The URL can be used to link to this page

Home My WebLink About198-236 Ima§ ~roject Well History File Cover ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. / ~ ~'-~ ~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds NOTES: [] Other Project Proofing BY: BEVERLY ROBIN ~SHERYL MARIA WINDY Scanning Preparation _~ x 30 = ~ BY: BEVERLY ROBIN~HERYL MARIA WINDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: ~'~/ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES BY: BEVERLY ROBI~HERYL MAR,A WINDY DATE:~"'~,-0~ /S/ ~/~ Stage 2 IF NO IN STAGE '], PAGE(S) DISCREPANCIES WERE FOUND: ~ YES BY~ BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: /S/ (SCANNING IS COMPLETE AT THIS POINT UNLE~ SPECIAL ATTENTION IS REQUIRED ON ~1 INDIVIDUAL PAGE BASIS DUE TO QUAMTY, GRAYSCALE OR COLOR IMAGES ) NO NO RESCANNED BY~ BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: ~si General Notes or Comments about this file: Quality Checked 12/10102Rev3NOTScanned wpd MICROFILMED 7130102 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE M:/weepie/m[crofilm marker.doc Saved as - ALASKA OIL AND GAS CONSERVATION COM~SSION TONY KNOWLES, GOVERNOR 333 W. 7m 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 198-236 DATE November 25, 2000 Re: Expired Permit Action WELL: Prudhoe Bay Unit 13-12AXX AP1 # 50- 029-20538-95 Permit Issued: 11/25/1998 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. 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. Steve McMains Statistical Technician 'ONY KNOWLES, GOVERNOR ALASKA OIL A~H) GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 :AX: 907) 276-7542 November 25. 1998 James E. Smith Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit 13-12A ARCO Alaska. Inc.. Permit No: 98-236 Sur Loc: 739'NSL. 1051~3/EL. Scc. 14. T10N. RI4E. UM Btmhole Loc. t594'NSL. 3401'WEL. Scc. 23. T10N. R14E. UM Dear Mr. Smith: Enclosed is thc approved application for permit to redrill thc above referenced well. The permit to re. drill docs not exempt you from obtaining additional pcrmits required bx' law from other governmental agencies, and docs not authorize conducting drilling operations until all other required permitting dcterminations are made. Blowout prevention equipment (BOPE) must be testcd in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must bc given to allow a representative of thc Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given bx' contacting thc Commission petroleum field inspector on thc North Slope pager at 65%3607. BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game. Habitat Section w/o cncl. Department of Environmental Conservation w/o cncl. ~ STATE OF ALASKA '-', ALASKA ~,~_ AND GAS CONSERVATION COM,,:ISSION 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 [] Sin~ile Zone [] Multiple Zone 2. Name of Operator 15. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan KBE -- 78.8' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation ,~ Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 739' NSL, 1051' WEL, SEC. 14, T10N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number U-630610 3999' NSL, 4008' WEL, SEC. 23, T10N, R14E, UM 13-12A At total depth ~ ~ 9. Approximate spud date Amount $200,000.00 1594' NSL, 3401' WEL, SEC.