psi/ft). Complete evacuation of the \vellbore. except for a 0.11 psi/ft gas gradient. is asslIDled. MASP Calculations for Drilling 6-1/8" hole section MASP (pore pressure) = (10,282 ft)(0.458 - 0.11) = 3,578 psi / MASP (fin breakdown) (8~379 ft)(0.915 - 0.11) = 6,745 psi / Therefore. MASP in the 6-1/8" hole section is 3.578 psi. It is planned to routinely test the BOPE to 4.000 psi. ./ Formation Intee;rity Test (FIT) and Leak-Off Test (LOT) Procedures Note that the terms used in the procedures and the spreadsheet of FIT/LOT results are defmed as follows: . Formation Integrity Test (FIT) - Formation is tested to a pre-determined equivalent mud weight. Leak-Off Test (LOT) - Pressure is exerted against the formation until fluid begins to discernibly pump away. Pressure at which this first occurs is the leak-off point. LOT Limit - 16.0 ppg EMW for all surtàce casing shoe tests; determined from previous experience with formation breakdown problems by attempting higher leak-offs. Open Hole LOTs (OH LOTs)- Leak-off tests performed with open hole fron1 the casing shoe to some point above the target reservoir. Generally done when leak-off is required but could not be achieved just below the casing shoe; or where weaker formations are suspected above the target reservoir but below the casing shoe. and assurance is required of being able to achieve estiInated mud weight. . . . Procedure for FIT: 1. Drill 20' of new hole below the casing shoe. 2. Circulate the hole to establish a uniform mud density throughout the system. PIU into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shoWTI, plot the fluid pumped (volume or strokes) vs. drillpipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in I-Ininute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surtàce pressure for each tormation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing tor an appropriate amount of kick tolerance in case well control measures are required. Formation integrity tests are conducted on all casing shoes with the exception of some surtàce casing situations. Where annular pumping will be done on a welL the fonnation below the J surface shoe is taken to leak-off. This ensures that future disposal fluids can pumped a~'ay without risk ofdamage to the surface shoe. If two attempts at establishing leak-off at the shoe are unsuccessful (using 16.0 ppg EMW LOT limit per defmition above), then an open-hole LOT is performed. ~"ere required. the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise. but at a slower rate. The system is shut in and pressure monitored as with an FIT. CasiU2 Properties and Desi2n Casing Performance Properties Inten1al Collapse Tensile Strength Size Weight Yield Resistance Joint Body TVD lVID Design Safèty Factor* (in.) (lb/ft) Grade Crum (QW úlli) (1.000 Ibs) (ft RKB) (ft RKB) T B C 16 65 .H-40 N/A 80 80 9-5/8 40 L-80 BTC 5.750 3.090 947 916 2.779 3.000 8.85 3.16 2.58 7 26 L-80 BTC 7,240 5.410 641 604 8,379 9,059 2.96 2.02 1.43 4-1/2 12.6 L-80 IBT -Mod 8,430 7.500 209 209 10,282 10.962 9.40 1.79 1.59 * Tensile design safety factors are calculated using pipe weight less buoyancy. Burst design satèty fàctors for 9-5/8" and T' casing are calculated using ASP calculations. Safèty fàctor for 4-1/2" liner is calculated using TD fonnation pressure with no formation backup pressure at TOL.. Collapse design safety factors are calculated assuming complete evacuation of the casing. Casing Setting Depth Rationale 4-1/2" 1 0,962' RKB. TvID Conductor casing to support unconsolidated surfàce deposits and provide initial hole stability. Surface casing to provide sufficient fracture gradient and well control until TD is reached. The BOP stack will be installed on this casing. Intermediate casing to provide hole stability and pressure integrity during drilling of the final portion of the well. Production liner to provide hole stability and pressure integrity during well testing operations. 16" 80' RKB, MD 9-5/8" 3,000' RKB, MD T' 9.059' RKB, MD BOP Control System The BOPE control system on Nabors Rig #14-E is an NL Koomey Model 40200-3S blowout preventer control unit \vith a 202-gallon volume tame Main energy is provided by a 40 HP electric n10tor driven triplex plunger pump rated at 20.2 gpm at 3,000 psi. The pump charges twenty (20) eleven-gallon bladder-type separator accumulators. A second energy charging system consists of two Model 31-00 103 air pumps rated at a combined volume of 11.0 gpm at 1,200 psi, or 7.2 gpm at 3,000 psi. The above two energy systen1S are backed up by six 220 cubic toot nitrogen bottles connected to the manifold system. All of the systems are controlled by a Model SU2KB7 series urnnifold with seven manual control stations at the unit. r-ì7nVO'D 'i1f': ~ J~['J'f¿,-r,~~ . ~ ~ D., : I~ \:f': ~ . ~ ~ - -' ftl " "D" " ,~ ~ I~ ~ l8I '\" ~ : =J:"f15"rlf, :LJl~ .i~ ~ ~'---.JL-....J L....-...JL-....J L- L-....J' -.. ~ B ~ J--&-+~ I - r---1r-f - \yl\ i\ I \ / \ / , f X /\/ \ /\ / .:.- L-" ~ t--a-it--a-iF==f 1111 ~ / ~ I ~( - 1\ Iv ~ . 16" KNIfE V'ALVE ----.-~I I 4/"tl-~~------¿~~_._--~ ! \ DD. '\ &. .&. \ 16" DI'IERTER LINE lID r '\ h , 'i""'~"--- ~ ~ 16" KNIFf V'AlVE 1111 "'. ' - f711'!1, iN IoN -....J w-=-: II I ~ ~~~~-~9 lJILJn~nllllllnlllnl _.~- -' [ ~---_._,.~~__!!!._L_~__- " / Jf'l "" 00 "" "" "" II~ t'" ~ ~ H ,ACADFILE\ 1..1ÐAIJADARKO-2001 \ 1 -IEOOO3 DWG. 11/28/01 04 1-1:36 PI'''' , 1 II 1 I ~ ~~Bf ~ ,. DNER7ER NIMJIJR HORiWlY 0Æ1t 2. fABR/+\I.\'t NORIWLY CLOSED I " ....,DXFg I ~~ I I~,~ -~~ & " I~ ~-- _~fi- /DI~ ,I i 'I ~I && --.I--I~ ~~ "''' ",.-= ~\ ¡ l....-",,,, "... " "'ff "'''' ANSI JOO FI.ANG£S f & 100'-0'- 19JUNOI D JA CONYmTED DRAWING TO NAD f"OR!.IAT ~:~~:~ ~:: ~- K~ A:~= ~:ltW 19NOV92 A PM '~~~II:H Sp'OOl ANO Hl:LCJCAIW PM DRAwING 004.01l!> M1E ".ro 0: W' DESCRIPIION =c: ~ =~= ~o~~~~~~D=~ ~ or flit ,,~~::.~~L-~ NabD" AIDOka Drilnog I". ~-~ 2526 C Sine! Suite 22DO ~7"..o28!~8=kD aa!lOJ-2BJII NABORS ALASKA RIG 14E ........ DIVERTfR LINE LAyour - 16" DIVERTfR S'fSTfM DRAIiII 8" I CHõCII£I) B't I .\PI'fIO/EI) B't I R!V a~~ - - D ~~/J2"."-O" DArf9 JUNE 2001 DrIØ. NO. 146000J ~lIIi of I PRG.tC'r 1111..[ I ~ i i I I I I I ! I '/a"r-.-----------.---.-----. --------- ~: ! ,'. 1/8' C I => SINGLE 4 1/2' x 7" VARIABLE RAM ~. . ]/a'r---;:~~¡'-;-K;A~;;-.----_._-------- (g: i I g) . CLAMP CONNECTOR ~ ,'. I/a' 3' SOOO# GATE VALVE l C ! => . SHEAR RA!.tS- <0 '/a'~--~~~~.~-~~~~~-~~ J: ! ~ ~ - CJ:... ~~~~O~;NH:E~T~:VE " 10 3/Bn2" KILL UNE""iI~~--+--~I~ 3" CHOKE LINE '/a'S------- ------._------.- - ---j-/ r i o~" 3" 50001 GATE VALVE . 2 9/16" x 2 1/16" ADAPTER FLAN~r-~ i ~ CLAMP CONNECTOR 3 1/16" x 2 9/16" ADAPTER FLANGE ~ ' ~ 2' 6 I/Bn ~ I ~ SINGLE 3 1/2" x 6" VARAIBLE RAM - 3Ia'þ.-------------- ------ - ------------ ~ I I ~ CLAMP COtINECTOR l' 4" I I I - I I-I--r- ~--r--~ v?5~------ ~~--¡ I r ¡ I I - . 4' 3 7/B" 13 5/8" 5000# HYDRIL ANNULAR BOP g) . CLAMP CONNECTOR ADAPTER SPOOL HUB x FLANGE ~~ ~ =~= ~~ ~~~~a ;~::r~D~:S ~ or Uaborø AmBIto Drillrr'9 111C. 4J00 B Slr..1 ~~~Sê~~~gka 99SG:! fllt~~ BOP STACI< ELEVATION H'\J.,CAOFII_t\14E 14E-AOGCC BOP.4E-AIJADARI\O.DWG, 11128,1)1041904 Pt,! P~MCT NABORS AL~SKA RIG 14E BOP STl..CK ilTL£ II/F/O' A JA ROD ~. CREAŒD rOR 1'10 14t ANAR~R~O I'I>O.¡£CI DATt ~1f ~>J. ~C' 0",,". BY ItH[C~tD BY I""P~u) j'r I PlY. J.A. R K. R K. A 5CALE ""it: [¡lit) .