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Home My WebLink About195-035 • I Post Office Box 244027 Anchorage,AK 99524-4027 Ilileorp Alaska,LLC JUL 3 V 201'. 3800 Centerpoint Drive Suite 100 Anchorage,AK 99503 AOGCC Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission Q 3`- 333 West 7th Avenue, Suite 100 f}x Anchorage, AK 99501 SGANNe� 01 X0/6 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 "I" 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 4-20/134" (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_WeIINo PermitNumber WellName WellNumber 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 3-33/1<37 3-33 50029216680100 2032150 DUCK IS UNIT SDI 3-33A/J35 3-33A 50029217010000 1870200 DUCK IS UNIT SDI 3-35/136 3-35 50029225540000 1950510 DUCK IS UNIT SDI 3-37/L35 3-37 50029217640000 1871160 DUCK IS UNIT SDI 3-39/J39 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/J40 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 4-38/1<34 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. (~-- 0 ~'~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~ TO RE-SCAN Vincent Nathan Lowell Date: Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: /si Memorandum State of Alaska Oil and Gas Conservation Commission To' Well File: Duck Is Unit 3-49A/J40 Permit # 195-035 Cancelled Permit Action Duck Is Unit 3-49A/J40XX APl # 029-21735-95 August 31,2001 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 name for a cancelled or expired permit is modified with an appended xx. These procedures are an addendum to the APl numbering methods described in AOGCC staff memorandum "Multi-lateral (wellbore segment) Drilling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. 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) Steve McMains Statistical Technician oN oR BEFO STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM~;sSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: . Abandon x Suspend Alter casing __ Repair well Change approved program Operation Shutdown .... Re-enter suspended well Plugging ~ Time extenslon~ Stlmulate.~ Pull lubing Variance ~ Perforate __ Other ~ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2499'SNL, 610' WEL, Sec. 8, T11N, R17E At top of productive interval 5058' SNL, 2753' WEL, Sec. 3, T11N, R17E At effective depth 5. Type of Well: Development Exploratory Slratigraphic Service RECEIVED 6. Datum elevation (DF or KB) KBE = 55.15 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-49/J-40 SDI 9. Permit number 87-6O 10. APl number 50- 029-21735 4991' SNL, 2222' WEL, Sec. 3, T1 ln, R17E At total depth 4982'SNL, 2142' WEL, Sec. 3, T11N, R17E 12. Present well condition summary Total depth: measured MAR 1 4 1995 Effective depth: Casing Structural Conductor Sudace Intermediate Production true vedical measured true vertical Length 122 2476' 14681' feet 11. Field/Pool Alaska 0ii & Gas Cons C0mrn/ssi0n Endicott Oil P~ool ~ A,uhora-'~ / % ,\ / 10518 BKB feet Sizo Cement d Moasured lm~.g~di~l d~pth 30" Driven ~ ~61' 161' 133/8" 3495c. f. Per.rest ~ 2515' 2514', 9 5/8" 860 c.f. Class ~ 14720' 10037 Liner 1177' 7" 425c. f Class G 14473'- 15650' 9910'-10518 Perforation depth: measured 14840'- 14886'; 14900'- 14910'; 14966'- 15040'(plugged off) 15050'- 15070'(plugged off) true vertical (Subsea) 10044'- 10067'; 10075'- 10080'; 10109'- 10148~ (plugged off); 10153'- 10164'(plugged off) Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 TDS tubing with 3 1/2" tailpipe to 14528' Packers and SSSV (type and measured depth) 9 5/8" Packer at 14415'; 7" WD Packer at 14923'; 4 1/2" SSSV at 1524' 13. Attachments Description summary of proposal × Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 3/20/95 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,'~,,~ ~""~,.~'~_...