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Home My WebLink About198-019 • RECEIVE' Post Office Box 244027 I � 3��}} Anchorage,AK 99524-4027 Hilcorp Alaska,LLC JU�_ O 201 .1 3800 Centerpoint Drive Suite 100 AOGCCAnchorage,AK 99503 Phone: 907/777-8300 July 29, 2015 Fax: 907/777.-8301 Commissioner Cathy Foerster CrDI Alaska Oil & Gas Conservation Commission � g - 333 West 7th Avenue, Suite 100 3 ,a ' A x )( Anchorage, AK 99501 SCANNEr Re: Duck Island Unit Well Renaming Request Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "/" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD# 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp • Orig New API_WelINo I PermitNumber WellName WellNumber I WellNumber 50029219460600 2032160 DUCK IS UNIT SDI 3-17F/K30 3-17F 50029224630000 1940490 DUCK IS UNIT SDI 3-19/R28 3-19 50029217140000 1870330 DUCK IS UNIT SDI 3-21/L34 3-21 50029217149500 1980190 DUCK IS UNIT SDI 3-21AK35XX 3-21AXX 50029216450000 1861550 DUCK IS UNIT SDI 3-23/N32 3-23 50029221250000 1901820 DUCK IS UNIT SDI 3-25/M27 3-25 50029221250100 2010200 DUCK IS UNIT SDI 3-25A/N24 3-25A 50029221250200 2030210 DUCK IS UNIT SDI 3-25B/L27 3-25B 50029215860000 1860830 DUCK IS UNIT SDI 3-27/M33 3-27 50029221060000 1901560 DUCK IS UNIT SDI 3-29/J32 3-29 50029228380000 1972270 DUCK IS UNIT SDI 3-31/K32 3-31 50029216680000 1861800 DUCK IS UNIT SDI 3-33/K37 3-33 50029216680100 2032150 DUCK IS UNIT SDI 3-33A/J35 3-33A 50029217010000 1870200 DUCK IS UNIT SDI 3-35/L36 3-35 50029225540000 1950510 DUCK IS UNIT SDI 3-37/L35 3-37 50029217640000 1871160 DUCK IS UNIT SDI 3-39/139 3-39 50029217640100 1970910 DUCK IS UNIT SDI 3-39A/I37 3-39A 50029218780000 1881260 DUCK IS UNIT SDI 3-41/K39 3-41 50029224160000 1931700 DUCK IS UNIT SDI 3-43/P36 3-43 50029218110000 1880510 DUCK IS UNIT SDI 3-45/M39 3-45 50029215690000 1860640 DUCK IS UNIT SDI 3-47/Q35 3-47 50029217350000 1870600 DUCK IS UNIT SDI 3-49/140 3-49 50029217350200 1970570 DUCK IS UNIT SDI 3-49A/M40 3-49A 50029217359500 1950350 DUCK IS UNIT SDI 3-49AJ40XX 3-49AXX 50029217890000 1880220 DUCK IS UNIT SDI 4-02/Q28 4-02 50029219680000 1890860 DUCK IS UNIT SDI 4-04/T26 4-04 50029219680100 2090190 DUCK IS UNIT SDI 4-04A/T30 4-04A 50029217230000 1870430 DUCK IS UNIT SDI 4-06/Q32 4-06 50029217230100 1961660 DUCK IS UNIT SDI 4-06A/Q30 4-06A 50029216920000 1870080 DUCK IS UNIT SDI 4-08/P27 4-08 50029224640000 1940500 DUCK IS UNIT SDI 4-10/M28 4-10 50029224640100 2022380 DUCK IS UNIT SDI 4-10A/L28 4-10A 50029218630000 1881040 DUCK IS UNIT SDI 4-14/R34 4-14 50029218630100 2080120 DUCK IS UNIT SDI 4-14A/S-37 4-14A 50029218960000 1881490 DUCK IS UNIT SDI 4-18/S30 4-18 50029216400100 1861730 DUCK IS UNIT SDI 4-20/M35 4-20A 50029216400000 1861500 DUCK IS UNIT SDI 4-20/T34 4-20 50029218350000 1880720 DUCK IS UNIT SDI 4-26/034 4-26 50029218700000 1881110 DUCK IS UNIT SDI 4-28/N37 4-28 50029225590000 1950690 DUCK IS UNIT SDI 4-32/K38 4-32 50029227050000 1961550 DUCK IS UNIT SDI 4-34/038 4-34 50029224820000 1940740 DUCK IS UNIT SDI 4-38/K34 4-38 50029222650000 1920420 DUCK IS UNIT SDI 4-40/P43 4-40 50029217310000 1870560 DUCK IS UNIT SDI 4-42/P38 4-42 50029222540000 1920190 DUCK IS UNIT SDI 4-44/M44 4-44 50029222549500 1970470 DUCK IS UNIT SDI 4-44AM40XX 4-44AXX 50029219570000 1890690 DUCK IS UNIT SDI 4-46/N39 4-46 50029219720000 1890970 DUCK IS UNIT SDI 4-48/K43 4-48 50029219400000 1890440 DUCK IS UNIT SDI 4-50/K41 4-50 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. ,/~,'~/~ File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: n Poor Quality Original - Pages: n Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [~ Logs of various kinds ~ Other COMMENTS: Scanned by: Bevedy Mildred Dareth~Lowell TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha~Nathan,I)-owell Date: Is' MICROFILMED 7~30~02 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE Saved as M:/weepie/microfilm-marker'd°c ALASKA OIL AND GAS CONSERVATION COPl~I~SSION TONY KNOWLES, GOVERNOR 333 W. Tr" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 September 6, 2001 Fritz Gunkel, Manager Drilling BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519 Re: Cancelled or Expired PTD's. Dear Gunkel: 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 198-019 DATE February 25, 2000 Re: Expired Permit Action WELL: Duck Is Unit 3-21A/k35XX API# 50-029-21714-95 Permit Issued: 02/25/1998 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. 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. Steve McMains Statistical Technician TONY KNOWLE$, GOVEFtNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 February 25. 