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Home My WebLink About198-050Pages 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. J*~/-A~ File Number of Well History File /lOci,-..- PAGES TO DELETE RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: n Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] OVERSIZED Diskettes, No. Other, No/Type Logs of various kinds Other Complete COMMENTS: Scanned by: Beverly Mildred Damth~owell TO RE-SCAN Notes: Date' Isl Re-Scanned by: Bevedy Mildred Damtha(Nathan ~-owell Date: Is* ~KA OIL AND GAS CONSERVATION COMPlISSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 September 6, 2001 Fritz Gunkel, Manager Drilling BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519 Re: Cancelled or Expired PTD's. Dear Gunkel: The Alaska Oil and Gas Conservation Commission ("AOGCC") approved the following referenced permit to drills. The AOGCC has a long-standing policy of releasing cancelled or expired permits two years from the date the application was approved by the AOGCC. The following files are scheduled to be released October 1,2001. Permit to Drill No.'s: 97-047 98-019 99-002 97-056 98-050 99-009 97-082 98-135 97-090 98-154 97-100 98-155 97-121 98-164 97-159 98-167 97-191 98-177 98-210 98-211 98-223 98-236 98-257 98-261 ., Sincerely, Executive Secretary Memorandum State of Alaska Oil and Gas Conservation Commission To: WellFile: It~7"~c.~O DATE /~ Re: Cancelled o(E~ ~ermit Action EXAMPLE: Point McIntyre P2-36AXX API# 029-22801-95 This memo will remain at the front of the subject well file. Our adopted conventions for assigning APl numbers, permit numbers and well names did not specifically address expired or cancelled permits. This omission has caused some inconsistencies in the treatment of these kinds of applications for permit to drill. Operators have asked us to adopt formal procedures for this class of permit application in order to prevent future database disparities. If a permit expires or is cancelled by an operator, the permit number of the subject permit will remain unchanged. The APl number and in some instances the well name reflect the number of preexisting redrills and or multilaterals in a well. In order to prevent confusing a cancelled or expired permit with an active well or multilateral these case sensitive well identifiers will be changed for expired and cancelled applications for permits to drill. The APl number for this cancelled or expired permit is modified so the eleven and twelfth digits is -95. The well number for a cancelled or expired permit is modified with an appended XX. CANCELED PERMITS ARE RELEASABLE 2 years from the date on the letter received from the operator requesting the permit canceled.. (Memorandum January 23, 1997 by Dave Johnston, subject: Canceled and Expired Permits) EXPIRED PERMITS ARE RELEASABLE 2 years from the date on the application was issued by the commission, unless the operator ask for extended confidentiality. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION CO~E~IISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 10. ! 998 Chip Alvord Enginccring Supcrvisor BP Exploration (Alaska) Inc. POBox 196612 Anchorage. AK 99519-6612 ac~ Milnc Point Unit MPC-40 BP Exploration (Alaska) Inc. Pcrmit No: 98-050 Sur. Loc.: 751'NSL. 2316'WEL. Scc. 10. TI3N. RIOE. UM Btmhoic Loc: 3022'NSL. 3922'WEL. Scc. 16. TI3N. RIOE. UM Dcar Mr. Alvord: Enclosed is thc approvcd application for permit to drill thc abovc rcfcrcnccd wcll. Thc pcrmit to drill docs not exempt you from obtaining additional pcrmits rcquircd bx' law from othcr govcrnmcntal agencies, and docs not authorizc conducting drilling opcrations until all other required permitting dctcrminations arc made. Blov,-out prcvcntion cquipmcnt (BOPE) must bc tested in accordance with 20 AAC 25.035. Sufficicnt noticc (approximatcly' 24 hours) of thc BOPE tcst pcrformcd bcforc drilling bclow thc surface casing shoe must bc given so that a representative of thc Commission may witness thc tcst. Notice may bc givcn bx' contacting thc Commission pctroicum ficld inspector on thc North Slope pager at 659-3607. David W. Johnston / "'"" ---'-~ Chairman '"'-x......