() 5 1 ~JTS IK./ 01 HeOOO9 1 of , DE!.CRII71ION (' J Client: Anadarko Well : Altimura #2 String: 9 5/8 District: Prudhoe Bay Country: USA Loadcase: 958 Surface (a) Sc~IBßlbepgep Fluid Description: 9-5/8" Surface Casing Mud DESIGN Fluid No: 1 Density : 10.00 Ib/gal Rhea. Model : BINGHAM Pv : 50.000 cP At temp. : 80 degF Ty : 20.00 Ibf/10OO2 Gel Strength : (lbf/10OO2) MUD Mud Type :WBM Job volume : 221.4 bbl Water Type : Fresh MUDPUSH XL DESIGN Fluid No: 3 Density : 10.50 Ib/gal Rhea. Model : POWER_LAW n : 0.490 At temp. : 80 degF k : 7.1 OE-3 Ibf.s^n/ft2 Gel Strength : (lbf/10OO2) Job volume : 50.0 bbl Fluid No: 4 Rhea. Model At temp. : BINGHAM : 65 degF DESIGN BLEND Name : ASL 3 Dry Density: 199.77 Ib/ft3 Sack Weight: 94 Ib BASE FLUID Type : Brackish wa. Additives Code S001 0046 0079 0065 0044 Cone. 1,500 %BWOC 0.600 %BWOC 1.500 %BWOC 0.500 %BWOC 9.000 %BWOW Thickening Time Compressive Strength Sie1Je 2 Slurry DESIGN ....... \""c;a:,.0 .,- : 10,70 Ib/gal : 28.096 cP : 21.291bf/10OO2 : (lbf/10OO2) Density Pv Ty Gel Strength SLURRY Mix Fluid: 20.721 gal/sk Yield : 4.45 ft3lsk v". Porosity: 62.3 % Job volume: 455.0 bbl Quantity: 574.68 sk v Density: 8.32 Ib/gal Base Fluid: 20.152 gallsk Function ACCELERATOR ANTI FOAM EXTENDER DISPERSANT ACCELERATOR API Schedule API Schedule 70 Bc 300 psi at at 06:00 hr:mn 48:00 hr:mn Anadarko AI13mura 2 cfw 09282001. LoadCasE- 958 Surfalt' (a). VerSion wcs cem42a_6 Page 8 Client. Anadarko Well : Altimura #2 String' 95/8 District. Prudhoe Bay Country: USA Loadcase: 958 Surtace (a) Fluid No: 5 Rhea. Model At temp. : BINGHAM : 65 degF DESIGN BLEND Name : G Dry Density: 199.771b1ft3 Sack Weight: 94 Ib BASE FLUID Type : Fresh water Code S001 0065 0046 Conc. 1,500 %BWOC 0.300 %BWOC 0.200 %BWOC Thickening Time Com pressive Strength ~ 1 Slurry DESIGN ~\ \ Density Pv Ty Gel Strength SLURRY Mix Fluid: 5.098 gal/sk , Yield : 1.17 ft3/sk / Porosity: 58.2 % Density: 8.32 Ib/gal Additives Function ACCELERATOR DISPERSANT ANTI FOAM API Schedule API Schedule 70 Bc 800 psi Sc~luDlbepgep ;' : 15.80 Ib/gal : 35.687 cP : 56.15 Ibf/1 0002 : (lbf/10OO2) Job volume: 121.0 bbl Quantity: 580.44 sk / Base Fluid: 5.098 gal/sk at at 05:10 hr:mn 12:00 hr:mn An.:.darko Altamura 2 cfw : 09 28 2001, LoadCase 958 Surtac,," (a) V"rSlon wes et'm42a_6 Page 9 Client: Anadarko Well : Altamura #2 String: 7 District: Prudhoe Bay Country: USA Loadcase: 7 Intermediate (a) Sc~lulßbepgep Fluid Description: 7" Intermediate Casing Mud DESIGN Fluid No: 1 Rheo. Model At temp. : BINGHAM : 80 degF Density Pv Ty Gel Strength /' : 11.00 Ib/gal : 35.000 cP : 20.00 Ibf/10OO2 : (lbf/10OO2) MUD Mud Type: WBM Water Type: Fresh Job volume: 314.5 bbl CW100 DESIGN Fluid No: 2 Rheo. Model At temp. Density : 8.32 Ib/gal .' : NEWTONIAN : 80 degF Viscosity: 5.000 cP Gel Strength: (lbf/10OO2) Job volume: 10.0 bbl MUDPUSH XL DESIGN Fluid No: 3 Rheo. Model At temp. : BINGHAM : 80 degF Density : 12,00 Ib/gal Pv : 30.000 cP Ty : 25.00 Ibf/10OO2 Gel Strength: (lbf/10OO2) Job volume: 30.0 bbl Page 7 Anadarko Allamura 2 ctw . 09.28,2001: LoadCase 7 Inlermedlale (a) . VerSion wcs cem42a_6 Client. Anadarko Well : Altamura #2 String . 7 District. Prudhoe Bay Country' USA Loadcase: 7 Intermediate (a) Fluid No: 5 Rheo. Model At temp. : BINGHAM : 130 degF DESIGN BLEND Name : G Dry Density: 199.77 Iblft3 Sack Weight: 94 Ib BASE FLUID Type : Fresh water Additives Code 0065 0046 0800 Cone. 0.300 %BWOC 0.200 %BWOC 0.190 %BWOC Thickening Time Com pressive Strength Tail Slurry DESIGN Sc~lullb.epgep Density : 15.80 Ib/gal ~ Pv : 20.469 cP Ty : 7.59Ibf/100ft2 Gel Strength: (lbf/10OO2) SLURRY Mix Fluid: 5.101 gal/sk Yield : 1.16 ft3/sk . Porosity: 58.8 % Density: 8.32 Ib/gal Function DISPERSANT ANTI FOAM RETARDER API Schedule API Schedule 70 Bc 2440 psi Job volume: 78.4 bbl Quantity: 379.43 sk v' Base Fluid: 5.101 gal/sk at at 04:30 hr:mn 20:30 hr:mn Anad:Hko Alt3mura 2.clw . 09.28.2001 LoadCa~t: 7 IntNmedlale (a'¡. V(:r~lon wc~ ce-m42,,_ó Page 8 Client: Anadarko Well : Altamura #2 String: 4.5 District: Prudhoe Bay Country: USA loadcase: 4.5 Liner (a) Sc~lußlbepger Fluid Description: 4.1/2" Production Liner Mud DESIGN fluid No: 1 Rhea. Model At temp. : BINGHAM : 80 degF Density : 11.00 Ib/gal Pv : 35.000 cP Tv : 20.00 Ibf/10Oft2 Gel Strength: (lbf/10OO2) MUD Mud Type: WBM Water Type: Fresh Job volume: 151.6 bbl CW100 DESIGN fluid No: 2 Rhea. Model At temp, Densily : 8.32 Ib/gal : NEWTONIAN : 80 degF Viscosity : 5.000 cP Gel Strength: (lbf/10OO2) Job volume: 20.0 bbl MUDPUSH XL DESIGN fluid No: 3 Rhea. Model At temp. : BINGHAM : 80 degF Density: 12,00 Ib/gal Pv : 30.000 cP Ty : 25.00 Ibf/10Oft2 Gel Strength: (lbf/10OO2) Job volume: 25.0 bbl Page 7 Anadarko Allamura 2 cfw : 09,28.2001 LoadCa'õe 45 Lmer (a) , Ver'õ,on wcs.c~m42.;_6 Client: Anadarko Well . Altamura #2 String' 4.5 District. Prudhoe Bay Country. USA Loadcase: 4.5 Liner (a) Fluid No: 5 Rhea. Model At temp. : BINGHAM : 140 degF DESIGN BLEND Name : G Dry Density: 199.77 Iblft3 Sack Weight: 94 Ib BASE FLUID Type : Fresh water Code 0065 0046 0800 Cone. 0.600 %BWOC 0.200 %BWOC 0.120 %BWOC Thickening Time Compressive Strength Tail Slurry DESIGN Density Pv Tv Gel Strength SLURRY Mix Fluid: 5.093 gal/sk Yield : 1.16 ft3/sk ., Porosity: 58.6 % Density: 8.32 Ib/gal Additives Function DISPERSANT ANTI FOAM RETARDER API Schedule API Schedule 70 Bc 3100 psi Sc~IDlßberger : 15.80 Ib/gal ,," : 61.905 cP : 46.75 Ibf/10OO2 : (lbf/10OO2) Job volume: 47.2 bbl Quantity: 228.09 sk ./ Base Fluid: 5.093 gallsk at at 04:00 hr:mn 20:00 hr:mn Anadarkü Allamurd 2 cfw : 0928.2001' LoadCa~e 45 L,ne-r (3) : Ve-r~lon vvc~ cem42a_6 Page 8 ã) ~ 600- II) 0'I,r CO E~ 1:: II ~D ~ () 00'<'- ~\I~ 'l;~'\~"O 0\00 0\1':> OiJ\\ ~ O'2.~\~J'ì' \000. , \1'3~ ~' \" . '\' 00 . '1\ 'ò0 (}O I '(iI J . 'õ) A.O 5'3\\ '= 0\( ~. S\'ð(o. aeq\\"' Ó 0\( v ~\~ 1111111/",." :: ! /lrge,lfu'¡;." ~("i' .'t.¡ ::'Um II 0, ,',::O.IIJ \, ::-15 -.I', - I: /..~......, I , / ) I CIJ ~ If) , "'~/ Oil' @ 4.000'/100ft . 5788.91ft MO, 5149.18ft TVO End Oir. Start Sail @ 0.000" : 6583.92ttMO,5904.00itTVO 0- I 0 Scale. 11nCh -:: 6001t I 600 I 1200 Eastings (Well) I 1800 I 2400 Referenc.e I:> True North 0 - i -Begin Oil' @ 4.000'"/10Oft : 1000.00f1 MO, 1000.0Oft TVO 1600 - ;\. -End 0". S'a" Sa" @ 31 ~O1' : 1795.02ftMD.1754.83ftTVD Anadarl(p! Petroleum Corporation 951S" 30C'O~OfI MO 277S~9ft TVO 't". j200 - Anadarko Alaska Altamura Altamura 2 WP04 ro .g Q) > , , \ spar'r'y-sul1 DRILLING SERVIc:es A Halliburton Company ã) :s ü 2 J5 4800- c ã. Q) ,,:) Begin Oil' @ 4.000"/100il . 578B.91ft MO, 5149 18i1 TVO End OIl', Start Sail @ 0.000' : 6583.92ftMO,5904.0OfITVO 6400 - ~. ~ k.'1 .=~:~-=--~- cur~n~_~~;~~~n~==--= ~-=--=-~~=~I ! 1-1.:.11. '".C.nI¡] r;,:..: f'í1.,,1I1;~ ' R';I ('lUt'"1I (""~',~1h-.lff. '. ~~,' ;:'rru,-rUlEo r,t:-' Gb':'J'"ilr,t...:.-.. L:,~..:r'].I1.~" h""EtEIo1.~t",,1 , '. ~ .. I::.J ('¡(II" "It'C'1f.o r.'If,,:¡r'". 5",,3 L",...I 1!=',J (lIlr, ..",.t;J ~1"i.JI~tlJ'~ i1'J£r;"r6':Y~__---~".~ :~~~;' ..:: 9600- ù S ~ 1/~ 'ù9~.1 9ft 1.10 1ü::'f!2 Oft i'!D H 1- --"._--"-- Proposal Dat;t~ Ãitam~-2 wpO¡- ---==~~~=I I V¿.ru,:al Orl~,n Str\.Clue ¡ ~,~ra~~"eta':';>~;~~.I" ~Jall I r J(,r¡1 R..rer..n.:.. Tr,..e ~ürlh ; I Dc>qIo3'JSt3venl) ------- -"'-D;:p;e~,-~;;~1;:;-~"IIUS; --- --- ------------: "'Eo",ca' Seeton kJrn..lt, 75639 I I ',drill; ~I Si'C1icn D.. ;,CT'ptün W,;I I ¡ \,,;r~.:.~S.::tQr, IJ~~,---~O~~L~E__- I Mea~ured Incl Az,m Vertical Northings Ea~lIng~ Vertical Dogleg I I_DPP::~,,--,~,-;~- ":A;': -"-~~~-_. -~~ III'"'[--~~~~' -~at~-' I ",CI) 1"1"1 11111".1 "I'''' :,,',- 'J';IJ'-IIII II f(1 ~J r.l".I [ I111I 11111111 : I_II".) I)) I) 1"."..1 ~,.:... :,h ~ : 11111.1 11I1 (111".1 ',' 1'1 1".11" ~' 1"1 1:.:"1 ,-1 \"':'';II~ ~I"""" -~"""J I-"J!\~ ~~r""I~... ~1.1..1..:)[ ~I';I"I~ III,JII"'I i ~~"-I\\jl :"~I, ..';f......~'1 ~11ÙIi\ ';.,-I~N ~:.NI"[ ~JI'''''- IItAlI1 I I,~~;~f~ :::::,~: !:.~ i:~ "~~;~:'::-': ;,~:: ::-:~ W=~.= [ i~~~::~ :J::::: ~¡ I '1I''''''',Ioj~ '-'I"U'-I ;,,,,~,:,- 'I'(.