1998 Steve Shultz Engineering Supervisor BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Duck Island 3-21A/K-35 BP Exploration (Alaska) Inc. Permit No. 98-0019 Sur. Loc: 2758'NSL. 779'WEL. Sec. 8. T1 IN. RI7E. UM Btmhole Loc: 3662'NSL. 2344'WEL. Sec. 4. TI IN. R17E. UM Dear Mr. Shultz:' Enclosed is the approved application for permit to rcdrill the above rcfercnccd xvcll. The permit to rcdrill does not exempt you from obtaining additional permits required bx' law from other governmental agencies, and docs not authorize conducting drilling operations until all other required permitting determinations arc 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 thc Commission ma3' witness the test. Notice may be given bx' contacting the Commission petroleum field inspector on the North Chairman '~.~} '" BY ORDER OF THE COMMISSION dlf/Enclosure Department of Fish & Game, Habitat Section xv/o cncl. Department of Environmental Conservation w/o encl. /""--.. ;,---,, STATE OF ALAS~", /.-._.-~SKA .,_ AND GAS CONSERVATi,..,,,'-CCi.. :IsSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work C~] Drill I--IRedrill Ilb. Typeofwell I'"lExploratory [-I Stratigraphic Test I~ Development Oil [] Re-Entry [] DeepenI [] Service [] Development Gas [] Sin~lle Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 56' Endicott Field / Endicott Pool 3. Address 6. Property Designation P.O. Box 196612, AnChorage, Alaska 99519-6612 ADL 047503 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2758' NSL, 779' WEL, SEC. 8, T11N, R17E, UPM Duck Island At top of productive interval '~. Well Number Number 25100302630-277 2334' NSL, 2944' WEL, SEC. 4, T11N, R17E, UPM 3-21A/K-35 At total depth 9. Approximate spud date Amount $200,000.00 3662' NSL, 2344' WEL, SEC. 4, T11N, R17E, UPM 03/01/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 312828, 1618'I No Close Approach 2560 13947' MD / 10200' TVD 16. 'To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 12090' Maximum Hole Angle 53° Maximum surface 4055 psig, At total depth ('DVD) 9590' / 4900 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2-7/8" 6.4# L-80 STL 1886' 12061' 9736' 13947' 10200' 68 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 feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented M D TVD Structural Conductor Surface Intermediate Liner Production Perforation depth: measured0RIGINAL true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Chris West, 564-5089 Prepared By Name/Number: Kathy Campoamor, 564-5122 21' I hereby certify that t~is t'~;nd~ the best °f my kn°wledge Signed Steve'Shultz_ ~"...)~'f,¢</",,~ Title Engineering Supervisor Date Commission Use Only Permit N.umber I APl Number I Ap.~rovaI,D~ See cover letter ~<~- {~0t ¢{ 50- ¢.);t.~f- 2.1"/1~- O! ~"~ forother requirements Conditions of Approval: Samples Required []Yes [~No Mud Log Required -- []Yes [~No Hydrogen Sulfide Measures []Yes []No Directional Survey Required [~'Yes []No Required Working Pressure for BOPE []2M; E]3M; ,~5M; [] 10M; r-] 15M Other: Original Signeo by order of Approved By David W. J0hnst0r, Commissioner the commission Date Form 10-401 Rev. 12-01-85 Subm{ riplicate I Well Name: 13-21a/K-35 , Well Plan Summarg IType of Well {Producer or injector): Producer Well Design {Conventional, slimhole, etC.): TTRD SIDETRACK FSL FEL SEC TWP RNG Surface Location: 2758 778 8 11N 17E Tie in survey Location: 2078 3102 4 11N 17E Target 1 Location: 2334 2944 4 11N 17E Bottom Hole Location: 3662 2344 4 11N 17E IAFE Number: 1727018 I Estimated Start Date: 1/March/98 I Rig: I DOYON 15 I Operating days t° dri" and [12+3comp,otc: Formation Markers Well Bore: Formation Tops MD TVDSS EMW RESERVOIR PRESSURE KBE -56 Max surface pressure =4055 psi TOP WEST SAK TOP SEABEE/AYLYAK TOP SHALE WALL/TUFFS TOP HRZ BASE HRZ KOP 12,090 MD / 9702 TVDSS LCU 12,429 9900 KEKIKTUK - Top Flow 2B 12,459 9911 9.83 4900 psi @ 9590 TVDSS Top Flow 2A 13,568 10100 K-35 Target Base 2A 13,795 10160 TD 13,947 10,200 ,. RECEIVED Logging Program: I Logs: 3.75" Hole Curve and Tangent DPC Open Hole Cased Hole: MWD-GR Slim hole Quad Combo NA Casin,c/Tubinc. Pro!;Iram: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD 3.75 2.875" 6.4 L-80 STL 1886 12061/9736 13947/10200 TBG 4.5" 12.6 L-80 IBM 9462 38 9500/8867 3-21a/K-35 Drilling Permit Directional Plan #2 1/27/98 Cementing Program' · Hole Section Liner Size Depth Volume Cement Production 2.875" Liner from Cement from ± 68 Sxs Class 'G' 12,061 to 13,947 12,061 to 0.5% CFR 2 with 2.875" x 4.5" 13,947 0.7% Halad 344 liner hanger 0.1% HR-5 2 pps Super CBL Mud Program: Production Mud Properties: 13.75" hole section' LSND Depth Density Marsh Yield 10 sec LSR YP pH Fluid Flow (PPG) Viscosity Point 10 Min Loss Rate Gel Milling 9.5-10 150-180 50-60 8-16 8.5- <6 600 11-24 9.5 Intermediate 10.0 - 65 - 95 25 - 35 8 - 16 8.5 - < 5 600 10.2 11 - 32 9.5 Reservoir 10.2 - 45 - 65 16 - 24 4 - 10 7 - 11 8.5 - <4 250 10.4 9.5 Hazards/Concerns Pore pressure (__.8.6 - 9.4 ppg EMW) based on offset SIBHP. Lost Circulation due to overbalance in Flow sands. Differential sticking with overbalance situation. Excessive Torque to be combated with lubricant additions after testing. Maintain minimum YP of 25 #/100 sq ft WELLHEAD EQUIPMENT Casing Head: Casing Hanger: Tubinghead: X-mas Tree: IMcEvoy 13 3/8" X 13 5/8", 5M Flange SSH McEvoy Mandrel Hanger McEvoy 13 5/8",5M X 13 5/8", 5M Cameron 4-1/8",5M DIRECTIONAL STATS FOR 9 5/8" CASING ON 3-21aJK-35 IAverage Angle: Maximum Angle Maximum Dogleg Top of Cement 50 53° 37" @ 9570' 4.38°/100@4057' 3.41 °/100' @4157' 10607 (Calc. assuming 30% washout) Drilling Hazards DRILLING CLOSE APPROACH WELL SHUT-iNS After the sidetrack of the original 3-21a/K-35 well-bOre, there are not any wells which are a close approach. The clos~ is the original well 3-21/L-34 which quickly diverges from the sidetrack. This well will meet the deep intersection risk assessment. Close attention to the tolerance lines are necessary to avoid this well. See the TC plot for details. 