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Home My WebLink About195-134XHVZE Pages NOT Scanned in this Well History File 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. /~'j~'"'/..~ 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 Dian~athan Lowell /si [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ 'ON OP- BEFOt Memorandum To- Well File: State of Alaska Re: Oil and Gas Conservauon Conunission Cancelled or Expired Permit Action EXAMPLE: Point Mclntyre P2-36AXX APl # 029-22801-95 This memo will remain at the from of the subject well fie. Our adopted conventions for assigning AP! numbers, permit numbers and well names did not specifically address expired or cancelled permits. This omission has caused some inconsistencies i the treatment of these kinds of applications for permit to ddil. 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 remair unchanged. The APl number and in some instances the well name reflect the number of preexistin! reddlls and or muitilaterals in a well. In order to prevent confusing a cancelled or expired permit w~ an active well or multilateral these case sensitive well identifiers will be changed for expired and cancelled applications for permits to ddil. The AP! number for this cancelled or expired permit is modified so the eleven and twelfth digits is 9[ The well name for a cancelled or expired permit is modified with an appended xx. These procedures are an addendum to the AP! numbenng methods descnbed in AOGCC staff memorandum "Multi-lateral (weitbore segment) Ddiling Permit Procedures, revised December 29, 1995. AOGCC database h'as been changed to reflect these changes to this permit. Statistical Technician OXY USA INC. Box 50250, Midland, TX 79710 September 20, 1995 Alaska 0il and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192.- Attention: Mr. Bob Cranda!l (FAX 907 276-7542) Reference: Application for Deviation Exception for the Milne Point H-08i Well (20 AAC 25.050) Dear Mr. Cranda!l: OXY USA inc., an affected party, has no objection to the drilling of the Milne Point H-08i well proposed in Joe Polya's memo to you dated September 19, 1995. Should you have any ~estions, please give me a call at 915 685- 5673. Sincerely, Edward J. Beb_m, Jr. Asset Lead Heavy Oil Team EJB/esm An Occidental Oil and Gas company BP EXPLORe;]'ION Memorandum Date September 25, 1995 To~ David W. Johnston Alaska Oil & Gas Conservation Commission From: Kathy Campoamor Technical Assistant Subject: Permit Revision for MPH-08, (95-134) We wish to cancel the above mentioned Permit To Drill, as it is not needed due to MPH-07 not having economical hydrocarbons in the Kuparuk formation. Regards, Kathy Campoamor /klc 4~Chorag~; C°~iss/.or~ BP EXPLORATION To: From: Date: Subject: Bob Crandall, AOGCC Joe Polya, BP (Shared Services Drilling) September 19, 1995 MPH-08i Change of Plan The scope for the MPH-08i well has changed -- the well is now planned for an injector to support the MPH-07 well which is currently being drilled. The target has moved from the southeast quarter to the southwest quarter of Section 12, T12N, R10E. Please replace the original MPH-08 Permit to Drill request with the attached MPH-08i Permit to Drill request. The well design has not changed at all aside from the target location and the injection status. A spacing exception letter was submitted with the original MPH-08 well and certified copies were sent to ARCO, BPX, Chevron, Mobil, and Oxy USA. I understand this original permit was approved and we did not recieve any objection from these operators. The move to the southwest quarter section eliminates Chevron and Mobil as affected parties; however, Arco, BPX, and Oxy USA remain affected parties. We are sending an Application for Deviation Exception to Arco and Oxy USA for this target move within Section 12, T12N, R10E. We will request that they fax a non-objection letter to your office just as was done for the recent MPH-07 well. This well will follow MPH-07 in the drilling schedule and therefore could spud as early as September 25, 1995. I apologize for this late change -- Your prompt attention and assistance in this matter are very much appreciated. If you have any questions, please call me at 564-5713. Respectfully, oe Polya CC' Arco BPX Oxy USA Alas~ .0il .& Gas Cons. Commission -.: gnchorago STATE OF ALASKA REVISED 09/20/95 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill [] Redrill CIIlb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []1 Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 66 feet Milne Point / Kuparuk River 3. Address 6. Property Designation P. 0. Box 196612, Anchorage, Alaska 99519-6612 ADL 380109 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 2767' NSL, 4061 WEL, SEC 34, T13N, RIOE Milne Point Unit At top of productive interval 8. Well number Number 1565' NSL, 4572' WEL, SEC 12, T12N, RIOE MPH-08 2S100302630-277 At total depth 9. Approximate spud date Amount 1180' NSL, 4417' WEL, SEC 12, T12N, RIOE 09/25/95 $200,000. O0 12. Distance to nearest 113. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 025637 1180 feet No Close Approach feet 2560 16274'MD/7300' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 500 feet Maximum hole angle 75 o Maximum surface 2830 psig At total depth (TVD) 7000'/3500 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# IH-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset l (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 7469' 31' 31' 7500' 4038' ~o ,~ ,~ p~, 6~6 ,x ~,. ~o~ ,~ ,~, ~F. to ,~ ,G,, ~ ,x .~ ~ 8-1/2" 7" 26# L-80 Btrc 16244' 30' 30' 16274' 7300' 219 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ~'~i ~ .... '" i.,,} Conductor ~., .., L_ ~ ,~ iL. Surface Intermediate SF--.[') ~ 'i '~995 Production Liner &t~$_~ pit .& Gas Cons, C0rr~miss[0.Q Perforation depth: measured ..... ;~ch0rage ' true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed reportl-] 20 AAC 25.050 requirementsC1 21. I hereby,,--.- /-, 'certify that the foregoing is... , ~__true and correct to the best of my knowledge Signed (;~~o-,'q¢'"~' ~w~..~~~.~L~-- Title Senior Drilling Engineer Date ff/zo/'~5" Commission Use Only Permit Number APl number I , o-o -$ ?.2_IAppr°valdate See cover letter for other requirements Condibons ct approva~ Samples required [] Yes [] No Mud Icg required []Yes [] No Hydrogen sulfide measures [] Yes [] No Directional survey required [] Yes [] No Required working pressure for BOPE [] 2M; 1-13M; 1~5M; r-I10M; I--I15M; Other: by order of Approved by Commissioner me commission Date Form 10-401 Rev. 12-1-85 Submit in triplicate BP EXPLORATION To~ From: Date: Subject: Bob Crandall, AOGCC Joe Polya, BP (Shared Services Drilling) September 19, 1995 Application for Deviation Exception for the Milne Point H-08i Well (20 AAC 25.050) The MPH-08 well is planned to drill into the Kuparuk River formation in the South West Quarter of Section 12, T12N, R10E. This section is located to the South of the Milne Point Unit Boundary. This quarter section is bounded on the West, Northwest, North, Northeast, and East by quarter sections within ADL 380109 for which the operators are BPX 91.19 and Oxy USA 8.81; and on the Southeast, South, and Southwest by quarter sections within ADL 025637 for which the operators are Arco 50.00 and BPX 50.00. (See the Attached Map.) The MPH-08 well is planned as an injector to support the MPH-07 well which is currently being drilled to the west in Section 11, T12N, R10E. The drilling of MPH-08i is contingent upon MPH-07 having economical hydrocarbons in the Kuparuk formation. The Surface Location for the MPH-08i well is 2767' fsl and 4062' fel in Section 34 T13N R10E. Entry Point in the Kuparuk formation (C1 Sand) is planned for 1565' fsl and 4572' fel in Section 12, T12N, R10E with the planned TD at 1180' fsl and 4417' fel Section 12, T12N, R10E. We have notified Arco and Oxy via E-Mail and requested that they send AOGCC Letters of Non-Objection to allow BP to drill the MPH-08i well and also requested that they waive the 15 day waiting period as was done for MPH-07. This well will follow directly behind MPH-07 in the drilling schedule with a tentative spud date of September 25, 1995. Thank you for your assistance in this matter. Please direct any questions to Mark Bendersky at 564-4666. Respectfully, e Polya CC: Arco BPX .~. ~Li , L Oxy USA $ F__P 2 'l 1995 Alaska Oil & Gas Cons. Commission Anchorage 380109 °/I.17 8.81 I I ~it .~ (~as Co~s. Commissioa ..... , I~chorage I 211 I ~~ H-08i et ADL 380110 I I I I I I I 615 8 I I I I I Pru~lho, I I 100% C sand Oil Column Lease Well H-08i Target Location BSM 9/6/95 Well Name: [ MPH-08i Well Plan Summary Type of Well (producer or injector): [ Kuparuk Injector [ Surface Location: 2767 NSL 4061 WEL Sec 34 T13N R10E UM., AK. Target Location: Bottom Hole Location: 1565 NSL 4572 WEL Sec 12 T12N R10E UM., AK. 1180 NSL 4417 WEL Sec 12 T12N R10E UM., AK. [AFE Number: I 330180 ] [ Estimated Start Date: [ 9/25/95 [ [MD: [ 16274 [ ITVD: [ Well Design (conventional, slimhole, etc.): [Rig: I Nabors 22-E Operating days to complete: [16 17300' bkb [ I KBE: Milne Point Ultra Slimhole 7LS [66' Formation Markers: Formation Tops MD TVD (bkb) base permafrost 1844 1815 NA 6346 3741 Top of Schrader Bluff Sands (8.3 ppg) OB 7163 3951 (8.3 ppg) Seabee Shale 7241 3971 Base of Schrader Bluff Sands (8.3 ppg) HRZ 14892 6256 High Resistivity Zone Top Kup 15432 6501 Kuparuk Cap Rock Top C1 Sand--Target 15628 6805 Target Sand (9.9 ppg) Total Depth 16274 7300 Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MDflWD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9 5/8" 40# L-80 btrc 7469 31/31 7500/403~ 8 1/2" 7" 