~:I"'I t.:I'I'I'I~J :J'-,;-[ :'~d"'''¡ 1"1'-1"'1 BODO - 7' '1(/5f1 r-m 1.10 ,o.:<ì9 (111 ï\'D J l --0-- ....- I'r,..""'. I ,f'. r '.'.",'.",'I,' \j .." ",, 'I I' ";,, ,,, \ .'.J; - I, - '!:: :5 to Q.; rtI ~ I 0 1600 Scale. Ilneh = 1600ft SE-CIIOn AZlmulh 75 8j9' C'I~IÛu~ ~ I») (09 (11')6 Vertical Section (Well) \ TrLJe ~Jorth ----- -.-- --- .-- ----------- Sperry-Sun Drilling Services . Proposal Report for Altamura 2 wp04 Revised; 6 December, 2001 Anadarko Alaska Sperry-Sun Drilling Altamura Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (C /1 OOft) 000 0.000 0.000 -154.00 0.00 0.00 N 0.00 E 5895754.70 N 283695.60 E 0.00 654.00 0.000 0000 500.00 654 00 0.00 N 0.00 E 5895754.70 N 283695.60 E 0.000 0.00 Base Permafrost 950.00 0.000 0.000 796.00 950 00 0.00 N 0,00 E 5895754.70 N 283695.60 E 0.000 0.00 1000 00 0,000 0.000 846 00 1000.00 0.00 N 0.00 E 5895754.70 N 283695.60 E 0.000 0.00 Begin Dir @ 4.000~/10Oft: 1000 OOft MD, 1000.00tt TVD 1100.00 4.000 75.839 945,92 1099.92 0.85 I\ 3.38 E 5895755.46 N 283699.01 E 4.000 3.49 1 200 00 8000 75.839 1045.35 1199.35 3.41 N 13 52 E 5895757.72 N 283709.21 E 4.000 13.94 1300 00 12.000 75.839 1143.81 1297.81 7.66 N 30.35 E 5895761.49 N 283726.16 E 4.000 31.30 1400.00 16.000 75.839 1240.82 1394.82 13.57 N 53.80 E 5895766.74 N 283749.77 E 4.000 55.49 1 500 00 20 000 75.839 1335.91 1489.91 21.13N 83.76 E 5895773.44 N 283779.93 E 4.000 86.38 1 600 00 24 000 75.839 1428.61 1582.61 30.30 N 120.07 E 5895781.56 N 283816.49 E 4.000 123.84 1 700 00 28.000 75.839 1518.47 1672.47 41.02 N 162.57 E 5895791.07 N 283859.27 E 4.000 167.67 1795 02 31 801 75 839 1600.82 1754 82 52 60 N 208.49 E 5895801.34 N 283905.50 E 4.000 215.02 End Dir, Start Sail @ 31.8010 : 1795 02ftMD, 1754.83ttTVD 1800 00 31.801 75.839 1605.06 1759.06 53 25 N 211.03 E 5895801.91 N 283908.07 E 0.000 217.65 1900 00 31 .801 75.839 1690.05 1844.05 66,14 N 262.13 E 5895813.34 N 283959.51 E 0.000 270.34 2000 00 31 801 75 839 1775.04 1929.04 79.03 N 313.22 E 5895824.77 N 284010.95 E 0.000 323.04 2 100 00 31.80 1 75,839 1860 02 2014.02 91 92 N 364.32 E 5895836.20 N 284062.39 E 0.000 375.74 2200 00 31 801 75.839 1945.01 2099.01 104.81 N 415.42 E 5895847.63 N 284113,83E 0.000 428.43 2300 00 31 .801 75.839 2030.00 2184.00 11771 N 466.51 E 5895859.06 N 284165.28 E 0000 481.13 2400 00 31 801 75 839 211499 2268.99 130 60 N 517.61 E 5895870.49 N 284216.72 E 0.000 533.83 2500 00 31 801 75.839 2199.98 2353 98 143.49 N 568.70 E 5895881.92 N 284268.16 E 0.000 586.52 2600 00 31 80 1 75.839 2284.97 2438.97 156.38 N 619,80 E 5895893.35 N 284319.60 E 0.000 639.22 2700 00 31 80 1 75.839 2369.96 2523.96 169.27 N 670.89 E 5895904.78 N 284371.04 E 0.000 691.92 2800 00 31 .801 75.839 2454,94 2608.94 18217 N 721.99 E 5895916.21 N 284422.49 E 0.000 744.61 2900 00 3 1.801 75.839 2539.93 2693.93 195.06 N 773.08 E 5895927.64 N 2844 73.93 E 0.000 797.31 3000 00 31 .801 75.839 2624 92 2778 92 207.95 N 824.18 E 5895939.08 N 284525.37 E 0.000 850.01 9 5/8" Casing 3100 00 3 1 80 1 75,839 2709.91 2863.91 220.84 N 875.27 E 5895950.51 N 284576.81 E 0.000 902.70 3 176 59 31 801 75.839 2775 00 2929.00 230.71 N 914.40 E 5895959.26 N 284616.21 E 0.000 943.06 K3 Marker 3200 00 31 .801 75.839 2794.90 2948.90 233.73 N 926.37 E 5895961.94 N 284628.25 E 0.000 955.40 3300 00 31 801 75.839 2879.89 3033.89 246.63 N 977.46 E 5895973.37 N 284679.70 E 0.000 1008.10 3400 00 31 80 1 75.839 2964 88 3118.88 259.52 N 1028.56 E 5895984.80 N 284731 .14 E 0.000 1060.79 -- - --- -- -- ------- -------- --- ---------- ---~------------ -------------- ---------- 10 December, 2001- 11;17 Page 20f6 DriflQuest 2.00.09.006 Sperry-Sun Drilling Services . Proposal Report for Altamura 2 wp04 Revised: 6 December, 2001 Anadarko Alaska Sperry-Sun Drilling Attamura Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 3500 00 31,801 75839 3049.87 3203,87 272.41 N 1079.65 E 5895996.23 N 284782.58 E 0.000 1113.49 3600 00 31 80 1 75.839 3134.85 3288.85 285.30 N 1130.75 E 5896007.66 N 284834.02 E 0.000 1166.19 370000 3 1 80 1 75.839 3219.84 3373.84 298.19 N 1181.84 E 5896019.09 N 284885.46 E 0.000 1218.88 3800.00 31 801 75.839 3304.83 3458.83 311.08 N 1232.94 E 5896030.52 N 284936.90 E 0000 1271.58 3900.00 31.801 75839 3389.82 3543.82 323.98 N 1284.03 E 5896041 .95 N 284988.35 E 0.000 1324.28 4000.00 31.801 75,839 3474 81 3628.81 33G.87 N 1335.13 E 5896053.38 N 285039.79 E 0.000 1376.97 4100.00 31.801 75.839 3559 80 3713.80 349.76 N 1386.23 E 5896064.81 N 285091.23 E 0.000 1429.67 420000 31 801 75.839 3644,79 3798.79 362.65 N 1437.32 E 5896076.24 N 285142.67 E 0.000 1482.37 4300 00 31 .801 75.839 3729.77 3883.77 375.54 N 1488.42 E 5896087.67 N 285194.11 E 0.000 1535.06 4400.00 31 801 75839 3814.76 3968 76 388.44 I'J 1539.51 E 5896099.10 N 285245.56 E 0,000 1587.76 4476.76 31 801 75.839 3880.00 4034.00 398.33 N 1578.73 E 5896107.88 N 285285 04 E 0.000 1628.21 Base Brookian Sands 450000 31 801 75 839 3899.75 4053.75 401 33 N 1590.61 E 5896110.53 N 285297 00 E 0.000 1640 46 4600 00 31 801 75.839 3984 74 4138.74 414.22 N 1641 .70 E 5896121.96 N 285348.44 E 0.000 1693.15 4700.00 31.801 75.839 4069,73 4223.73 427.11 N 1692.80 E 5896133.39 N 285399.88 E 0.000 1745.85 4800.00 31 .801 75.839 4154.72 4308.72 440.00 N 1743.89 E 5896144.82 N 285451 .32 E 0.000 1798.54 4900 00 31 801 75.839 4239.71 4393.71 452 90 N 1794.99 E 5896156.25 N 285502.77 E 0.000 1851.24 5000 00 3 1 80 1 75.839 4324.69 4478.69 465.79 N 1846.08 E 5896167.68 N 285554.21 E 0.000 1903.94 5100 00 31 801 75 839 4409 68 4563.68 478.68 N 1897.18 E 5896179.11 N 285605.65 E 0.000 1956.63 5200.00 31 801 75839 4494,67 4648.67 491 57 N 1948.27 E 5896190.5-1 N 285657.09 E 0.000 2009.33 530000 31 .801 75,839 4579 66 4733 66 504 46 N 1999.37 E 5896201.98 N 285708.53 E 0.000 2062,03 5400.00 31 80 1 75 839 4664.65 4818.65 517.36 N 2050.46 E 5896213.41 N 285759.98 E 0.000 2114.72 5500 00 31.801 75.839 474964 4903.64 530.25 N 2101.56 E 5896224.84 N 285811.42 E 0.000 2167.42 5600 00 31 801 75.839 4834.63 4988.63 543.14 N 2152,65 E 5896236.27 N 285862.86 E 0,000 2220.12 570000 31 .80 1 75.839 4919.62 5073.62 556 03 N 2203.75 E 5896247.70 N 285914.30 E 0.000 2272.81 578891 31 801 75.839 4995 18 5149.18 567.49 N 2249.18E 5896257.86 N 285960.04 E 0.000 2319.67 Begin Oir @ 4.000'/10Oft . 5788.91ft MO, 5149.18ft TVO 5800 00 31 357 75.839 5004,63 5158.63 568.91 N 2254.81 E 5896259.12 N 285965,71 E 4.000 2325.47 5900 00 27357 75.839 5091.77 5245.77 580.91 N 2302.34 E 5896269.75 N 286013.56 E 4.000 2374.49 6000 00 23 357 75.839 5182.11 5336.11 591.38 N 2343.85 E 5896279.04 N 286055.35 E 4.000 2417.31 6100 00 19.357 75.839 5275 23 5429.23 600 29 N 2379.15 E 5896286.94 N 286090.90 E 4.000 2453.72 6200 00 15 357 75.839 5370.66 5524.66 607,58 N 2408.08 E 5896293.41 N 286120.01 E 4.000 2483.54 --- - --. -"- ---- -- - -- - -------- --- ---- ------------------- -- 10 December, 2001 - 11:17 Page 30f6 DrHlQuest 2.00,09,006 Sperry-Sun Drilling Services . Proposal Report for Altamura 2 wp04 Revised: 6 December, 2001 Anadarko Alaska Sperry-Sun Drilling Altamura Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (~/100ft) 6300,00 11.357 75.839 5467.93 5621.93 613.24N 2430.47 E 5896298.42 N 286142.56 E 4.000 2506.64 6400 00 7357 75,839 5566.58 5720.58 617.21 ~J 2446.23 E 5896301.94 N 286158.43 E 4.000 2522.89 650000 3357 75,839 5666.12 5820.12 619,50 N 2455.28 E 5896303.97 N 286167.54 E 4.000 2532.23 6583 92 0.000 0.000 5750.00 5904.00 620.10 N 2457.67 E 5896304.50 N 286169.94 E 4.000 2534.69 End Dir, Start Sail @ 0.000' : ....