~ BY ORDER OF THE COMMISSION dll;enclosures cc; Department of Fish & Game. I lahilat Section w o cncl. I)cparlmcnt ol' Environmental Conscrx-ation w o encl. STATE OF ALASKA "'-" ALASKA ,.,~L AND GAS CONSERVATION COrvlMISSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work l~ Drill I--IRedrill Ilb. Typeofwell I--IExploratory I--IStratigraphicTest I~ Development Oil [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 49.3' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 315848 ~ 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 751' NSL, 2316' WEL, SEC. 10, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 3064' NSL, 3826' WEL, SEC. 16, T13N, R10E, UM MPC-40 Attotal depth 9. Approximate spud date Amount $200,000.00 3022' NSL, 3922' WEL, SEC. 16, T13N, R10E, UM 03/22/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025515, 1358'I No Close Approach 1280 11218' MD / 7382' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 300' Maximum Hole Angle 60.65° Maximum surface 2853 psig, At total depth (TVD) 7145' / 3567 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 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 4861' 31' 31' 4892' 3549' 1014 sx Class 'G', 994 sx PF 'E' 8-1/2" 7" 26# L-80 Mod-Btrc 11188' 30' 30' 11218 7333 225 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 MD TVD Structural Conductor Surface Intermediate Liner Production - -~ ~ CE I ~/~ ~,~ ' ORIGINAL Perforation depth: measured _~asJ(a Oil & Gas Cons. C0r~;r.',jssi,,. ' Anchora.~ true vertical ' 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: Lance Spencer, 564-5042 Prepared By Name/Number: Kathy Campoamor, 564-5122 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/~_ ~ (~-~ Title Engineering Supervisor Date Chip Alvord ~- _ Commission Use Only Permit Number I APl Number I Ap_provalDate I See cover letter °1(~ -00~0 50- O~¢~- ~,,~ 971 ;'~JlQ)lOl'~ forother requirements Conditions of Approval: Samples Required []Yes []No Mud Log Requir[ed [ I--lYes []No Hydrogen Sulfide Measures I~Yes []No Directional Survey Required ~Yes []No Required Working Pressure for BOPE []2M; []3M; [~5M; []10M; []15M Other: '~ ~-?,d By Approved By Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit n Triplicate Shared Services Drilling Contact: I Well Name: Type of Well (producer or injector): Lance Spencer IMP C-40 Well Plan Summary 564-5042 I Kuparuk Producer Surface Location: 751' NSL, 2316' WEL, Sec. 10, T13N ,R10E, UM., AK Target Kuparuk Bottom Hole Location: 3064' NSL, 3826' WEL, Sec. 16, T13N, R10E, UM., AK 3022' NSL, 3922' WEL, Sec. 16, T13N, R10E, UM., AK I AFE Number: 1337120 I Estimated Start Date: I 22 March 98 I I MD: 11~,2~S' I ITvD: I Well Design- Ultra Slim Hole Long String HAW Rig: I Nabors 27-E Operating days to complete: I 13 I 17,382' Bkb I I KBE: 149. 'I I 9-5/8", 40# Surface X 7", 26# Production Formation Markers: Formation Tops MD TVD (ss) EMW Formation Pressure Base Permafrost 1912 1800 8.4 ppg 786 psi NA Schrader Bluff 6096 4090 8.4 ppg 1829 psi OA Schrader Bluff 6382 4230 8.6 ppg 1892 psi OB Base Schrader Bluff 6525 4300 8.6 ppg 1923 psi Top HRZ 10251 6430 9.0 ppg 3009 psi Base HRZ 10414 6580 9.0 ppg 3079 psi TKLB(MK-19) 10517 6675 9.4 ppg 3263 psi TKUD 10576 6730 9.4 ppg *3290 psi TKUC 10757 6900 9.6 ppg *3444 psi TKUB 10768 6910 9.6 ppg *3449 psi TKUA3 10912 7045 9.6 ppg '3517 psi TKUA2 10933 7065 9.6 ppg *3527 psi TKUA1 10975 7105 9.6 ppg *3547 psi Miluveach 11018 7145 9.6 ppg 3567 psi Total Depth 11218_+ 7333_+ 9.6 ppg 3661 psi · *These are estimated maximum pressures and the actual pressures may be lower. ~aslng/i umng Proc.ram: 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 btm 4,861 31/31 4,892/3,549 8-1/2" 7" 26# L-80 Mod. 11,188 30/30 11,21 8/7,333 btm The internal /ield pressure of the 7" 26# casing is 7240 psi. The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKAlat _+ 7,145 TVDbkb In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of _7,145 TVDbkb. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3,567 psi is 2,853 psi using a 0.1 psi/ft gas gradient, well below the internal yield pressure rating of the 7" casing. MP C-40 Drilling Permit 1 3/5/98 Cementing Program: Halliburton Cementing Services Hole v Ca~ing Interval Volume~ Spacer Type of Cement Propertiesz Cate~lory Size/Depth Surface First Stage 9-5/8" @ 2,112-4,893 1014 sx 70 bbls Premium Class "G" w/ Den 15.8 ppg 10,035 208 bbls Fresh water 0.2 % CaCI, Yield 1.15 ft 3/sx 0.15 #/sk Celoflakes Water 4.9 gps TT 4.0 hrs Second Stage Stage collar° @ 0-1,912' 994 sx 75 bbls Permafrost "E" Den 12.0 ppg 2,112' 1,912-2,112' 384 bbls Fresh water Yield 2.17 ft 3/sx Water 11.63 gps TT 4.0 hrs Production 7" @ 9,757'- Lead' ' Lead Lead Den 15.8 ppg First Stage 19,704 11,218' 225 sx 