3-21a/K-35 Drilling Permit Directional Plan #2 1/26/98 FEB 04 '98 0£:59PM BPX ENDICOTT DEVP ~ .... ~ p~st-lt~' br~-~.f, ax tran~ittal memo ' ~ R~ ~,, ~ ,w--[~ '~' ~""~:~ ~' ~°"~'~ --'T-- l"" ~?~ ~_~ _ J'"' ~- ~ . ! I 2,505' I ------ ] _._" 4-1/2' 12.6"'1t 13Cr80 SE CORR SION ~ ~ GAS LI~MANDRELS ( CAMCO NOTE~ U O ~ NO. TVD-SS MD-BRT _ S~ DEEPER THAN ORIGINALLY ~ [ ~4 7014' 8002' . PLANNED. UNDER CERTAIN GAS LI~ ~ ~ ~3 ~ ~45' 9161' =:CONDITIONS, THERE I~,A DANGER OF ~ ~2 ~ 8258' 10017' COL~PSING THE g-5/8 ~G. . [ [ ! ~1 .~; 8498' 1~00' / HES 'X' Nipple [ 11872 ' ' 12 045' - ' ' NIPPLE 12,006' -- I I ~ _ 4-1/2 XN Nipple I 1' 0~-' ~1 ! ~,~67' -I ~~ [' (HES) (3.725"~D) I " II ' ' ' ~'~~L/ ~,~" I ,~,o~=' I · ~~ ' WLEG ~ .... ~ ~ ~~ ELMDOFW 12,051' I REF: L~G: DLL-GR ii~~ TOC MO i-"i2 ~4I REF: LOG: PDK-GR (8/11/~) ** ~~j~ ...... ~ I '~ o .~cn I ......... ~-- .~,v,~ I '"~-- I ~ws 3-3/,~ 6' '[~3~;'-~=3~0' (s~z, ~;'i~~~MDTOP of ! ~,~' I 3-3/8- AWS 2-1/8' d 12400'-12482' (sqz) ' %_ .............. I 12 4~' 2-7/8" WLEG I 1~;646" II II I III1[ --. ~AT~ ~v. ~ COMMENTS ENDICOTT WELL 3-~1 / L-34 _.~ ~n/94 s~w ~wo 7/~/~ n,~ Sa;~:b~CMT ~ BP EXPLORATION, INC. I I ....... I I IIII CO. £IZE SPF INT~_~VAL .. AW$ 3-3/$~ 6 123~7'-12340' (~qz) AW~ 3-3/8' 6 1237~'-12386' AW~ 2-1/8 ~ d 12400' -12482 ' (sql) SOS 5' 5 12502'-12588' (sgz) SOS 5" 5 ~26~0'-~262~' (sqz) SOS 5" 5 12658'-Z27~0'(sqz) ~Ela 0 4 '~998 Gas Coas, Commission And'tomge FEB 04 '98 O3:00PM BPX ENDICOTT DEVP ' a/K-35 Proposed Completion (TTRD Sidetrack out of 7" Liner) P.2/~ 13-3/8" ~ sssv ~ ~,555' Mgl X NIpple 11872' MDi Tubing (3,958" ID) GAS LIFT MANDRELS NO. TVD-SS MD-BRT #~ IsT~r I 60~4' .4 1 70~4' I eo02' #3 1 77~'I #~ Is25s'I rL · · 9161' 10017' 10400' X Nip. p_le 12,006' MD (3.813" ID) "Mil/ecl out" XN Nipple @ 12,061' MD g-5/8" x 4-1/2" Production Packer @ 11,933' MD 4.172' x 2-7/8" Liner Hanger @ 12,006 MD of 7" Uner @ 12,045' MD End of 4-1/2" Tubing £$fimated TOG for £-7/8" b'ner @ I-:)b"casing @ 12T287' MDI IAngle@ ~KOP -- :~-.41 I ,.~Top of Through Tubing Whipstock -- KOP @_12.0~0' Mn I ~:~;~" hoi~l Cemented, Perforated Liner 12,006'-13,947 MD !TO;= ~%e47' MD I @ 7" Liner 12~920 MDJ ,,,DATE Chris West Squeezed Perforations 12,327'. 12,710' MD cE8 0 4 '~998 Alaska 0il & Gas Cons, CommOn Anchorage COMMENTS Proposed ~21~/K-35 TI-RD Sidetrack ! .... I Il [--- ' __ · ENDICOTT WELl. 3-21A/K-35 APl# 50-029-31714 'l~'P'~.z~lerati°-~ (Aia-s-ka)-' SUMMARY PRUCEDURE COMMENTS 1. The 9-5/8" x 4-1/2" production packer is a TIW permanent packer with a tubing seal assembly above. The packer and tubing will not be recovered. 2. The existing perforations have been plugged with cement. 3. This well will be sidetracked at app. 12,090 feet. PRE-RIG OPERATIONS 1. RU wireline, Pull the WL SSSV. Drift and dummy off gas lift mandrels. 2. RU and run coil tubing across perforations, and establish circulation. 3. Place sand to cover perforation to 12,300' MD. 4. Pump 31 sx of class G cement and circulate down the coil tubing. Displace to place cement (above sand back placed in step 2) from 12,150' to 12,300' MD AND at least 100' above top perf. Squeeze cement if possible up to 1500 psi. 5. Circulate the 4.5" tubing with 1.5 volumes of sea-water. Check that the well is dead. Freeze protect the top 200' with diesel. Set BPV. RIG OPERATIONS (SUMMARY) . , . . . . . 10. 11. 12. 13. 14. Mobilize Doyon 15. Review Endicott Simultaneous Operations Plan concerning rig moves. Check that the well is dead. If not circ well w/brine or milling fluid until dead. ND the tree, and NU the BOPE. Test the BOPE and pull BPV. (1/2 day) Pick up 2-7/8" Drillpipe and underreamer BHA, TIH to ¢leanout cement to 12,080'. POOH. Run and set 'IFRD Whipstock at · 12,080' MD. Displace seawater with drilling fluid (1/2 day). Cut TTRD window through both 7" and 9-5/8" casing. Pick up Sperry directional BHA to turn and build @ 8°/100 feet to 81° at appx 12,617' MD. Drill ahead as specified by the rig supervisor to CP at 13,947. POOH. (12 days) If there are hole problems, run a HO over whole interval and spot lubricant in OH section. POOH. Run a 2.875" solid liner from 12,061 to 13,947 MD with inner string, cement as per plan. (2 days). Test the tubing to 3500 psi. Test the packer and IA to 3500 psi. Make a clean out trip with bit and scraper and displace with KW Brine. Perforate with DPC based on intervals picked from the open hole logs. Pump Corrosion inhibitor. (1/2 day) Set the BPV. ND the BOPE, and NU the tree. Shear the RP valve and freeze protect the well. (1/2 day). 