- '"t'rl T 7- 0,- 6583.92ttM 0, 5904.00ttTVD 7226 92 0000 0.000 6393.00 654 7 .00 620.10 N 2457.G7 E 5896304.50 N 286169.94 E 0.000 2534.69 TI F.C. Slumps 7971.92 0000 0.000 7138.00 7292,00 620.10 N 2457.67 E 5896304.50 N 286169.94 E 0.000 2534.69 BI F.C. Slumps 8092 92 0000 0.000 7259.00 7413.00 620.10 N 2457.67 E 5896304.50 N 286169.94 E 0.000 2534.69 TI HRZ 8167,92 0.000 0.000 7334.00 7488.00 620.10 N 2457.67 E 5896304.50 N 286169.94 E 0.000 2534.69 Base HRZ 8319,92 0.000 0000 7486.00 7640.00 620.10 N 2457.67 E 5896304.50 N 2861139.94 E 0.000 2534.69 K-1 8399.92 0000 0000 7566,00 7720.00 620.10 N 2457.67 E 5896304.50 N 286169.94 E 0.000 2534.69 LCU 9058.92 0.000 0.000 8225.00 8379.00 620.10 N 2457.67 E 5896304.50 N 286169.94 E 0.000 2534.69 7" Casing 910892 0.000 0.000 8275,00 8429.00 620.10 N 2457.G7 E 5896304.50 N 286169.94 E 0.000 2534.69 TI Upper Jurassic Altamura 2 Target, 300.00 Radius.. Current Target 9227.92 0000 0.000 8394.00 8548.00 620.10N 2457.67 E 5896304.50 N 286169.94 E 0.000 2534.69 UJU 931792 0000 0.000 8484.00 8638.00 620.10 N 2457.67 E 5896304.50 N 286169.94 E 0.000 2534.69 TI Nuiqsut "A" 1067992 0000 0.000 9846.00 10000.00 620.10N 2457.67 E 5896304.50 N 286169.94 E 0.000 2534.69 1071392 0000 0000 9880.00 10034.00 620.10 N 2457.67 E 5896304.50 N 286169.94 E 0.000 2534.69 TI J-3 10961.92 0000 0000 10128.00 10282.00 620.10 N 2457.67 E 5896304.50 N 2861G9,94 E 0.000 2534.69 4 1/2" Liner TO All data IS In Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Ver1lcal depths are relatIVe 10 Structure. Northings and Eastlngs are relative to Well. The Dogleg Seventy is In Degrees per 100 teet (US). Vertjcal SectIOn IS from Well and calculated along an Azimuth of 75.839' (True). Based upon Minimum Curvature type calculations. at a Measured Depth of 10961.92ft.. The Bottom Hole Displacement IS 2534.69ft , In the Direction of 75.839: (True) --- -.--- n__- -- - --- .. - - - . -- - ------ - ------------ --------------- --- 10 December, 2001- 11:17 Page 4 of6 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Altamura 2 wp04 Revised: 6 December, 2001 . Sperry-Sun Drilling Anadarko Alaska Altam ura Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings ~) ~ ~ Comment 1000 00 1795.02 5788.91 6583 92 1000 00 1754 83 5149.18 5904 00 0.00 N 52.60 N 567.49 N 620.10 N 0.00 E 208 49 E 2249 18 E 2457,67 E Begin Olr @ 4.0000/100ft: 1000.00ft MO, 1000.0Oft TVO End Oir, Stan Sail @ 31.801: : 1795,02ftMO,1754 83ftTVO Begin Oir @ 4.000"/100ft : 5788.91ft MD. 5149.18ft TVO End Oir, Stan Sail @ O.oooe : 6583.92ftMO,5904.0OftTVD Formation Tops Formati on Plane (Below Well Origin) Sub-Sea Dip Dip Dlr. (ft) Deg. Deg. Profile Penetration Point Measured Vertical Sub-Sea Depth Depth Depth (ft) (ft) (ft) Northings (ft) Eastings (ft) Formation Name 500 00 0.000 358.367 654.00 654.00 500.00 0,00 N 0.00 E Base Permafrost 2775.00 0.000 358.367 3176.59 2929.00 2775.00 230.71 N 914.40 E K3 Marker 3880.00 0.000 358367 4476.76 4034.00 3880.00 398.33 N 1578.73 E Base Brookian Sands 6393.00 0000 358.367 7226.92 6547.00 6393.00 620.10 N 2457.67 E TI F C. Slumps 7138 00 0000 358367 7971 .92 7292.00 7138.00 620.10 N 2457.67 E BI F.e. Slumps 7259.00 0000 358.367 8092,92 7413.00 7259.00 620.10 N 2457.67 E T f H RZ 7334 00 0000 358.367 8167.92 7488.00 7334.00 620.10 N 2457.67 E Base H RZ 7486.00 0.000 358.367 8319,92 7640.00 7486.00 620.10 N 2457.67 E K-l 756600 0.000 358.367 8399 92 7720.00 7566.00 620 10 N 2457.67 E LeU 827500 0.000 358.367 910892 8429 00 8275.00 620.10 N 2457.67 E TI Upper Jurassic 8394.00 0000 358 367 9227.92 8548 00 8394.00 620.10 N 2457.67 E UJU 8484 00 0.000 358 367 9317.92 8638.00 8484.00 620.10 N 2457 67 E TI Nuiqsut "A" 9880 00 0.000 358.367 1071392 10034.00 9880.00 620.10 N 2457.67 E TI J-3 1012800 0.000 358.367 10961.92 10282 00 10128.00 620.10N 2457,67 E TO -- - -- .----- ------ .- ----- - ---------------- --------- ------- ------ 10 December, 2001 - 11:17 P~e5~6 Dril/Quest 2.00,09.006 Sperry-Sun Drilling Casing details Fro m Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> <Surface> <Surface> <Surface> <Surface> Targets associated with this wellpath Target Name Altamura 2 Target - - -- - - - - - --- -- - -------- 10 December, 2001-11:17 To Measured Vertical Depth Depth (ft) (ft) 3000 00 9058.92 10961.92 Sperry-Sun Drilling Services Proposal Report for Altamura 2 wp04 Revised: 6 December, 2001 Casing Detail 2778.92 -- 9 5/8" Casing 837900 -- 7" Casing 10282 00 --- 4 1/2" Liner Mean Sea Level/Global Coordinates. Geographical Coordinates' ----"---- -- - -------------------.--------- Page 60f6 Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 8429.00 8275.00 620.10 N 2457.67 E 5896304.50 N 286169.94 E 70' 01' 10.8609" N 151~ 43' 00.8717" W --_._~------ . Anadarko Alaska Altam ura Target Target Shape Type Circle Current Target DrilIQuest 2,00.09,006 Altamura D."illing P."og."anl NPRA Alasku 200 1-20(l~ Drilling SC¡Json ~a ~trQi.eum C.;)fpomtIOI1 Baroid Drilling Fluids Program (10/29/01) General Discussion: A 6% K.CllPol~ mer Mud \\ ill be used to drill this well 1T0m spud TO TD. This inhibitive mud will reduce dilution rat~s and th~ subsequent drilling \\aste \\hile pro\iding maximum wdlbore stabilil). This mud !\y~t~m has ~vo"'ed o\'~r the lasl to drilling season~ in the NPRA and has been recognized for success in both of thes~ areas. HOWe\èT. it is a vel) "fine" lin~ between running this mud system \\l1h minimum dilulion rates to r~duce drilling "asl~ while maintaining a qualil) mud S)stem for good hole cleaning support and effecti\e ,,~lIbore stabilil) and to enhance the 0\ era II drilling operation~. Pleas~ refèr to the Mud Program for specific det3ils concenling ùli~ mud s~slem. SU22ested I\lud Properlie') Suñaee Hole (12 ~.. Hole rlSpud to 9 5/S" Casing Point at 3000' TI\1 D): Mud Density (ppg) Viscosi~ YP rv 10 S. Gel Properties (S\.'"C/qt I Initial 10.0 80 - I 00 35 -"5 13 - 2 I 10- 15 Base PF 10.0 50 - 70 20 - 30 15 - 23 10- 15 Final 10-1O.~ I 50 - 70 15 - 25 15 - 23 10 - 15 API FL (cc"5130 minI <15 ó-IO 6-8 Comments' This intenal or the well will be drilled \\ilh a 10.0 ppg ¡';'ClPol~mer mud (rom spud to TD. Primary lOCus (or this intenal or the \\ell "ill indude basic hole deaning support for the large diameler drilling' 12 ~ ~.. hole) and close al1~nlion for the possibilil) orshallo\\ gas. (S~~ I\lud Program lor det3ils. I Inlermediate Hole (S ~.. lIole r/Base Surraee Casing to top .'Slump" at 5979' TMD): API FL Mud Propertiö Densil) (ppgl YP P\' IOS.Gd CI (cc's¡JO PH minI Inllial 9.5 10-15 6-1~ 1-5 27- 6-10 9-9.5 311\. Final 9.5 ./ 15-25 8-14 2-6 27- <6 9-95 321\. Comments: The mud lTom surfuce hole drilling operations will be conditioned and used 10 drill ah~ad in this inl~f\al of the well. The mud should be "\:Ieaned-up" prior 10 drilling out of the surtàc~ casing 10 oplimiz~ drilling condilions in the initial 8 ~ ~., hole. While drilling th~ R I::"" hole, the mud should be kept in good conditions so as to be r~cepti\'e the lIIud weight incr~ase \\hieh \\ ill be r~quired beginning at th~ lOp ofth~ "Slumps". (Se~ Mud Program for d~tails.) Intermediate Hole (S Yz"' Hole flTop '.Slump~" 10 7" Casing Poinl a18300. TI\ID): HTHP API FL Mud Prop~rties D~nsi~' (ppg) yp P" 10 S. Gel (cc'sl30 CI (cc's.'30 PH minI minI Top "Slumps "" 27- 9-95 to H RZ 9.5-12.0 15-15 15-25 5-10 <10 321\. <6 Top HRZ to 8 11-12 / 15-25 15-25 5-10 <10 27- <6 9-9.5 I:"" TD 32K Comments' The mud "eight "III be increased 1Ì"0m 9 5 ppg to 11-12 ppg while drilling 1Ì"0m the top ofth~ "SIumps" to the top of the HRZ (7520' TI\.1D). The mud \\cighl will th~n be maintained al that elevated le\el \\hile drilling 10 th~ final 8 ~:" TD al 8300' (See Mud Program tor details) Production Inlen-al (6 lIS" lIole fJ7" Casing Point 10 tbe Final Well TD at 10,000' TI\ID): HTHP API FL Mud Properties Denslt) (ppgl YP PV 10 S Gel (cc'sl30 CI (cc's/30 PH min) mm) FT" Casing 10 ' 17- Well TO 9.5-10'" 15-15 10-20 5-10 <'".10 32K <6 9-9.5 Comments. If no "speclal"" drill-in/coring fluid IS needed for this mt~n'al oflhe "ell. this ¡nten'al "ill be drilled with "condllion~" mud !Tom Ih~ pr~~ing inl~nal ofth~ well. The mud "eight "III be r~u~ as allowed to the 9.5-10.0 ppg range . - The reduced mud "~ighl for this inl~nal of the "ell is ~ on th~ assumptIOn thai the T casing dfecti\'ely isolates the troublesome shales abO\~ th~ targ~t sands behind casing. Altanlura Drilling Progn1m N PRA AI"ska .::!