26# L-80 btrc 16244 30/30 16274/7301 Internal yield pressure of the 7" 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 7000 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3500 psi is 2830 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: Surface Intermediate Final Cased Hole Logs: MWD Directional and CDR (Gr/Res) across Schrader Bluff N/A 1. PDC Bit f/Seabee to TD w/MWD Dir and LWD (GR/CDR/CDN). GR/CCL will be run in 7" casing to Tie-in the TCP Guns for Completion. Mud loggers are not required for this well. Mud Program: Special design considerations [ None- SPUD MUD Surface Mud Properties: [ Density Marsh Yield i0 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 50 15 8 10 9 8 to to to to to to to 9.4 100 35 15 30 10 15 Intermediate Mud Properties: N/A [ Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: [ None- LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 10 3 7 8.5 6-8 to to to to to to to 10.4 50 15 10 20 9.5 4-6 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 drilling fluid system schematics on file with AOGCC. Directional: I op: I SOO' Close Approach Well: (No Shut Ins) Disposal: grmhorafla "- ' Cu~ings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reseme pit can be opened in emergencies by noticing Karen Thomas (564-4305) with request. Fluid Handling: All drilling and completion fluids can be annular injected. Approvals have been granted for MPH-05, MPH-06, MPH-07 wells for annular pumping. Request to AOGCC for Annular Pumping Approval for MPH-06: 1. Approval is requested for Annular Pumping into the MPH-07 9-5/8" x 7" casing annulus. 2. Aquifers in the Milne Point Unit have been exempted from Class II injection activities by the AOGCC by Aquifer Exemption Order #2 as referenced in Area Injection Order #10. There are no domestic or industrial use water wells located within one mile of the project area. 3. The 9-5/8" casing shoe will be set at 8723' md (4266' tvd) which is below the Schrader Bluff Sands and into the Seabee formation which has a long established history of annular pumping at Milne Point. 4. The burst rating (80%) for the 9-5/8" 40# L80 casing is 4600 psig while the collapse rating (80%) of the 7" 26# L80 casing is 4325 psig. The break down pressure of the Seabee formation is 13.5 ppg equivalent mud weight. The Maximum Allowable Surface Pressure while annular pumping is calculated according to the following equation and is 2540 psi for a 10.4 ppg fluid in this well (Assumes worst case in which 7" casing is filled with gas). MASP = 4325 psig - ((fluid density ppg - 1.9) X 0.052 X 9-5/8" Casing Shoe TVD 5. A determination has been made that the pumping operation will not endanger the integrity of the well being drilled by the submission of data to AOGCC on 7/24/95 which demonstrates the confining layers, porosity, and permeability of the injection zone. 6. The cement design for this well ensures that annular pumping into hydrocarbon zones will not occur. AREA WELL PREV VOL PERMITTED PERMITTED INJECTED VOL DATES (BBLS) (BBLS) Milne Point MPH-05 0 0 11 995 Milne Point MPH-06 0 0 ~1995 Milne Point MPH-08 0 0 1995 DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. MPH-07 Proposed Summary of Operations 1. Drill and Set 20" Conductor. Weld a starling head and top job nipple on conductor. 2. Prepare location for rig move. 3. MIRU Nabors 22E drilling rig. 4. NU and test 20" Diverter system. Build Spud Mud. 5. Drill a 12-1/4" surface hole as per directional plan and run and cement 9-5/8" casing. Run only Dir MWD and LWD CDR (Gr/Res). 6. ND 20" Diverter, NU and Test 13-5/8" BOPE. 7. MU a PDC bit on a motor, with Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). RIH, Drill out FE and 10' of new formation -- Perform LOT. 8. Drill 8.5" hole to TD -- This hole section will be logged LWD with Triple Combo (GR/Res/Neu/Dens). Run and Cement 7" Casing. Displace and bump plug with Source Water (w/Corexit 7726) and Freeze Protect Top 2000' of with diesel. 9. ND BOPE, NU and Test Tree. RDMO Nabors 22E drilling rig to drill next well. 10. MIRU Nabors 4ES. NU & Test BOPE to 5000 psig. 11. RIH while PU 3-1/2" drill pipe and 7" 26# scraper and bit. RIH to PBTD, perform a casing wash while displacing the hole with 10.2 ppg brine. Filter brine water to 2 micron absolute. 12. POOH & PU Drill Pipe Conveyed Perforating Guns. RIH and Set Packer. ROPE Perforate the well. Kill. well while circulating 10.2 ppg kill weight brine. 1 3. POOH laying down 3-1/2" Drill Pipe. 1 4. Change Rams and run Electric Submersible Pump on 2-7/8" threaded tubing. 15. Install Surface Lines and Wellhouse and put the well on production. Drilling Hazards and Risks: 1. Hydrates have been encountered while drilling the MPH-05, 06 and 07 wells. 