~ . '~--'/'~-~.J"' Title Drillin,cj En,cjineer Supervisor FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test__ Location clearance __ Mechanical Integrity Test__ Subsequent form required 10- J Approval NO. ~,._,,~-_ 0~/ Approved by order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ALAS OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVEI~NOI~ 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (g07) 279-1433 FAX: (907) 276-7542 March 23, 1995 Bob Laule Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Duck Island Unit/Endicott 3-49/J-40A BP Exploration (Alaska), Inc. Permit No: 95-35 Sur. Loc. 2781'NSL, 610'WEL, Sec. 8, TllN, R17E Btmhole Loc. 1377'NSL, 198'WEL, Sec. 4, TllN, R17E, UM Dear Mr. Laule: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrili 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) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at David W. Johnston ~ - ~hair~a~ / BY ORDER OF T O SSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] RedrilllTlllb. Type of well. Exploratory ['-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-11 Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration BKB=56 feet Endicott Field/Endicott Pool i3. Address 6. Property Designation P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 47503 4. Location of well at surface ,7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 2781'NSL, 610' WEL, SEC. 8, T11N, R17E Duck Island Unit/Endicott At top of productive interval 8. Well number Number 1171'NSL, 197' WEL, SEC. 4, T11N, R17E 3-49/J-40A 2S100302630-277 At total depth 9. Approximate spud date Amount 1377' NSL, 198' WEL, SEC. 4, T11N, R17E 3/26/95 $200,000.00 12. Distance to nearest 113. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD andTVD) property line ADL 47502-5082' feet No close approach feet 2560 13779' MD/10196' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 10200 feet Maximum hole angle 6o o Maximum surface 3900 psig At total depth (TVD) 10000'/4890 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 29# L-80 BUTT 3062' 10000' 7631' 13779' 10196' 253 sx Class "G" "i'C""'"D K; I:lVE Mi R 20 995 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary ^nch0ra~e Total depth: measured 15650 feet Plugs (measured) Plug set in WD Packer @ 14923' true vertical 10518 feet Effective depth: measured 15555 feet Junk (measured) true vertical 10468 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 122' 30" Driven 161' 161' Surface 2476' 13-3/8" 3495 cuff PF 2515' 2514' I nte rm e d i ate 14681' 9-5/8" 860 cu ft "G" 14720' 10037' Production L i n e r 1177' 7" 425 cuft "G" 15650' 10518' Perforation depth: measured 14840'-14886', 14900'-14910', 14966'-15040', 15050'-15070'(Squeezed) true vertical 10044'-10067', 10075'-10080', 10109'-10148', 10153'-10164'(Squeezed) 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed reportl-I 20 AAC 25.050 requirementsl-I 21. I hereby certify t~t the foregoing is true and correct to the best of my knowledge Signed /~'¢;~_--¢'~.~ Title Drilling Engineer Supervisor Commission Use Only / ' Permit Number APl number Approve/date See cover letter ~--,~,~ 50-0.2_?----~-,/~'~--~/ -~"¢~"""' ¢'~,~"' for other requirements Conditions of approval Sampled [] Yes :Ii~NO Mud Icg required []Yes .J~ No Hydr~easur~Ye_s []~i~-~i.f.e~tional survey required ,1~ Yes [] No OR~wo~g ~~ 1-13~; ,5M; I'-I10M; I-I15M; by order of e,~,~/~_,,.~ Approve~.~ ,/= _ . Commissioner tne commission Dat Form 10-401 Rev. 12~5 ,~ Submit l Well Name: [ 3-49/J-40A Redrill Plan Summary I Type of Redrill (producer or injector): I Producer Surface Location: 278 I'-FSL 610 FEL S08 TIIN P~17E UM Target Location: 1171 FSL 197 FEL S04 T1 IN R17E UM Bottom Hole Location: 1377 FSL 198 FEL S04 T11N R17E UM I AFE Number: [727002 I Estimated Start Date: 1 3-26-95I I Rig: [DOYON 15 IOperating days to complete: 24 ITVD: I10196 I IKBE: 156 I1VID: I13779 I I Well Design (conventional, slimhole, etc.): I CONVENTIONAL SIDE TRACK Objective: 3A3S and 3A2S PRODUCER 9996TVD/10066TVD Top Tuffs 12,26 i'MD 9131' TVD Top HRZ 13,081 MD 9706' TVD Top Put River 13,465'MD 9976 TVD Top Kekiktuk 13,494' MD 9996TVD MILLING FLUID Program: A 10.20 ppg Biozan polymewater based FLUID will be used. ISpecialconsiderationsdesign [ 10.2PPG BIOZAN POLYMER WATERBASE Depth Density PV YP INT 10MIN FL OIL SOLIDS (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) KOP' 10.2 50 20 30 6 0 to to to to to to to