--'~Z, T~0N, R14E, UM 12/01/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028315, 1594' MDI No Close Approach 2560 12855' MD /8995' TVDss 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e} (2)} Kick Off Depth 10050' MD Maximum Hole Angle 91.4° Maximum surface 2699 psig, At total depth ('rVD) 8926' / 3600 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) 6" 4-1/2" 12.6# L-80 IBT 2956' 9899' 8682' 12855' 8995' 325 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. , ;U ,; . Present well condition summary Total depth: measured 10885 feet Plugs (measured) Aiaska 0il & 6as Cons, C0i~lmissi0p true vertical 9639 feet Anch0rag8 Effective depth: measured 10858 feet Junk (measured) true vertical 9613 feet Casing Length Size Cemented M D TVD Structural Conductor 80' 20" 232 sx Arcticset II 80' 80' Surface 1650' 13-3/8" 7600 sx Permafrost II 2726' 2726' Intermediate Production 9966' 9-5/8" 500 sx Class 'G' 10042' 8880' Liner 1127' 7" 350 sx Class 'G' 10858' 9613' Perforation depth: measured 10049' - 10069', 10158' - 10175', 10178' - 10197', 10202' - 10212' true vertical 8886'-8903', 8981'-8995', 8998'-9015', 9019'-9028' ORIGINAL 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: Chris Brown, 564-5582 Prepared By Name/Number: Terrie Hubble, 564-4628 21 . I hereby ceil'fy that the foregoin,~ is tru, eand correct to the best of my knowledge Ja ~ ~"~ /¥r ~u-'~,', Title Senior Drilling Engineer Date m~ Commission Use Only Permit Number APl Number Approval Date...,~ I See cover letter ~oc~.-- ~ 3.4~ 50-029-20538-01 //~' ~'-"" ~'f~"I for other requirements Conditions of Approval: Samples Required []Yes '~ No Mud Log Required []Yes J~ No Hydrogen Sulfide Measures 'J~Yes [] No Directional Survey Required ~Yes [] No Required Working Pressure for BOPE []2K; []3K; 1--14K; ~L5K; r-110K; [] 15K Other: Ui'i~;i';2.! !-~;.~?3d ~y by order of Approved By 0avid W. J0hnstorl Commissioner the commission Date// Form 10-401 Rev. 12-01-85 Submit In Triplicate [Well Name: [DS 13-12a HST Sidetrack Summary Type of Well: I Producer Surface Location: 739' FSL, 1051' FEL, S14, T10N, R14E, UM Target Location: 3999' FSL, 4008' FEL, S23, T10N, R14E, UM Bottom Hole Location: 1594' FSL, 3401' FEL, S 12, T10N, R14E, UM I AFE Number: 14J0390 I I Estimated Start Date: [ 12/1/98 ling: [Nabors 22E Operating days to complete: 123 IMD: 112,855, I IT VD: 18,995. ss I I KB Elev. 178.8, I Well Design: I HST Sidetrack Objective: This well is to be drilled as a horizontal sidetrack. The new sidetrack will develop the EPWZ periphery between DS 12 and DS 13, leaving a wellbore design set up for a future Sag CT sidetrack, and replacing the leaking L-80 completion with a new 13Cr80 comple- tion Formation Markers Formation Tops MD TVD (ss) TJB NR 8632' 10049' 8808' TSag K/O 10050' 8809' TSHU 10099' 8850' TSAD 10208' 8926' CGOC 10208' 8926' HOT 12855' 8995' TD 12855' 8995' CWOC NR 9000' TZ3 NR 9132 Directional I KOP: [ 10,050' MD Maximum Hole Angle: Rig Move Close Approaches: 91.4° through targets There are no nearby well close ap- proaches. The nearest wells are over 100' distant Drilling Close Approaches: None Casing/Tubing Program Hole Size Tubular Wt/Ft Grade Conn Length Top Btm O.D. MD/TVDss MD/TVDss 6" 4-1/2" 12.6g L80 IBT 2956' 9899'/8682' 12855'/8995' Production Tubing NA ] 4-1/2" 12.6g 13Cr80 NSCT 9873' 26'/-52.8' 9899'/8682' Mud Program Milling Interval: 6% KC1 Milling fluid Density, ppg , Funnel Vis, secI LSRV pH ] API FL, cc Hazards/Concerns Maintain viscosity at 50 - 65 to insure adequate removal of metal cuttings. Ensure adequate preparation to eliminate metal entering motor and MWD from mud bypassing solids control equipment. Production (6" hole) Section: 4 % Quickdriln (viscosified SW) Density, ppg [ Funnel Vis, sec I LSRFI pH [ API FL, cc 8.7 - 8.8+ 50 - 65 > 35,000 8.5 - 9.0 NC Hazards/Concerns Be alert for lost circulation, differential sticking due to