2. MPH-05 experieced major lost circulation in the surface hole while drilling at 3700' tvd -- this lost circulation caused the 9-5/8" surface casing to be set shaflow MPH-06 and MPH-07 were drilled without incident. 3. Minor losses were experienced while drilling the MPH-01,2, and 3 wells. _A/Bska,-_ .0it ~,,. Gas f.,0ns. O0mmissi0r~ .... Anchorage MPH-07 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON STAGE I CEMENT JOB across the Schrader Bluff Formation: CIRC. TEMP: 60° F BHST 80° F SPACER: 10 bbls fresh water followed by 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. LEAD CEMENT TYPE: ADDITIVES: Retarder WEIGHT: 12.0 ppg gal/sk APPROX #SACKS: 440 Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 THICKENING TIME: Greater than 3-4 hrs at 60° F. TAIL CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.2% Halad 344 YIELD: 1.15 cu ft/sk WEIGHT: 15.8ppg APPROX # SACKS: 616 FLUID LOSS: 100-150 cc MIX WATER: 5.0 gal/sk THICKENING TIME: 3-4 hours @ 60° F. FREE WATER: 0cc @ 45 degree angle. STAGE II CEMENT JOB ACROSS Prince Creek to Surface: CIRC. TEMP: 60o F BHST 40° F SPACER: 75 bbls fresh water. LEAD CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX #SACKS: 704 THICKENING TIME: Greater than 3-4 hrs at 60° F. TAIL CEMENT TYPE: Premium G ADDITIVES: 2% CaCI2 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk APPROX # SACKS: 50 THICKENING TIME: 3-4 hours @ 60° F. FLUID LOSS: 100-150 cc FREE WATER: 0cc @ 45 degree angle. TOP JOB CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX NO SACKS: 250 CENTRALIZER PLACEMENT: 1. 9-5/8" x 12" Straight Blade Rigid Centralizers-- two per joint on the bottom 33 joints of 9-5/8" Casing (66 total). This will cover 200' above the Na Sand. 2. Run one 9-5/8" x 12" Straight Blade Rigid Centralizer on each side of ES Cementer (2 Total). 3. Total 9-5/8" x 12" Straight Blade Rigid Centralizers needed is 68. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 10-14 bpm. Batch mixing is not necessary. CEMENT VOLUME: 1. Stage 1 cement volume is calculated to cover 500' md above the Na Sand with 30% excess. 2. Stage 2 cement volume is calculated to cover from the top of Stage 1 to 1500' md with 30% excess and from 1500' md to surface with 100% excess. ^ncl~0rag~ : CIRC. TEMP: SPACER: 11 CEMENT MPH-07 Well PRODUCTION CASING PROGRAM- HALLIBURTON 140° F BHST:170 deg F at 7040' TVDSS. 20 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. LEAD CEMENT TYPE: ADDITIVES: Retarder WEIGHT: 12.0 ppg Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX #SACKS: None THICKENING TIME: Greater than 3-4 hrs at 180° F. TAIL CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.8ppg APPROX # SACKS: 21 9 YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FLUID LOSS: < 50cc/30 min @ 140° F FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7-1/8 .... x 8-1/4" Straight Blade Turbulators -- 46 Total (2 per joint on bottom 23 joints). 2. Run two 7-1/8" x 8-1/4" Straight Blade Centralizer 60' above the 9-5/8" casing shoe. 3. Total 7-1/8 .... x 8-1/4" RH Turbulators needed is 48. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME: 1. The cement volume is calculated to cover 1000' md above the C1 Sand with 30% excess. BP EXPLORATION To~ From: Date: Subject: Bob Crandall, AOGCC Joe Polya, BP (Shared Services Drilling) August 28, 1995 Application for Spacing Exception for the Milne Point H-08 Well (20 AAC 25.055) The MPH-08 well is planned to drill into the Kuparuk River formation in the South East Quarter of Section T12N and R10E. This section is located to the South of the Milne Point Unit Boundary. This quarter section is bounded on the West, Northwest, and North by quarter sections within ADL 380109 for which the operators are BPX 91.19 and Oxy USA 8.81; on the Northeast and East by quarter sections within ADL 380110 for which the operators are BPX 91.19 and Oxy USA 8.81; on the Southeast by a quarter section within ADL 047446 for which the operators are Chevron 50.00 and Mobil 50.00; and on the South and Southwest by quarter sections within ADL 025637 for which the operators are Arco 50.00 and BPX 50.00. See the Attached Map. The MPH-08 well is planned as a high angle producer to be completed with an electric submersible pump. The Surface Location for the MPH-08 well is 2766' fsl and 4062' fel in Section 34 T13N R10E. Entry Point in the Kuparuk formation (C1 Sand) is planned for 1682' fsl and 2368' in Section 12, T12N, R10E with the planned TD at 1330' fsl and 2157' fel Section 12, T12N, R10E. We have notified all owners and operators via registered mail as per the AOGCC Regulation 20 AAC 25.055 -- See Attached Plats and Registered Mail Notice. This well is contingent upon the results of MPH-06 and could be drilled immediately after MPH-06 in the schedule. Thank you for your assistance in this matter. Please direct any questions to Mark Bendersky at 564-4666. Respectfully, Joe Polya CC' Arco BPX Chevron Mobil Oxy USA sEP 0 1995 Oil N Gas Cons. Commiss%oa -' .. 