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Home My WebLink About201-050 Image~~' .'oject Well History' File Cover R je 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. _~_{~J - O_~_~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Other, No/Type [] BY: BEVERLY ROBIN VINCENT SHERY[~WINDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL QWINDY Scanning Preparation x30= + BY: BEVERLY ROBIN VINCENT SHERY~WINDY Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds Production Scanning Stage 1 PAGE COUNT FROM SCANNED FLEE: _~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION' ~,~ YES Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~ YES BY: BEVERL~INCENT SHERYL MARIA WINDY '7 (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) NO NO RESCANNEDB'Y: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: /SI Quality Checked 12/10/02Rev3NOTScanned.wpd e e ~~, . It. ~ "'ik ,;'-',;;, MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F: \LascrFiche\CvrPgs _Il1serts\Microfilm-..;Marker. doc Memorandum State of Alaska Oil and Gas Conservation Commission To: Re.' Well File 201-050 Expired Permit Action WELL: Moose Tooth Trailblazer G-01XX Permit Issued: 3/21/2001 DATE March 21, 2003 API# 50-103-20315-00 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 well number for a cancelled or expired permit is modified with an appended XX. EXPIRED PERMITS ARE RELEASABLE 2 years from the approval date on the application approved by the commission, unless the operator ask for extended confidentiality. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician ALASKA OIL AND GAS CONSERVATION CO~I~ISSION Paul Mazzolini Drilling Team Leader Phillips Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Exploration NPRA Moose's Tooth C-A Phillips Alaska, Inc. Permit No: 201-050 Sur. Loc. 1915'FNL', lll5'FWL, Sec. 3, T10N, R01E, UM Btmhole Loc. 191'FSL, 1351'FEL, Sec. 3, T10N, R01E, UM Dear Mr. Mazzolini: Enclosed is the approved application for permit to drill 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. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission' s internal use. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, subsequent LOT data following setting production casing, and any CQLs must be submitted to the Commission on form 10-403 prior to the approval of disposal operations. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (Moose's Tooth C-A PH) and API number (50-103-20315- 70) from records, data and logs acquired for well Moose's Tooth C-A (API number 50-103- 20315-01). In your application, it is indicated that it may be necessary to stimulate the productive intervals in the well. If stimulation is determined necessary, a Sundry Application (Form 403) detailing the planned stimulation(s) should be submitted for approval. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the diverter function test and BOPE tests must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE C~O)/IMISSION DATED this ~/' a__c day of March, 2001 dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. i STATE OF ALASKA 'l' ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work:. Drill [~] Reddll r'"] I lb. Type of well. Exploratory ~] StratigraphicTestD Development oil r~ Re-entry [~ Deepen ~]I Service f'] Development Gas [~ Single Zone [] Multiple Zone r-] 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. GL 135 & 35' RKB feet 3. Address 6. Property Designation Exploration P.O. Box 100360 Anchorage, AK 99510-0360 AA-81805 / 5150 4. Location of well at sur/ace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 1915' FNL, 1115' FWL Sec. 3, T10N-R01 E, UM Exploration NPRA Statawide At top of productive interval 8. Well number Number 389' FSL, 1526' FEL, Sec. 3, T10N-R01 E, UM Moose's Tooth C-A #59-52-180 At total depth 9. Approximate spud date Amount 191' FSL, 1351' FEL, Sec 3, T10N-R01E, UM March 10, 2001 $200,000 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in properly 15. Proposed depth (MD and TVD) 191' @ TD feet Moose's Tooth C, 4490' TD 