to to END 10.2 60 30 40 8 0 OD KOP Mud Program: A 10.20 ppg Biozan polymer/KC1 water based mud will be used. RECEIVED Special design considerations J 10.2PPG WATERBASE MAR 2 0 1995 I Alaska Oil & Gas Cons. Commission gnchora, ~e Redrill Plan Summary Page 1 Depth Density PV YP INT 10MIN FL OIL SOLIDS (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) KOP' 10.2 10 15 5 10 10 0 5 to to to to to to to to to TD' 10.2 18 30 15 30 5 0 8 Directional: IKOP: ] 10,200MD I Maximum Hole Angle: 60 Close Approach Well: NONE The above listed wells will be secured during the close approach. Casing/Tubing Program: Hole Size Csg/ WffFt Grade Conn Length Top Btm Tbg O.D. MDfFVD MD/TVD 8.5 7 29 L-80 butt 3062 10000/7631 13779/10196 Cement Calculations: I Liner Size: I I Basis:175¢o open hole ex~ess, 40' shoe joint, Top Cement 1000'MD above Putt River' Total Cement Volume: 253 sxs of Class G Blend @ 1.18 ft3/sx A liner top packer will be set on subsequent trip. I Liner Size: I I ! , Basis:I Total Cement Volume: RFCFIVFD Well Control: Redrill Plan Summary MAR 20 199,5 Ai~ska 0il & Gas Cons. Commission Anchora. ,, Page 2 Well control equipment consisting of 5000 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 mud fluid system schematics on file with AOGCC. Redrill Plan Summary RECEIVED MAP, 2. 0 i995 oii & Gas Cons. Commission Anchora,?~ Page 3 10. 11. 12. SUMMARY PROCEDURE:3-49/J40a 1. Pre-rig work: Test intermediate casing mandrel pack-off to 5000 psi. Test casing to 3500 psi. CTU squeeze perforations. Cut tubing at 14,300' Freeze protect and set a BPV. 2. Pull BPV. 3. After ensuring that the well is dead. Set BPV. Remove the production tree. 4. Install BOP's and test to 250/5000 psi. Monitor volumes carefully to ensure that the fluid is not being pumped down tubing. Remove the test plug and BPV. 5. Pull and lay down the 4.5" tubing. 6. Replace the 9-5/8" mandrel packoff and test to 5000 psi. Install wear ring. 6. RIH and set bridge plug - 200' ( at 10450') below proposed 9-5/8 section. ( To be witnessed by AOGCC. ) 7. Displace to milling fluid and spot a 18 ppg pill on bottom. 8. Test casing to 3500 psi. 9. POOH and P/U 9-5/8 section mill cut a 50' section in the 9-5/8" casing starting from about 10195' MD. 8. Spot a balanced cement kick-off plug (180 cubic feet minimum) through open-ended drillpipe from 100' below the base of the section to 200' above the top of the section. 9. Run in with an 8-1/2" steerable drilling assembly ( GR/MWD ) and dress the cement to 5' below the section top. Prior to kickoff circulate hole clean so that it is free of cement. Kickoff and directionally drill to the target with 46° hole angle at 10,140ss/13779 MD as per the attached directional plan. Obtain wireline conveyed DIL/MSFL/LDT/CNL/GR/CAL FMT(15POINTS) formation evaluation logs starting from the top of the 9940' Kekiktuk .If logs can not wire line conveyed only DIL/MSFL/LDT/CNL/GR/CAL will be drill pipe conveyed not FMT. Run a 7" 29# L-80 liner assembly to bottom in the 8-1/2" hole and space the liner hanger (L-80) about 150' up inside the 9-5/8" casing. Cement the liner in place with the total cement volume based upon 75 % open-hole enlargement plus the 80' shoe volume, The minimum top of cement to extend to 1000' MD above the Putt River sands.( Note: if the caliper Icg is available use it and add 20% to caliper volume Or the above volume which ever is larger) RIH with TIW SNAT packer. Set inaccordance with TIW Procedures Break circulation and witness pressure increase as first seal engage. Shut down pump Slack off to set packer with a minimum of 40,000# (the more the better) MORE Pressure test backside to 3500 psi. Release from the liner hanger. ,OT T.ST ^T T, S T,. ECEIVED MAR 20 1995 Alaska Oil & Gas Cons. Commission 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. Run SBT bond Icg. Log 24hrs after placing cement. POH. PU 3.5 DP and 9-5/8" casing scraper spaced out to the liner top. RIH change the well over to seawater. Spot inhibited brine in the liner. Test casing liner and liner lap to 3500 psi. Run the 4-1/2" 13CR-80 completion string assembly. Locat