15. Turn the well over to Production. 3-21aJK-35 Drilling'Permit Directional Plan ~ 1/26/98 PORE PRESSURE / LL,~T CIt,,.,ULATION Production Interval (8.5"): The Kekiktuk Sands reservoir pressure may be slightly higher than normal AND VARIES GREATLY, but the Asset estimate of pore pressure of 4800 psi at 9590 TVDss should range from +_ 7.4 to 9.5 ppg EMW. The formation also has the potential for lost circulation (see Geologic Prognosis for faulting details). Lubricant additions (see above) should be utilized if torque and drag become troublesome, and after extensive testing of mud on location. Flex collars should be utilized in the BHA to minimize potential differential sticking. Liquid casing and OM seal should be on location to help combat severe lost circulation. NOTE: See-the Geologic Prognosis for a detailed description of the expected fault locations and sizes. Review the Pad Data Sheet for trouble highlights throughout MPI history. Well Control: Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Disposal Cuttings Handling: Fluid Handling: CC2A Annular injection is not available at Endicott for this well. Contacts Office Home Pager Drilling Superintendent Dan Stoltz 564-4922 349-6483 Sr Drilling Engineer Steve Shultz 564-5405 373-1657 Operations Drilling Engineer: Chris West 564-5089 345-4699 Production Engineer Mark Sauve 564-5407 279-9049 Reservoir Engineer Kim Coyne 564-5308 349-0226 Geologist: Evvy Goebel 564-5367 276-1045 Geophysicist: Steve Roberts 564-5911 348-0358 Sperry Sun Directional Gordon Hecht 563-3256 Sperry Sun MWD/LWD Jim Galvin 563-3256 349-2746 Baroid Dave Higbie 248-3511 345-0398 275-4570 275-1789 275-7530 275-1337 3-21aJK-35 Drilling Permit Directional Plan #2 1/26/98 Drilling Discussion General The 3-21a/K-35 well on MPI at Endicott will target the Kekiktuk in the 2A in accordance with the 1998 development plan. We will have to abandon the existing perforation in the 3-21/L-34 well by pumping cement down coil-tubing, setting a through tubing whipstock and kick off through the 7" casing to the K-35 BHL utilizing the 2.875" liner design. We will not pull the existing production packer or tubing in this well. The 2.875" liner length will be _+ 1886 feet, with the top of the liner hanger back into the 4.5" production tubing. The existing 6 valve (ultra)slimhole (4.5" x 1.5" for 9.625" casing) GLM design for the completion on a 4.5" L-80 tubing design with a X/XN nipple profile. Directional Plan: The directional plan for the 3-21a/K-35 well consists of kicking off with a whipstock and conventional BHA's fOr the Kekiktuk Flow sands. Current plans call for up to 8°/100' doglegs in this section, but this may be adjusted pending results during the drilling process. After sidetracking, drilling the tangent at 81° degrees, and steering directionally back into the Sands with 74° of inclination, the well will be drilled to _+13,947 MD (10,256' TVD). Ensure that any and all tolerance lines are not crossed to avoid policy violations. Please coordinate this through both the Operations Drilling Engineer and the Endicott Drilling Superintendent. There are not any known close approaches which require wells be shut in. Any BHA's indicating less than required BUR should immediately be pulled for a more aggressive assembly. Recommended BHA's All motors should NOT be jetted to account for the proposed flowrate and motor performance. Hole conditions and directional objectives should dictate actual flowrates. As mentioned previously, flex collars should be utilized in the 8.5" hole sections to minimize potential differential sticking. We will be using bent housing motors with either 7/8 for a roller cone or 5/6 rotor/stator configurations for PDC bits IF run. Sperry proposed BHA's are attached, however the actual BHA with motor design, MWD/LWD tool configuration, MWD battery life, bit hydraulics will be discussed at the daily wellsite meeting. Directional Survey Program The survey program for 3-21a/K-35 calls for use of Sperry's SOLAR MWD surveys the entire well. Because of Sperry's standard practice of changing the MWD probes after every bit run, an electronic single shot (ESS) will not be needed, and a gyro is not warranted. Close attention to JORPS is required, with the use of checkshots and survey data validation. Bit Program We will kick off the in the HRZ with a conventional directional BHA and PDC bit, which should make it to the Kekiktuk. After milling the window, a 3.75" tangent section is planned to the Kekiktuk. The penetration rate will vary due to the variable lithology, but these bits have proven durable enough to drill through most of this interval. However, if there is any indication of bit failure such as torque spikes, the bit should be pulled at the descretion of the rigsite