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Home My WebLink About198-135XHYZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspectiOn. /~.<~-~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages' Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages' DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy Mildred Dareth~~t-owell Oa,e / Isl TO RE-SCAN Re-Scanned by: Bevedy Mildred Dareth~~"}-owell Date:~7 /S/ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich Commissioner THRU: Jim Regg ~,~!-[{l.i"i. P.I. Supervisor FROM: John H. Spaulding Petroleum Inspector DATE: July 12, 2003 SUBJECT: Mechanical Integrity Tests CPA 1E 35 KRU Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. P.T.D.I 1981350 Type testI P I Test psiI 1476 I Casingl 1575 I 25001 2500 I 25001 P/F I P I Notes: WellI P.T.D.I Notes: WellI I Type Inj. P.T.D. I Type test Notes: Notes: WellI I Type Inj. P.T.D. I Type test Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S - SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to CPA's KRU 1E-35 to witness the 4 year MIT. Jared Brake was the CPA rep. today. The pretest pressure were monitored and found stable, the standard annulus, pressure test was the performed. 1E-35 appears to meet the AOGCC criteria for a successful MIT. M.I.T.'s performed: 1_ Number of Failures: 0 Total Time during tests: 1_ Attachments: cc: MIT report form 5/12/00 L.G. OAN ED AUG ! 20D3 2003-0712_M IT_KR U_ 1 E-35js.xls 7/18/2003 ~KA OIL AND GAS CONSERVATION COMPreSSION TONY KNOWLES, GOVERNOR 333 W. 7'r" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Fritz Gunkel, Manager Drilling BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519 Re: Cancelled or Expired PTD's. Dear Gunkel: September 6, 2001 The Alaska Oil and Gas Conservation Commission ("AOGCC") approved the following referenced permit to drills. The AOGCC has a long-standing policy of releasing cancelled or expired permits two years from the date the application was approved by the AOGCC. The following files are scheduled to be released October 1,2001. Permit to Drill No.'s: 97-047 98-019 99-002 97-056 98-050 99-009 97-082 98-135 97-090 98-154 97-100 98-155 97-121 98-164 97-159 98-167 97-191 98-177 98-210 98-211 98-223 98-236 98-257 98-261 Sincerely, Memorandum State of Alaska Oil and Gas Conservation Commission To: Well File: 198-135 DATE July 22, 2000 Re.' Cancelled or Expired Permit Action EXAMPLE: Prudhoe Bay Unit Z-37XX API# 029-22901-95 This memo will remain at the front of the subject well file. Our adopted conventions for assigning APl numbers, permit numbers and well names did not specifically address expired or cancelled permits. This omission has caused some inconsistencies in the treatment of these kinds of applications for permit to drill. Operators have asked us to adopt formal procedures for this class of permit application in order to prevent future database disparities. If a permit expires or is cancelled by an operator, the permit number of the subject permit will remain unchanged. The APl number and in some instances the well name reflect the number of preexisting redrills and or multilaterals in a well. In order to prevent confusing a cancelled or expired permit with an active well or multilateral these case sensitive well identifiers will be changed for expired and cancelled applications for permits to drill. The APl number for this cancelled or expired permit is modified so the eleven and twelfth digits is -95. The well number for a cancelled or expired permit is modified with an appended XX. CANCELED PERMITS ARE RELEASABLE 2 years from the date On the letter received from the operator requesting the permit canceled.. (Memorandum January 23, 1997 by Dave Johnston, subject: Canceled and Expired Permits) EXPIRED PERMITS ARE RELEASABLE 2 years from the date on the application was issued by the commission, unless the operator ask for extended confidentiality. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician TONY KNOWLE$, GOVERNOi=t ALASK& OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 22, 1998 James E. Smith Drilling Engineering Supervisor BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re; Prudhoe Bay Unit Z-37 BP Exploration (Alaska) Inc. Permit No. 98-135 Sur. Loc. 4310~NSL, 3912'WEL, Sec. 19, T1 IN, R12E. UM Btmnhole Loc. 48ffNSL, 4158~VEL. Sec. 11, T11N. R11E, UM Dear Mr. Smith: Enclosed is the approvcd application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. 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 max' witness the test. Notice may be given bv contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. · Chairman BY ORDER OF THE COMMISSION diflenclosures cc: Department of Fish & Game, Itabitat Section w/o encl. Departn]ent of Environmental Conservation w~o encl. STATE OF ALASKA ALASKA L~,L AND GAS CONSERVATION COM,v,,'SSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI []Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 85.1' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028240 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 4310' NSL, 3912' WEL, SEC. 19, T11N, R12E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 4992' NSL, 957' WEL, SEC. 14, T11N, R11E, UM Z-37 Attotal depth 9. Approximate spud date Amount $200,000.00 480' NSL, 4158' WEL, SEC. 11, T11N, R11E, UM 07/21/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028245, 480'I Z~7, 37' at 2450 MD 2560 17396' MD / 8821' TVDss 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 2000' MD Maximum Hole Angle 96.5° Maximum surface 2993 psig, At total depth (TVD) 8857' / 3879 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' Surface Surface 80' 80' 260 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 40# L-80 BTC 3239' Surface Surface 3239' 3095' 1210 sx PF, 555 sx Class 'G' 8-1/2" 7" 26# L-80 BTC 13563' Surface Surface 13563' 8685' 1133 sx'G', 139 sx'G' Lite, 180 sx'G' 6" 4-1/2" 12.6# L-80 BTC-Mod 3974' 13413' 8590' 17365' 8821' 440 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feetORIGINAL Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate LPirn°edructiOnR EC E iV E D 08 1998 Perforation depth: measured Alaska 0JJ & Gas Cons. Commission true vertical Anchorage 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: William B. Lloyd, 564-4016 Prepared By Name/Number: Carol Withey, 564-4114 21' I hereby certify~ ih.~ ~°reg°i~ is'~2nd c°rrect to the best of mY kn°wledgeSigned ~- , ....,~,,. Dan Stor~t.~8~/~-/~ ?J,..i._p...~ ~ Title Drilling Engineering Supervisor Date,'~ !/ Commission Use Only Permit Number ! APl Number Approv~ Date "*~"~1 See cover letter c~ l~ - ! ~-~-', 50- O~°/_ ~ ~. ~ O ~ ? ,,,,_,~ .-.~", for other requirements Conditions of Approval: Samples Required []Yes ~No Mud Log Required ~_,.