5720 9425' MD / 8335' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 3114 MD Maximum hole angle 29° Maximum surface 2701 psig At total depth (TVD) 3590 psig 18. Casing program Setting Depth size Specifications Top Bottom Quant~ of Cement Hole Casinc, I Welc, lht Grade coupIin~l Length MD TVD MD TVD (include sta~e data) 8.5 7 26# L-80 BTC-Mod 8885 Surface Surf. 8885 7865 380 sx. Cl G 6.125 4.5 12.6 L-80 BTC-Mod 690 8735 7734' 9425 8335 130 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 Conductor <~O ~ ~ (~ I ~> i " RE VED Production . MAR 0 g ?.001 Perforation depth: measured Alaska Oil & Gas Cons. Commission Anchorage true vertical 20. Attachments Filing fee ['~ Property Plat r'~ BoP Sketch D Diverter Sketch r-~ Drilling program [~] Drilling fluid program [~] Time vs depth plot r'~Refraction analysis D Seabed report D 20 AAC 25.050 requirements D 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call William Lloyd265-653 Signed Title: Drilling Team Leader Date Paul Mazzolini ~ ~ W~L Commission Use Onl} Permit Number I APlnumber i I See cover letter ,~,O ,/,,- ~;3 .~"~"3, 50- //'~:~ ' ,~- O ;~ / ~'"' ~ / / Ifor other requirements Conditions of approval Samples required ~' Yes ['~ No ~l~'~og~equired J~ Yes BI No Hydrogen sulfide measures ~ Yes D No Directional survey required ~ Yes'D No Required working pressure for BOPE "~' ~ .., ~ by order of ' '~'-'~*" "-' ' Commissioner the commission Date Approved by / Form 10-401 Rev. 12/1/85 · O < GtNAL Submit in triplicate N 0 T~E S_: 1[ ~ ~ HORIZONTAL AND ~R~CAL LOCA~O~ ~OOSE ~~~~~~'"~ ~. ARE MONUMENTS 3-1~-1 ~ ~1~-1 SET 2, COORDINA~ SHO~ ~E A~SKA STA~ P~NE ZONE ~. NAD 27. ,. E~VA~ONS SHO~ ~RE BRmSH PE~O~U~ MEAN SEA LEaL DA~M. ~u~ ,~ ~- ~ , 5, A~ DISTANCES ARE ~UE. 6, I~ PAD IS ROTA~D 7~' EAST ~ NOR~. 7. DA~S OF SURLY: g2/27/2g~l. ViCINiTY MAP SCALE: 1" = 2 MILES ~ . MOOSE'S TOOTH "C" ~ ~ ~ ~ ~ LOCA~D ~[N PRO~AC~D ' ~e~ ~ ~~' SEC, ~ ~ ~I~ ~- .~'~~ ~ UMIAT MERIDIAN, ~ ~ ~ .- ~ ~ ~ ~ ~ LAT = 7e'15'e6,7e" ~ ;j , ,, LON~= 151'51'58.87" ~ 1115'~ ~ ~ ~ ~ ~' Y - v'~ ", ~?~ MOOSE ~ ,,, x = 269,e44.8 ~ ~j,,~ TO~ C '~ 1915' F.N.L., 1115' F.W.L. ~,, ~.~-- ~ GROUND ELEVA~ON = 46,5' RECEIVED ~'¢ ~ ~R ~ ~ ~00t ~ tOe ~c,~ ~ Alaska Oil & Gas Cons. Commission ~ · ~ -,~ ~ Anchorage AREA:- ~ODU~: - UNIT: t PHILLIPS Aleske, Inc. MOOSE'S TOOm "C" A S~b~d;ory o¢ PH~Lb~PS PETROLEUM COMP*NV EXPLORATORY ~LL CONDUCTOR AS-STAKED LOCA~ON LK6e~4e4 2/28/e~ NSK 6,01 - d404 Phillips Alaska, Inc. , Drill and Case Plan for Moose's Tooth C-A General Procedure: 1. Make up 8 1/2" bit and BHA and RIH to KO plug set from Moose's Tooth C well 2. Directionally drill 81/~'' pilot hole wellbore to +9425' MD/+8335' TVD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 3. TOOH and LD BHA. RTH and set abandonment plug(s) as required by applicable regulations. If additional geologic evaluation is required (cores), RIH w/OE drill pipe and set sidetrack plug to 6000' MD / 6000' TVD. 4. After setting sidetrack plug, WOC. RIH with 81/2'' drilling assembly and twin well to top of ]4/UCU. Run MWD / LWD logging tools in drill string as required for directional monitoring and to properly identify objective top. 5. Run 7" intermediate string to isolate potentially sensitive shales located just above the objective (est.@ 8885' MD / 7865' TVD). Cement casing to bring cement _+800' above 7" shoe or as required by regulations. 6. Make up 6 1/8" mill tooth bit and BHA and RIH to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town 7. Drill float equipment, CCM, displace to coring fluid and TOOH. (LOT is not planned for this casing string - see attached explanation). 8. PU core barrel, RIH and core at least one 60' core. TOOH, LD core barrel and PU 6-1/8" bit and drilling assembly and TIH. 9. Drill wellbore to _+9429' MD / --+8335' TVD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. · Condition hole and mud for e-line logs. 10. Log 6-1/8" wellbore as necessary. 