overbalanced MW. Maximize solids control to keep fluid as clean as possible. Max mud weight 8.8+ ppg. Cement Calculations Lead Cement Tail Cement Casing/Liner Sk / Wt / Yield Sk / Wt ! Yield Comments 4-1/2" N/A 325 / 15.7 / 1.19 Class G: 40% excess; Pump time = 4 hr.; TOC 200' above TOL. Volume assumptions: Gauge hole + designated excess; 80' shoe joints; TOC as designated. Open Hole Logs: 6" Hole Cased Hole Logs: Logging Program MWD Dir/GR/4 phase resistivity Platform Express/Sonic DPC logs None Well Control 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. Bottom hole pressure is expected to be 3600psi @ 8926' TVDSS. Maximum expected surface pressure is therefore 2699psi (assuming gas column of 0. lpsi/ft). Drilling Hazards/Contingencies The main production target for this well is Zone 4. Drilling Close Approaches No drilling close approaches are expected for this well H2S Drill Site 13 is considered to be an H2S Drill Site - highest readings encountered are 122ppm in 1/97 although lower readings have been recorded recently. The scope and objectives for H2S op- erations are outlined in SSD's 'H2S- Standard Operating Procedure(SOP)'. When decompleting the well, until the packer has been removed, all fluids circulated from the well must be taken down an adjacent production flowline to avoid potential rig crew exposure to H2S. Intermediate Section There is no intermediate section to be drilled on this well and hence precautions concerning Kin- gak are not considered here. Production Section Faults are known to be conductive in the Drill Site 13 area. Although, no faults are expected to be crossed while drilling this wellbore, losses have occurred in the past while drilling both Shublik, and Zone 4. Normal lost circulation precautions are to be taken while drilling this well, and a close eye kept on the fluid system. Stuck pipe has been recorded in the Sag but only on one well in which a stiff hole opening assembly was run into a previously cored section, hence stuck pipe is not expected to be a severe problem. The pad data sheet indicates that normally, low reservoir pressures should be expected on DS 13. However, the closest existing well to the proposed well- bore is an injector which has raised the local pore pressure - the geological pore pressure prognosis based on this offset well has a relatively high value of -7.8ppg. Differential sticking should not be a problem with Quikdriln in the hole as long as severe losses due to faulting are not encountered. Kick Tolerance The kick tolerance for the 7" whipstock exit point would be an infinite influx (annular volume) as- suming an influx at the 12,855' TD. This is a worst case scenario based on a 7.0-8.0ppg ppg pore pressure and a minimum fracture gradient of 10.0 ppg with a 8.8 ppg mud in the hole. Note that the original well provided a 11.9ppg fracture gradient at 9-5/8" casing shoe when drilling the original 8-1/2" hole. Disposal All cuttings should be hauled to the ball mill at CC-2A for disposal. 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. Operations Summary Pre-Rig Work 1. Pull the 4-1/2" SSSV. Valve is set at 1922' MD. 2. Lay an LCM pill in the 7" liner across the perfs from PBTD to the tubing tail at 9,702'. Ensure the well is static with no fluid losses. Note that this well has an Alpha Soft Set patch at 9,491' (ID 2.687") which is not retrievable. 3. Test 4-1/2" tubing x casing annulus from the production packer at 9,628' to surface to 3000 psi for 30 minutes (holding pressure on tubing if necessary). 