70 bbls Premium Class "G" w/ Yield 1.15 ft 3/sx 46 bbls NSCI Spacer 0.2 % CFR-3 Water 5.0 gps 0.1% HR-5 TT 3.5-4.5 hrs @140° F 0.45% Halad 344 FL 50cc/30 min @ 140° F 9 10 11 12 13 Volumes are rounded up to the nearest 10 sacks. Ensure thickening times are adequate relative to pumping job requirement. Actual times should be based on job requirements and lab tests. Perform lab tests on mixed cements, spacers and mud's to ensure compatibility prior to pumping job. A Type H ES Cementer will be installed in the 9-5/8" csg. 200' md below the base of the Permafrost at 2,112'MD_+ The surface hole First Stage Cement Volume covers the Interval from 2,112-4,892' md. The estimated first stage lead cement volume from 2,112-4,892 md is equivalent to the annular volume calculated from the 9-5/8" ES Cementer at 2,112' md which is 200 ft md below Base of the Permafrost at 1,912' md (1,849' TVD bkb) to surface hole TD at 4,892' plus 30% open hole excess and the shoe joint volume. The estimated shoe joint volume is equivalent to the capacity of 80'md of 9-5/8", 40# casing. The surface hole Second Stage Cement Volume covers the interval from 0-2,112' md The estimated second stage lead cement volume is equivalent to the annular volume calculated from the ES cementer located at 2,112' MD (2,098' TVDbkb) to surface. From the base of the Permafrost at 1,912' to the ES Cementer at 2,112' use 30% open hole excess and from the base of the Permafrost to surface include 250% open hole excess and from 1,945-2,145' use a 30% open hole excess and the shoe joint volume. The estimated shoe joint volume is equivalent to the capacity of 80'md of 7", 26# casing.. For surface install one(l) Bow Spring Centralizers per joint on the bottom 10 joints of 9-5/8" casing (required). The production hole will be cemented in a single stage. The Cement Volume covers the interval from 9,757- 11,218' md The estimated first stage tail cement volume is equivalent to the annular volume calculated from 9,757' which is 1000'+ above the Kuparuk C Sand to TD at 11,218" plus 30% open hole excess and the shoe joint volume. The estimated shoe joint volume is equivalent to the capacity of 80'md of 7", 26# casing. Use 7" x 8-1/4" Straight Blade Rigid Centralizers and install one per joint from 120' above the Kupaurk C-Sand and use two per joint on the shoe joints. Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing. Install two 7" marker joints and position three joints above the Kuparuk C sand. Place all centralizers in middle of joints using stop collars. Mix all cement slurries in the surface and production holes on the fly - batch mixing is no~t necessary. If the Schrader Bluff is productive the 7" production casing will be cemented in two stages. 13.1 The ES cementer will be installed 200' below the base of the Schrader Bluff OB sand at 6724. 13.2 The first stage will be cemented as described in 7 above. 13.3 Use 7" x 8-1/4" Straight Blade Rigid Centralizers and install one per joint from the base of the Schrader OB to the top of the Schrader NA and from TD to 120' above the Kupaurk C-Sand. In addition use two per joint on the shoe joints. 13.4 The production casing Second Stage Cement Volume covers the interval from 5596-6,724' md The estimated second stagel cement volume is equivalent to the annular volume calculated from 5596' which is 500'+ above the Schrader Bluff NA Sand to the ES Cementer which is 200' below the Base of The Schrader Bluff OB Sand at 6,724' plus 30% open hole excess~ MP C-40 Drilling Permit 2 3/5/98 Logging/Formation Evaluation Program: Anadrill Schlumberger Open Hole Logs: Surface-12-1/4" Intermediate Final Production 8-1/2" Cased Hole Logs: Mud Logging None 1. M10 Power Plus MWD Directional from top to bottom of surface hole.. 2. DWOB/DTOQ from top to bottom of surface hole. N/A 1. M10 Power Plus MWD Directional 2. LWD (CDR/AND/GR/ROP) (ReaITime) 3. DWOB/DTOQ N/A Schlumberger IDEAL System in the surface and production holes. SPIN Log: Record: GR, Depth, Surface Torque and DWOB/DTOQ, ROP, Hook Load, RPM, Pump Pressure, GPM (in and out) during all operations. 