'Anchorage TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 September 18, 1995 Tim Schofield, Sr Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Miine Point Unit MPH-08 - BP Exploration (Alaska), Inc: Permit No 95-134 Surf Loc 2766'NSL, 4061'WEL, Sec. 34, T13N, R10E, UM Btmhole Loc, 1330'NSL, 2157'WEL, Sec. 12, T12N, R10E, UM Dear Mr. Schofield: Enclosed is the approved application for permit to ddil the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representati..ve of the Commission may witness the test. Notice may be given by contacti :he Commission petroleum field inspector 659-3607. David W. Chairman BY ORDER OF THE COMMISSION /enct c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill [] Redrill FIIlb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenFII Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 66 feet Milne Point / Kuparuk River 3. Address 6. Property Designation P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 380109 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 2766' NSL, 4061' WEL, SEC 34, T13N, RIOE Milne Point Unit At top of productive interval 8. Well number Number 1682' NSL, 2368' WEL, SEC 12, T12N, RIOE MPH-08 2S100302630-277 At total depth .9. Approximate spud date Amount 1330' NSL, 2157' WEL, SEC 12, T12N, RIOE 09/10/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property'15. Proposed depth (MD and'rVD) property line ADL 025637 1330 feet No Close Approach feet 2560 16654'MD/6852' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth soo feet Maximum hole angle z2 o Maximum surface 2796 psig At total depth (TVD) 6852'/3460 psig 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 7973' 31' 31' 8004' 4216' ~pF'~,~92,x~:~,~'~.5o~'~',~5osx'E' 8-1/2" 7" 26# L-80 Btrc 16624' 30' 30' 16654' 6852' 221 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 Measured depth True Vertical depth Structural Conductor ~,,'' .... ~' "'~'~ Surface L. ~ L~ ~ ,, Intermediate Production AUG 2 9 i995 Liner Perforation depth: measured b~[~,.~ ~l.& Gas Cons. C0mmissi0_r~ true vertical '"'" ~ach0ra¢e 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report[-I 20 AAC 25.050 requirements[] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~¥~"~,~--~'-- ~"T¥~,~, ,~,~.~~ Title Senior Drilling Engineer Date Commission Use Only Permit Number [APl number IAppr~v¢ date ISee cover letter ¢..T..,/,.jr.H lbO_O~_'p... 2_ 2.-.~?.2_.., -- /~-',G...B"' Ifor other requirements Conditions of approval Samples required [] Yes [] No Mud Icg required []Yes [] No Hydrogen sulfide measures [] Yes..-~-No Directional survey required [] Yes [] No Required working pressure for BOPE 1-12M; 1-13M; 1~bM; I-I10M; I-I15M; Other: Original Signed By by order of /3/ Approved by David W. Johnston Commissioner ~ne commission Date'S././ Form 10-401 Rev. 12-1-85 Submit i Well Name: I MPH-08 Well Plan Summary Type of Well (producer or injector): I Kuparuk Producer Surface Location: Target Location: Bottom Hole Location: 2766 NSL 4061 WEL Sec 34 T13N R10E UM., AK. 1682 NSL 2368 WEL Sec 12 T12N R10E UM., AK. 1330 NSL 2157 WEL Sec 12 T12N R10E UM., AK. [AFE Number: [ 330180 Estimated Start Date: I MD: I16654' I ITVD: Well Design (conventional, slimhole, etc.): [Rig: [Nabors 22-E Operating days to complete: [ 16 1 6852' bkb I IKBE: [ Milne Point Ultra Slimhole 7LS [66' Formation Markers Formation Tops MD TVD (bkb) base permafrost 1846 1816 iNA 6920 3886 Top of Schrader Bluff Sands (8.3 ppg) OB 7609 4096 (8.3 ppg) Seabee Shale 7674 4116 Base of Schrader Bluff Sands (8.3 ppg) HRZ 14418 6171 High Resistivity Zone Top Kup 15730 6571 Kuparuk Cap Rock Top C! Sand--Target 16222 6721 Target Sand (9.9 ppg) Total Depth 16654 6852 Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9 5/8" 40# L-80 btrc 7973 31/31 8004/421{~ 8 1/2" 7" 26# L-80 btrc 16624 30/30 16654/685: Internal yield pressure of the 7" 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 7000 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3460 psi is 2796 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: Surface intermediate Final MWD Directional and CDR (Gr/Res) across Schrader Bluff N/A 1. PDC Bit f/Seabee to TD w/MWD Dir and LWD (GR/CDR/CDN). Cased Hole Logs: GR/CCL will be run in 7" casing to Tie-in the TCP Guns for Completion. Mud loggers are not required for this well. AUG 29 1995 AlaSka 0il & Ga~ Con~, Commission Anchorage Mud Program: Special design considerations I None- SPUD MUD Surface Mud Properties: [ Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 50 15 8 10 9 8 to to to to to to to 9.4 100 35 15 30 10 15 Intermediate Mud Properties: N/A Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: I None- LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 10 3 7 8.5 6-8 to to to to to to to 10.4 50 15 10 20 9.5 4-6 ~ -,,Well Control: . ':.