4. Chemically cut the 4-1/2" tubing as per current best recommended method at 9,488', 3' into the joint : immediately below the last GLM. The tubing patch at 9491' has a 2.687" ID restriction which will not allow a chemical cutter to pass through. This leaves a 6' gap between the GLM and the tubing patch. Note also that the tubing is internally plastic coated, and therefore a multiple anchor and double add cylinder cutter will be required. A special spacer will be used on the chemical cutter to allow the cutter anchor to set above the last GLM. Note: Should the pre-rig work be unable to cut at 9488' for any reason, the cut will be made in the middle of the first full joint above the last GLM. 5. Circulate with seawater to ensure the well is dead and freeze protect the well to -2200'. Bleed tubing and annuli pressures to O psi. 6. Test the Gray 9-5/8" mandrel packoff to 5000 psi for 30 minutes and tubing hanger to 5000 psi for 30 minutes. Function lockdown screws. 7. Set a BPV in the tubing hanger and secure the well. 8. Notify the operations engineer of the well's status upon resolution of the work. Rig Operations Abandonment * Notify the AOGCC for witnessing rig operations on BOPE testing and w/th intent to plug and abandon * 1. MIRU Nabors 22E. 2. · Circulate out freeze protection. Set TWC using a test dart in the BPV. 3. Nipple down tree. Nipple up and test BOPE. 4. Pull 4-1/2" tubing from cut at 9,488'. 5. Washover and latch the tubing with an overshot. Rotate to release the tubing anchor and POOH. Check to ensure that the Alpha soft set patch was retrieved with the remaining tubing. 6. Mill and recover the Baker production packer at 9,628' and tailpipe. The packer has a Mill-out Exten- sion and may potentially be retrieved with the milling assembly. If not, a fishing run will be required. 7. RIH with a 7" RTTS and test the 7" x 9-5/8" casing from 10,000' to surface to 3000 psi for 30 minutes. 8. RIH with a 7" Halliburton cement retainer on e-line with GR/CCL. Tie-in to the top of the Sag River ("~10,047') and set the cement retainer top at -~10,070', 23' below TSag. 9. The top of the cement retainer will be set with open Sag River perforations above. The planned 4.5" liner top packer will lap the highest perforation by 150' minimum and will be fully cemented. 10. RIH with cementing string. Sting into the retainer and establish an injection rate with seawater (close annular preventer). Pump 34 barrels of 15.6 ppg Premium cement to fill the casing volume between PBTD at 10,858' and the cement retainer plus squeeze 5 barrels to the perforations. Unsting and circu- late out any excess cement. Sidetrack 1. RIH with 7" whipstock and set 20° right of high side. KOP should be 10,050' (3' below Top Sag). 2. Displace the well with 4% Quick&il and mill the window through the existing perforations. Monitor torque / drag closely due to the perforations. 3. Directionally drill building from 30-90° angle. Drill the --~2,805' of 6" horizontal section with MWD / GR / 4 Phase resistivity to a planned TD of 12,855'. 4. Run drill pipe conveyed Platform Express/Sonic logs from TD to 7" window. 5. Run and fully cement a 4.5" L-80 production liner. The production liner will have a RA tag in a coupling spaced at TSag. Displace the cement with clean seawater. Land the liner top packer at 9,899' or shallower, a minimum of 150' liner lap above the top existing perforation at 10,049' is required. 6. Test the 4-1/2" x 7" x 9-5/8" casing from the 4-1/2" landing collar to surface to 3000 psi for 30 min- utes. 7. Run a DPC 2.75" perforating assembly shooting locations determined from LWD and DPC logs. Ap- proximately 50% of the drilled interval will require perforation. 