12-1/4" and 8-1/2" Hole M10 PowerPlus IWOB: GR: CDR: ADN: ROP: Directional Inclination and Azimuth DWOBB/DTOQ Gamma Ray Compensated Dual Resitivity Azimuthal Density Neutron (Density, Porosity, and Sonic Caliper) Rate of penetration Mud Program: Baroid Drilling Fluids Inc. Surface Mud Properties: LSND Freshwater Mud Density Marsh Yield 10 sec 10 min pH Fluid Solids (PPG) Viscosity Point gel gel Loss % 8.6-9.6 50-150 15-35 8-15 10-30 9-10 8-15 <9 Production Mud Properties to Change LSND Freshwater Mud Over Depth at TKUD Density Marsh Yield 10 sec 10 min pH APl HTHP Solids (PPG) Viscosity Point gel gel Filtrate %LGS 8.6-9.3 35-45 6-20 3-10 7-20 8.5-9.5 6-12 8-10 <6 Production Mud Properties from HRZ to LSND Freshwater Mud TD. Density Marsh Yield 10 sec 10 min pH APl HTHP Solids (PPG) Viscosity Point gel gel Filtrate %LGS 9.3-9.8 35-45 6-20 3-10 7-20 8.5-9.5 <4 8-10 for <6 HRZ Miluveach Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. The diverter, BOPE and drilling fluid system schematics are on file with AOGCC. MP C-40 Drilling Permit 3 3/5/98 Directional: KOP1 Tangent Hole Angle Final Drop Maximum Hole Angle Close Approach Wells Survey Program 300' Start Variable @ 1.0°- 3.0°/100 to 60.65° inc. and 246.4° az. EOB @ 3,012' md. 60.65° from 3,012-8,995' Start Final Curve 8,995' @ 3.0°/100 to 20° incl. and 246.40Az° EOD 10,712' md 60.65° from 3,012-8,995' All wells may remain flowing while drilling C-40 and no shut-ins are required. 1. Surface to 4,892' MWD surveys. 2. 4,892-11,218' MWD surveys 3. ~ :.i:.ii~?:~:i;:i~iiii:!ii:?~i:ili~i:i?ili:i:::~:i,~:,!::?~?~:;i after Nabors 27E RDMO. Disposal: No "Drilling Wastes" will be injected or disposed into C-40 while drilling this well. Cuttinqs Handlin_~: 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. Fluids Handlinq: All drilling wastes will be hauled off and disposed of in accordance with pertinent rules and regulations. GENERAL DISCUSSION Well Obiective: MPU C-40 is planned as high angle 60.45°, Kuparuk River A Sand producer with a final departure of 7,508' at a measured depth of 11,21818'. The S-shaped well profile with a final angle of 20°, will intersect the targets in the Schrader Bluff and Kuparuk for optimum production. The surface casing will be shallow set above the Schrader Bluff at 4,892'md (3,549' bkb). Geology This well is located to southwest of C-Pad. The primary targets include the Kuparuk A3, A2 and A1 sands with some potential in the overlying Kuparuk C and B sands. The water contact is expected at 7,105'. The hydraulic unit in which the target is located contains 6.4 mmstb OOIP in the Kuparuk "A" sands. Recoverable reserves associated with this producer are estimate at 2.75 mmstb (0.96 mmstb primary and 1.28 MBO from secondaray) EOR benefits provide an additional 0.51 mmstb. Injection support will be provided by MP C-05A, which will be converted to an injector. DRILLING HAZARDS AND RISKS SUMMARY: The well profile has been designed to avoid close approaches and no wells will be shut in while drilling this well. Lost circulation and stuck pipe have occurred but not recently and are not expected. Formation pressures are expected to be normal (3444 psi at 6900' tvdss, 9.6 ppg EMW) in the Kuparuk formation, however may be partially depleted due to area production. No hydrates have been encountered while drilling on MPU C-Pad and are not expected. Close Approaches There are no close approaches associated with the drilling of MP C-40, however, tolerance lines should be carefully monitored and deviations from the proposed well path minimized. Water, Gas and WAG Iniection There has been no injection in Hydraulic Unit #28 into which MP C-40 is planned. Annular Iniection Currently annular injection is not permitted on C-Pad. Lost Circulation: Lost circulation is prevalent while running casing and cementing in the surface but also occurs in the production hole. Losses are extremely probable while cementing the production casing in wells with shallow set surface casing. Losses have been experienced while drilling the 12-1/4" surface and while circulating to condition mud before, while and after running surface casing to bottom. Major losses have also occurred while cementing the production casing. In many instances, the losses were minimized by reducing swab and surge pressures, minimizing mud weight and conditioning the mud before cementing. Contingencies have been incorporated to well program remedy loses if encountered. The losses normally occur in the Ugnu and Schrader Bluff with the shallow set surface casing design especially while cementing the 7" csg. MP C-40 Drilling Permit 4 3/5/98 Stuck Pipe Potential: Running gravel's, sticky clays, tight coal sections, packing off, bridging, and stuck pipe have occurred while drilling the 12 1-4" surface holes on C-Pad. Excessive