team. Recommended Jet Sizes Expected Interval Bit Type Flowrate HSI Casing Section Standard Window Mills 90 - 120 gpm 3.75" Kickoff STAR 09 90 - 120 gpm 3 x 12 2.9 - 4.8 3.75" Tangent PDC Bit 90 - 120 ~lpm 3 x 15 2.9 - 4.8 3-21a/K-35 Drilling Permit 1/26/98 Directional Plan #2 NOTE: Real time rigsite information such as condition of bits previously pulled, hole conditions, drilling fluids, downhole motor constraints (if any) will be instrumental in actual final bit selection. Mud Program: We will use LSND on this well to both mill the window and drill to TD. There should not be any additions of any lubricants in this well without extensive testing of the actual fluid on location. A new Gel/Biozan polymer will be used for milling the window. Ditch Magnets should be used and WEIGHED to ensure metal cuttings removal. Rheology control can be maintained using Gel and Biozan polymer. At this time raise the LSR YP to the recommended range using Biozan. Biozan sweeps should be pumped to assist in hole cleaning and to prevent the build up of cuttings beds. Mud sweeps are essential for good hole cleaning while drilling. Additions of 3#/BBL each of Baranex and Barotrol should be maintained throughout this well. This treatment should result in an HPHT of <14 which is our target. Maintain the pH in the 9-9.5 range using caustic soda. If torque problems arise, a treatment of 1- 2% Lubetex should be used. If the torque persists, the ERD lubricant mix should be evaluated. The LSND mud will be taken to TD on this well. Maintain the weight at the density required in the intermediate section. The Barotrol and Baranex treatments should be maintained at 3#/bbl untill the ICP. The APl filtrate should be reduced to the 4 cc range with PAC and starch. This will reduce the chances of differential sticking and reduce filtration invasion. Tripping Practices / Stuck Pipe / Hole Cleaning Tripping should be undertaken with caution due to swabbing possibilities with high viscosity fluids in the tight annular clearance. The bottom hole pressure is approximately 4800 psi (7.4 to 9.5 ppg ). It is recommended that mud weights be maintained in the 10.2 to 10.4 ppg range to control the hydrocarbon intervals, maintain shale stability and minimize the possibility of differential sticking. Faulted intervals may require additions of LCM prior to tripping to insure that the hole remains full at all times. Keep the pipe moving and have an ample supply of lost circulation materials on hand. Baroid recommends utilization of Iow viscosity sweeps to assist with hole cleaning and to minimize the formation of cuttings beds on the Iow side of the hole. No potential hazardous levels of H2S are anticipated in the 3-21a/K-35 well. There have been H2S reading on offset SDI wells of over 1000 ppm. Ensure rig gas detectors are calibrated prior to N/D tree and/or circulating to kill the well. 3-21a/K-35 Drilling Permit Directional Plan #2 1/26/98 Logging Program: Logs: 3.75" Hole Curve and Tangent MWD-GR DPC logs In open hole Slim hole QUAD Combo Cased Hole: NA Sample catchers and a wellsite Geologist are planned to be used while drilling reservoir. Casing and Cementing This TTRD sidetrack will require a 2.875" 6.4# L-80 liner to be run across the entire interval. This will be hung off in the 4.5" tubing at 12,061 feet. Ensure that prior to running liner that the hole is in good condition and that the mud has been conditioned to run casing. Before POH to run liner spot lubricant across the open hole section. If this is considered essential to getting the pipe to bottom ensure that adequate lubricant testing has been performed prior to doing this. Also, consideration must be given to a hole opener trip prior to running liner if hole conditions suggest that there may be problems running pipe. This liner will use STL connections to allow rotation and reciprocation. Special equipment will be required for this including XO for safety valve and having the liner hanger cut with a STL connection on bottom. The liner should be filled every 5 joints, and circulated prior to going into open hole. Any problem intervals identified while drilling, such as ledges, will require special care while running casing through. The liner will require 1 straight blade centralizers on every other joint to the window. If the liner starts to packoff in the open hole, establish circulation and try to wash through. Do not continue to run casing without circulation. If necessary, we will pull casing and make a wiper trip prior to running the liner. The liner running procedure in the detail section should be reviewed. The cementing program is designed place cement to at least1000 feet above the top of the Kekiktuk formation, or to the liner hanger. The approximate volume will be 68 sacks of Class 'G' with additives as speficied in the casing detail section. Cementing operations at Endicott are continue to be critical with the advancement of both the waterflood and gas fronts. Close attention