8. Run a 4-1/2" 13Ct completion spacing the WLEG into the 4-1/2" liner tieback sleeve. 9. Test the tubing to 3500 psi for 30 minutes. Test the annulus to 3000 psi for 30 minutes. 10. Nipple down BOPE. Nipple up the adapter flange/tree and test to 5000 psi. 11. Freeze protect the well to --~2200' and secure. 12. Rig down and move off. Anadrill Schlumberger Alaska District 1111 East 80th Avenue Anchorage, ~ 99518 (907) 349-4511 Fax 344-2160 DIRECTIONAL WELL PLAN for Shared Services Drilling Well ......... : DS13-12A {PllA) Field ........ : Prudhoe Bay C~putation..: Minimun Curvature Units ........ : FEET Surface Lat..: 70.21583765 N S~face bong.: 148.49804520 W 50CATIONS - AI~SKA Zone: Legal Description X-Coord Surface ...... : 739 FSL 1051FEL S14 TION R14E UM Tie-in slu~vey: 4074 FS5 3909 FEL S23 TION R14EUM Enter Target.: 3999 FSL 4008 FEL S23 TiON R14E UM BHL .......... : 1594 FSL 3401FEL S23 T10N RI4E UM 4 ¥-Coord 686196.17 5930780.31 683388.48 5928766.59 683291.36 5928689.35 683960.00 5926300.00 PROPOSED WELL PROFILE Prepared ..... : 02 Nov 1998 Vert sect az.: 167.76 KB elevation.: 78.80 ft Magnetic Dcln: +27.914 (E) Scale Factor.: 0.99993938 Convergence..: +1.41333814 STATION ~ASURED INCLN DIRECTION VE~ICAL-DEFI~S IDENTIFICATION DEPTH MqGLE ~ZIMUTH TVB SUB-SEA SECTION DEPART COORDINATES-FROM V;ELLHEAD ALASKA Zone 4 X Y BHRZ 8268.80 8190.00 TOP KINGAK 3B 8710.80 8632.00 TIE-IN SURVEY 10002.80 31.22 251.70 8847.02 8768.22 TSGR 10049.19 30.70 253.34 8886.80 8808,00 TOP OF WINDOW 10050.00 30.69 253.37 8887.50 8808.70 KOP/CURVE 24/100 10055.00 30.64 253.55 8891.80 8813.00 SHUBLIK 10099.24 36.15 236.97 8928.80 8850.00 10100.00 36.26 236.72 8929.41 8850.61 10200.00 53.96 213.40 9000.18 8921.38 T~ 10208.00 55.54 212.05 9004.80 8926.00 TARGET ENTRY 10208.01 55.54 212.05 9004.80 8926.00 1294.33 1296.51 1296.54 1296.73 1302.21 1302.37 1341.84 1346.46 1346.46 1943.98 S 2856.68 1951.15 S 2879.44 1951.27 S 2879.84 1951.99 S 2882.28 1962.33 S 2904.10 1962.57 S 2904.47 2013.30 S 2952.15 2018.80 S 2955.68 2018.80 S 2955.68 W 683388.48 5928766.59 W 683365.90 5928758.86 W 683365.51 5928758.73 683363.08 5928757.94 683341.53 5928747.07 683341.16 5928746.82 683294.76 5928694.94 683291.36 5928689.35 683291.36 5928689.35 TCOL aL/ FACE 100 122R '~ 121~/ 2.14 121R~2.14 52L 24.00 52L 24.00 35L 24,00 34L 24.00 34L 24.00 (Anadrill (c)98 1312APll 3.2C 3:22 PM P) DS13-12A (PllA} 02 Nov 1998 Page 2 STATION IDENTIFICATION TARGET BSL 90 INCLINATION END 24/100 CURVE CURVE 7/100 8/loo END 8/100 CURVE CURVE 8/100 ~ASURED INCLN DEPTH ANGLE ::~ ..... 10219.33 57.80 10300.00 74.42 10373.60 90,00 10380,30 91.42 '10875.55 91.42 10900,00 91,25 11000,00 90,52 11071.25 90,00 11100,00 88,69 11115,23 87,99 11419.15 . 87,99 11419,51 87,99 11500,00 88,25 11600,00 88,59 11700.00 88,96 El{II 8/100 CURVE 11763,82 89,21 4-1/2" LINER PC)IHT 12854,69 89,21 TD 12854,69 89,21 ZONE 3 PROPOSED WELL PROFILE DIRECTION VERTICAL-DEPTHS AZIMUTH TVD SUB-SEA 210.24 9011.02 8932.22 199.32 9043.66 8964.86 190.89 9053.62 8974.82 190.14 9053.54 8974.74 190.14 9041.24 8962.44 SECTION DEPART 1353.34 1412.18 1476.74 1482.92 1940.73 188,44 9040,67 8961,87 1963,47 181,47 9039,13 8960,33 2058,93 176.51 9038,80 8%0.00 2128.79 174.63 9039,13 8960,33 2157,27 173,62 9039,57 8%0,77 2172,40 173.62 9050.22 8971.42 2474.55 173.62 9050.24 8971.44 2474.90 167.19 9052.88 8974.08 2555.22 159.19 9055.65 8976.85 2654.78 151.20 9057.79 8978.99 2752.29 146,10 9058,80 8980,00 2812,56 146.10 9073,80 8995,00 3826,28 