amounts of reaming have been required to condition the hole to run surface casing. While running 9-5/8" casing the following problems were experienced: hole packing off; tight hole, bridging, and stuck casing. While drilling the surface hole additional time has been spent reaming and conditioning the hole prior to cementing because of tight hole. Attention should be given to The Ugnu and Schrader Bluff formations to reduce the chances of differential sticking in these formations with higher mud's weights with the shallow set surface casing design. While drilling the production section increased torque and drag have been experienced after drilling into Kuparuk D Shale. This common occurrence has often caused difficulties, so care should be taken to avoid the stuck pipe potential while drilling the 8 1/2" production interval. Shale instability is possible in the Miluveach and may result in tight hole or packing off so preventative measures must be taken to alleviate this risk if the Miluveach is inadvertently entered. Differential sticking is most likely to occur while running the production string. Formation Pressure: KUPARUK C SAND 6,900' TVDss 3,412 PSI 9.6 PPG EMW KUPARUK A1 7,105' TVDss 3,547 PSI 9.6 PPG EMW Formation pressures are expected to be normal and the pore pressure is estimated at 9.6 ppg EMW. The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKA1 at __. 7145' TVDss. In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of ~7,145' TVDbkb. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3,567 psi is 2,853 psi. The maximum expected pore pressure for this well is 9.1 ppg EMW (3,494 psi @ 7,102' TVDbkb). There has been injection in this region, however the reservoir pressure is not expected to exceed this estimate. See the updated Milne Point L-Pad Data Sheet prepared by Pete Van Dusen for information on~L pad and review recent wells drilled on L Pad. MP C-40 Drilling Permit 5 3/5/98 MP C-40 Kuparuk Producer Proposed Summary of Operations 1. Drill and Set 20" Conductor. Weld an FMC landing ring for an FMC Gen 5A Well head on conductor as well as a nipple to aid in performing potential well head stability cement job. 2. Prepare location for rig move. 3. MIRU Nabors 27E drilling rig. 4. NU and test 20" Diverter system. Ensure the diverter is as per AOGCC specifications and is approved by an AOGCC supervisor. Build Spud Mud. 5. Drill a 12-1/4" surface hole as per directional plan. Run Directional MWD/LWD (GR/DiR/CDR/DWOB/DTOQ) from surface to 12-1/4" TD. 6. Run 9-5/8" casing. Space out ES Type H Cementer to 2,112' md. 7. Perform Two Stage Cement Job. Complete the surface casing cementing check list. 8. ND 20" Diverter, NU and Test 13-5/8" BOP 9. MU a PDC bit on an extended power section medium speed motor, with Directional MWD and LWD (GR/DIR/CDR/DWOB/DTOQ). RIH, Drill out Float Equipment and 20' of new formation. Perform the Leak Off Test as per Recommended Practices Manual. Record pressure versus cumulative volume during the LOT test for the well file. 10. Drill 8.5" hole to TD as per directional plan. Make sure sufficient footage is drilled to provide a minimum ov 250' of production rat hole between the base of the Kuparuk A1 sands) and PBTD before running the 7" casing. 11. Run 7" casing. 12. Perform Single Stage Cement Job. Complete the production casing cementing check list. 13. Displace cement with 8.6 ppg filtered sea water and enough diesel to cover from the base of permafrost to surface (+-2200' MD). 14. Test casing to 3500 psig. 15. ND BOPE and 11" drilling spool NU tubing spool and dry hole tree and Test Tree. RDMO Nabors 27E. 16. RDMO Nabors 27E. THE WORKOVER PROGRAM WITH A DETAILED COMPLETION PROCEDURE SHALL BE SUBMITTED ONCE THE PERFORATION INTERVALS ARE SELECTED. MP C-40 Drilling Permit 6 3/5/98 Anadrill 8c hl~mberger Alaska District 1111 East BOth Avenue Anchorage, AK 99518 (907) 349-451~ FBLX 344-2160 ANADI~ILL AKA-DPC APPROVED FOR PERMITTING ONLY PLAN # 6/ Mell ......... : M~C-40 (P04) Field ........ Co0~p~tatio:..: Mi~£m~m Curvature ~ita ........ : FEET S~rface Lat.,: 70,48993734 Surface Legai Descriptio: Surface ...... : 751 FSL 2316 FEL $i0 T~3N RlOE UM C-97A Target,: 306~ FSL 3826 PE5 S16 T13N RIOE UM BBL .......... : ~022 FSL 3922 FEL 816 T15N R1OE UM AOCATIONS - ALASKA 5one: 4 X-Coord ¥-Coord 558547,65 6829033,57 551~8~.0~ 6026017.00 55~29~.3~ 6025974.