to detail for this part of the well is critical for the economical success of our drilling program. DPC Perforating This sidetrack well will require a DPC perforating across the intervals picked from LWD logs. 3-21a/K-35 Drilling Permit Directional Plan ~¢2 1/26/98 SDI WELL ,3-21A / K-35 (Wp2) - SURFACE & DOWNHOLE LOCATIONS 1/27/98 ITEM NAME COMMENTS ALASKA STATE PLANE ZONE 3 (NAD 27) I DECIMAL DEGREES (NAD 27) S & E SEC LINE OFFSETS SECTION, TOWN., i NEAREST SECTION LINE OFFSETS NO. Y Xt LATITUDE (N°) LONGITUDE (VV~) FSL FEL RANGE, UMIAT, AK I DIST. !LINE DIST. LINE I SDI 3-21A/K-35 Surface @ SDI Surface Location 5,970,975.92' 270,263.25' I 70.322326° 147.862886° 2758 778 SEC 08 T11N R17E I 2521 N 778 E 2 SDI 3-21A/K-35 MD:12090.00 Tie In Point 5,975,484.68' 273,345.46'! 70-334895° 147.839014° 2078 3102 SEC 04 T11N R17E ! 2078 S 2177 W 3 SDI 3-21A/K-35 MD:12459.48 TFU2B-Top of Kekituk 5,975,735.39' 273,510.24' ! 70.335593° 147.837739° 2334 2944 SEC 04 T11N R17E ! 2334 S 2335 W 4 SDI 3-21A/K-35 MD:13947.00 TD/ 2 7/8" Liner 5,977,.045.28' 274,146.77' 70.339222° 147.832897° 3662 2344 SEC 04 TllN R17E I 1617 N 2344 E Notes: Coordinates shown are North American Datum 1927 (NAD 27). · .~ F. Robert Bell & Assoc. Jeff Cotton 564-4969 File Name: DIUBH127.xls 1/27/98 NW Sec 5 T11N R17E Umiat X=265980.55 ¥=5978913.24 NW Sec 8 SW Sec8 T11N R17E Umiat X=265688.10 Y=5968357.70 528O 91o46'08,, N Sec 5&4 528O 91o46'07" 3-2~/K-35 "3-21" SURFACE LOCATION X=270263.25 Y=5970975,92 N Sec 8&9 5280 271o46'06'' 5280 91 °43'42" M D 12459.48 Top Of Kekituk . X=273510.24 / Y=5975735.39 / ~. / MD12090.00 / Tie In Point X=273345.46 528O 271o43'40· S Sec 8&9 N Sec 4&3 MD13947.00 2 7/8" Liner (TTRD) X=274146.77 Y=5977045.28 N Sec 9&lb S Sec 9&10 528O 91o41'17'' 5280 91o41'16" 528O 271o41'16" NE Sec 3 T11N R17E Umiat X-281812.67 Y:5978435.49 SDI Well 3-21/K-35 Wp2 Downhole L-.ocation Scale: 1": 2000' 1/27/98 Jeff Cotton NE Sec 10 SE Sec 10 T11N R17E Umiat X=281520.22 Y=5967880.08 528O 91 °46'08" N Sec 5&4 T11N R17E Umiat 528O 91 °43'42" N Sec 8&9 T11N R17E umiat 528O 91o46'O7" 2935 2335 MD12459.48 Top Of Kekituk X=273510.24 Y=5975735.39 2177 MD12090.00 Tie ln Point X=273345.46 Y=5975484.68 II II MD13947.00 2 7/8" Liner (TTRD) X=274146.77 Y=5977045.28 N Sec 4&3 5280 T11N R17E Umiat 91 °41'17" N Sec 9&10 T11N R17E Umiat 5280 91o43'42" 5280 91o41'16" Shared Services Drilling I DriHQuesr 6200 - 6000 - 5800 - 5600 - '- 5400- '1~ o Z 5200 - 5000 - 4800 - Scale: linch = 200ft Eastings 2800 3000 3200 3400 3600 3800 .. I I ' I I I I 2 7/8" Liner (TTRD) - 13947.00 MD, 10256.00 TVD f .... P¥6~0sa-g~-Target 'Summary Target Name: TVDss: TVDrkb: Wellhead Offscls: Global Coordinates: 1 3-21A/K-3~(TOP2A) 10100.00 10156.00 5855.18N, 3539.87E 5976720.00 N, 273980.70E ~ z~ 3. usr~ 4600 - I I 280O 3000 Scale:linch = 200ff 1015e.00 ~ 6865.18 N, 3,530.87 E 10000.013 1o3°°.%~,~ / I 3200 Eastings I 3400 - 6200 - 6000 - 5800 - 5600 5400 - - 5200 - 4600 I I 3600 3800 Re~mnceis Tme Nodh - 4800 - 5000 Shared Services Drilling Proposal Target Summary Target Name: TVDss: TVDrkb: Wellhead Offsets: 3-21A/K-35 (TOP 2A) 10100.00 10156.00 5855.18 N, 3539.87 E I Global Coordinates: 5976720.00 N, 273980.70 E SURFACE LOCATION REFERENCE ~ PLOT DATE: 17 - Dec - 1997 Horizontal Coordinates: RKB Elevation: Coordinate System: 5970975.92 N, 270263.25 E i 41.50ft Rig(EST)'CreatedBy: ~ ~,~j 14.50 ft Well (CBE) 56.00 ft RKB - AMSL Checked By: NAD27 Alaska State Planes, v , Zone 3, US Foot Proposal Data for 3-21a/K-35 Wp2 Vertical Odgin: Well Horizontal Odgin: Well Measurement Units: ft North Reference: True North Dogleg Sevedty: Degrees per 100ft Vertical Section Azimuth: 25.420' Vertical Section Description: KOP Vertical Section Origin: 4600.92 N, 2942.79 E Measured Incl. Azim. Vertical Northlngs Eastings Vertical Dogleg Depth Depth Section Rate i 12090.00 41.423 38.696 9758.48 4600.92 N 2942.79 E 5418.68 12120.00 43.515 36.954 9780.61 4616.92 N 2955.21 E 5438.46 8.000 12617.71 81.604 23.405 10006.58 4995.13 lq 3164.50 £ 5869.89 8.000 [N~ 13389.37 81.604 23.405 10119.25 5695.70 N 3467.74 E 6632.80 0.000 , X.,.~o.oo 13568.34 74.687 25.292 10156.00 5855.18N 3539.87 E 6807.81 4.000 I '~ ~ 13947.00 74.687 25.292 10256.00 6185.39 bl 3695.91 E 7173.03 0.000 IN 9750-] ,~oo ' ~ ~00 ................................................. l. cu 10000- 10250 - - 13947.00, 10256.00 TVD 10500- I I I I I I I I 5375 5625 5875 6125 6375 6625 6875 7125 Scale: linch = 250ft Vertical Section section Azimuth: 25.420° (True North) Sperry-Sun Drilling Services Proposal Report for 3-2lA~K-35- 3-2la~K-35 Wp2 Shared Services Drilling Endicott Alaska State Plane Zone 3 Endicott SDI Measured Vertical Depth Incl. Azim. Depth Northings Eastings (ft) (ft) (ft) (ft) Vertical Dogleg Section Rate (ft) (°/lOOft) 12090.00 41.423 38.696 9758.48 4600.92 N 2942.79 E 12120.00 43.515 36.954 9780.61 4616.92 N 2955.21 E 12617.71 81.604 23.405 10006.58 4995.13 N 3164.50 E 13389.37 81.604 23.405 .10119.25 5695.70 N 