146.10 9073,80 8995,00 3826,28 9210.80 9132,00 COORDI~TES-FROM ALASKA Zone 4 WELLHEAD X ¥ 2026.90 S 2960,57 W 683286,67 5928681,14 2093.68 S 2990.91W 683257,99 5928613,63 2163,83 S 3009,74 W 683240,90 5928543,04 2170,42 S 2657,78 S TOOL DL/ FACE 100 33L 24.00 29L 24.00 28L 24.00 3010.96 W 683239.84 5928536.43 lis 24.00 3098.13 W 683164.72 5928047.10 %L 0.00 2681,90 S 3102,08 W 683161.37 5928022,88 96L 7,00 2781,45 S 3110,71 W 683155,20 5927923,15 %L 7,00 2852,67 S 3109,46 W 683158,20 5927852,00 125L 7,00 2881,33-S 3107.24 W 683161.13 5927823.40 125L 8.00 2896,47 S 3105,68 W 683163,06 5927808,31 HS 8,00 3198.33 S 3071.95 W 683204.22 5927507.39 HS 0.00 3198.69 S 3071.91W 683204.27 5927507.03 88L 0.00 3277.97 $ 3058.51W 683219.62 5927428.11 88L 8.00 3373.58 S 3029.63 W 683250.85 5927333.25 8IL 8.00 3464.26 S 2987.72 W 683294,9~ 5927243.63 87L 8.00 3518,73 S 2954,53 W 683329,50 5927190,00 4424,07 S 2346,13 W 683%0,00 5926300,00 4424.07 S 2346.13 W 683960.00 5926300.00 8.00 0.00 0.00 (Anadrill (c)98 1312APll 3.2C 3:22 PR P) Well: 13-12 = .... Date:01-02-81 £rL~inal RKBE:76' ?cp of Formation: 10154' ?-~.ular Fluid:Diesel/9.6 NaC1 Reference Log:BHCS ARCO Alaska, Inc. - Pruclhoe Bay ?-~I ~: 50-029-20538-00 Cc.,~pletion: ~ x_ ~ - _ ~; Hanger Type: 5- !. £ ' Gray :~x Hole .Angle:-'_3~ ~ MD: 8900' Date:02-03-61 Tie In: ~: PRODUCER etazus:New Har. ger:31' .Angle @ TS:28 Angle @ TD:22 Daue: 00-00-00 ALL DEPTHS ARE RRB SSSV = CAT ~ I Il II J-2 kC-1 G-1 DRILLING MD TO TOP OF EQUIPMENT EXCEPT WHERE NOTED. Jewelry (J) FILE COPY Depth Description i 38' Crossover 5-1/2' x 4-!/2" 2 !922' 4-1/2' Camco RAL-O SSSV Nipple ID=3.813' 3 9491' 4-1/2' Alpha £cf-_ Set Sktbing ~atch (Set 08,'93) i;=2.687" 4 9612' 4-1/2" B0T PBR .'-_~s~biy 5 9670' 4-1/2' Camco EL-~ Larxiing Nipple ID=3.687' 6 9628' 9-5/8' x 4-1/2' BOT C--AB Packer 7 9702' 4-1/2' Baker S~-=~rou[ 8 9702' 4-1/2" Tubing '_-=_il 9692' ~ Tubing Tail {Logged 02/06/86) FISH: CA-.gD (Lcs5 08/23/92) FISH: CA-.RD {ics~ 08;01/90) FISH: CA-FD-.~X los~ ~6/28/90) Min ID: &-1/2" Alpha Soft Set Tubing Patch (Set 08/93) ID=2.687" J-3 HOLE e 9502' J-4 J-5 J-6 J-7.8 C-2 P-1 Casing and Tubing (C) Size Weight Grade ! 13-3/8' 72# 2-~O-95 2 9-5/8' 47# L-80 3 7' 29f L-80 5-1/2' 4-i/2' 12.6# N-80 Hole in 9~bing @ 9502' Gas Lift Information (G) MD 4458' {198' 7376' Stn 4: ~734 5771 9085 9!22 9400 9439 9476 Stn 12: Top Bottom Description 0' 2726' Casing 0' 10042' Casing 9731' 10858' Liner 0' 38' Tubing-PC 38' 9702' Tubing-PC TVD Stn Mandrel Valve Ty~e Latch Port TR0 Date i2553') 1CA-._~2~G. }~ VR-STD ~ 1/4" 1659 ~9-14-92 ~4442') 2 CA-.%14G .MC VR-STD ~K i/4' 1639 09-14-92 (5868') 3 CA-.~U~G CA RD RK {6756') 4 CA~3 .MC VR-STD RK 5/16' 1690 09-14-92 Depth Corrected by E-Line Log Sta 4,5,6 & 7 ~7502' ) 5 CA-._u/iG CA RD (7~51') 6 CA-._~E~G CA RD RK ;7580') 7 CA-._v/.'~G. C~ .RD (8112') 8 CA.-MMS CA RD RK {8139') 9 CA-.ml~ CA RD RK (8352') 10 CA-PlUG CA RKED RKP (B383') 11 CA-.-~2~G CA RD (8412') 12 CA-MMG HES 02-20R RK 3/8° 0R/F 01-10-94 02-20R pulle~ 01/10/94-Top Decking peele~ & rolled ~10,11,12 C-3 Perforation Data (~.