()()1-2002 Drilling Season ~t PQ\rO/o..Jm CO/'pOf'allQl1 Anadarko Petroleum Corporation Altamura No.2 Baroid Mud Program (10/29/01) General Discussion: This exploration well will be drilled &om an ice pad in the northeastern NPRA. The well will be drilled as a straight/low angle hole and spudded with a 12 ~'4" bit and drilled to a surface hole TO of @3000' TMD where 9 5/S" casing will be run and cemented. An S ~/:!"" intermediate hole will then be drilled to @S,300 TMO where T' casing will be run and cemented. A 6 lIS" hole will then be drilled/cored to TO @~ 10,000' TMO where a 4 1/2" liner ma} be run and cemented. Spud the well with an inhibited 6% KCI/PHPNClayseal mud weighted to 10.0 ppg per the current trend flNPRA drilling. The mud weight will then be held at that 10.0 ppg mud weight to the surface hole TO unless hole conditions dictate otherwise. Our primary focus for surface hole drilling operations will be adequate mud weight for well control and sufficient mud viscosity for efficient hole cleaning. This spud mud is formulated with several mechanisms to provide effective well bore stabilization and to reduce drilling waste, i.e.. ionic inhibition (KCI), polymer encapsulation (PHPA) and anionic bonding (Clayseal). For the S 1'2"" intermediate hole, the continued use of the inhibited KCI mud is suggested with again the primary focus being to provide effective well bore stabilization and the reduction of drilling waste. The top-set casing program as planned for this well, is designed to better isolate the target sands to avoid the lost circulation/differential sticking problems which have been associated with previous long-string casing designs. (Note: As tbe current 7" casing point is ab"ove tbe Jurassic age formations, tbere is tbe possibilif)' tbat tbe bigher mud weights of the 8 ~"hole (11.0+ ppg)" will be required for etTecfh'e shale stabilization in the 6 1/8" "tail" section of tbe well.) When drilling th is interval of the well a certain amount of new mud will be required for whole mud replacement to keep the low gravity solids content within acceptable limits. The mud weight for this interval of the well will range tTom 9.5 to 12.0 ppg. The use of the T' as an intermediate casing string also offers the possible use of annular injection as a disposal mechanism for drilling waste (mud and cunings). To enhance the potential. a balI-mill should be considered to slurry the cuttings for annular injection. For the 6 I/S"" tail section of the well, two drilling mud alternatives are possible. First. one could drill ahead with the inhibited mud fÌ"om the 8 1/~" interval of the well. OR as an alternative based upon the coring interests, a custom core fluid could be used. Obviously, the continuation of the KCI mud fÌ"om the S Y/' hole would offer a significant economic advantage as well as being a very good drilling fluid for this interval of the well. However, if specific coring objectives dictate the use of a "bland" core fluid with specific bridging capabilities to minimize invasion, then a custom core fluid should be considered and is the base case for this mud program. As for the mud weight for this interval of the well, if the T' casing effectively isolates the troublesome shales behind the casing, a reduced mud weight of 9.5-10.0 ppg may be used to drilllcore this interval. However, as indicated above, the mud weight for this interval of the well may continue to be in the 11.0+ppg range if the T' casing does not cover all the troublesome shales above the target sands. Special Considerations: * Maintain a sufficient quantity of Oriltreat (lecithin) to accomplish a 2 ppb treatment in the event gas hydrates are noted. * Lime and zinc carbonate should be on location for H2S contingency «(@ I pallet No Sulf and 2 pallets lime). * Maintain an adequate barite supply (and other necessary products) to increase the mud weight of the current circulating volume by 1.5 ppg at any time (@~ 1000 sxs barite on location at all times). * Due to the remote nature of this location, maintain an adequate supply of LCM and the other mud additives. which may be required to support this drilling program. * To reduce the potential for hole erosion/wellbore de-stabilization, hold the jet velocity below 200 fps and minimize ECD "drive" when drilling the S ~"'2" and 6 lIS"" intervals of the \\'ell. * Possible shale instability issues in the "Slumps"/Jurassic interval of the well (tight filtrate control/mud weight). Altan1ura D.-illing Program NPRA Alaska 1001-2002 Drilling Season ~a P'tJlrOIC-.ltn CorpOffl!IOJ' * Possible lost circulation problems in target sands with the elevated mud weights that are often required in this area for shale stabilization. Altanlura Drilling Prog..~un NPRA Alaska 200 l-l00~ Drilling Season Formation Tops/Casinf! Proe:ram: Spud Base PermatTost K3 Marker 9 5/8" Casing Point B/Brook ian Sands T/F.C. Slumps B/F.C. Slumps HRZ T' Casing Point Top Jurassic Nuiqsut ""A" .1-3 Well TO TVD/TMD 0' 620" 2895 . 3000' ..- 3920' 5979" 7169" 7520 8300'~ 8395" 8604 ' 975'2' 10,000" ~! PDt'oIO~lm CO'POf.1~,:'),., Hole Angle Comments 0' 10.0 ppg density Possible gas hydrates (ppg)* Mud Wt 10.0 10.0 10.0 10.0 9.5 9.5 10.9 11.3 11.3 9.5 9.5 9.5 9.5 Condition mud for casing Begin mud weight increase I 1.3+ ppg mud/Baranex treatment Condition mud f/casing Possible shale problems Condition/displace t7coring Condition mud f/liner . - Based upon an effective T' top-set which allows a reduced mud weight in the 6 1/8" hole. Surface Interval (12 ~" Hole to 3,000' TMD): The surface interval of this well will be drilled with a 6% KCI/PHPAlClayseal spud mud as formulated below: 10ppg Formulation Water KCI EZ Mud DP Clayseal Dextrid Barazan-D KOH Aldacide-G Baroi d .905 bbl 21.6 Ibs (30K ppm chlorides) .751bs .84 gal 31bs 1-21bs .1 Ibs .2lbs @74.5 Ibs (API tiltrate of 6-12 cc's) (as required for an initial 35 YP) (pH = 8.5-9) ( X-Cide 207 for rig maintenance) ( 10.0 ppg) Spud the well with maximum flow rates to ensure good cuttings transport. Target an initial YP in the 35 range then adjust as dictated by the actual hole cleaning requirements of the \vell (no gravel is anticipated - mostly clays and sand). Reduce viscosity as allowed (previous wells in the area have TD'ed the surface with a -25 YP). However, if hole cleaning appears to be inadequate, do not hesitate to quickly raise the viscosity as required. Polymer viscosity in the form of Barazan-D additions should be utilized to provide rheological support as needed. Utilize high viscosity sweeps to supplement the hole cleaning capabilities of the system. Spud the well with a 10.0 ppg density mud and hold that mud weight unless dictated by actual hole conditions. * Make sure all members of the drilling team are aware of the potential of encountering gas hydrates. * If gas hydrates are encountered, close monitoring of the system volumes and mud properties at the tlow-line by rig crew members and mud engineers is of critical importance. * Frequent checks of tluid density at the suction pit are critical to ensure that gas is not re-circulated down the well. * A mud weight