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Home My WebLink About202-051 Image Project Well History File Cover Page 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. c2o~- OSL ',Well History File Identifier DIGITAL DATA rescan Needed OVERSIZED (Scannable) Organizing (done) RESCAN .t./ Color items: 0 Two-Sided 0 Diskettes, No. 0 Maps: Other items scannable by large scanner 0 Grayscale items: 0 Other, NofType 0 0 Poor Quality Originals: Other: OVERSIZED (Non-Scannable) NOTES: , 0 0 Logs of various kinds BY: BEVERLY ROBIN VINCENT SHERYL ~INDY R 0 ¡ Other DATE7 q Olþ vnJ BY: ßEVERL Y ROBIN VINCENT SHERYLF>vINDY DATEr/¡ ~/SI vrJ} \~ ~j , f~ }( Project Proofing Scanning Preparation I x 30 =::30 + ~ = TOTAL PAGES (~~ , ~ , Production Scanning r ~ Stage 1 PAGE CDUNT FROM SCANNED FILE: 3'1- CJJyJ2A..l. ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION:, ¿ES - NO BEVERLY ROBIN VINCENT SHERY~INDY DATE: S? , 11,'df1 mf Stage 2 IF NO IN STAGE 1 PAGE(S) DISCREPANCIES WERE FOUND: - YES - NO BY: ßEVERL Y ROBIN VINCENT SHERYL~INDY DATE:7 9 Off/SI BY: BY: BEVERLY ROBIN VINCENT SHERYLP.ARI. VINDY DATE: ISI (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECiAl ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) ReScanned (i¡¡(fi\'id¡/;.11 pJ~I" 1:;1)(~r:i.ll ,~tl01HioIl15r.,.1ìJnìIt9 ¡;omp"~¡()d) RES CANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: ISI General Notes or Comments about this file: Quality Checked Idnl\(~1 12/10102Rev3NOTScanned.wpd e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc ~~~~.~ ) :} ~~~~~~!Æ \ ALASKA. OIL AND GAS CONSERVAnONCO~SSION Paul Mazzolini Drilling Team Leader Phillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 TONY KNOWLES, GOVERNOR 333 W, ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: NPRA Pioneer # 1 Phillips Alaska, Inc. Pennit No: 202-051 Sur. Loc. 525' FSL, 87' FWL, SEC. 11, T9N, R2E, UM Btmhole Loc. 600' FSL, 87' FWL, SEC. 11, T9N, R2E, UM Dear Mr. Mazzolini: Enclosed is the approved application for pennit to drill the above referenced well. The pennit to drill does not exempt you from obtaining additional pennits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennitting 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. 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 Pioneer # 1 PH and API 50-103-20416-70 from records, data and logs acquired for well Pioneer # 1. 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. The well must be logged using gamma ray, resistivity, neutron, density, and sonic from the base of the conductor to TD. Annular disposal has not been requested as part of the Pennit to Drill application for Pioneer # 1. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test perfonned before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, CJJ. (kLvÞ . ~,~/ C~hSIi Taylor D Chair BY ORDER OF THE COMMISSION DATED this 8th day of March, 2002 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1b, Type of well. Exploratory 0 Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 0 5. Datum elevation (DF or KB) GL 100 & 35' RKB feet ,~ ) " 1a, Type of work: Drill 0 Redrill 0 Re-entry DDeepen 0 2. Name of Operator Phillips Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 525' FSL, 87' FWL Sec. 11, T9N-R02E, UM At top of productive interval 600' FSL, 87' FWL, Sec. 11, T9N-R02E, UM At total depth 600' FSL, 87' FWL, See 11, T9N-R02E, UM 12. Distance to nearest property line 13. Distance to nearest well 5367' @ TD feet Rendezvous #2, 3.86 miles 16. To be completed for deviated wells Kickoff depth: 5657 MD 18. Casing program size Maximum hole angle 10,10 Hole Casing Weight 24" 16" 63# 12.25" 9.625" 40# 8.5" 7" 26# 6.125" 4-1/2" 12,6# Specifications Grade Coupling B PEB L-80 BTC L-80 BTC L-80 BTC Length 80' 3115 8554 680 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured true vertical feet feet Effective Depth: measured true vertical feet feet Casing Conductor Surface Production Length Size Cemented Perforation depth: measured true vertical ) W4A 3/'1/07- 4- ~{Co Development Oil 0 Multiple Zone 0 10. Field and Pool 6, Property Designation AA081780 I AK5125 7, Unit or property Name 11. Type Bond (see 20 AAC 25.0251) Exploration NPRA Statewide 8, Well number Number Pioneer #1 #59-52-180 9. Approximate spud d;.te Amount March 19, 2002 $200,000 14. Number of acres in property 15. Proposed depth (MD and TVD) 5756 9119 ' MD 