~Y. es ~'No Hydrogen Sulfide Measures ~.Yes~No Directional Survey Required 1,4 Yes [] No Required Working Pressure for B-OPE I--i2M; []3M; [~SM; []10M; [--115M Other: by order of Approved By Urlginal Signed By Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate Iwell Name: IZ-37 I Well Plan Summary Type of Well (producer or injector): I Ultraslimhole Extended Horizontal Producer Surface Location: 4310' FSL, 3912' FEL, Sec. 19, T11 N, R12E X = 598766.03, Y = 5959100.06 Target Start Location: 4992' FSL, 957' FEL, Sec. 14, T11 N-R11E X = 591410 Y = 5964970 Turn Point: 249' FSL, 3181' FEL, Sec. 11, T11 N-R11E X = 589180 Y = 5965480 Target End/BHL: 480' FSL, 4158' FEL, Sec. 11, T11 N-R11E X = 588200 Y = 5965700 Bottom Hole Location: 480' FSL, 4158' FEL, Sec. 11, T11N, R11E X = 588200 Y = 5965700 I AFE Number: 1 4P0995. I Estimated Start Date: 17/21/98 MD: 17396' I Well Design (conventional, slimhole, etc.): TVD: I Rig: I Nabors 18E Operating days to complete: 8821 'ss 1 34 fEKB/ I5.1 / urface levation 4.7 a.m.s.I) Conventional ultra-slimhole high angle producer IObjective: I Targeting undrained reserves on the northern end of the central graben between the I Highlands State and Main fault blocks Formation Markers Formation Tops MD TVD (SS) Base Permafrost 1884 1800 2000 1916 Begin 2.5°/100 build 3245 3100 Surface casing point in shale, 9-5/8" 40# L-80 Surface casing below the hydrate zone and above the potential hydrocarbon zone - Ugnu UG4 3304 3150 4341 3870 End 2.5°/100 build CM3 / K-12 6313 4900 THRZ 9531 6580 TKUP 9723 6680 LCU 9838 6740 Kingak 11332 7520 ~ I"~,', ~, ~ ~ ~ ,.. ,., TJF 11707 7716 I~ £ ~. I:: I V b I) TJE 12186 7966 TJD 12598 8181 ~UL OR TJC 13039 8411 ~ 011 & Gas C0.s. Anchorage TJ B 13297 8546 TSAG R 13556 8681 13563 8685 Intermediate Casing Point, 7" 26# L-80 S h ublik 13613 8711 13680 8746 Begin 10°/100' curve CGOC 13714 8763 14066 8857 End 10°/100' curve TSAD 14066 8857 16355 8930 Curve 100/100' 16439 8930 End 10°/100' curve THOT 8932 OOWC 8942 TD 17365 8821 Casinc /Tubing Pro_c_ ram Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. M D/TVD M D/TVDss 30" 20" 91.5# H40 WELD 80' surface 80'/80' 12-1/4" 9-5/8" 40# L-80 BTC 3239' surface 3239'/3095' 8-1/2" 7" 26# L-80 BTC 13563' surface 13563'/8685' 6" 4-1/2" 12.6# L-80 BTC- 3974' 13413'/8590' 17365'/8821' Mod tubing 4-1/2" 12.6# L-80 BTC- 13370' surface 13370'/8563' Mod General Mud Program Surface Mud Properties: Fresh water bentonite I 12-1/4" hole section spud mud I Density Marsh Yield 10 sec 10 min pH APl (PPG) Viscosity Point gel gel Filtrate 8.6 300 15 8 10 9 8-15 to 10.5 <150 35 15 30 10 8-15 Intermediate Mud Properties: KCl/NaCl/NaBr - XC Polymer 8-1/2" hole section Density LSRV Funnel pH APl HTHP (PPG) Viscosity Filtrate Filtrate Initial 9.3 60K - 80K 50-70 9.0-9.5 6-12 NA Final 10.6 60K - 80K 50-55 9.0-9.5 4-6 NA Production Mud Properties: Filtered Seawater 6" hole section Density Viscosity pH APl Chlorides (PPG) Filtrate 8.6 - 8.8 28-35 8-9 NC 1 OK - 17K Directional KOP: _+2000' MD (estimated) Maximum Hole Angle: 96.5° Close Approach Well: Z-7 Shut In during drilling of surface interval. If flowing, 6' from tolerance hardline @ 2450'. If shut-in, 37' from tolerance Cement First Stage Second Stage Casing/Liner Sx / Wt / Yield Sx / Wt / Yield Comments 9-5/8" surface Class "G" tail: Permafrost Lead: Two Stage Job: 465/15.8/1.15 1210/12.2/1.92 First stage calculated as Class "G" tail from TD to the ES cementer at 2100'md @50% excess Class "G" tail: Second stage calculated as a class "G" 90/15.8/1.15 tail tack from 2100'-1850'md @30% excess and then Permafrost cement circulated to surface assuming 300% excess. First Stage Second Stage Casing/Liner Sx / Wt / Yield Sx / Wt / Yield Comments 7" Intermediate Single Stage: Class G Lite Single Stage Anticipated = First stage only Class (3 139 / 11.0 / 3.31 Two Stage Job w/ES Cementer @ 5900' 1133/15.8/1.16 First Stage brings cement 100' above shoe Two Stage: Second Stage brings cement above upper Class G Premium Tail: hydrocarbon intervals (if present). 