~ Prepa~ad ..... : 02 ~(ar 1998 Uert sect az.: 246,40 KB elevation,: 49.30 ~L Ma~etic Dcl~: %27.82~ (E) Sca~e Factor.: 0.999903~4 Co~verg~ce..: +0.448042~3 @ROPOSED W~LL PROFILE STATION ~EABURED [NCLN DIRECTION VERTICA~-DE~T~S SF~TION COORDINATeS-FROM AI2%SKA Zone 4 TOOL DL/ ID~FI~T~ON DE~H ~ ~ZI~ T~ S~-S~ DEPOT ~LH~ X y FA~ ~ 0.fi0 O.00 O.O0 0.DO -49.30 O.O0 O.OO N O-OO E 558147-65 6029033.57 1141 0.GO KOP/BUI~ ~.00/100 300.00 0.00 246.40 300.00 250.70 -0.00 0.00 ~ 0.O0 E 558~47.65 6029033.57 ~41 0.00 400.00 1.00 2~6.40 399.9~ 350.6~ 0.87 0.35 S 0-B0 W 55~46.85 6029033.21 ll~L 1.0O BUID 1.5/100 5O0.0O 2.00 246.~0 499.96 450.66 3.49 1.40 ~ 3.20 W 55814~.Q6 602~o32.15 ll~5 %.0o 600.00 3.50 240.~0 599.84 550.54 ~.29 3.32 S 7.59 W 558~40.08 6029030.~9 1~4~ %.50 3> t~ 700.00 5.aa 246,40 699.56 650.26 L5.70 6,28 S 14.39 W 558133-32 6029027.17 1141 1,50 SgO.O0 7,00 246.40 799.01 749.71 26.15 10.47 S 23.96 W 558125.77 6029022-92 H$ 2.00 900.00 9.00 246.40 898.03 848.73 40,07 16.04 S 36.72 W S50111.06 6029017.25 ES 2.00 LO00.OO 11.00 246.40 996.51 947.21 57.43 22.~ S 52,63 W 558095,21 6029010.17 ES 2.00 1100.00 13.00 246.40 1094,32 10~5.02 78.22 31.31 S 71.68 W 558076.2~ 6029001.70 HS 2.00 1200.00 15.00 246.~0 1191.34 1142.04 L02.41 41.00 S 93.85 W 558054.13 6028991.84 HS 2.00 1300.00 I7.00 246.40 1287.46 1~38.16 129.97 52,03 S 119.11 W ~$$028.97 6028980.61 ~S 2.00 (Anadrill (c) 98 MPC40~O4 3.2C 11:36 STATION 2/I00 BUIS0 PERMAFROST SUXLD 3.00/100 ~ 3.00/100 BUILD PROPOSED WEI. L E~RO~'rLE MEASU~ I~C~ DIRECTION DH~TH Alq~L~ AZI[~[UTH 140B,O0 19,00 1500.00 AI,O0 246.~0 ~600.00 23.00 1700.00 ~5.00 ~46.40 l~OO.O0 27.00 2~6,40 1866.43 28.33 246.40 I9A1.87 28-33 246.40 ~934.60 2~.33 2000.00 30.29 246.40 2100.00 33.29 246,40 2200.00 36.29 246.40 2300,00 39,29 246.40 24~0,00 42,29 246.40 2500,00 45.29 246.40 260~.00 48.29 246.40 2700.00 5~.29 246,40 25~0.00 54.29 246.40 2900.00 57.29 246.40 3000.00 60.29 246.40 30~2.04 60.65 246.40 VERTICAL-DEPTAG SECTION TVD SU~-$EA DEPART 1382.56 1333,~6 160.88 1476.53 1427,23 ~95.G8 1569,24 1519.94 232.$3 1660,59 16~L.29 273.2~ 1750.47 L701.17 317.04 02 Mar 1998 Page 2 COORDInATES-FROM WELLHEAD 64.40 S 147.42 78,09 $ 178.76 93,09 S 213,09 126-92 S 1809.30 t760.00 347.88 139.26 1549.30 1800. O0 369.44 547.90 ~869.30 1820-D0 380.23 152,2L 1926.33 1877.03 412.25 165.03 2051.32 ~962.02 464.92 2093.44 2044,14 521.97 2172.45 2123,15 $$3.24 2248.15 2198.~5 64B.57 2320.35 2271.03 7Z7,76 2388.79 2339.49 790,64 2453,34 2404.84 867.00 2513 .~1. 2464.51 946.63 257'0.02 2520.72 1029.32 2621.83 2572.53 1114.84 262~. 77 2578.47 1125.32 POSSIBLE CASING PT 4892,29 60.65 246.40 3519.30 3500.00 2764.25 NA 6096.09 60.65 246,40 ~139,30 4090-00 3813-56 OA 635[.74 60.65 246.40 4279.30 4230.00 4062.55 BASE 08 6524.57 60.65 246.40 4349.30 4300.00 4187.04 POSSIBLE CASING PT 6677.59 60.65 246.40 4424.30 4375.00 4320.43 X Y FACE 100 557969.52 6028954.09 BS 2.0O 290.5~ ~ 557858,~S 602B904.40 HS 2.00 338.55 W 5578[0.30 602aSB3.05 ~ 0.00 34e.~3~ ssvsoo.~s 6oz~8~.6s ~s a.oo 208-96 S 470-32 W 55767L.02 6028820.90 ~ 3.00 233-48 S 534.47 W S~76L5.07 6028795,94 HS 3.00 259.63 S 59i.33 W 557555.43 6028769.32 HS 3.00 289.33 S 652.74 W 557492.2~ 6028741.13 HS 316,5[ S 724.52 W 557~25,70 6028711.44 ~S ? TOOt, D~,/ 3.00 3.00 347.08 $ 394.50 ~ 557355-97 6028680.33 ~S 3.00 378.96 $ 867.47 W 557283.25 6026647.88 H8 3,09 412.06 S 943.25 W 557207.75 6028614.19 HS 3.00 446.29 $ lO21,6L W 557129.66 6028579.35 HS 3.00 450,49 S 1031.21 W 557120.09 6028575.08 HS 3.00 1106.5B $ 2533.09 ~ 555623.53 6027907.32 H3 0.00 1526.64 S 3~94.65 W 554665.38 6027479.80 HS 0.00 1626.52 S 3722.82 W 554438.02 6027378.35 H$ 0.00 1676-~6 S 3836.90 W 554324.34 6029327.63 KS 0.00 1729.55 S 3959.14 W S54202.54 6027273.28 ~S 0.00 DROP 3.00/~00 6995.06 60.65 246.40 9000.00 60.50 246.40 9300.00 57.50 246.40 5560.12 5510.82 6340.47 2538.21 S 5510,25 ~ 552357.9~ 6026450.25 I~ O.O0 5562.55 5513.25 6344,77 2539.94 S $814.20 W 552354.05 6026448.49 I~q 3.00 5614.04 5564.74 6430.49 2574.25 S 58~2.74 ~ 552275-79 6026413.57 LS 3.00 STATION fD~NT IF I CAT fON SND 3.oo/~00 o~,oP TOP I{RZ uRom 1/loo TKUD WELL PROFILE MEASUREO INCLN DIRECTION VERTICAL-DEFIeS DEPTH A~GLE AZIMUTH TV~ SUB-SEA 9200.00 54.50 246.40 5669.95 5620.65 9300.~0 51.50 246.4~ ~730.12 5680.82 9400.00 ~$.50 246.40 5$94.38 5745.08 950~.00 45.50 246.40 5862.57 5815.27 9600,00 42-5~ 246.40 5934.49 5885.19 9700.00 39,~0 246,40 6009.95 5960.65 9800.00 36,50 246.40 60~8.74 6~39.4~ 99~0.00 33.50 246.40 6170.64 10000.00 30.50 246.40 6255.4~ 6206.13 lOIO0.OO 27.50 246.40 6342.88 6293.58 ~0200.00 24,50 246-40 6432.75 6383.