3467.74 E 13568.34 74.687 25.292 10156.00 5855.18 N 3539.87 E 13947.00 74.687 25.292 10256.00 6185.39 N 3695.91 E 5418.68 5438.46 8.000 5869.89 8.000 6632.80 0.000 6807.81 4.000 7173.03 0.000 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Nodhings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 25.420° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13947.00ft., The Bottom Hole Displacement is 7205.47ft., in the Direction of 30.859° (True). Formation Tops Measured Depth (ft) Vertical Sub-Sea Depth Depth Northings Eastings (ft) (ft) (ft) (ft) 12429.82 9956.00 9900.00 4832.12 N 3087.22 E 12459.48 9967.00 9911.00 4856.64N 3099.78 E 13795.53 10216.00 10160.00 6053.31 N 3633.49 E Formation Name LCU TFU2B Base K2A Casing details From Measured Vertical Depth Depth (ft) (ft) <Surface> <surface> To Measured Vertical Depth Depth (ft) (ft) 13947.00 10256.00 Casing Detail 2 7/8" Liner (TTRD) Targets associated with this wellpath Target Name K-35 Mid Poly (T2A) K-35 Polygon (3-21A~ Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 10156,00 5855.18 N 3539,87 E 56.00 5796.15 N 3703.06 E Target Shape Point Polygon Target Type Geological Geological 17 December, 1997 - 10:02 - ~ - DrillQuest Sperry-Sun Drilling Services Proposal Report for 3-2IA~K-35 - 3-2Ia~K-35 Wp2 Shared Services Drilling Endicott Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 12090.00 41.423 38.696 9702.45 9758.45 12100.00 42.117 38.100 9709.94 9765.94 12120.00 43.515 36.954 9724.61 9780.61 12200.00 49.524 33,914 9779.84 9835.64 12300.00 57.126 30'.802 9839.33 9895.33 12400.00 84.793 28.186 9887.85 9943.85 12429.82 67.088 27.473 9900.00 9956.00 12459.48 69.374 26.787 9911.00 9967.00 12500.00 72.501 25.882 9924.23 9980.23 12600.00 80.233 23.767 9947.79 10003.79 12617.71 81.604 23.405 9950.58 10006.58 12700.00 81.604 23.405 9962.60 10018.60 12800.00 81.604 23.405 9977.20 10033.20 12900.00 81.604 23,405 9991.80 10047.80 13000.00 81.604 23.405 10006.40 10062.40 13100.00 81.604 23.405 10021.00 10077.00 13200.00 81,604 23.405 10035.60 10091.60 13300.00 81.604 23.405 10050.21 10106.21 13389.37 81.604 23.405 10063.25 10119.25 13400.00 81.193 23.5i5 10084.84 10120.84 13500.00 77.327 24.560 10083.48 10139.48 13568.34 74.687 25.292 10100.00 10156.00 13600.00 74.687 25.292 10108.36 10184.36 13700.00 74.687 25.292 10134.77 10190.77 13795.53 74.687 25.292 10160.00 10216.00 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (o/~ooft) (ft) 4600.99 N 2942.75 E 5978484.68 N 273345.46 E 5418.73 4606.14 N 2946.93 E 5975489.70 N 273349.80 E 8.000 5425.17 4616.92 N 2955.21 E 5975500.22 N 273358.40 E 8.000 5438.46 4684.23 N 2988.77 E 5975546.48 N 273393.40 E 8.000 5495.60 4731.98 N 3031.57 E '5975612.88 N 273438.25 E 8.000 5575.15 4808.04 N 3074.51E 5975687.60 N 273483.50 E 8.000 5662.29 4832.12 N 3087.22 E 5975711.27 N 273496.94E 8.000 '5689.49 4856.84N 3099.78 E 5975735.39 N 273510.24 E 8.000 5717.02 4890.96 N 3116.76 E 5975769.18 N 273528.27 E 8.000 5755.31 4979.10 N 3157.50 E 5975856.03 N 273571.69 E 8.000 5852.41 4995.13 N 3184.50 E 5975871.84N 273579.17 E 8.000 5869.89 5069.84N 3196.84E 5975945.52 N 273613.78 E 0.000 5951.25 5160.62 N 3236.14 E 5976035.06 N 273655.84E 0.000 6050.11 5251.41 N 3275.43 E 5976124.61N 273697.90 E 0.000 6148.98 5342.20 N 3314.73 E 5976214.15 N 273739.96 E 0.000 6247.85 5432.99 N 3354.03 E 5976303.69 N 273782.02 E 0.000 6346.71 5523.78 N 3393.33 E 5976393.23 N 273824.07 E 0.000 6445.58 5614.56N 3432.62 E 5978482.78 N 273866.13 E 0.000 6544.45 5695.70 N 3467.74 E 5976562.80 N 273903.72 E 0.000 6632.80 5705.34N 3471.93 E 5976572.31N 273908.20 E 4.000 6643.31 5795.06 N 3511.93 E 5976660.76 N 273950.93 E 4.000 6741.51 5855.18 N 3539.87 E 5976720.00 N 273980.70 E 4.000 6807.81 5882.80 N 3552.92 E 5976747.20 N 273994.59 E 0.000 6838.35 5970.00 N 3594.13 E 5976833.10 N 274038.44E 0.000 6934.80 6053.31N 3633.49 E 5976915.17 N 274080.34E 0.000 7026.94 Comment LCU TFU2B Target: K-35 Mid Poly (T2A), Geological Base K2A Alaska State Plane Zone 3 Endicott SDI Continued.** December, 1997 - 9:52 - I - DrillQuest Sperry ..,..Sun ,Drilling Services P, roposal~R~.P.o, rt for,,$-21A/K-35- 3-2Ia~K-35 Wp2 · .. Shared Services Drilling Endicott Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 13800.00 74.687 25.292 10161.18 10217.18 13900.00 74.687 25.292 10187.59 10243.59 13947.00 74.687 25.292 10200.00 10256.00 6057.20 N 3635.33 E 5976919.00 N 274082.30 E 0.000 7031.25 6144.41 N 3676.54 E 5977004.91 N 274126.16 E 0.000 7127.70 6185.39 N 3695.91 E 5977045.28 N 274146.77 E 0.000 7173.03 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 25.420° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13947.00ft., The Bottom Hole Displacement is 7205.47ft., in the Direction of 30.859° (True). Comment 2 7/8" Liner (TTRD) Alaska State Plane Zone 3 Endicott SDI 17 December, 1997 - 9:52 - 2 - DrillQuest VENDOR Al ASKAST 14 OO DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 010598 C~0i0598E i00. 00 i00. 