180 / 15.8 / 1.16 4-1/2" Liner 440 / 15.8/1.16 150' liner lap, TOC 200' above TOL, Class "(3" cement, 50% excess Logging Program LWD Logging: 12-1/4" Hole MWD directional 8-1/2' Hole MWD/GR directional 6" Hole Open Hole Logs (eline): 12-1/4" Hole 8-1/2" Hole 6" Hole Cased Hole Logs (eline): MWD directional / GR / Res, Mud Logging No Logs needed None (PEX, SWC's, RFT's may be run under separate AFE) 1) Platform Express (GR/RES/LDT/NUE) DPC None Well Control Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics will be provided when determining rig (rig will be in the current fleet of north slope rigs and the schematics should therefore be on file with AOGCC). Maximum anticipated bottom hole pressure is 3879 psi at 8857'TVDss (8.4 ppg EMW). Maximum anticipated surface pressure assuming gas in entire annulus (0.1 ppg) is 2993 psi. Hazards · Ugnu may be slightly overpressure due to water disposal at GC-2 which is ~10 miles to the east. Estimated mud weight requirement is 9.3 - 9.5 ppg. · Hydrates in the surface interval are anticipated to require mud weights in the range of 10.2-10.5 ppg · One 25' fault anticipated at ~4900' tvdss in the Colville Mudstone, one 170' throw fault anticipated at -,,6650'tvdss in the Kuparuk, and one 40' throw fault anticipated in the Kingak at ~8370' · Kingak shale instability - minimum mud weight of 10.5 ppg · Low reservoir pressure and potential lost circulation Disposal Cuttings should be hauled to the ball mill at CC-2A. Fluid Handling: Haul all drilling and completion fluids and other class II wastes to CC-2A for injection. Haul all Class I wastes to Pad 3 for disposal. In addition, haul all cuttings from drilling operations to CC-2A for disposal. Z-37 Short Well Summary Rig 1. 2. MIRU. NU diverter and function and pressure test same per SSD drilling policy. Directionally Drill 12-1/4" hole with MWD Directional to ~3244'MD/3100'TVDss. Run and cement 9- 5/8" 40#/ft L-80 casing to surface with Halliburton ES cementer (two stage surface cement job). 3. ND diverter, install Blow out prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer. Function test BOPE to 250/5000 psi per SSD Drilling Policy. 4. RIH with PDC bit, Test 9-5/8" casing to 3000 psi for 30 minutes. Drill out float equipment and shoe and 20' of new formation; perform a formation leak-off test using the BJ cement unit as per the SSD Leak off Test Procedure - expect ~13.5 ppg EMW test. 5. Drill 8-1/2" well bore with MWD/GR building @ 2.5o/100' from the surface casing shoe to ~4347'. Drill ~59° tangent interval to 7" casing setting depth of ,-,13563' MD (8685' TVDss). (Run discretional logging program prior to drilling the Kingak, if required). 6. Run and cement 7" 26# L-80 casing to surface with either a single stage or 2 stage job, dependint upon the presence of shallow hydrocarbons. Bump the plug(s) with 3500 psig, check the floats. 7. RIH with 6" bit, drill the 7" shoe and 20' of new formation with 9.5 ppg mud for kick tolerance determination. Displace fluid with filtered seawater 8. Drill 6" hole with MWD/LWD (IAB/GR/DEN-NEU/RES to TD of 17,366'md (8821' TVDss). 