of 10.0 ppg range is currently programmed for drilling the gas hydrate interval of the well. if encountered. * As lower viscosities are predicted due to the absence of gravel. gas break-out should be enhanced. AIt~'n.ura D."illing Prognlm N PRA Alaska lOll 1-2110;! Drilling Season ~n Pötrok'u.lI) COrpófo1tOI~ * If gas hydrates are noted, treat the system with 2.0 ppb of Oriltreat (Lecithin) and '/2~'O by volume Dril-N-Slide. (The mud engineers who are working the Milne Point operations have reported that the addition of the Drill-N-Slide acts as a mud conditioner that facilitates the breakout of the gas tTom the mud and helps keep the mud on the shaker screens.) * Maintain the mud as cool as possible. Hydrates that have been studied at the Cascade Prqject in the Milne area appear to be more stable at temperatures under 60c'F. Efforts to keep the fluid cool include mudding up \I\o'ith cold water and diluting the mud with cold water. The Baroid mud plant in Prudhoe Bay can be utilized to supply the initial volume of tluid for the spud. Make every effort to maintain the system as clean as possible through the normal dilution process and maximization of solids control equipment utilization. Other mud maintenance issues are as follo\\.s: I. If possible, use 6%) KCI water to maintain volume while drilling ahead. Maintain the mud chlorides at (@30.000 ppm with KCI 2. Use Oextrid and PAC's for API filtration control. Target 6-12 cc's initially, dropping the fluid loss to the 6 cc range prior to running casing at the surface hole TD. 3. Hold the pH in the 8.5-9 range with KOH. -I. By material balance, maintain the Clayseal concentration in the 2%) by volume range. 5. By material balance. maintain the EZ Mud DP in the. 75 ppb range. 6. Keep penetration rates below ISO'lhr for controlling the clay "chunks" as seen on some wells in the area. 7. Daily additions of X-Cide 207 are needed to control bacterial action. 8. Corrosion inhibitors should be run with this mud system (Baracor 700/ Barascav D). 9. Keep MBT < II ppb. Heavy amounts of clay may be present below the permatTost that could require additions of ConDet and Dril-N-Slide to reduce BHA balling and screen blinding. S\'Y'eeping the hole with high viscosity sweeps prior to the short trip at TD and again prior to coming out of the hole to run the surface casing is recommended. If possible, reduce the fluids rheology to <20 YP after the casing is on bottom prior to starting the cement job (dilution can be used as a lower weight will be desired to drill the initial 8 ~..~.. hole). Surface Hole l\lud Properties (12 Y.." Hole fISpud to 9 5/8" Casing Point at 3000' TMD): Mud Density Viscosity YP PY 10 S. Gel API FL Properties (ppg) (sec/qt) (cc's/30 Olin) Initial 10.0 80-100 35--15 13-21 10-15 <15 Base PF 10.0 50 -70 20 - 30 15 -13 10 - 15 6-10 Final 10-10.2 50 - 70 15 - 25 15 - 23 10 - IS 6-8 Intermediate Inten'al (8 ~'" Hole to (âl8300' TMD): (Drill-out to top ""Slump'") Prior to drilling out the surface casing water back/centrifuge the spud mud to 9.5 ppg. Ensure the chlorides are in the JOK ppm range. Maintaining the chlorides in this range will reduce dilution rates and ease the displacement to the 6% KCI. coring fluid ifused Initially. target a mud density of 9.5-9.6 ppg and a YP of the fluid in the 10 to 20 range and maintain until out of the sticky clays usually found below the casing seat. Then. adjust YP as required with Barazan-D pol)mer as needed for efticient hole cleaning. Ifscreen blinding ITom heavy clays is a problem. use ConDet and Dril-N-Slide treatments. Once through the stick) Altalnura Drilling P.'ogram NPRA Alaska ~O() I-lOll:;! Drillmg Scason ~a P.'1trolomur... Corpoamof' clays, adjust the YP up to the 15-25 range with Barazan-D to ensure good hole cleaning support. Regular sweeping of the hole with high viscosity sweeps is recommended every 4-6 hours while drilling to supplement the hole cleaning ability of the tluid. Flow rates of 400-450 GPM will provide annular velocities of 200-215'/min (5"" pipe I 8 1/2" hole) which should suffice in this near vertical hole. All personnel should be aware of the possibility of encountering unexpected pressure. Close monitoring of return mud weights, pit volumes, and the flow-line flow meter are of utmost importance at all times and will give warning of changing pressures. Maintain ample stocks of barite on location. Maintain the mud as clean as possible through the use of solids control equipment and dilution as required. Maintain the API filtrate <6 with PAC/Dextrid. Maintain the chlorides in the 27,000-31,000 range with KCI. Daily additions of X-Cide 207 should be made to control bacterial action. KOH should be used for pH control. Keep MBT < II ppb. Intermediate Hole (8 ~~' Hole f/Base Surface Casing to top "Slump" at 5979' TMD): ] Mud Density API FL YP PV 10 S. Gel CI (cc's/30 PH Properties (ppg) min) Initial 9.5 10-15 6-11 2-5 27- 6-10 9-9.5 31K Final 9.5 15-25 8-14 2-6 27- <6 9-9.5 32K (Top of "Slumps" to 7" Casing Point) As has been seen of several of the oft:'set \vells, the mud may need to be weighted-up (to 11.0+ ppg) prior to entering the "Slump/Disturbed" zone for effective wellbore stabilization. However, for this mud program, begin increasing the mud weight at the top of the "Slump" tram the 9.5-9.6 density of the upper 8 ~l2" hole to 11.3 ppg by the top of the HRZ at 7520'. Weight-up as required using barite down to the top of the HRZ.. The HTHP should also be lowered to < I 0 cc before entering the HRZ. Maintain this tight filtration to TO of the interval with N-Dril HT and Baranex. A 2 ppb treatment with Soltex will be made once the weight-up is complete and the HTHP has been reduced to the targeted value. Keep low gravity drilled solids to a minimum «6% by volume if possible). Maintain the MBT at < II ppb through dilution. Maintain the pH between 9.0-9.5 with KOH. Daily additions of X-Cide 207 should be made to control bacterial action. The chloride level should be kept in the 27-32K range through additions of KCI. The Clayseal and EZ Mud concentrations will be maintained at their respective programmed concentrations. A 20-25 YP should be maintained using N- Vis/Barazan D. Special efforts should be made to keep ECD's and surge/swab pressures to a minimum to reduce damage to the exposed shales. In past drilling in this area, the targeted 11.3+ ppg mud weight should give r@ 100 psi differential on the shales which doesn't allow for much swab. Prior to tripping, a 10-12 ppb Barotrol pill should be considered for spotting across the lower shales. The YP of this pill should be raised to the 35 range with N-Vis/Barazan-D. Short trip the well and condition the mud as needed prior to the TOOH to run and cement the T' casing. After running the casing, condition the mud as needed (YP <20 ifpossible) prior to beginning the cement job. Intermediate Hole (8 ~" Hole fITop "Slumps" to 7" Casing Point at 8300' TMD): Mud Density HTHP API FL YP PV 10 S. Gel (cc's/30 CI (cc's/30 PH Properties (ppg) min) min) Top 17- 9-9.5 "Slumps" 9.5-12.0 15-25 15-25 5-10 <10 32 <6 to HRZ K Altao1ura Drilling Program NPRA Alaska ~OO I-litO::! Drjlling Season ~! Pctfoleum CorpOf,aIIQl' Top HRZ to 8 I,~" TD 11-12 15-25 15-25 5-10 <10 27- 32 K <6 9-9.5 Production/Corin! Inten/al ( 6 118" Hole to 10.000' DID ): For this interval of the well. two options are possible. One option. would be to clean-up the current mud system and drill ahead to TO with re-conditioned mud from the 8 ~/2" hole reducing the mud weight as allowed (to 9.5 ppg if possible). This would certainly be the most cost effective option and the 6% KCI fluid design should be well