~5 10250,86 22.98 246.40 6479.30 6430.00 10250.86 22.98 246.40 6479.30 6430.00 I0413.79 22.98 246.40 6629.30 6580.00 10413.79 22,98 246.40 6629.30 6580200 10S00.O0 22,12 246.40 670B.92 6659.62 10516.59 21.95 246.40 6724.30 6675~00 10575.77 21.36 246.40 6779.30 6730.00 L06OO.O0 2t.12 246,40 6801.8~ 6752.59 ~0700.00 20.12 246,40 6895.48 6846,18 END 1/100 O~OP 10711.5B 20,00 246.40 6906.36 6857.06 TKUC 10757.27 20,00 246.40 6949.30 6900.00 TKIIB 10767-92 20,00 246.40 6959.30 6910.00 TARGET 1091~.58 20.00 246.40 7094.30 7045.00 TKA3 10912.58 20.00 246.40 7094.30 7045.g0 SECTION DEPART 6513.~8 6593.2~ 6669.84 6742,97 6852.44 6878.04 6939.60 6996.96 7049.95 7098.43 02 Mar 1998 3.00 LS LS 3.ao C00RD~NATES-P~OM ALASKA Zone 4 TOOL W~LLBEAD X Y FACE 2607.44 S 5968.70 ~ 552200,09 6026~79.80 LS 2639,40 S 604i.88 W 552127.17 6026347,26 2670.07 S 6[~2.08 W 5520~7.22 6026316.85 2699.35 S 6109,10 W ~5E990.45 6026286-25 L~ 3.00 2727.15 S 62~2.75 W 55[927.02 602625~.95 18 3.00 2753.41 $ 6302~87 W 551867.11 6026231.22 LS 3.00 2778.06 S 6359.28 W 551810.90 6026206.~4 LS 3.00 2801.02 S 64L1.84 W $517~$.52 6026182.77 L~ 3.00 2822.Z3 S 6460.40 W 55[7/0-14 6f126161.18 L~ 3.00 254~.64 S 6504.83 W 55[665.87 6026141.43 LS 3.00 7142.27 2859-19 S 6545.00 H 551625.84 6026123.57 LS 3.00 7162,75 2867.~9 S 6563.~6 W 551607.14 602611~.23 7~62.75 2867.39 S 6563.76 W 551607.~4 6026115-23 HS 3,00 7226.35 2892.85 S 6622.05 W 551549.86 60260~9.31 LS O.00 72~6.~5 2892.85 S 6622.05 W ~54549.06 6026089.31 L8 0.00 7259.41 2906.08 S 6652.34 W 551518.88 6026075.84 LS 1-00 7265.63 2908.57 $ 6658.04 ~ 551513.19 6026073.32 LS 1.00 7287,46 2917.32 S 6678.05 ~ 551493.25 6026064.¢1 LS 1.00 7296.24 2920.83 S 6686.10 N 551485.24 6026060.83 7331.45 2934.93 $ 6715.36 W 551453-09 6026046.49 LS 1.OO 7335.42 2936,52 S 6722.00 W 551449.46 60260~4.$7 KS 1-00 7351.0S 2942.77 S 6736,32 W 551435.19 6026035.50 85 O.O0 7354.69 2944.23 S 6739.66 W 551~31.87 6026037-02 HS 0.OO 7%03.83 2963.90 S 6784.69 N 551387.00 6026017.00 ~IS O.O0 7403.83 2963-90 S 6784.69 ~ 551387.~0 60260[7.00 HS 0.00 7' TKA2 10932.86 20.00 246.40 711~,30 7065.00 TKAL 10975.43 20.00 246.40 715~.30 7105.00 TMLV i1018.00 20.00 246.40 7194.30 7145.00 7411.11 2966.83 $ 6791.56 W 551380.35 60260~4.03 HS O.OO 7425.67 2972.64 S 6804.70 W 551367.06 6026008,/0 ES O.O0 7440.23 2978.47 S 6818.04 W 551353.76 6026002.'17 H$ O.OO '"U /:> m PROPOSED N~LL @ROFILE 02 Mar Z998 Page 4 STATION ~ASURED INCLN DIRECTrON VERTICAL-USPT~$ SECTI0~ COOR~INATES-FROM ALASKA Zone 4 TOOL DL/ EDENTIFICATION SEPTH AN~L~ AZIMUTI{ TVD SU~-SEA DEPART WELL/{EAD X Y FACE TD / 7" CAGING PT [1218.00 20.80 246.40 7392.24 7332.94 ' 7508.63 30fl5.85 $ 6888.72 W 551291-30 6025974.30 ; A;qADRIU.. '~ AKA-~.,:r ~., APPROVED FOR PE;RMrtTTING ONLY PLA, N #_ /--/.~. -D ........ ~ n.n adr_i kl.._Lc.').a8 .-~IP.C~ oP.o.~i..3....2.C.. 1.1. ;~3..6...A~..~ ). (KB> SHAREB SER VT6E-S iii _ .. i ii __ i ii i i ilell i i._ i i! , ,,,,! ,,,,, [ /dqADRILL AK..A-.,,r CI AnadrJ l ] Schlumberger . . i ii ii1~11~ ii i ii MPC-40 (PO4) VERTICAL SECTION VIE~ I APPRO~IED._ i Jse~on al:: 246 40 B _1_ F()R P ERI, TTIr~G J.JTVD Scale,: ~ inch= 1400 feet ' JOep Scale,: 1 inch = ~4OO ~'- gN ~ ] gra.n ..... : 02 ,ar ~998 '- ~ I ~L.AN ¢ ¢ ~ I -- ~8pkeP ]dent~f~cst~en ~ BKB SE6TN (~ A) KB O a O 0. ...... ~-~ ~r-~& B) K~/BUILD 1.OO/lO0 300 300 -O 0,0 ~ C) BUILD t.5/tDO 500 500 3 2.0 ...... 8] BUILD 2/100 700 780 16 5.0 E1 END 2/10~ BU]LD ~866 LBO9 348 28.3 F~ BUILD 3.DO/tOO ~935 ~868 380 28,~ ' , .... j... B) END 3.00/100 ~ILD 3012 2628 ~25 60.6 j ~ H) POSSIBLE EASINB PT 4892 3549 2764 60. I) POSSIBLE :ASINB PT 6678 4424 4320 60. __ ~ J) ~OP 3.00/tO0 89~ ~60 ~340 50.6 .._ ~~ K) END 3.80/tO0 DROP 10251 6479 7t~3 F~ L) DROP t/~O0 ~04t4 6829 72~ M) E~ ~/100 D~P t07~2 6906 7335 ~- =,~ .... . ....... ~ N) TARGET t99~2 7094 7404 20.~ ~~-:= -='== ~-==~~=: ......... = ..... O) TD/ 7' CASI~ PT tt~8 7362 7509 20.~ .... .... .... , ............. ~~ ........... .... ~ ... ~r~:~ 3 ...... ~-~ ::::::=::=: : ~j~ ................................................. ... . - .............. ~ .... &~ ............. ~ ....... ~ ................ Anadr~.)] (ci"~e ~c4(:eo4 3.2c t:l':'~'7 AN P) 0~ 70~ 140~ 2~.0b 280~ 3§05 420~ 4§0~ 560~ 630~ 700~ 770~ 84ab 9too 9t~t]D 30500 11200 ..... Sect io,,n Departure ....................... &igOO z ' SHARED ERVI-CES DRILLING ...... ' VERTICAL SECTION VIEW i"T~'=~4~¢ ....................... Section ~(' ~46.40 TVD Scale.' 