9. Run platform express logs on eline (GR/RES/LDT/NEU). 10. Run and cement 4-1/2" 12.6# L-80 solid drilling liner (150' of lap inside 7" casing). Test Casing. 11. Run DPC perforating guns and perforate per post drilling log evaluation. 12. Run 4-1/2" L-80 tubing completion and set a 4-1/2" x 7" production packer with tubing tail stung into liner tie-back sleeve. 13. Test tubing and annulus. Set TWC. 14. ND BOP, NU and test tree. 15. Pull TWC, freeze protect, set BPV, RDMO. 16. Well will be tested by PE group following rig release. ............. S'HARE 0 SERV'I:C"ES DR" LL i N'G .... 9 Z~ CLOSUt~E · 12459 feet at Azimuth 302.74 Z-37 (D) (P3} ' PLAN VIE~ II I . . _ Iii _ _ I_ III ......... ' ' ....... ~ .............. ~ I -- IDECLINATION,: +27.624 (E) ISCAL£ ..... ..: ! inch = ~.SOO feet ., ............................ . IDRA}IN ....... : 25 Jun ~998 ..... i , , IH , IllIII .......... ~-~..~ ~"~ ~. ~'~) , : Mar~erA) ~B [d~nLi ficat ion MO0 oN/$~ E/~O ~~ ~~tart JP[int) B) KOP BUILO ~,5/~00 2000 0 ~ 0 ~~ C) 9-5/8" gSG PT <Il> 3245 81~ N 253 ........................... D) ENO 2.5/t00 ~ILE 4341 702 ~ flAl 7' C~ PI <11> i3563 5746 N 6875 , ............ ~ .... ~ I1 ENO lo/Ia0 CURVE IB439 65~ N 9583 J} ID ~-1/2' LN~ PT<}[> t7~6 673~ N 10~7~ ~ ~.......... ,, , ~ ...... , .............. 1 ..... - ~ ....... ) ....... ~......... ~q~ .... . . ...... _ ;',gR ~ERN,~iTT! NG ~ _ : ~ -"" ~ ...... "- O~LY ' ' , ~~' . . ....... ~ ...... ) _. ~ ~1 ....................... ~ ............ ~ ' ' I' ' ~} ...... 12750 i~O00 i 150 10500 g750 9000 8250 7500 6750 5000 5250 4500 37.50 3000 2250 1500 750 0 750 <- NEST' EAST -> ii ,1111 iii i iiii ii . I I __ ii1.1 . ii iii i _. - ..... . :' IlJJ IJ I . i i ! i iii - SERV 'CES DRILLING - S" qARED lllll . _ 9000 ! ANADRILL AKA-DPC j. i A?PROVF, D I I i Ii Iii Anadr J ]] Sch]umberger II II Z-37 (D) (P3) VERTICAL SECTION VIEW : ' Secti at: 302.74 ................. ., ';, .~C ~, "'".~J '~'JN~J""':'I ' ~ '"" ~ '~ I"~'""I~VD Sca]e.:~" ~="~ inch ~ = 500 feet ' ~ JOep Scale.: 1 inch : 500 feet · , ~)NL,,,, ~ , ~, ,~ .~ : /Draw~ ..... : 25 Jun 1998 .................. ~anken Id~ntification MO BKB SECTN ~L A] 7' CSG PT <t1> 13563 8769 889~ ~.5 '~ ~-~ B) CURVE tO/iOO i~BSO 8B~ 8990 ~,5 C] END iO/JO0 CURVE t4066 894~ 9350 ~-- ,,, , BI CURVE tO/tOD 'fa¢-~ E] END tO/~O0 CURVE ~6439 901~ t~590 F] TD 4-t/2" L~ PT<II> ~7366 8905 ~2459 96.5 ~ ....... , , ....... ) ..... ~- -~ .... ~~:~ ........ ~ , ........................... -, 8500 8750 9000 9250 950~ 2750 toono 10250 $0~0 i0750 !ltOI]O 11250 11500 J 1750 12000 12250 12500 12750 13000 Section Departure ,'KB> Z-37 iD) in3) VERTICAL SECTION VTE Sec(ion at: 302.74 -- ,' ' ' ..... ~', ..... I TVB Scale.: ] inch = t600 feet I ~Oep Scare.:. ~ inch : ~600 feet M~rker Identification ~ BKB SECTN I~LN --- '"- A) KB O 0 0 0.00 ................................................... ~"P~,'~r-fl~ B) KQP BOILD 2.5/~00 2000 2000 -0 0.00 B - - 6) 9-5/8' CS6 PT <~ [ > 3245 3~84 3~7 3i.12 ~ O) E~O 2.5/~00 BUILO 434~ 3955 t087 58.53 E) 7' 6S6 PT <11 > ~3563 8769 8691 58,53 F) CURVE ~O/tO0 ~3BBO ~30 8990 58.53 .. G) E~ ~0/~00 CURVE t406B Bg4t 9350 8B.17 ) ..... -~-%=-' ....... ': .......................... ~ ~'~ H) 6~VE ~O/tO0 ~63~ ~4 ~51~ 88,17 I) E~ ~0/~00 ~URVE ~6439 ~1 ~590 9B.54 ~ J) lO 4-1/2" L~ PT<II> 17366 ~05 12459 96.54 '~r~f~- s ~ -~' ANA]RILL AKA-DP ,., ~m ~ I~r f ~,~ -~~ - ~- - ~ ..... 2 ...... ~ ~ ............ 2 2 2 2_. )0-:T~-~ ; ==== '--- - = ~z: ~.