~Vell control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular · ' pre enter ;~q[ll be installed and is capable of handhng maximum otentlal surface ressures .. ,.:.~_,. . ~, P P · .,D~vert¢f; BOPE and drilling fluid system schematics on file with AOGCC, ,',3~" Dl~icl;[bnal: o" I :oP: 15oo' .,,,? .~ Maximu~ Hole Ahgle: 172° ' '~-0~7.~:":' Close Approach Well: i (No Shut Ins) Disposal: Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. Fluid Handling: All drilling and completion fluids can be annular injected. Approvals have been granted for MPH-05 and MPH-06 wells for annular pumping. Request to AOGCC for Annular Pumping Approval for MPH-06: 1. Approval is requested for Annular Pumping into the MPH-08 9-5/8" x 7" casing annulus. 2. Aquifers in the Milne Point Unit have been exempted from Class II injection activities by the AOGCC by Aquifer Exemption Order #2 as referenced in Area Injection Order #10. There are no domestic or industrial use water wells located within one mile of the project area. 3. The 9-5/8" casing shoe will be set at 8004' md (4216' tvd) which is below the Schrader Bluff Sands and into the Seabee formation which has a long established history of annular pumping at Milne Point. 4. The burst rating (80%) for the 9-5/8" 40# LB0 casing is 4600 psig while the collapse rating (80%) of the 7" 26# LB0 casing is 4325 psig. The break down pressure of the Seabee formation is 13.5 ppg equivalent mud weight. The Maximum Allowable Surface Pressure while annular pumping is calculated according to the following equation and is 2450 psi for a 10.4 ppg fluid in this well (Assumes worst case in which 7" casing is filled with gas). MASP = 4325 psig - ((fluid density ppg - 1.9) X 0.052 X 9-5/8" Casing Shoe TVD 5. A determination has been made that the pumping operation will not endanger the integrity of the well being drilled by the submission of data to AOGCC on 7/24/95 which demonstrates the confining layers, porosity, and permeability of the injection zone. 6. The cement design for this well ensures that annular pumping into hydrocarbon zones will not occur. AREA WELL PREV VOL PERMITTED PERMITTED INJECTED VOL DATES (BBLS) (BBLS) Milne Point MPH-05 0 0 I1 995 Milne Point MPH-06 0 0 1995 Milne Point MPH-08 0 0 1995 CIRC. TEMP: SPACER: 11 CEMENT MPH-08 Well PRODUCTION CASING PROGRAM- HALLIBURTON 140° F BHST:170 deg F at 7040' TVDSS. 20 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. LEAD CEMENT TYPE: ADDITIVES: Retarder WEIGHT: 12.0 ppg Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11,63 gal/sk APPROX #SACKS: None THICKENING TIME: Greater than 3-4 hrs at 180° F. TAIL CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk APPROX # SACKS: 221 THICKENING TIME: 3 1/2 -4 1/2 hrs @ 140° F FLUID LOSS: < 50cc/30 min @ 140° F FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7-1/8 .... x 8-1/4" Straight Blade Turbulators -- 38 Total (2 per joint on bottom 19 joints). 2. Run one 7-1/8" x 8-1/4" Straight Blade Centralizer 60' above the 9-5/8" casing shoe. 3. Total 7-1/8 .... x 8-1/4" RH Turbulators needed is 39. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME: 1. The cement volume is calculated to cover 1000' md above the C1 Sand with 30% excess. ' SHARED S'ERVZCES Marker Identification MD BKB SECTN INCLN A) KB 0 0 0 0.00 B) KOP/BUILD 1/100 500 500 -0 0.00 C] BUILD 2/100 t000 999 22 5.00 O) BUILD 3/100 i500 1491 109 15.00 E) END 3/100 BUILD 3409 2826 137~ 72.26 F) 9-5/8" CASING POINT 3509 2846 t467 72.26 G) TARGET 16222 672! 13576 72.26 H) 7" CASING POINT ~6654 6852 13986 72.26 II TD 16654 6852 13986 72.26 DRILLING ! iii mm i Anadr~ ]l Schlumberger ! MPH-08 (PO3) VE~IICAL SECTION VIEW Section at: TVD Scale.: Oep Scale.: Drawn ..... : 149.03 1 inch : 1800 feet 1 inch : 1800 feet 08/27/95 0 900 t800 2700 3600 4500 5400 6300 7200 8500 9000 9900 ~0800 11700 12600 13500 14400 '~5300 Sect ion Departure (~,naori]] (c)93 NPHOSP3 81.52 g:26 PM 1) SHARED i Marker IUent~fication Al TARGET 8~ 7' CASING POINT C) TO MD ~6222 ~6654 ~6§54 sERVICES i BKB SECTN INCLN 672! ]3576 72.2§ 6B52 13986 72.26 6852 13986 72.26 DRILLING iii ill imm m /nadri ]l Schlumberger mm i i 11 i m m MPH-OB (PO3) VERTICAL SECTION VIEW m i · ill _ m Section at: TVD Sca]e.: iOep Scale.: Orawn ..... : 149.03 :1 inch = 300 feet 1 inch = 300 feet 08/27/95 , It700 1a850 12000 12150 12300 12450 1~ 12750 12900 13050 13200 i3350 13~0 i3650 13B00 13950 lalO0 la250 14400 Section Departure {~naorill (c}93 ~3 BI.52 ~ ~ 1] .......... SHARED SERV]:CES D'~Ti"LING MPH-08 (PO3) PLaN V~EW CLOSURE · 13986 feet at Azimuth ~49.03 iDECLINATION.' 