11. Run and cement 4 1/~,, 12.6# L80 EUE Liner 12. Make a cleanout run with bit and scrapers · Displace to filtered seawater · Pressure test well to 3000 psi for 30 minutes · Record results and fax to town 13. Run and land 4 1/:~,, tubing with gas lift completion 14. Nipple down BOP's. Install production tree and pressure test same to 5000 psi. 15. Secure well, release rig. 16. MI well testing equipment and surface test tanks. Perform production tests as required. Produced fluids will be either reinjected into the formation or trucked to Kuparuk or Alpine production facilities. 17. Upon completion of testing or if the well is not completed, plug and abandon the well per applicable regulations. Thoroughly clean location and block off further ice road access to location. Phillips Alaska, Inc. ii' DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Moose's Tooth C-A Drilling Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel API Filtrate pH % Solids Spud to surface casing point 9.5 - 10.2 ppg Drill out to TD (pilot & Intermediate hole) 9.5- 11.0 ppg 16 - 26 25 - 35 50- 100 10 - 20 15 - 40 7- 15 9.5 - 10 + 10% 6 - 20 5 - 20 35 - 50 2-6 14 - 20 < 6 below 7000' 9.0- 10 < 11% Twinned Hole I(Intermediate shoe to TD) 9.1 - 9.4 pp§ 8- 12 12 - 20 40 - 50 8- 12 12- 16 <10 9.0- 10.0 < 8% Drilling Fluid System: 2 - Triple Derrick Shale Shakers Derrick 20 cone Desilter/Mud Cleaner Derrick Centrifuqe Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Swaco Degasser Fluid Agitators Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure and Casing Design: The following information is used for calculation of the maximum anticipated surface pressures for the planned well' Pore Casing Casing Fracture Pressure Pore Size Setting Depth Gradient Gradient Pressure HASP Drilling 7" 8885' MD / 7865' TVD 1716 ppg 8.7 ppg 3610 1784 psi 4-1/2" 9425' MD / 8335' TVD 17.6 ppg 8.7 ppg 3610 2701 psi Expected Maximum Mud Weights: 8-1/2" pilot hole to 9425' MD / 8335' TVD: 11,0 ppg (for stabilization of shales) 8-1/2" Intermediate Twinned hole to 8885' MD / 7865' TVD: 11.0 ppg (for shale stabilization) 6-1/8" Production Hole to 9425' MD / 8265' TVD: 9.1 ppg ,, i Phillips Alaska, Inc. ( Procedure for Calculating I~aximum Anticipated Surface Pressure: HASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) HASP = [(FG x 0.052)- 0.11] x D Where: HASP: Maximum Anticipated Surface Pressure FG = Fracture Gradient at the casing seat in lb/gal 0.052 = Conversion factor from lb/gal to psi/it 0.11 = Gas Gradient in psi/it (above 10,000' TVD) D = True vertical depth to casing seat in it from RKB OR 2) MASP= FPP - (0.11 x D) Where: FPP = Formation Pore Pressure at the next casing seat HASP Calculations 2. Drilling below 9-5/8" Surface Casing HASP = [(FG x 0.052) - 0.11] x D MASP= [(14.8 x 0.052) - 0,11] x 2705 HASP : 1784 psi OR HASP = FPP- (0.11x D) = 3610- (0.11 x 7865) = 2745 psi 3. Drilling below 7" Intermediate Casing HASP = [(FG x 0.052) - 0.11] x D MASP= [(17.6 x 0.052)- 0.11] x 7865 MASP = 6333 psi OR MASP = FPP- (0.11x D) = 3610 - (0.11 x 8265) = 2701 psi Casing Design Performance Properties I Internal Tensile Strength Size Weight Grade Connection Yield Collapse 16" 63 ppf B PEB Conductor Casing Joint Body 9-5/8" 40 ppf L-80 BTC 5750 psi 3090 979 M 916 M 7" 26 ppf L-80 BTC-M 7240 psi 5410 667 M 519 M 4-1/2" 12.6 ppf L-80 BTC 8430 psi 7500 psi 304 M 267 M Casing Setting Depth Rational: 7' @ 8885' ND RKB Well Proximity Risks: None Drilling Area Risks: Phillips Alaska, Inc. 'il Intermediate casing is set strictly to provide isolation of potentially troublesome shales. Because the objective interval will be pre-drilled in the pilot hole at a higher mud weight than what is targeted below the 7", a leak off test will not be done below this shoe. The shoe of this casing will be set immediately into the top of the objective with a planned core to be taken immediately below the 7" shoe. A LOT would require 20' of additional hole to be drilled and would jeopardize targeted core recovery. Shallow Hazards: Refer to "Pre-Drill Seismic Pore Pressure Prediction for NPRA Proposed Wells: Hunter 1, Outlook 1, Oxbow 1, Rendezvous 