~Z~ ~E__ ~ ~ ..... =============================== ...... ...../ I }0 " _ ................... ~ nnnn nnnn annn ~a4on I ~poo t200O t2BO0 ~360[ O 800 ~.600 2400 3200 4000 4BO0 5600 6400 7200 Sect ion Oepan tune AnadriZZ Schlu~r~er Alaska Di~tr£ct [111 East BOth .AYe~ue A~%chorage, AK 99518 {907) 349-45Z1 Fax 344-2160 DIRECTIONAL WELL PLA~ for SKAR~D SERVICES well ......... : z-37 F~eid ........ : Prudhoe Bay, Z-Pad Co,ADulation..: Minimum Curvature Units ........ : FEET Surface Surface 5o~9.: 149.200~7654 W Legal D~scrtpt ion Surface ...... : (309 FSL 3922 F~L Target Start.: 49~2 F~L 957 Target M~d...: 249 FSL 3181 ~L B~ .......... : 460 F~L 4158 FEL L~CATION~ - ALASKA zone: 4 X-Coord Y-Coord $19 TkiN R12E UM 598766.03 5959100.06 S14 T[ZN RllE UM 591410.00 5964970.00 Sll TI1N RIlE L D4 589150.00 5965480.00 Sl~ TllN RllE IfM 588200.00 5965700.00 PRO~OSBD ~ELL PRDFILE STATIO~ MEASURED ~NCL~ [D~TIF~TION DE~TH A~ ~ 0.O0 O.OO BASE PERMA~OST ~B8~.40 0.00 KO? BUILD 2,5/~00 2000.00 0.00 ~100.00 2.50 "1 2200,00 5.00 2300.00 7.S0 2~00.~0 ~0.00 ~~~~ 2500.0012.50 2700.00 17.50 (~a~ill (c) 98 Z37P3 3.~C 9:33 ~4 P) D~R~CTrO~ ~RTICAL - DB ~T~{S S~C'~ I ON AZIMUTH TVD SU~-S~A DEPART O. O0 O. O0 -64.40 0 . O0 0.00 3.884.40 1800.00 0.00 0.00 2000.00 191..5.60 -0.00 309.88 2099.97 203.5.57 2.16 309.88 23.99.75 .2115.35 B.65 .. 309.88 2299.14 221%.74 19.~5 309.88 2397.97 2313.57 34.55 309.88 2496.~ 24[~.6~ 53-90 309.88 2593.17 2508.77 77.49 309.88 2689.17 2604.77 [05.25 309.85 2783.85 2699.45 137.14 grepared ..... : 25 Jua 1998 ver~ zect az.: 302.74 IQ] elevation,~ 84.40 ft Magnetic Dcl~: +27.624 (E) Sca~e Factor.: 0.99991[00 Conver~eoce..: +0.~5300505 ANADRILL AKA-DPC APPROVED FOR PERMITTING ONLY PLAN - -- _z .~. ,... : ,~ :-~-- : ..~_¥: :_~.~" ~ COORDIAXATE~-FRO~ ALASKA 5o~e 4 TOOL DL/ WELLHEAD X Y FACE 0.00 ~ O.O0 E 598766.03 5959100.06 MS O-O0 0.00 N 0.00 E 598766.03 5~59100.06 RS 0.00 0.00 N 0.00 E 598766.03 5959100.06 501 0.00 1.40 N i.67 ~ 598764.3~ 5959~01.~4 501 2.50 5.59 N $.69 W 598759.27 5959~05.56 KS 2.50 [2.57 N Z5.05 W 598750.82 5959ZI2.~3 HS 2.50 22.33 N 26.72 W 5987~9.02 5959Z22.03 HS 2.50 34.83 N 41.69 W 598723.89 5959134.34 }IS 2.50 50.07 N 59.93 W 598705.46 5959149-34 HS 2.50 68.02 N 81.40 W 598683.75 5959166.99 MS 2.50 88.63 N 106.06 W 598658.82 5959187.28 HS 2.50 PROPOSED WELL PROFILE MEA$URED INCLN DEPTH ANGLE 2900.00 22~5~ 3000.08 25.00 5100.00 27.50 3200.0~ 30.00 3~44.69 3~.12 UG4/K15-C~ ~300.~0 32.50 ~303.56 32.59 B~00.OO 35.00 3500-00 37.50 3600.00 40.00 D[RECTION AZIMUTH VERTICAL - QE t~I7{ S SECT ! QN T%~D SUB-SEA DEPART 309,~8 2877.~5 2792,65 173.L0 309.88 2968.57 2884.17 2~3.06 309.88 3058,25 2973.85 256.94 309.88 3[45,92 3061,52 304.67 309.88 3~84,~0 31g0,00 327.22 309.88 3231,%0 3147,00 356-L4 309.88 3234,40 3~50,O0 356.0i 309.88 33[~,54 3230,14 4LL.26 309.88 3395,18 3310,78 469.93 309.88 3453,16 3388,76 532.03 TO0~ DUI FACE 500 COORD~NATES-F~OM ALASKA Zone 4 WZLSHEAD X Y LLL.86 N 133.37 ~ 598630,71 59592/0.1¢ ~S 2.50 137.69 N 164.77 W 598599.%S 5959235.56 HS 2.50 ~66.04 N 198,7~ W 598565,17 5959263.~6 ~8 2.60 L96.88 N 235.6~ W 598527,87 5959293.81 ~L~ 2.S0 21[o~5 N 253,05 W 59851~,24 5959308.15 HS 2,50 230.1~ N 275.4l W 598487.63 S959326.55 ~ 2.50 23L.37 N 276,89 W 598%86,15 5959327.75 ~S 2.50 265.77 N 318.05 W 5984~4,~4 5959361.60 }tS 2.50 303.68 N 363,42 W 598398,68 5959398.91 ~S 2.