28.825 E SCALE · ! inch = 2000 feet DRAWN · 08/27/95 Anadri ]] Schlumberger ! ! ~000 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 ]0000 ]]000 12000 ~3000 <- WEST ' EAST -> (~adri)] (c)93 ~HOSP3 B~.52 ~: 2? P~ ~) ' BP EXPLORATION To'. From: Date: Subject: Bob Crandall, AOGCC Joe Polya, BP (Shared Services Drilling) August 28, 1995 Application for Spacing Exception for the Milne Point H-08 Well (20 AAC 25.055) The MPH-08 well is planned to drill into the Kuparuk River formation in the South East Quarter of Section T12N and R10E. This section is located to the South of the Milne Point Unit Boundary. This quarter section is bounded on the West, Northwest, and North by quarter sections within ADL 380109 for which the operators are BPX 91.19 and Oxy USA 8.81; on the Northeast and East by quarter sections within ADL 380110 for which the operators are BPX 91.19 and Oxy USA 8.81; on the Southeast by a quarter section within ADL 047446 for which the operators are Chevron 50.00 and Mobil 50.00; and on the South and Southwest by quarter sections within ADL 025637 for which the operators are Arco 50.00 and BPX 50.00. See the Attached Map. The MPH-08 well is planned as a high angle producer to be completed with an electric submersible pump. Entry Point in the Kuparuk formation (C1 Sand) is planned for 1682' fsl and 2368' in Section 12, T12N, R10E with the planned TD at 1330' fsl and 2157' fel Section 12, T12N, R10E. We have notified all owners and operators via registered mail as per the AOGCC Regulation 20 AAC 25.055 -- See Attached Plats and Registered Mail Notice. This well is contingent upon the results of MPH-06 and could be drilled immediately after MPH-06 in the schedule. Thank you for your assistance in this matter. Please direct any questions to Mark Bendersky at 564-4666. Respectfully, Joe Polya CC: Arco BPX Chevron Mobil Oxy USA 0il & Gas Cons. commission '/~ch0tag0 MPU Boundary DL 380109 ~ ! ADL 380110 I 0'/:i' 8:.81 I O'X ¥ 8, 81 I H-05 I ! I I I I 2 I H-( 61 5 11 KRU Boundary 7 8 50.00 ~.'. ·., t- I v 0il & Gas Cons. Commission Anchorage H Pad Tract Development Tract Well H-08 I Mile 25 August 1995 BSMc Z 142 7~3 111 No Insurance Coverage Provided U~ITEeST*TES DO not use for International Mail POSTAL SE~CE (See Reverse) Postage Certified Fee Special Deliver,/ Fee Restricted Delivery Fee Return Rece,pt Showing ~O Whom & Date Delivered Return Receiet Snowing.~ly~'b'~ Date, and Addressee sz~d~es¢,¢~ TOTAL Postage /.;.~ ? Postmark or Date ~ ~ © Z 142 7.S3 11~ ~-,.~.c¢-ipt for Certified ~ No Insurance Coverage Provided ..ITC0S,,TES Do not use for International Mail ~TAL (See Reverse) · Postage $ Speoal Dehvery Fee Restricted Delivery Fee to V,,'norn & Date Deh,,,ered , Return Receipt Showing to Whom, Date, and Addressee's A.~. , ,~. :~--~ TOTAL Postage Postmark or Dat~' . Z 142 753 113 ,~. Receipt for Certified Mail ~ No Insurance Coverage Provided Do not use for International Mail UNITED STATES POSTAL (See Reverse) P.O., State and ZIP Code Postage Certified Fee Special Delivery Fee Restricted Delivery Fee Return Receipt Showing tO Whom & Date Oeli',,'ered Return Receipt S~to Whom, Date a n d ~. ~ ~d'_d~ess Z 142 753 115 No Insurance Coverage Provided ~,,,..s,,,.s Do not use for International Mail P~TAL SE~E (See Reverse) P.O., State and ZIP C~e Certified Fee Special Delivery Fee Restricted Delivery Fee Date, and[AddCss~t~ ; ~ TOTAL P~s~ 9~ ~ ¢ ~ ~ Postmark 6~at~~ ~ , ._$ 2 9 1995 Oil & Gas Cons. Commission Anchorage BP EXPLORATION To.' From: Date: Subject: Bob Crandall, AOGCC Joe Polya, BP (Shared Services Drilling) June 23, 1995 Application for Spacing Exception for the Milne Point H-05 Well (20 AAC 25.055) The MPH-05 well is planned to drill into the Kuparuk River formation in the South East Quarter of Section T12N and R10E. This section is located to the South of the Milne Point Unit Boundary. This quarter section is bounded on the North, Northwest, West, Southwest, and South by quarter sections within ADL 380109 for which the operators are BPX 91.19 and Oxy USA 8.81. This quarter section is bounded on the Northeast, East, and Southeast by quarter sections within ADL 380110 for which the operators are BPX 91.19 and Oxy USA 8.81. See the Attached Map. The MPH-05 well is planned as a high angle producer to be completed with an electric submersible pump. Entry Point in the Kuparuk formation (C1 Sand) is 2328' FSL and 1053' FEL in Section 01, T12N, R10E and TD at 1867' FSL and 0392' FEL Section 01, T12N, R10E. We have notified all owners and operators via registered mail as per the AOGCC Regulation 20 AAC 25.055 -- See Attached Plats and Registered Mail Notice. Thank you for your assistance in this matter. Please direct any questions to Mark Bendersky at 564-4666. Respectfully, Joe Polya_ c c: BPX Oxy USA RECEIVED JUN 2T i99[ Alaska Oil & Gas Cons. Commission [_,.,,. _Receipt for Certified Mail No Insurance Coverage Provided Do not use for International Mail UN~TED STATES PO~TA L .~E R'¥]C E (See Reverse) Street and ~ ¢OA'~ ,~.