1 inch = :150 feet ~ .... Dep Scale.' J inch : J50 feet ' Drawn ' 02 Mar ~998 i i i ii i i i i i i i i i i ~-F~r-~ .......... Anadr~]] Sch]umberger Narker Identification MD BKB BEC?N INCL~ ~ ~) END 3,00/~00 DROP 10251 6479 7163 22.9~ ~-f~--~ ...... B) DROP ~/IOD 104~4 6629 7226 ~2,9( C) END ~/~00 DROP ~07~2 8906 7~5 20.0( ~-~. ~ ...... ~ -- D) ~ARGET ~OB~2 ?094 7404 20.0( E) TB / 7" CABIN6 PT ~2~8 7~82 7509 20,0( ~:~ ..... --- i :_q?& Jm g~t Jgadius 200 :eet ) " -fB~ - ~¢ ................... ~ - ~ .... ~ " . ., PFR~T~ ~N6 ~ .... , ON LY . '"~ ~. ~ I e ~m~.. ~'~ .... I ~"~"~'~"~'~"~'~'~¢~' "" ........ ' '""~" '~"' ....... · ",.~ ,. ,,,'~ ..... -~*.t.-' '" ~ ......... ilii iii Ul I · III~lm ii I ....... ;-40 (P04) 6900 6975 7050 7 t 25 7200 7275 7350 7425 7500 7575 7850 7725 7800 7875 FgSO Section Departure mi ii i mmm mi m ii iii illm . /~nadr Y ]J Sch]umbe£ger 4P6-40 (P04) PLAN VZEW ;LOSUI~E ' 7509 feet at Azimuth 246.40 imllll SHARED "-SER'V ICES .. __ DFilLLING" ' _.. . . )ECL]NAT]ON,' +27,82.t [E) J ~CALE ' I inch : tO00 feet ! )RAWN ' 02 Mar ~998 ....... ~arker Identif i~ation MD N/S E/W ............... t) KB 0 0 N 0 E ~) KDC/BU[LD ~.00/100 300 0 N 0 E ') BDILD 1.5/~00 500 I S 3 W )) BDZLD 2/~00 700 8 S 14 ~ ... ~, ~) E~ 2/~00 BUILD ~866 i3B S 319 ~ :) BDILD 3.00/lad 1935 15~ S 348 ~ ;) E~ 3.00/~00 BUILD 30~2 450 S ~031 W z () POSSI~E CASING PT 4892 Jig7 S 25~ W ._ :} ~SIBLE CASIflG ~1 6678 ~730 S 395~ W ~ J) ~P 3.00/~00 6995 2536 S 5810 W :J E~ 3.00/~00 OROP 1D~5~ 2667 S 6564 H E ~ .) ~aP ~1~00 t04~4 28~ s 662~ w ~~ ..... ioa ~ E~D t/~O0 DR~ 107~2 2937 S 6722 W l) lARGE) i09~2 2964 S 6785 ~ )} 18 / 7" CASI~ Pf 112~8 3006 S 688i w tm ........... ,D :-B7A ~ ~:ius 200 ~eet ) i Fl )R PI[RMI TTI~IG ...... ~ ..... lh~l ~r ...... . .............. . ................. ~,..,,~ ............ ..,.. ........... .,, .......... c .......... [[ ~ ........................................... ' ' ' ............................................. [2_..22 .............................. 3000 7500 )'OOg b~O ~090 5500 50~g 4000 4000 3~W ~9b 2bUO ~uOU XSgg io~O 500 0 500 'iOO0 <- WESf ' EAST -> ~,,~]t ~)~ "~&m, 3.~c ~: ~ m ,~ ................. ' ...... -'- ' ........................... Z H H 134377 '"'"' '~" I°2/~8/~al IDATE I O0i:3437710"EO'<NO' I VENDOR ALASI4AST 14 O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 021798 CK0217c28 100. O0 100. O0 HANDLIN~ INST: s/h kathu campoa~o~ x 51~2 THE AWACHEO CHECK m IN PAYME~ Pm roMS DE~RIBED A~VE. 1 O0. OD 1 OO. OD · WELL PERMIT CHECKLIST COMPANY FIELD & POOL F ] 0 0 INIT CLASS WELL NAME //~ ,' ~ GEOL AREA PROGRAM: exp [] dev J~redrll [] serv [] wellbore seg E: ann. disposal para req UNIT# I I ,'~ .~,~ ON/OFF SHORE __.0 ADMINISTRATION , 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. DATE 12, q~l"/~,~_ 0~ 13. Lease number appropriate ................... Unique well name and number .................. .~ N Well located in a defined pool .................. ~ N Well located proper distance from drilling unit boundary .... ~) N Well located proper distance from other wells .......... ~ N Sufficient acreage available in drilling unit ............ ~ N If deviated, is wellbore plat included ............. ~ N Operator only affected party ................... N Operator has appropriate bond in force ............. ~ N Permit can be issued without conservation order ........ ,,~ N Permit can be issued without administrative approval ...... N Can permit be approved before 15-day wait ........... N ENGINEERING 14. Conductor string provided ................... ~) N 15. Surface casing protects all known USDWs ........... N(~N 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved.. ',¢:.-,,..Y N ~..~,~r- 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... .N. 24. Drilling fluid program schematic & equip list adequate ..... N 25. BOPEs, do they meet regulation .... ~,,~~ ...... 26. BOPE press rating appropriate; test to ~ .psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. Y~__ GEOLOGY A~,~ DATE 30. Permit can be issued w/o hydrogen sulfide ~. Y N 31. Data presented on potential overpre~.~..,,~sur~-"ZOnes ....... Y N 32. Seismic analysis of shal~ones ............. Y N 33. Seabed co~.~:JJt,~"r's~-~ey 0'f off-shore) ............. Y N 34. ct name/phone for we,eklyprogress re@o. rts ....... Y N lexploratory only] REMARKS GEOLOgy,: RPC _ ENGINEERING' COMMISSION' BEW DWJ ~ JDH~ RNC~ co Comments/Instructions: HOW/lit A \F()RMSI"r,"'I'Iml r,',v ¢~'~',