suited tor the drilling of this interval of the well. For this option, the mud would be maintained in the same manner as from the preceding interval of the well targeting basically the same mud properties with the exception of the mud weight which can hopefully be reduced to the 9.5-10.0 ppg range. For this option. the basic mud properties would be as follows: Production Interval (6 1/8" Hole fJ7" Casing Point to the Final Well TD at 10,000' TMD): Mud Density HTHP API FL YP PV 10 S. Gel (cc's/30 CI (cc 's/30 PH Properties (ppg) Olin) Olin) fiT' Casing 27- 9.5-10* 15-25 10-20 5-10 <10 32 <6 9-9.5 to Well TO K The second option would be dictated by the need for a low-invasion "bland" core fluid if the well is to be cored. This special core fluid is outlined below and would be displaced into the well after as successful drill-out to include a satisfactory LOT/FIT. In this situation. kick-off the cement plug with the used KCI polymer system. The system should be maintained within the parameters set forth in the "Slump" to T' casing point section of this program. Once core point is reached. the hole should be swept with weighted/high vis sweeps to remove cuttings. Short trip, then displace to the core fluid before tripping out tor the core barrels. The core fluid tormulation is as follows: I Barrel (9.5-12.0 ppg) 6% KCI Core Fluid Soda Ash . I ppb Aldacide G .25 ppb ( X-Cide 207 for rig maintenance) Aq uagel 5 ppb Dextrid 8 ppb PAC L 1.75 ppb N- Vis .5-.75 ppb (as required for a 15-25 YP) KCI 19.5 ppb Baracarb 36.25 ppb ( 12 ppb of 5,12 ppb of 25. 12.25 ppb of 50) KOH as needed tor an 8.0 pH. Baroid as needed Target Properties Oensit) HTHP CWO deg. F) YP PH 9.5-12.0 ppg or as required. <7.5 cc's 15-25 IbslI 00 sq. ft. 7.5-8.5 Displace the used KCI polymer mud with the new core fluid as follows: I. Reduce the yield point of the KCI polymer mud to the 12-15 range on this final circulation and prepare the rig pit system to receive the coring fluid from the Baroid mud plant and to build the low viscosity and high viscosity spacers. Dump and clean the rig pits and flush all pumps. solids control equipment. and lines with fresh water and discard this water. It is very Altan1ura Drilling Progran1 NPRA Alaska 2001-1001 Drilling Season ~.! PtwolC\Jf~ 1 COfpOl'nnO(', important to get eve'1,thing extremely clean and dry before bringing the core fluid into the pits. Take the coring tluid into the pits and proceed with the displacement. 2. Pump a 30 barrel low viscosity sweep consisting of mud tram the previous section which has had the YP reduced to the 6 to 9 range through additions of Therma- Thin/SAPP and dilution. This spacer should be weighted to the equivalent mud weight as the base mud. 3. Pump a 30 barrel freshwater high viscosity spacer consisting of N- Vis mixed to a YP of 45 to 65 ( approximately 1.5 ppb N- Vis ') and weighted to the equivalent density of the base mud with Baroid. Manipulation of the pH to ensure proper polymer dispersion and hydration along with slow mixing of the polymer will prevent the formation of polymer fish eyes. 4. Once the high viscosity spacer is away. begin displacing with the coring fluid. Pump at rates of no less than 230 gpm. which should allow for efficient displacement. The drill string should be rotated while displacing to disturb any solids. Once displacement has started, the pumps should remain on until clean returns are seen. 5. Ensure the bit is on bottom as the new fluid exits the drill string. 6. Monitor the flow line for break through of the spacers and the new coring fluid. Discard the low viscosity and high viscosity spacers as they will be contaminated with ul1\\lanted drilled solids and cuttings which \\lould compromise the integrity of the coring system. 7. Pull inside the casing and clean the possum bellies. under the shal-..ers. and any pits which were taking the dirty returns. Mud maintenance while coring should focus on the following: I. Maintain mud weight at as needed \\lith Baracarb 50/barite (50/50 ratio). Target 34 ppb of Baracarb(s) and run tourly CaC03 checks to keep this amount in the mud. 2. If liquid additions are required, add 6~..o KCI brine or new 6~,'ô KCI Core Fluid. Do not add &esh water. Do not add an)' mud additives outside those in the base mud formulation without approval from the operator. Maintain the mud salinity at 27-31K ppm. 3. Control API filtrate and HTHP filtrate with DextridJPAC L additions. 4. Use N-Vis as required to adjust YP for good hole cleaning. 5. The pH should remain in the 7.)-8.5 range. 6. Continue with aggressive X-Cide 207 treatments to control bacterial activity. 7. Dry jobs should be mixed using Baracarb 50, After the coring work is complete. the core fluid can be treated as required to TD the well and in preparation tor the various end-of well activities. i.e., logging. running liners. etc. These treatments ma) include but are not limited to Caustic/KOH for pH control (8.0-9.0 target range), Therma- Thin and/or Desco CF to control mud rheology. high vis/high fiber sweeps to assist hole cleaning, barite for slugs. Baranex. etc. Condition the mud as allowed prior to the TOH to run the 4 II:!" liner. The yP should be reduced to the 10-15 range with the liner on bottom prior to beginning the cement job. FLOWUNE DERRICK 20 CONE DES/L TER ~., . ,II 1, -~. II ON<~I~~: .1.1 (J) DERRICK:i!:: . .-.., . SHAlf SHAKERS ¡:: ~ i -- MOD. 2000 a 1050 GPII fA. ~ . ,. 2 r\ A A Af\J\ A A A Af\ AA~, '"\Af\ Af\f\ f\ AA f\f'. f\ A!", f\ f\Af\ n AIIG£!l COIM't'OIi' I &. P h ~ I it ~ "'" 1 C£N1II1FIJGE 100 CPu 11 . l ~ ~" . - '\-=-:::-b IE: ~ :: GUN IIIJD CIL4N£R i I ~ CIÐIIOIL IlXER ~ I : ~;;¡ ~D is ---i:g. ~ ~ G I~fft~ TANK ~; :;;..,' I . ~ ...1 ~ .~ H-"'""",,, . ~ h '-r:-"~=- I ~ I - . . ":"'~ ~;~ "~ ~§ i' ~ -' r1 " . 1:'- . J:g::: g~ ~ r . !! ~i r¡~. t--~¡f.lll -¡:.M..I ¡T-fl-¡ ;~. .-.I..~. ..' ,.).. ~ b ''', ::: ~~ ~~ !I 9.~::. D~~'PI~~~D'~~~= UND~1DW ~ ~M-~= -. L -~¡r J>:fjr8: 1 . . cl I~~~i 1- : U . \ r'Þ: e I i~ 198.0 88L . 153 I B8L 1 BB!. 22B.B BBL 1I'OI.IJ/JF: Pff - I4h . IAlii - y, y ~ ~ f . - - 148.5 B8L ~ -:- . .. I ... - ~O ~ -= =- &. -~ &. - t' I : 1 ' I & &' - - - .... J~~r ~~ ... :~':h !",~.. . . LJ}, :'-'. ~ ~ '. ~ D£:SANDF:R JD CLE'ANŒ PUMPS ! PU/JP PWP ;A,/GHfR' ~'5'SÞ --¡ GALIGHER GAUGktll - /J/JD¡WAml S7DRÅGf PIT - 4 X 5 . ~" ,i'~.: "TO ~ ~LL & 4K8 2) 4XB ~ t ff;~~1 t Y c:) c:) c:)~ CASiNG ru. LINtS i - + . Y -. þ TO~?~~~ ~ .~ ~ 'II . r,. " . f::;/TAWis~ TO Þ VACUUM TR/JCKS :0 I '/III .. - . ~ Y 1œ:nbN TANI< i . 169.0 BBL cb ROti -FIL LINf Y t t t . . t ~ IlNf BLIND 80 &. - t '=: ~:s~ ~~~~~:SO:.J:£ Of' flþ 8..I-L.-.- .. 1-1-- lllabonl Alalka Drllnng klc. ~~ 2525 C Street SuRe 2200 --.--- ~1'..oür.:~ka 1111503-28311 PRW!X:I NABORS ALASKA RIG /4E MUD SfSTEM SCHEMATIC 7000 BBL AC7JV£ SYSTEM WITH DEWATERING UNIT bRIolIIN BY PM IQitl:1Œ1) BY -IAPÞAMII !I'I -IIIEY. B SCALI: NONF: DArl, JUNF: 2001 ÞIQ. NO I4eOOOB '1' OF I Jß1.[ H \ACAD~ILE\ 14EI l-1E-AOGW 14EOOO6 DWG, 1 1/28101 0-1:17 16 PI,' 19 I/C1I 01 8 R:R 2DJUN 01 A ~ /lNSED KJEr:rION pwp NIl DRi4IIS /ÐIOIÐ) ct»NEImD DlilIIIIIG II) WI ~r PM DRAWING 004,0206 DA1E ':f¡Y.' 'W. ~Il DE9CRIP1I)N r,1.:1,IN 907 2~3-Õ:;':'O ANAD,~ Rt<.O PETROLEUM CORPORAT' 3: )STREET SUITE 603 . ':'NCHOR':'GE ALASt<.:. 99503 Anadal'l(p! December 12. 200 I 1\ls. Cammy Oechsli. Chairman Alaska Oil and Gas Conser\'ation Commission 333 \Vest 7Lh .\.\'e.. Suite 100 :\nchorage. Alaska 99501 RE: Application for Permit to Drill: Anadarko Altamura #2 Dear 1\ Is. Oechsli. .