~., S~ate and ~P Postage Certified Fee Special De;ivery Fee Restricted Delivery Fee Return Receipt Showin~ to Whom & Date Delivered Return Receipt Showing to Whom, Date, and Addressee's Address - , TOTAL Postage & Fees /?~xO; Postmark or Date {~ i, ~, ~.'?~' (_? 1 ~;";_- RECEIVED JUN 2'f 1,995 Alaska 0ii & 6as Cons. Commission MPU Boundary 6PX I Section 2 S'e ~'[i o~ 1~ ', KRU Boundary PBU Boundary Tract Development Drilling Block Proposal Tract Wells H-05, H-06, E-24i I I I 380110 oxy us~ 8.81 Section 5 Section 8 I Mile 14 June 1995 BSMc i · SHA'REB' 'SERI'CES i'1 i i I i I'1 ~rker /~n~'ificat~on. I!0 BKB SEC~ A) ~ 0 ~ ~ 0.00 n) ~/~U~L~ ~/~ ~0 .5~ o o.~ O] B~ZLD 3/100 t~O ~49t JO9 t5.~ ~] ~ 3/~00 ~ILO 3~$9 2749 ~94 ~.~ . . Fl TA~T 129[5 66~ tO090 ~.~ ' G) I0 33793 6~5 t0896 ~.~ I ii ,DRILLING i I 1 TVD Scale ' 1 inch = 1600 feet Dep Scale · ! inch = ~600 feet OPa~n .... ' 06/23/95 i IIll I I MPH-05 (P4) 'VERTICAL SECltON VIE~ ! _ ~ , i "' FE ~SIB LIT' f PL~N .... ~ :": i ....... -' . .... 0 .-.. 800 16130 2400 3~00 4DO~ 4800 560D .B4D[} 72D0 81)0~ 88~X). 964XI tO400 11200 ~ ]2i~)1) . S360~ ' S~ction Oepar'ture R"~CES DRILLZ~G ....... ' ..... so/~z~'c'~r~r '" I SHARED SE. .4nadr'~]] ii iiiii i · i i i ii iii iii iiiii i i ii ii i i i i i i _ i i i i i i ! i m ii i ii i MPH-05 (P4) PLAN VIEW ~RE ..... :10896 feet at Azimuth ~24.89 9 500 .......... ~ . : ,.NATION.; 28.870 E .~ ~[ ': ...... ~ inch: ~200 feet . 0 0 0 , ,3/100 ~ILO 3~t9 ~ 979 ~T t2915 5~ , ~76 ,hADRILI AKA .DPC ~ , ~ blOT qPPttOVED, F()R 'j % E XEC ~I'ON WELL PERMIT CHECKLIST PROG~AM: exp [] dev [] redrll [] serv~ ADMINISTRATION 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Permit fee attached ................... Lease number appropriate ............... Unique well name and number .............. Well located in a defined pool ............. Well located proper distance from drlg unit boundary. Well located proper distance from other wells ..... Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included ......... Operator only affected party ............... Operator has appropriate bond in force ......... Permit can be issued without conservation order .... Permit can be issued without administrative approval. Can permit be approved before 15-day wait ........ N N 14. Conductor string provided ............... 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnm~t been approved. 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ............ ~,~ ....... 26. BOPE press rating adequate; test to .~)~ psig.~ 27. Choke manifold complies w/API RP-53 (May 84) ....... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............ ,,. ~EoLo~M 30. Permit can be issued w/o hydrogen sulfide measures .... Y N 31. Data presented on potential overpressure zones ..... Y N 32. Seismic analysis 9f shallow gas zones .......... Y N 33. Seabed condition survey (if off-shore) ......... Y N 34. Contact name/phone for weekly progress reports ..... Y N [exploratory only] GEOLOGY: ' -ENGIEERiNG: ............. c6MMi~SibN ~ ................ comments/Instructions: HOVV/jo - A:Y::ORMSlcheklist rev 03~4 ,, WELL PERMIT CHECKLIST ~.~m'T~6N ' ' ............ DA~E ENGINEERING INIT CLASS 2. 3. 4. 5o 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Lease numDer appropriate ............... Unique well name and n~ber .............. Well located in a defined pool ............. Sufficient acreage available in drilling unit ...... If deviated, is wellbore plat included ......... Operator only affected party ............... Operator has appropriate bond in force ......... Pe~it can be issued without conse~ation order ..... Ps,it can be issued without a~inistrative approval.. ~ .......... · .... ' ........ Conductor string provided ............... Surface casing protects all kn~ USDWs ........ CMT vol adequate to circulate on conductor & surf csg. ~T vol adequate to ~ie-in long string to surf csg . . ~ will cover all kno~ productive horizons ...... Casing designs adequate for C, T, B ~ pe~afrost .... Adequate tankage or resets pit ............ If a re-drill, has a ~0-403 for abnd~t been approved. Adequate wellbore separation proposed .......... If diverter required, is it adequate .......... Drilling fluid progr~ schematic & equip list adequate BOPEs adequate .................... BOPE press rating adequate; tss~ to ~~ psig.~ Choke manifold complies wl~I ~-53 (May 84) ...... Work will occur without operation shut~o~ ....... Is presence of ~2S gas probable ............ 30. Permit can be issued w/o hydrogen sulfide measures .... Y N 31. Data presented on potential overpressure zones ..... 32. Seismic analysis gf shallow gas zones ......... ~ N 33. Seabed condition survey (if off-shore) ....... /. Y N 34. Contact name/phone for weekly progress reports . ./<... Y N [exploratory only] Comments/Instructions: TAB HOW/jo - A:~FORMS~cheklist rev 03/94