~0 343.81N 411.45 W 598550,13 5959438.40 HS 2.SO' 3700.00 42.50 3800.00 45.00 3900.00 47.50 ~O00.O0 50.00 ¢100.00 52.50 309.88 3548,34 3463,94 597.45 309.88 3620,57 3536,17 666.06 309-88 3689.72 3605.32 737.73 309-88 3755.64 3671,24 812.32 309-88 33~8-23 3733,83 889.70 356.09 N ~62.04 W 5982~9.00 5959480.01 ~S 2.50 430.~2 N 515.10 W 5982~5,36 5159523.64 H~ 2.50 476.7~ N 570,53 W 59818],34 5159569.22 ~IS 2.50 524.9~ N 628,22 W 598131.03 59596~6.66 ~IS 2.50 574.95 N 688,~6 N 598070.54 5959665.86 ~S 2.50 END 2,$/L~0 BU!LB CM3/KZ2 TOP KRZ ¢200.00 55.00 ~300.00 57.50 ¢3~1.~3 55.53 6313-45 55.53 953L-36 55.53 TOP KUPARUK 9722.90 55-53 LCU 9837.83 88.53 TOP K/NGAK ~133X.86 58.53 TJF 31707.29 58.53 TJS 12186-X4 58.53 309.88 3~77.36 3792,96 969.7L 626.65 N $49.94 309.88 3932.91 38~8,5[ 1052.2L 679.96 N 813.73 309.88 3954.70 3870.30 1086.83 702.33 N 8~0.51 309.88 49~4.~0 4900,00 27~.97 1780.97 N 2131.35 309.88 6664.~ 6580,00 5479.25 3540.82 N 4237.%1 309.88 6764.~ 6680,00 5641,35 309-88 6524.&0 6740.00 5738.6i 309.88 7604.40 7520,00 700].99 309.88 7500.40 7716.00 ?320.70 3~9,88 8050.~0 7966.00 7725,95 598007.99 59597L6.75 HS 2.50 597943.50 5959769.21 HS 2.50 5979L6.44 595979~.23 HS ~.5~ 59~611.6~ 5960852.71 ~S 0.00 ~94482.83 5962584.57 ~S O.OO 3645.57 N 4362.78 W ~94356.11 59626~7.66 ~S 0.00 3708.43 N 4437.99 W 594280.08 5962749.51 KS 0.00 4525.50 N $415.81 ~ 593291.70 5963553.59 ES O.O0 {730.~L H 5661-52 W 593043.3~ 5963755.64 HS O.OO ~]2.70 ~ $97~.~2 W 592726.55 596%013.36 ~S 0.00 TJg 32597.96 58.53 TJC 13038-5L 58.53 'TJB ~3297.09 58,53 .., (3~nadrill (c)95 237P3 3.2C 9:33 A}~ P) 309.88 8265.40 $lBl.00 8074.47 309.88 8495.40 $411.00 8¢47.29 309.88 8630.~0 6546,00 8666.13 5217.9[ N 6244.~5 W 592454.11 5964234.99 H$ 0.00 5458.84 ~ 6532.78 W 592162.67 5964472,09 '~S 0.00 5600,26 N 6702.01 W 591991.60 596~611.26 HS 0.00 ANADRtLL AKA-OF*C APPROVED ,.FOR PERMITTING ONLY' Z-37 (D) {P3) 25 Jun 1998 Page 3 , ~ ~P SAG RI~R %3555,67 58,53 7' ~SG PT <~ [> 15563,33 58.53 ~P S~LIK 13613.13 58.53 ~R~ 10/~00 13679.72 58.53 13700.00 59.97 CGOC END [0/100 ctrRvE TOP SADL~ROCHIT CURVE 10/100 Et~D 10/100 C'b-RVE HOT OONC TOP DONE 3 TOP DON8 2 13713.93 60.97 13500.00 67.35 13900.00 75.04 14065.99 88.37 14065.99 88 16354.94 88,17 16400.00 92,68 16438.64 96,54 1.73,65.60 96 PROPOSED MBLL PROFILE DZR.~CTIO~ VERTICAL-DEPTHS AZ IMUTH TVD SUB -SF~A 309.88 8765,40 8601,00 309.88 S769,40 8685.00 309.88 8595,40 8711,00 309.88 8830.16 8~45.76 308.22 88~0-53 8756.[3 ~ECTION DEPART 8884,96 8891.45 8933.59 8989-9~ 9007.29 307.1E 8847.40 8963.00 300,65 8884.92 8800.52 293,93 8917.16 0832.76 ~87,65 8936.28 885L.88 ~83,64 89~l.40 8857.00 9019.35 9096.?0 9190.79 9286.67 9349.52 283,64 894/.t0 8857-00 9319,52 283.64 9014.40 8930-00 11511,25 283,5I 90~4.07 8929.67 ~553,80 283,4~ 9010.96 8926.56 11590.14 283.40 8905.60 8~25.00 ~2459.06 90L6.4~ 8932,00 9026.4~ 8942,00 914t.40 9057,00 91V8.~0 9094.06 COORD I NATES- FROM ALASKA Zone 4 TOOL DL/ ~fIiLLt{EAD X Y FACE 100 591820,54 5964~50.43 RS 591815.4? 5964~54.55 HS 591182.59. 596t981.35 HS 59173S.47 59618 LT.19 591724.?9 596t827.99 574T.68 ~ 6871,25 N 0.00 5745.87 ~ 6876,26 ~ O.O0 5773.10 N 6908,86 W 0.00 5809.52 N 6952.44 W 45L 0.00 $820.50 N 6965.97 W 44L lO.O0 S827.91 N 6975.57 W 591715.10 5964835.29 44~ 10.00 5870.96 N 7039.85 W 591650.26 $96487?.4~ 4iL lO,00 5914,20 N 7L23.90 W 591565.66 $9649/9.60 39L 10.00 59~8,93 N 72~5.58 W 591473.55 S96~95~.11 37L 10.00 5966.65 N 7278.90 W 5914~0.00 596~970.00 ~ 10.00 5966.65 N 7278.90 W 591410.00 5964970.00 H~ 10.00 6505.96 H 95U2.21W 589L80.00 5965400.00 2L 0.00 6516,53 N 9546.00 W $$9/36.08 5965489.99 2L 30.00 6525.49 N 9583.45 W 589098.52 5965498.46 tLS 10,00 6738.84 N 10479.32 W 588200.00 5965700.00 O.OO /., (A_naciz-ill (c)SB Z37P3 3.2C 9:33 AM P) 58 · ,35+ 8 · 7 [] 6 · 5 · 4 · 2 · 1 [] 11 · 12· 1,3· 14· 15· 16· 17· 18· 19· 20 · [] 35 I 52 · 31 · 50 · 29 m 28 · 27 [] 21 · 22 · 25 · 24 · 25 · 26 LEGEND AS-BUILT WELL CONDUCTOR [] EXISTING WELL CONDUCTOR IqPR 1/'-"-,98 3_5 ' 55 I',1o . 