1, Rendezvous 2, Spark 2, Spark 3, Spark 4, Spark 5, Lookout A" dated November 29, 2000, submitted under separate cover and Nooses Tooth C data. Drilling Risks: Drilling risks in the Moose's Tooth C-A area are intermediate interval sloughing shales, and lost circulation/breathing potential through the reservoir. Shale stability will be controlled while drilling with fluid chemistry, rheology, hydraulics and fluid density. Lost circulation will be addressed with lost circulation material (LCM) and managed flowrates. Annular Pumping Operations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted Class TI disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The Moose's Tooth C-A surface/intermediate casing annulus will be filled with diesel after setting intermediate casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. Geoloqy: Anticipated geologic markers, depth uncertainty, fluid properties, and pore pressures are as follows: FORMATION DEPTH (ss) UNCERTAINTY POSSIBLE FLUID EST. PORE TYPE PRESSURE~ psi Permafrost 600' K3 2680' 200' Oil or Gas 1200 Sequence 97 3235' 200' 1440 Sequence 95 3520' 200' 1575 Sequence 93t 3800' 200' 1700 Base Ponded Turbidites 5970' 200' 2700 Pebble Shale / Dist. Zone 6960' 200' 3150 LCU 7190' 200' Oil or Gas 3300 J4/UJU 7730' 200' 3610 Base 34 7900' 200' 3690 TD 8200' 200' 3830 Phillips Alaska, Inc. Formation Evaluation: Anticipated logging, coring and testing for this well is as follows: Im II. III. IV. Logging 8-1/2" Pilot Hole (Surface Casing setting depth to TD) LWD: GR/Res/FDC-CNL/Dipole Sonic 8-1/2" Twinned Well (Top HRZ- Top J4/UJU) LWD: GR/Resistivity 6-1/8" Twinned Well (7" Shoe to TD) LWD: GR/Res Wireline: GR/Res/FDC-CNL/Dipole Sonic/CIVlR (Contingency: RFT/RSWC) Coring Full Diameter 2.5" Core in Upper Jurassic (1 - 2, 60' cores); below 7" Potential Rotary Sidewall Cores (wireline conveyed) in the event full core operations are unsuccessful Mudlogging Mudlogging service should be in operation from the base of the surface conductor casing to TD. Service most likely will include ROP on 5' intervals, lithology, total gas, sample collection, gas analysis of cuttings, gas chromatography, and H2S detection Sixty-foot (60') wet and dry samples will be collected from surface to 4500' subsea Thirty-foot (30') wet and dry samples will be collected from 4500' subsea to well TD (pilot and twin) and ten-foot (10') wet and dry samples, or continuous, collected across the Kuparuk and Jurassic intervals. Flow Testing Flow testing and pressure build-up tests will be used to determine formation properties and estimate the commerciality of this exploratory well. Flow testing for any particular interval will consist of an initial unstimulated flow period followed by an appropriate pressure build-up. The flow period will be determined on-site in response to analysis of initial flow period, PBU and fluid properties. The well will be flowed to temporary surface production facilities consisting of gas separation and fluid storage tanks. Produced fluids will either be trucked to an existing production facility or reinjected into the formation following completion of the flow testing operations. Based upon pressure and flow characteristics during the unstimulated flow period, a reservoir stimulation may be performed in the form of an acid or frac treatment followed by a second flow test and pressure build-up. Additional prospective intervals may be tested as described above or may be commingled with the previously tested intervals. Tf commingling is chosen, production logging will be performed during the flow test to determine the productivity of the individual zones. Phillips Alaska, Inc. i Moose's Tooth C-A Drilling Hazards Summary (:to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 8-1/2" Hole / 7" Casinq Tnterval Event Risk Level Mitigation Strategy Lost circulation High (Pilot Hole Reduced pump rates, reduced trip speeds, real to TD) time equivalent circulating density (ECD) Low (Sidetrack monitoring, mud rheology, Pre-planned LCM to Topset) pills~ lost circulation material. Hole swabbing on trips Low Reduced trip speeds, mud properties, proper hole filling, real time equivalent circulating density (ECD) monitoring~ weighted sweeps. Directional Control Medium BHA design, on-sight geologic review and advisement of potential slump blocks. Sloughing Shale, Tight Medium Tncreased mud density and fluid composition Hole according to plan, controlled trip speeds, sweeps~ ECD monitoring. Abnormal Reservoir Low Well control drills, increased mud weight, Pressure contingencies for top set casing string. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices~ mud scavengers 6,-,1/8" Hole / 4-1/2" Casing :Interval Event Risk Level Mitigation Strategy Lost circulation Low Fluid density according to plan, reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology~ lost circulation material. Hole swabbing on trips Low Reduced trip speeds, mud properties, proper hole filling, real time equivalent circulating density (ECD) monitoring~ weighted sweeps. Directional Control Low BHA design, on-sight geologic review and advisement of potential slump blocks. Sloughing Shale, Tight Medium (Tf shoe set too high) Tncreased mud density Hole and fluid composition according to plan, controlled trip speeds, sweeps, ECD monitoring. Abnormal Reservoir Low Well control drills, increased mud weight, Pressure contingencies for top set casing string. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices~ mud scavengers 400 4OO 800 1200 16oo 2000 2400 2800 _ 3200- _ 3600- . 4000- . 4400- . 4800- . 5200- 5600 6000 - 6400 . 6800- . 7200- . 7600- 8000 8400 8800 1200 : Phillips Alaska, Inc. :Structure: Moo,asTooth C(a) (old Spark3) Wall : MsTth ESTIMATED RKB: 135'~ :: : " Field : Fxplorotion Location: Norlh Slope, Alaska KOP! . 3.00 ,; 6.00 DLS: 3.00 dog per 100 ft ,~ 9.00 Permafrost ,, 12.00 · 15.00 4, 18.00 ESTIMATED . 21.00 MOOSES TOOTH ,, 24.00 C ,. 27.00 TD LOCATION: EOC 4, 1905' FNL, 763' FWL : SEC. 3, TION, R1E 600 300 0 300 600 i i i i i i i i i i ~TD,~, .~ ~ Pc rmafrost 9 5/8 Casing.~, I u/ o,* ',~ ~ EOC 20.82 x / N 17.84 ~ ~ "% ' 14.86 S¢q97 11.89 Seq97 D~'~rbcl Simp Zone ~'"' ':',X_ 9 5/8 Casing . 6.03 ~'~ Eventual ST Pt Seq95 ~ 3 31 Seq95 Final EOC ' 1'86 Seq93 ~ ' ~eq95 %~ Seq97 3.74 Seq95 Seq95 ~ 6.52 Seq97 '~,,~, Seq95 9.44 t2.39 15.36 8.54 2 .33 Final EOC DLS: 3.00 deg per 100 ft Dstrbd Simp Zone , Peb/Shl Dist Zone ~ LCU LCU i TOT/J4/7 CsgPt i TGT/J4 ? 7 Casing ~ B/ J4 B/ J4 B/Prided Turb~ MOOSES TOOTH C TARGET LOCATION: 2036' FNL, 917' FWL SEC. 3, TION, R1E Easf (feel) -> 900 1200 1500 1800 Seq93 800 400 0 400 800 1200 1600 Verfical Secfion (feet) -> Azimuth 258.59 with reference 0.00 N, 0.00 E from slof #1 MOOSES TOOTH C-A TARGET LOCATION: 389' FSL, 1526' FEL SEC. 3, TION, R1E ESTIMATED SURFACE LOCATION: 1915' FNL, 1115' FWL SEC. 3, TION, R1E 2100 2400 2700 3000 i i i i i i i B/Pnded Turb \. , Peb/Shl Dist Zone LCU TOT/J4/7 CsgPt B/ J4TD~ ESTIMATED MOOSES TOOTH C-A TD LOCATION: 191' FSL, 1351' FEL SEC. 3, TION, R1E 300 30O 600 9OO ~.~. For: B Lloyd a~, plott*d: 27-F,1~-2001 Plot Reference i~ MOOlelTooth C Vets.#2. Coord;notol ~re ITrue ver~ico Dap nl ~KER ................................................ 1200 (./) 0 1500 1800 I 2100 V 2400 2700 300O 3300 3600 C,~te~ b, t~.ch For: B Lloyd Date plolted: 27-Feb--2001 p~ot Reference ~ MoosesToo[h C Ve~s.~2. C~rd~ales are ;n leal ~e[erence s~[ ~1. ~T;ue Ve~al Depths a~e reference RKB (Doyon ~141.~ Phillips Alaska, Inc. iStructur~: BooslsTooth C(o) (old Sp=r~$) Will: MJTfh £1eld: [xpZorafion L~catldn: North Slope. Alaska Mooses Tooth "C" Point KOP EOC 9 5/8 Csg Pt K3 Eventual ST Pt Seq97 Seq95 Seq93 Final EOC Dstrbd Simp Zone LCU TOT/J4 B/ J4 TD PROFILE COMMENT MD Inc Dir TVD 0.00 29.58 29.58 29.58 29.58 12.56 4.47 4.58 21.42 21.42 21.42 21.42 21.42 21.42 300.00 1279.27 2964.00 5078.75 5114.00 3677.44 3955.71 4231 .O9 4842.46 6489.05 7858.65 8406.48 8615.95 8959.69 DATA 0.00 138.43 158.45 1 38.43 138.43 145.47 159.48 291.42 310.45 310.45 31 O.45 510.45 510.45 510.45 300.00 12,36.92 27O5.OO 2805.00 2835.71 5360.00 3635.00 ,3910.00 4502.14 6055.00 7510.00 7820.00 8015.00 8335.00 North 0.00 -183.76 -802.13 -844.25 -857.18 -1010.92 -1045.44 -1051.49 -965.49 -575.40 -250.9.3 -121.14 -71.52 9.92 East 0.00 1 62.95 711.29 748.64 760.11 889.20 911 .O4 904.57 792.13 334.51 -46.13 -198.39 -256.61 -352.14 V. Sect Deg/lO0 0.00 0.00 -43.31 -189 O4 -198 97 -202 02 -252 07 -252 75 -224 O5 -172.90 14.37 170.14 232.45 256.27 295.37 3.00 O.OOi 0.00! O.OOi 5.00 5.00 ,5.00 0.00 0.00 0.00 0.00 0.00 0.00 .