00 HANDLING INST' s/h kathg campoa~oe x 5i~ mE A~AC~D CHECK IS IH PAYME~ FOR mm m~RIBED *~. ~(elf!ll ~ 1 uu~-uu~' OO STATE OF ALASKA ' ALASK/,._~ L AND GAS CONSERVATION CO~.~ISSION APPLICATION FOR SUNDRY APPROVAL Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Vadance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6.6!2 4. Location of well at surface 2522' SNL, 779' WEL, SEC. 8, T11N, R17E, UPM At top of productive interval 2980' SNL, 2888' WEL, SEC. 4, T11 N, R17E, UPM At effective depth 2837' SNL, 2762' WEL, SEC. 4, TllN, R17E, UPM At total depth 2795' SNL, 2718' WEL, SEC. 4, TllN, R17E, UPM Type of well: [] Development l-q Exploratory F-~ Stratigraphic I--] Service 6. Datum Elevation (DF or KB) KBE = 55.13' 7. Unit or Property Name Duck Island Unit/Endicott 8. Well Number 3-21/L-34 9. Permit Number 87-33 10. APl Number 50-029-21714 11. Field and Pool Endicott Field / Endicott Pool 12. Present well condition summary Total depth: measured 12920 feet true vertical 10363 BKB feet Effective depth: measured 12833 feet true vertical 10301 BKB feet Casing Length Size Structural Conductor 122' 30" Surface 2466' 13-3/8" Intermediate 12248' 9-5/8" Production Liner 875' 7" Plugs (measured) Junk (measured) Driven 3302 c.f. Permafrost 575 c.f. Class 'G' Cemented 161' 2505' 12287' 315 c.f. Class 'G' TVD BKB 161' 2503' 9906' 12045'-12920' 9724'-10363' Perforation depth: measured true vertical ~-12340', (Open) 12378'-12386', 12400'-12482', 12502'-12588'; 12610'-12624'; 12658'-~0' (All squeezed) (Subsea) 9'~82'-9889', (Open) 9917'-9923', 9934'-9994', 10008'-10070'; 10086'-10096; 10120'-10158' (All squeezed) Tubing (size, grade, and measured depth) 4-1/2" 12.6# 13CR80 to 12073' Packers and SSSV (type and measured depth) 4-1/2" 'HXO' SVLN at 1555'; 7" WD Packer at 12630'; 9-5/8" TIW 'HBBP' Packer at 11933' 13. Attachments [~ Description summary of proposal E] Detailed operations program E] BOP sketch 14. Estimated date for commencing operation December 24, 1997 116. If proposal was verbally approved Name of approver Contact Engineer Name/Number: Chris West, 564-5089 Date approved 15. Status of well classifications as: ¢;;(] Oil I--I Gas I--] Suspended Service 0RI61NAL Prepared By Name/Number: Kathy Campoarnor, 564-5122 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed .~ SteveShultz ..~/}__. _~_~ ~ {~)~,~.'- ¢. (~k-.¢'~- Title Senior Drilling Engineer Commission Use Only Date I Approval No. ;onditions of Approval: Notify Commission so representative witness Plug integrity t.,/" BOP Test ~ Location clearance Mechanical Integrity Test Subsequent form require(;[,,,10- ORIGINAL SIGNED BY ~,~.~6 ~v ~9,~~' omm~ss~oner Approved by order of the Commission Robert N. Chdstensgt! ! ~.e ~_,.,. Cf.~C~ ' ' Form 10-403 Rev. 06/15/88 Date/~ Submit In Triplicate · WELL PERMIT CHECKLIST COMPANY FIELD & POOL ~ ;)~ 13[ (~ O INIT CLASS ~ ~0 . WELL NAME ~1 (,J,- ~-),Jf)/l<~-.~ ~'- PROGRAM: exp [] dev ~l['redrll J~r'serv [] wellbore seg [] ann. disposal para req [] !"~ &dl - t~ '~ ~. GEOL AREA ~ c~ ~ UNIT# ! 0 %/-~'''' ~ ON/OFF SHORE 0/-/q,, ADMINISTRATION 2, 3. 4. 5. 6. 7. 8. 9. 10. 11. DATE , 12. Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. _(~ N Well located in a defined pool .................. ..~ N Well located proper distance from drilling unit boundary .... { N Well located proper distance from other wells .......... ! N Sufficient acreage available in drilling unit ............ ~N If deviated, is wellbore plat included ............... *. N Operator only affected party ................... ) N Operator has appropriate bond in force ............. ,( N Permit can be issued without conservation order ........ ¢ N Permit can be issued without administrative approval ...... N Can permit be approved before 15-day wait ........... N REMARKS ENGINEERING 14. Conductor string provided ................... Y N "~ ~ 15. Surface casing protects all known USDWs ........... Y N ~ ~ / 16. CMT vol adequate to circulate on conductor & surf csg ..... Y N 17. CMT vol adequate to tie-in long string to surf csg ........ N 18. CMT will cover all known productive horizons .......... N 19. Casing designs adequate for C, T, B & permafrost ....... N 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... N -~c~ 7 --,~.-~' ~' 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 'N 25. DOPEs, do they meet regulation ...... ~N 26. DOPE press rating appropriate; test to ~'~' ' I~sigl(~ N 27. Choke manifold complies w/APl RP-53 (May 84) ..... '... N ~.,~ / 28. Work will occur without operation shutdown ........... N 29. Is presence of H2S gas probable ................. N GEOLOGY A~ DATE 30. Permit can be issued w/o hydrogen sulfide ~ N 31. Data presented on potential overpre~.~ones ....... Y N 32. Seismic anal~one, s. ............ .Y. N 33. Seabed condi~y (if off-shore) ............ Y N 34. Co ame/phone for we.eklyj3ro~ress reports ....... Y N lexpmra~ory only] RPC ~ BEW~?_./¢ DWJ~ - JDH (..~ RNC~ CO ~'/1~(~ Comments/Instructions' HOW/lit - A:\FORMS\chekhst rev 09/97