# DEPTHS) (P) Interval Zone FT SPF Date Comments i 10049-10069 SAG 29 2 01-04-91 APERF 10158-10175 4 17 4 08-04-90 RPERF 10178-10197 4 19 4 08-04-90 RPERF 10202-10212 4 10 4 08-04-90 RPERF FKAC 08/18/90 BALL SEALER TREATW~T 08/16/90 Datum 9700' SS= 9920' MD ?D10858' ~800' _c5=10037' MD ._-C=10885' Revision Date: 08-11-97 by ENH Reason: SSSV = C17=2 Previous Reason: '--11-94 Well 13-12 TREE: 6' 13-1 2 (Pre-rig Status) WELLHEAD: Gray r ~ SSSV LANDING NIPPLE @ 1922, ID = 3,813" PROTECTION AT +/- 2200' MD' -- -- L-80, BTRS @ 2726' ~ 12 X 4-1/2" X 1~1/2" GLM's 4-1/'2", 12.6#/ft, N-80, BT&C, IPC-- TUBING iD: 3,958" CAPACITY: 0.0152 BBL/FT ~ 8.SPPG SEAWATER CHEMICAL CUT TUBING 2.687" ID (NON-RETRIEVABLE) BAKER PBR ASSY. --@ 9,6t2' 9 5/8"X4-1/2" SOT SAB PACKER, @ 9,628' 4 1/2,12.6#/ft, N-80 BT&C, I PC TAILPI PE -- 4 i/2" DB-6 NIPPLE, 3,813" ID @ OIL/GAS FLUIDS @ 7,34PPG -- 9,67f' -- 4-1/2~ TUBING TAIL @ 9,702' (SOT SHEAR OUT SUB) 7 LINER TOP @ 9,731' -- ~ (ELMD @ 9,692') L-80, BTC @ 10,042' OPEN PERFORATIONS __ 10049'-i0069' BAG 10158'-10175' Z4 LCM PILL ACROSS -- ~ 10178'-10197' Z4 PERFORATIONS / 10202'-f 0212' Z4 -- FISH: 6/28/90, 8/1/90, 8/23/92 3 X Gas Lift Valves PBTD @ 10,8~8' TD @ 10 885 -- - ............ 7% 29#,L-80LTCSrd DATE REV. BY COMMENTS 11-9-98 CJB Pre-ri,q Status .~_ APl NO: 80-029-20538-00 BP Exploration (Alaska) DS G12 (Rig Abandonment us) TREE: 6" Gray - m ~ m - ORiGiNAL KB. ELEV = 76' WELLHEAD: Gray CB. ELEV = 49.3' e.5PPG SEAWATER 7" LINER TOP,,~ 9,731' -- -- ~ CEMENT RETAINE OPEN PERFORATIONS @ 10070' ~10049'-10069' SAG ~SQU.E, EZED ,PERFORATIONS ~10t 58-t0175 Z4 ~,'~ ;~,~ FISH: $/28/90, 8/1/90, ~ 8/23/92 3 x Gas Lift Valves PBTD @ 10,958' --~ . TD @ 10,885 .................. 7 29# L-80 LTC 8rd DATE REV. BY COMMENTS 11-9-98 CJB Rig Abandonment Status APl NO: 50-029-20538-00 BP Exploration (Alaska) DS 13- HST (Proposed Complan) TREE: 6" Gray -- -- ~ -- -- ORIGINAL KB. E,LEV = 76' WELLHEAD: Gray ~ CB. ELEV = 49.3 ~ J J 5~ t /2" ~ 4--1/2" CROSSOVER X NIPPLE FOR SSSV @ -2000', -- -- ID = 3.813" ~ ____6,SPPG DIESEL FREEZE , pROTECTION AT +/- 2200 MD ~ ~ 7 LINER TOP ~ 9,731 7= X 4-1/2" BAKER S-3 PACKER e -9799'~ 4-1/2 X NIPPLE ~ ~ 4 1/2" WLEG STABBED INTO ~ --LINER TOP ~ 7" X ~1/2" LINER HANGE~PACKER ~ --~ 9899' WHIPSTOCK SET FOR PBTD ~ 10,858' TD ~ 10,885' ~ DATE REV. BY COMMENTS 11-9-98 CJB Proposed Completion A~I NO: 5~O29-20S38-O1 BP Exploration (Alaska) Shar~d Serv 1 c~s Dr 1 1 1 1 ~ Norker IdentlflcotlOn MD N/S E/W A) TIE-IN SURVEY lDO03 1944 S 2~7 B) TOP OF WINDOW 10050 IgSl S 2B80 C) KOP/CURVE 24/100 10055 1952 S 2882 D) TARGET ENTRY 1D2[]8 2Dlg S 2956 E) lARGEl BSL 1021§ 2027 S 2t~1 F) gO INCLINATION 10974 2164 S gOlD G) END 24/100 CURVE lOSBO 2170 S 3011 H) CURVE ?/1DO 1087B 2§58 S 3Dgg I) CURVE 8/100 11071 2B53 S 3IDg J) END B/IOD CURVE 11115 2B96 S 9106 K) CURVE 8/100 11419 3198 S 9072 L) END B/lDO CURVE 117~4 9§19 S 2§55 N) 4-1/2' LINER ~INT 12B55 4424 S 2946 N) TD 12855 4424 S 2946 DS13-12^ (P11^) PLAN VIEW CLOSURE ..... : 5008 Feet at Azimuth 207.94 DECLINATION.: +27.914 (E) SCALE ....... : I lnch= 5DO feet DRAWN ....... : 02 Nov lggB ~nodr l 11 Sch l umberg~r 4000 37,5)0 ~ ~ 3000 27.50 2500 2~ <- WEST (Anoflrtl! (c)g8 1312APII 3.2E 3,25 PM ?) ii i ' ' Shar~d S~ Mork~r Id~ntlFlcotlom J~J] ~ SE~ A) TIE-iN S~VEY 10003 BB4? 1294 31.~ B) TOP ~ VI~ 10050 ~7 1207 ~.~ D) TA~G~ ENT~ 102~ g~ 1948 55.~ ~ TARG~ 8SL lO21g 9011 I~ 57.~ ~) gO I~LINATI~ 10374 g~4 14~ go.~ G) ~NO 24/100 ~E 10380 g~4 14~ 9i.42 H) CURVE 7/100 10878 g041 1941 91.42 I) CURVE 8/100 1~07I ~39 21~ ~.~ J) E~ 8/100 C~VE 11115 ~0 2172 87.~ ~ C~VE 8/100 11419 ~0 24~ 87.~ L) ENO ~/100 C~ 11784 ~g 2819 89.21 M) 4-1/2' LINER ~INT 12855 g~4 98~ 89.21 · TO 12855 ~74 ~ ~.21 .... A~dr i i i Sck i u~r£er 0S13-12A (Pi lA) VERT I g~L SEgT I ON V I E~ Sactlon at: 167.76 TVD Scale.: 1 lnch= 300 fe~t Oep Scold.: i inch = 300 F~et Brown ..... : 02 Nov 1908 1200 1350 1500 1850 1BOO 1950 21DD 2250 2400 2550 2700 S~ctlon Departur~ (An~d~lll (c)g8 1312AP11 3.2C ~24 PM P) 2850 9000 3150 3300 9450 9:600 3750 3900 Alaska hared ervlces rilling WELL NAME DS 13-12A DRILLING PERMIT/SUNDRY/PRE-RIG COVER SHEET This cover sheet is applicable to: (only one category per cover sheet) DRILLING PERMIT PRE-RIG WORK D Pre-Rig Memo Reviewed: SDE/ES: ~'--'l Pre-Rig Memo Sent to Slope: Datel ODE: Date: Pre-Rig Sundry Documentation Prepared: ODE: Date:.