~ ........ ~nch For: B Lloyd Date plotted: 27-Feb-2001 Plot Reference is MoosesTooth C-A Vets.jr2. Coord;noies ore ;n Feet rele[ence s~ot ~1. iTrue Vert~col Dep[hs are reference RKB (Doyen jr141j Phillips Alaska, Inc. Slruciure: MoosesTooth C[,~) (old Spork3) Well: MsT/h Field: Explorulion Location: North Slope, A~aaka Mooses Tooth "C-A" Point KOP Permofrost EOC 9 5/8 K-3 Csg Pt Seq97 Seq95 Seq93 B/Pnded Turb Peb/Shl Dist Zone LCU TGT/J4/7 CsgPt i B/ 04 PROFILE MD COMMENT 300.00 Inc Dir TVD 0.00 138.44 300.00 738.85 13.17 138.44 735.00 1279.27 29.58 158.44 1256.92 2964.00 29.38 138.44 2705.00 5090.24 29.38 138.44 2815.00 29 38 29 38 29 58 29 38 29 38 29 38 29 58 29 38 29 38 3727.14 4054.20 4575.52 6865.76 8001.86 8265.80 8885.47 9080.58 9424.85 DATA North Eost V. Sect Deg/lO0 0.00 0.00 0.00 0.00 -57.56 55.50 50.20 5.00 -185.76 162.95 245.60 3.00 -802.15 711.28 1072.08 0.00 -848.48 752.37 1134.01 0.00 138.44 3370.00 -1082.26 959.66 1446.46 138.44 3655.00 -1202.51 1066.11 1606.90 138.44 3935.00 -1320.25 1170.69 1764.55 138.44 6105.00 -2234.29 1981.19 2986.17 138.44 7095.00 -2651.50 2350.96 3545.50 138.44 7325.00 -2748.18 2436.87 3672.99 138.44 7864.98 -2975.65 2638.55 3976.98 138.44 8035.00 -3047.25 2702.06 4072.69 138.44 8335.00 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 1000 2000 3000 4000 5000 6000 7O0O 8OOO 90OO DRILLING TIME AND MUD WEIGHT CURVE --e-Depth Rendezvous 'A' ....... Mud Weight Mo~e in ri'g 4/1 i/00 f/NanL~kl__I,' ,L ....... ,' .... ,'---', ,' :, ,' L___~, , ...... ,L ............ , L___, -1- .... I ....I- -I ....i- - - - -I- ~ ~ I _ _ _ L _ _ _ _~ .... I ....L .... L _ I _ _ _ _1 .... I ....... J .... ~ ....L _ _ _ J .... 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[--T--i-IF-£ -- -l--i- - +- ~ .... .--,--.-.--,--.--,--.-. .... +- ~-- ~--l .... +-~--~- + .... +--l--i- - + .... ~- ~--i-- + .... ~-w- -i- - > .... ~ - + --~- - ~- - I I I I I _ _l_ _ L _ J _ _ I- - _l _ _l I I I I I I I I I I I I I I I I I I I I I I I I I I --~--I--Y--I .... ,--,--,-,--,--,--,--,-, .... ~- -- --I-- -- F--- ~ .... Y --i- -i- - ~' .... F-~--i--T .... ~--- ~----I-- -- ~' .... I'- I i---l-- ~' .... I- -- ~- ---I- - F'- - 0 5 10 15 20 25 30 35 40 45 TIME TO DRILL (DAYS) 12.0 11.8 11.6 11.4 11.2 -~._. 11.0 10.8 10.6 10.4 ~ 10.2 ~u 10.0 ~ 9.8 ~ 9.6 9.4 9.2 ~-- 9.0 8.8 8.6 8.4 8.2 jt 9/99 Mooses Tooth C-A WELLBORE SCHEMATIC and CEMENT DESIGN 6" Conductor Casing at 35' MD / RKB Base of permafrost 739' MD Surface Casing set and cemented as part of Moose's Tooth C drilling program 9-5/8" Surface Casing at 2,964' MD Top of Cement at 7,000' MD 7~ Intermediate Casing at 8,885' MD 4-1/2" Production Liner @ 8,735' MD to 9,424' MD 8-1/2" Hole 6-1/8" Hole Conductor Casing Size/Hole Size 20" in 24" hole Depth: 135' MDRKB Top of Cement Surface Excess Calculated: 100% Volume Calculations: (135 If) (0.9599 cf/If) (2.00) = 259 cf (259 cf) /(0.93 cf/sx) = 280 sx Slurry Volume:259 cf or Arctic Set 1 280 s~ Slurry Weight 15.7 ppg rounded Slum,/Yield 0.93 cf/sx Surface Casing excess 9-5/8" in 12-1/4" hole Stage 1: Volume (739 If)(0.3132 cf/If) (2.50) = 810 cf (2,101 If) (0,3132 cf/If) (1.45) = 954 cf Lead (1,764 cf) /(4.44 cf/sx) = 397 sx Tail (124 If) (0.3132 cf/If) (1.45) = 56 cf shoe joint vol 34 cf + (56 cf)/(1.17 cf/sx) = 77 sx System: Lead (Arctic Set 3 Lite cement + 9% D44 (NaCl) + 30% D53 (gyp) + 50% D124 (spheres) + 1.5% SI(CaCl2) + 1.5% D79 (ext.) + 0.4% D46 (defoam.) Tall (LiteCrete @ 12.0 ppg) Lead Slurry Volume:1,764 cf or 400 sx Slurry Weight 10.7 ppg Arctic Set 3 Lite Slurry Yield 4.44 