\.nadarko Petroleum Corporation hereby applies for a Permit to Drill an onshore exploratory well in the NPRA area of the North Slope. The well, called the AJtamura #2. ./ will be located approximately 19 miles southwest of the \'illage of Nuiqsut and 3.3 miles south of Phillips Alaska's Rendez\'olls #2 well Anadarko plans to spud Altamura #2- approximately FebnJal")' 15. 200 I. / Upon receipt of all necessary permits and appro\'als (including tundra tra\'el authorization). construction equipment \vill be mobilized to the AJtamura #'2 location \'ia rolligon and an ice drilling pad built. 1\leanwhile. an ice road will be constructed from Phil~ps' Rendez\'ous #'2 \\~ell site to the Altamura location. The drilling rig. Nabors 14-E. / will then be mobilized \'ia rol1igon (or truck, if the ice road infrastructure is in place) to the ice pad and the well drilled to TO and tested if log results warrant. The rig will be demobilized via ice road. Pertinent infonnation attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill (Public Information) - 1 copy '2) Form 10-401 Application for Permit to Drill - 3 copies 3) Fee of $1 00.00 payable to the State of.-\Jaska 4) \Vell Prognosis and discussion of Operational Considerations 5) Location Plat and Drill Pad Layouts 6) Days \'S. Depth Drilling Cur\'e 7) Drilling Procedure 8) \Vellbore and \Vellhead Schematics 9) Pressure Information including pore pressure. mud \\eight and fracture gradient cur\'es. offset well mud weight cur\'es. maximum anticipated surface pressure calculations. FIT and LOT procedures. and casing properties and design tàctors. 10) Di\'ener, BOP and choke manifold schematics 11 ) Cement Program 12) Directional Program 13) Drilling Fluid Program RECEIVED DEC 1 2. 2001 Alaska Oil & Gas Cons. CommIssion Anchorage 1\ls. Cammy Oechsli Page 2 .¡' As part of this Application. Anadarko also requests approval for the annular injection of drilling \vastes as discussed in the attachments. The AOGCC is requested to keep confidential al1 information included in the Application for Permit to Dril1 (except the Public Information copy) as information in these documents is dra\'v'n from research and data proprietary to Anadarko. For your information. this permit request is being simultaneously submitted to the U.S. Bureau of Land 1\'lanagement. If you have any questions or require additional information. 273 -93-00 v;o~ Sincerely. please contact me at (907) ~~~~~ Tommy Thompson Drilling Superintendent enclosures RECEIVED DEC 1 2 2001 Alaska Oil & Gas Cons. CommissIOn Anchorage "'" TOMMY W. THOMPSON 4-93 MELISSA K. THOMPSON 3 GREYCREST PL 281-364-8186 THE WOODLANDS. TX 77382 3071 37-65/1119 2731 Date 12 Urc.: "2U0 l Pay to the S ~ ' I ~ ( 1\ l "- -c: L -- A.. G 6'-- ( ~&~ ~ ~~ ~~~~ j} \ iI' ~e{ ~(Ùe V\~\U'L1.. A.,..;>¿ ({;),J .WELLS FARGO BANtS TEXAS, .~.A. ~ 1030 ANDREWS HIGHWAY, , i MIDLAND, TX 7970'1 . , 'l~','.' ,:. ,'. www.wellsf3rgo.com. "'~'" .'. ~. Memo A~~~~ "-2 A\"t> -- ~ ~~-=-_-!! :~..:.. .gOOb Sg.: 5.030 3 .ab~ 3D? (.~. . '.' -" 1$ ,.["". -" .._-~ ~:;;..,....- Dollars l!J õ~..:::;...... CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRlLL EXPLORA7' INJECTION '''ELL INJECTION "/ELL RED RILL TRANSl\iIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER 'YELL NAJ\1E .AIIaÞHé.^-r4.- #2-- CHECK 'VIlA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR DISPOSAL L--> NO ANNULAR DI~ y5YF$ ANNULAR DISPOSAL THIS \\/ELL "CLUE" The permit is for a new wellbore segment of existing well ---' Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and log!ì acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS L--> YES + SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. ~rll;""47 ~/(, /~Þj.~ ~~ ~~-~~~ d '7 A rr-o.. v ~ I <.-!k-v rÞLU-d.f Æ;J 14 k oftJL'¡- ¿?c.- ivt/ .4R;k. t' ~ lo;Y(~i?/~,~:.n.'>j< '/VU<.~/ ~\4: 7J/~<--""<- ) ;~ be. c£f~,~ o/'-71A.- 6~ ¿) ~<J<-~ /0 I-Þ. ~ APPR DA T~ lJ,A Z{ lOIO¿ ;M-7Wl ÇJ-;;; 0 GEOLOGY WELL PERMIT CHECKLIST COMPANY 4~k WELL NAME.4-4W.//rz¡{ ~PROGRAM: Exp V Dev - Redrll- Serv - Wellbore seg - Ann. disposal para req- FIELD & POOL /v/J INIT CLASS é;.x:.Pi (Wi '-;;u:_~~) GEOL AREA f?7/)J UNIT#.,v'.'1- ON/OFF SHORE O~ ADMINISTRATION 1, Permit fee attached. . . , . . . . , . . . . . . . . . . , . .. ~~~N 2. Lease number appropriate. . , . . . . . . . . . . . . . . . . N 3. Unique well name and number. ,. . . . . . . . . . . . . , , . 'í.,~ 4, Well located in a defined pool.. . . . . . . . . . . . . , . . . ~, 5. Well located proper distance from drilling unit boundary. . . . r 6. Well located proper distance from other wells., . . . . . . . , N 7. Sufficient acreage available in drilling unit.. , . , . . . . . . . , N 8, If deviated, is well bore plat included.. . . . . . . . . . . . . . N 9. Operator only affected party.. . , . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . , , . N 11. Permit can be issued without conservation order. . . , . , . . N AP/~R DATE z." 12. Permit can be issued without administrative approval. . , N pI) 2-" 19 D- 13. Can permit be approved before 15-day wait.. . . . . Y , N ENGINEERING 14. Conductor string provided. . . , . . , . . . . . . . . . . . . ~ r;t.f ~))). C~ I T Y. I? .4 , " , / /.. / /? 11 A" 15. Surface casing protects all known USDWs, ~ . , , . , , , . . y ~Cff¡¿''--~ .,.qKA-~w:> -, i?S ¿Jc.'-'(~/7c.-r?c..o"~ ~~ ~/,~~~tb~"~ . 16. CMT vol adequate to circulate on conductor & surf csg. ~ a~-L4~d ~~.~ c.~ ¿eu-'1 /£.f- 3~) /~D ~// 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y æ .1 ~ OO~1...t:;k,é' ¿(sp¿ð ;', ~, 18, CMT will cover all known productive horizons, . . , . . . . . . ~ N A ~ lL.4I':tt e..¡.J,/¿ {..V U ,/~. [ P....... t . - ~~: ~~:~~a~:~~~~~;:~i~:~~~~ ~¡t:" ~ ~ ~~r~~fr.o~t.. ~ ~ .' ~ ~ ~ @ ~ NC1 b.?; s ,~~ é . 21, If a re-drill, has a 10-403 for abandonment been approved. . . -¥---N- AlIA 22. Adequate wellbore separation proposed., , . . . , . . . . . . ¥--N- N/I\ 23. If diverter required, does it meet regulations. . . . . . . . . , iN 24. Drilling fluid program schematic & equip list adequate, , . , . N ~:'\ . \' - \ \ ,\ l ?"'"P'V"\(""', 25, BOPEs, do they meet regulation. . . , , , . , . , . , . , , , N t<..\S \. ~ 1\ t"\Q.~\'f" <; ~ ~ {> ~ '-0 ""''M.<'! r<.J \ V'\ \",,' '-J.. ',,"1õ;,. \ ~ð~.J.-J'--.J 26, BOPE press rating appropriate; test to '1000 psig, I N j./f A6 P = ~s 7 ~ {$-" fJ..rv.¡.. C C; (7 I þ~ t :: '1-000 f <..~ . 27. Choke manifold complies w/API RP-53 (May 84), . . , . . , . N 28. Work will occur without operation shutdown. . . . . . . . . . . ~ ~ 29, Is presence of H2S gas probable.. . . . . . . , , , . , . , . , Y &I 0~ f¡¿ {.:Jl..c.:o ' ;~: 6:::'~::'~~t:~s~~ep~;:~ti~¡~~~~~~~~~ez~~:~.'~s.. .. .. .. .. ~>y./~ ~:'¿;""i:1- ~. 'I ~ ~:::i~ðo?1~( æd.~;<I'¡ v~ e-~~-K 32, Seismicanalysisofshallowgaszones~....,...,. 2::95~-'~'",:"....L$~ ft."'? 'Jð(~C~'~'- ~ ~. '~~~#2ýp~~~.J. APPR DATE 33, Seabed condition survey (if off-shore). , , , . . , . . . . ,. .vA ¥ N ~ ~ ~~~ ~ <-fø~.¿~ P'7t ~ '~... -)'1' Z-b z.... 3¿:>...p(/ Ii'v"*-' <:.... ,.0 f /1 ".¿.. 34. Contact name/phone for weekly progress reports [~ratory only]@ N ~4/a.,~ e?&'~ 'J::J( þ~ . £" //".n""'14 -r7,,~>-~ 2. '73 ~ 3~ ANNULAR DISPOSAL 35. With proper cementing records, this plan -.I ~~ . (A) will contain waste in a suitable receiving zone; , , , . . ,. (~/ N APPR DATE (B) will not contaminate freshwater; or cause drilling waste, ,. ?fJ N to surface; (C) will not impair mechanical integrity of the well used for disposal; ð! N (D) will not damage producing formation or impair recovery from a CZ; N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412, 62 N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: RPC~ TEM~~ òI/¡o COT SFD ~---, - WGA i'~ DTS :? I ~ , ¡o <:;J- ":;i!jfT JMH .' 1\'.1 H 2../ ¿j/t)2. Com mentsllnstructions: G: \geology\perm its\checklist.doc