006 F:'. 02/CI7" PINE RI). VI~CINITY MAR T. 11 N., R. 12 £., U.M., AK -'OF SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT i AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF APRIL 11, 1998. NOTES 1. DATE OF SURLY: APRIL 11, 1998 2. REFERENCE FIELD BOOK: W098-¢1 (Pcs. 39-4¢). 3. ALASKA STALE PLANE COORDINATES ARE ZONE 4, ALASKA, NAD 27. 4. PAD SCALE FACTOR IS ¢.9999112. 5. HORIZONTAL CONTROL IS BASED ON Z PAD CONTROL MONUMENTS MON.2 AND MON.3. 6. ELEVATIONS ARE BPX M.S.L. DATUM. 7. ~RTICAL CONTROL IS BASED ON Z PAD MONUMEN TATION. LOCATED WITHIN PROTRACTED SEC. 19 T, 11 N. R. 12 E., UMIAT MERIDIAN ALASKA LUL,/A I LU 111 I,I Illl i i,v i~,w,v,~v -~, .... · -- · , "WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTIbN NO. COORDINATES COORDINATES POSITiON(DMS) POSITION(D.DD) BOX ELEV. OFFSETS Y=5,959,099.98 N= 2,453.67 70'17'51.759" 70.29:~7108' 54.6 4,308' FSL Z-34 X= 598,871.37 E= 1,86.9.97 149'11'57.565" 149.1995236' .. 5,806..' FEL ' ' 4,509' FSL Y= 5,959,100.00 N= 2,468.97 70'17'51.764" 70.2977121 54.9 , :Z-35 X= 598,836.08 E= 1,869.99 149'11'58.594" 149.1996094' 5,841. FEL Y= 5,959,100.06 N= 2,559.02 70'17'51.775" 70.2977148' 54.7 4,310' FSL Z-37 X= 598,766.03 E= 1,870.05 149'12'00:636" 149.2001765' 5,912' FEL WEEEHEAD: FMC mum>: 96~5o PROPOSED COMPLETION RKB Elev: 85;1' ~ac~ng 14.5i~:WLEG ~,, 13400' I AFE Est, = $3.490 MM Actual = $ DATE REV. BY 6/25/98 I W. B. Lloyd COMMENTS RIG 18E PRUDHOE BAY UNIT WELL: Z-37 APl #: 50-029-22XXX SEC__!9. T11N, R!2E, UM. BP [-Exploration (Alaska)~ Hi37172 rr ..: 'VEN~R AI_ASKAST14 O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 042298 CK04~298~ i00. O0 100. O0 HANDL[N~ INST' S/H KATHY CAMPOA!~OR X 51~2 · WELL PERMIT CHECKLIST COMPANY r'~ ~ WELL NAME F) ~ L,IL 7_. - .~ 7 PROGRAM: exp [] dev,~l~ redrll [] serv [] wellbore seg [] ann. disposal para req [] FIELD & POOL INIT CLASS GEOL AREA ~' ~/0 UNIT# / I ~ ~-0 ON/OFF SHORE Oct./ ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided . .................. 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10,403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ........ . ........ 26. BOPE press rating appropriate; test to .psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY .~)N '~)N ~'N {~-N ANNULAR DISPOSAL APPR DATE 30. Permit can be issued w/o hydrogen sulfide measure~.. Y N 31. Data presented on potential overpressur_~.~ ....... Y N. 32. Seismic analysis of shallo~ ............ Y N 33. Seabed conditions_..~Jo,~jr(E~off-shore) ............. Y N 34. Co~y progress reports ....... ' Y N ory onlyj 35. With proper cementing records, this plan (A) will contain waste in a suitable receive'. ..... Y N (B) will not contaminate freshwater~use drilling waste... Y N to surface; ~ (C) will not impair me_.,~cal integrity of the well used for disposal; Y N (D) will notd~ producing formation or impair recovery from a Y N ~d will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLI~,GY: RPC ~ ENGINEERING: UlC/Annular COMMISSI.~ON: JDH ~ RNC co Comments/Instructions: M:cheklist rev 05~29~98 dlf:C:\msoffice\wordian\diana\checklist