cf/sx Thickening Time 6.0+ hours Tail Slurry Volume:56 cf or 80 sx Slurry Weight 12.0 ppg Class G Slurry Yield 1.17 cf/sx Thickening Time 3.5 - 4.5 hours Intermediate CasingSize / Hole Depth: Top of Cement Excess Calculated: BHT (Static): Volume around 7 " (1,885 If) shoe Joint vol 17cf+ (418 cf) System: (Class G cement + 1% D800 Size 8,885' 7,000' 75% 160~ F (0.1268 cf/If) /(1.17 cf/sx) 7" in 8-1/2" hole 130~ F BHT (Circ): excess (1.75) = 418 cf = 372 sx + 0.2% D46 + 0.3% D65 Slurry Volume: 435 cf or 380 sx Slurry Weight 15,8 ppg Class G Slurry Yield 1.17 cf/sx Thickeninc~ Time 3.5 - 4.5 hours Production Casing Depth: Top of Cement Excess Calculated: BHT (Static): Volume around 4-1/2" (539 If) Vol. Between liner & Int. shoe joint vol 7 cf + (76 cf) Volume of 200' above liner Size/Hole Size 4-1/2" In 6-1/8" hole 9,424' 8,650' 50% 1600 F (0.0942 cf/If) /(1.20 cf/sx) 1300 F BHT (Circ): ~xcess (1.50) = 76 cf = 20 sx = 69 sx 40 sx System: (Class G cement w/Gasblok + 0.1 gps D47 (defoam.) + 3% D53 (Gyp) + 0.75% D65 (disp) + 1 gps D135 + 2 gps D600 + 0.1% D800 (ret.) Slurry Volume: 135 cf or 130 sx Slurry Weight 15.8 ppg Class G Slurry Yield 1.20 cf/sx Thickeninq Time 3.5 - 4.5 hours 2/28/01 Moose' Tooth Proposed Completion Schematic PHIL,_I S Alaska, Inc. A Subsidiary of ILLIPS PETROLEUM COMPANY 16" 65# H-40 @ +/- 120' MD Depths are based on Doyon 141 RKB Surface csg. 9-5/8" 40.0# L-80 BTCM (+/- 2964' MD / 2705' TVD) 4-1/2" FMC Gen V Tubing Hanger, 4-1/2" L-80 EUE8RD pin down 4-1/2" 12.6# L-80 EUE8RD Spaceout Pups as Required 4-1/2" 12.6# L-80 EUE8RD Tubing to Surface 4-1/2" Camco 'X' nipple w/3.813" profile set at +/- 500' MD. 4-1/2" x 6' L-80 EUE8RD pup installed above and below 4-1/2" 12.6# L-80 EUE8RD tubing to landing nipple 4-1/2" x 1" Camco 'KBG-2' mandrels w/DV's and RKlatch, 6' L-80 handling pups installed above and below. Spaced out w/4-1/2", 12.6#/ft L-80 EUE8rd tubing as needed. 4-1/2" x 1" Camco 'KBG-2' mandrel w/shear valve and latch pinned for 3000 psi shear (casing to tubing differential), 6' L-80 handling pups installed above and below. Intermediate csg. 7" 26.0# L-80 BTCM (+/- 8885' MD / 7865' TVD) Production Liner 4-1/2" 12.6# L-80 EUE8rd (+/- 9424' MD to 8735' MD) 1 joint 4-1/2" 12.6# L-80 EUE8RD tubing 4-1/2" Camco 'X' nipple w/3.725" No-Go profile. 4-1/2" x 6' L-80 EUE8RD handling pups installed above and below 1 jt 4-1/2" 12.6# L-80 EUE8RD tubing 5.125" x 4" Baker Iocator sub 4-1/2" Baker GBH-22 casing seal assembly w/12' stroke, 4-1/2" L-80 EUE8RD box up Liner Assembly (run on drillpipe), Baker 7" x 5" 'ZXP' Liner Top Isolation Packer with HR profile Baker 7" x 5" 'Flexlock' Liner Hanger Baker 20' Seal Bore Extension XO Sub, 5" Stub Acme box x 4-1/2" EUE8rd pin 1 jt 4-1/2" 12.6# L-80 EUE8rd liner as needed 4-1/2" Baker Landing Collar 1 jt 4-1/2" 12.6# L-80 EUE8rd tubing 4-1/2" Baker Float Collar 1 jt 4-1/2" 12.6# L-80 EUE8rd tubing 4-1/2" Baker Float Shoe WBL, 01/22/01, vl , 1,000' 2,000' 3,000' 4,000' 5,000' 6,000' 7,000' 8,000' 9,000' NPR-A Exploration Drilling Mooses Tooth C-A .... Planned ~ Actual .......................... ' '~. ~ ~,~,,,~ ~ ~ ~,,;~:,,~ ....... ; ..... ! .'.. _~ ~ , 0 I 2 3 4 5 6 7 8 9 101112131415161718192021222324252627282930 Days 2/2 8/01 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX 100360 ANCHORAGE. ALASKA 99510-0360 February 28, 2001 Daniel ]. Seamount, Ir., Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Application for Permit to Drill: Surface Location: Target Location: Bottom Hole Location: Moose's Tooth C-A (Exploratory Test) 1915' FNL, 1115' FWL, Sec 3, T10N-RiE 389' FSL, 1526' FEL, Sec. 3, T10N-RIE 191' FSL, 1351' FEL, Sec. 3, T10N-RIE Dear Commissioner Seamount, PHILLIPS Alaska, Inc. hereby applies for a Permit to Drill an onshore exploratory test well from the referenced location in the National Petroleum Reserve - Alaska. The well is designed to penetrate, evaluate and test the production potential of the objective sands. As indicated in the attachments, the drilling program will entail drilling an 8-1/2" wellbore