tail pipe in the top of liner Reverse circular Corrosion inhibitor into the annulus. Set and test packer. ( Refer to completion diagram and standard completion running procedure ) Install TWC. Test TWC to 1000 psi. Remove BOP's. After completing this well TREE ( 7-1/16" x 4" ) against TWC to 5000 psi. After testing is completed pull TWC and install BPV. Test the tubing x casing annulus to 3500 psi for 30 minutes. Shear RP valve in the upper GLM and freeze protect the well. Fill out all necessary forms and hand them over to production. Release the rig. RECEIVED MAR 2 0 1995 ~iaska 0il & Gas Cons. C0rnrr~ission Anchor~ ;: MAR-20-1995 14:17 FROM ANADRILL i SH RED SERV ICES DRILL I NG : i i; i ii i il iii · i ~,~ i1__ - · i i o-- : .... 3-49/J-40A ANADRIL! I AK/,-DPC VERTICAL SECTION! VIEW AP[ RQ-,ME!, ' 600 ..........~- ...... ' ' ' ; ' Section at: 25.51 , · I TVD Scale.' ! inch-- ~200 feet!'. ·; i Iit~.R :~ 0i1995, Oep Scale ' ~ inch - f200 fe~tI 1200~-- ; - - , . ~ . ~ : ~.J~ grain ' 03/20/95 ', ' INiT " laO0 .... ~ - ' ' ~400-- ..~.. I ~arker [denLiticaLian '~O BKB ~SECTN ~ I ~) HE-]N SURVEY t0t0t 7684 ': 3362 50.34 [ B) TOP 0F H]NO0~ t0~g5 773t ~. 3~22 50.~ ' ~ C] K0P CURVE 6/100 10200 7733 I 3425 50.~0 3000 ......... , ...... ~ ~ .......... Bi END 6/I00 6URVE 108~4 8115: 3853 45.42 I El TA~OET-150' R~IUS ~3¢94 9996 ~ 5762 B '~'~:f~'~ =~: ................ + " F] TO 13779 10195 ~' 5965 45.~8 . ~~ '. K 3600 '~=~.z. : .... ~ : ' ...... ~ I ~ i I . , , i ~ ~ ~ ~e,~,~ ~ ......... ~ i 48~- ~ .... ~.' . . ~% ~. , 5400-~- :.; . ' ~ I · ~ · .I . ~ ....... , ..... ~. ,~ . . .., . . . ; 6008-- ; %%, [ - .- , . . I '' ~% ~ '," i ' I i, ;, ~ ; , . j · . , ~ I -.. · ,1. , 7200 -- : ~ % " . .. ~, ', .i [ ][ ~.... , i ~-~ -r~ ............ , ; gooo........ ~ :'2 2' ~-',~¢ _~Z L'6'Z_: L L_'_ L '*- " ' ', "~ 1995:' ..... ~ ......... ~'~'~':' ~ .~,~F~. iii a Ga~ ~dr, s. Con mission I 9600,,, : ._~i= . JO200- ~ ........... ' . . F = ~~== ==== = ::::::::::::::::::::::::: ..... ~ ==:::~=:::= 10800 - . .... ~ ,. I : 0 600 1200 t800 2400 3000 3600 1200 4800 5400 6000 BS00 7200 7800 , ..... 3-.49/J-..40A. (PiO) .PLAN -V.IEW CLOSU~ ' 6940 [eet aL Azimuth 56.25 DECLINATION.' 29.868 E SCALE-:'..-,'.. :-:- ! inch -- 'IO00"feel: :I]RAI~N · 03/20/95 .... SHARED "SER'V I'CEs Narke¢ Ident i f i c~t ion A} TIE-IH -S. URy.EY 31)t01 16t3 4427 i]] 10P O~ NINDOI~ .30195 1643 4503 -CI ...KOP CURVE.'.6/[O0 -]O~l)O ......... 1§44'. 4507 .... : ......... O! END 6/i00 CURVE 'J08i4 1949 486i El TARGE1-150' RADitI~ 13494 367~2 5683 Ft ID 13779 3855 577 'D'R I'L'L'IN'G i lime ii I im ii ii i 500 0 500 1000 t500 2000 2500 3000 35'0'0 4000 4500 500'0 5500 6000 6500 ?000 '7500' 8000 ' 8§00 (- ~IES~ - EASI -> 0 WELL PERMIT CHECKLIST CO~A~Y __/~p · / 3-~/~ ~d)A PROGRAM: exp O dev [] redrll~ aery [] VNI # ON/O F ADMINISTRATION ENGINEERING 1. 2. 3. 4. 5. 6. ~ 7. 8. .9. 10. Il. 12. 13. Permit fee attached .................. N Lease number appropriate ............... N Unique well name and number .............. N Well located in a defined pool ............. N Well located proper distance from drlg 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 APPR D~TE Conductor string provided ............... 16. CMT vol adequate to circulate on conductor & surf csg. 17. C_MT 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 .... Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. ~ 22. Adequate wellbore separation proposed .......... If diverter required, is it adequate .......... 23. Drilling fluid program schematic & equip list adequate 24. 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to ~--~ psig.~ 27. Choke manifold complies w/API BP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of ~2s gas probable ............ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N / 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis 9f shallow gas zones .......... Y 33. Seabed condition survey (if off-shore) ........ ~ N 34. Contact name/phone for weekly progress reports ..../Y N [exploratory only] / GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: HOW/jo - A:~FORMS~chekJist rev 03/94