~ Pre-Rig Sundry Application Reviewed: SDE/ES: Date: Pre-Rig Sundry Application Submitted: TA: Date: Sundry Documentation Prepared: ODE: Date: Sundry Application Reviewed: SDE/ES: Date: I I Sundry Application Submitted: TA: Date: NOTE: 1~ SUNDRY IS FOR PRE-RIG WORK~ USE PRE-RIG WORK SECTION AT BELOW LEFT AND CHECK "ABANDON" BOX BELOW Reason for Sundry (Check all that apply) Abandon Change Approved Program Alter Casing Operation Shutdown Suspend Re-enter Suspended Well Repair Well Time Extension Plugging Perforate Pull Tubing Stimul~.t.e Other(Explain): Aia I<a Oil & (las Cons. Commissi~r, /-~ncnora~e FltJPLI£ATE APPROVAL TO PROCEED ~ DATE H 1'42928 ,.., ~ o~. / ~-,,'~ CHECK NO. O01429'28 VENDOR ALASKA, ST DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 09! 598 CK09! t.V~ i00. OD ! 00. C-',f.'~ HANDLING INST' I , -IE ATTACHED CHECK IS IN PAYMENT FOR ri'EMS DESCRIBED ABOVE. m~[O]~llr~-l~ ~ I F', ..-"~ O..- r-; ] - BP EXPLORATION (ALASKA), INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND. OHIO No. H 142928 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 412 PAY To The O~dee O~ ONE HUNDRED & ******************************************** US DDLLAFi ALASKA STATE DEPT OF REVENUE 3001 PORCUPINE DR AN~ MU.~ AGp_ AK 99501-3120 DATE AMOUNT 09/16/98I $100. 001 NOT VALID AFTER 120 DAYS o WELL PERMIT CHECKLIST .:,. COMPANY .~~_~-~ _WELL NAMEx~_~~ .x"~_~ -//.~ PROGRAM: exp [] dev~edrll~~vrv I-I wellbore segl, ann. disposal para req,, FIELD & POOL INIT CLASS GEOL AREA ~~> UNIT# ON/OFF SHORE ADMINISTRATION 1. Pernrtit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper dislance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling [init ............ 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 AT APPI~.~.~ 2~}~5 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CM 1- vol adequate to circulate on conductor & surf csg ..... 17. CMl' vol adequate to tie-in long string to surf csg ........ 18. CMl'' 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 diveder 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 ..5-0o<3 psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... N N N N N N N N N N N N Y N N GEOLOGY ANNULAR DISPOSAL 35. APPR DATE 29. Is presence of H2S gas probable ................. ~ N 30. Permit can be issued w/o hydrogen sulfide measures ..... y N//" ~ ........................................................................................................... 31. Dala presenled on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones. ' _ ?_ ...................... 33. Seabed condition survey (if off-shore) ............. 34, Contact nam, e/phon,e.for weekly progress reports ...... .// Y N [exploratory omy] / .............................................................................. With proper cementing records, this plan / (A) will contain waste in a suita~e receivingzone,. ...... Y N (B) will not contaminate freshwater; or cause~lfilling waste... Y N to surface; (C) will not impair mechanical integ~'[the well used for disposal; Y N (D) will not damage producing f~r, rfia~pair recovery from a Y N_ pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: COMMISSION: RPC DWJ ENGINEERING: UIC/Ann~ar JDH -----,.-- RNC . :.' CO ~c>"l~.~,/.e ~' Comments/Instructions: M chel,,hsl iov 0512919~J