through the objective with a full LWD logging suite for evaluation. Based upon favorable log data, the well will be plugged back and twinned to the top of the objective and a 7" intermediate casing will be run in order to case off potentially sensitive shales. At least one 60' core will be cut through the objective zone beginning immediately below the 7" shoe. The well will be drilled to TD and a 4-1/2" liner will be run and the well will be tested, post-rig. The proposed casing program will utilize a 9 5/8" surface casing string (set previously for drilling the Noose's Tooth C well, submitted under separate cover), a 7" intermediate casing, a 4-1/2" production liner and either 4-1/2" or 3-1/2" tubing. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottom hole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Diagrams and descriptions of the BOP and diverter equipment to be used (Doyon 141) as required by 20 AAC 25.035 (a) (1) and (b) are on file at the AOGCC office 5) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 6) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. R E C E IVE D 0 2 208I Alaska Oil & Gas Cons. Commission Anchorage 7) 8) Seismic refraction or reflection analysis as required by 20 AAC 25.061(a) (submitted earlier under separate cover - reference Spark #3 data) PHILLIPS does not anticipate the presence of H2S in the formations to be encountered in this well. However, H2S monitoring equipment will be functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. Complete mudlogging operations such as type Icg generation and sample catching are planned. The following are PHILL[P's designated contacts for reporting responsibilities to the Commission: 1) Completion Report (20 AAC 25.070) Sharon Allsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs Greg Wilson, Geologist (20 AAC 25.071) 263-4748 The anticipated spud date for this well is March 10, 2001. If you have any questions or require further information, please contact Bill Lloyd at (907) 265-6531 or Paul Mazzolini at (907) 263-4603 ,~ William 13. LIo ~ Senior Drilling'Enginee~ cC: CONFIDENTIAL - Moose's ToOth C-A Well File Paul Mazzolini ATO-1570 Andy Bond ATO-1310 RECEIVED Alaska Oil & Gas Cons. Commission Anchorage American Express' Cash Advance Draft 120 ORDER OFFS' PAY TO Issued by Integrated Payment System, En~lewood, Colorado Payable ~t Norwest B~nk of Grand Junction - Downtown, Grand Junction, Color~o PERIOD ENDING /'~r.~,(",~ C,.. '"~.-.-',./.-~A /'~ .._.~.. i.' &O B ~OOhOOl,' ~ 5 NOT VALID FOR AHOUNT OVER $1000 ,,,O ~ ? SDOD S ~g~l'O ~ ~O I~/ELL PERMIT CHECKLIST COMPANY FIELD & POOL ~ ,~, IN~T'CI~.A~S ADMINISTRATION WELL NAME--'~-~ ~-~'-,~ PROGRAM: exp ~ dev redrll '>~ serv wellbore seg ann. disposal para req ENGINEERING 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available' in ddlling unit ............ 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 ........... GEOLOGY 14. Conductor stdng 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 abandonment been approved... 22. Adequate wellbore separation proposed ....... ; ..... 23. If diverter 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 ,..~ '.~ 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 ................. 30. Permit can be issued wlo hydrogen sulfide measures ..... 31. Data presented on Potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. GEOL AREA ~,~ ~ UNIT# ./~,~ ,~. i. ON/OFFSHORE oJ APPR D T 33. Seabed condition survey (if off-shore) ........ ,,,~.~o. Y N 34. Contact name/phone for weekly progress reports [exploratory only]L'~ N ANNULAR DISPOSAL35. With proper cementing records, this plan APPR DATE (A) will contain waste in a sUitable receiving zonei ....... Y N (B) will not contaminate freshwater; or cause drilling waste Y N to surface; ' (C) will not impair mechanical integrity of the well used for diSposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E). will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: c:Vnsoffice\wordian~diana\checklist (rev. 11101//00) O Z O z -.I -1-