1 9115 ' TVD 17. Anticipated pressure (sej2° AAC 25.035 (e)(2)) Maximum surface 3127 psig At total depth (TVD) 4130 psig Setting Depth Exploration Top Bottom Quantity of Cement MD TVD MD TVD (include stage data) Surface Surf. 115' 115' 200 sx AS I , 'To ~Gk Surf. Surf, 3150' 3150' 410 sx AS III Lite & .1Q&'sx Class G Surf. Surf. 8589 8585 190 sx Class G+ additives 8439 8435 9119 9115 130 sx Class G+ additives Plugs (measured) Junk (measured) Measured depth True Vertical depth RECEIVED fES .1 tt 2002 Alaska Oil & Gas Cons, Commission Anchorage 20. Attachments Filing fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program 0 Drilling fluid program 0Time vs depth plot ~efraction analysis 0 Seabed report 020 AAC 25.050 requirements 0 21. I here~ certify that the fOregOin~ i~ t/and nrrecïo the best of my knowledge Questions? CallI om :a. s;,o,:e,ld }.206...~-6377 SignV~ ,f,{ h~ ~, Title: Drilling Team Leader Date v /¡ --It. - Paul Mazzolini V~4t ~L--h.i T.IR Commission Use Only Permit Number - I API number i / / /:;-o..,/' I APprov~te / -:2-D'2.. - oS I 50- /a~~ - 2C) ,fb'-C,-J ~- ~ 0 d.- e: Conditions of approval Samples required l8J Yes D No Mud log required Hydrogen sulfide measures ~ Yes 0 No Directional survey required ~ Yes Required working pres~ure\fo: BOPE D2M; 0 3M; 0 ,5M; 0 10M; 0 ~() 0 Other: 500ù ~\ \'<'\\\\v\ ~)(~-\- ,~5a~ \>">\ X-"\.~u-.ç.\<l-~~ fìV7 b~ orter of Approved by Original Signed By Commissioner the commission Cammy uechsll Form 10-401 Rev. 12/1/85. ~ee cover letter for other requirements Yes U No 0 No Date ~"31 'l/ D .~) 01JGNJ,~ Submit in triplicate ) Phillips Alaska, Inc. ) Drill and Case Plan for Pioneer #1 General Procedure: / 1. MIRU Doyon 141 over pre-installed 16" conductor casing. Weld landing ring on conductor. ¡ 2. Install diverter & function test same. Notify regulatory agencies 48 hours prior to test. ,/' 3. Spud well and drill 12 1/4" hole to the surface casing point at 3150' MD/3150' TVD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. /,' 5. Run and cement 9 5/8" 40# L80 BTC casing string to surface. . Employ lightweight permafrost cement lead slurry and Dowell LiteCrete high compressive, lightweight tail slurry to assure cement returns to the surface in a one-stage job. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. / 6. Nipple down diverter, nipple up BOP's. Test BOP's. Notify all regulatory agencies 48 hours prior to test 7. Make up 8 V2" bit and BHA and R~ to top of float equipment . Pressure test casing to 3000 psi for 30 minutes . Record results and fax to town .,/ 8. Drill float equipment and approximately 20' of new hole . Perform LOT (or FIT if gradient reaches 16 ppg equivalent) . Record results and fax to town /' 9. Drill 8112" pilot hole well bore to .::!:.9115' MD/.::!:.9115' TVD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 10. TOOH and LD BHA. RIH 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 5657' ,./. MD / 5657' TVD. /' 11. After setting sidetrack plug, WOe. RIH with 8112" drilling assembly and twin well to top of J4/UCU. Run MWD / LWD logging tools in drill string as required for directional monitoring and to properly identify objective t~. 12. Run 7" intermediate string to isolate potentially sensitive shales located just above the objective (est.@ 8589' MD / 8585' TVD). Cement casing to bring cement .::!:.800' above 7" shoe. 13. 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 14. Drill float equipment, CCM, displace to coring fluid and TOOH. (LOT is not planned for this casing *' string - see attached explanation). 15. 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. ,/' 16. Drill twinned wellbore to .::!:.9119' MD / .::!:.9115' 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. 17. Log 6-1/8" wellbore as ne<=9sary. 18. Run and cement 4 112" 12.6# L80 EUE Liner 19. Make a cleanout run with bit and scrapers . Displace to filtered seawate~, . Pressure test well to 3000 psi for 30 minutes . Record results and fax to town C D ~ l' :~' f ~~~, i tí j l;f ¡ j ~~ j~~ - ~. ) Phillips Alaska, Inc. 20. Run and land 3-1/2" or 4 1/2" tubing with gas lift completion 21. Nipple down BOP's. Install production tree and pressure test same to 5000 psi. 22. Secure well, release rig. 23. 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. 24. 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. ) 0 :) !'G Ji,;" N~ ; 11. ,Vii.... ~HI~LIPS ~ ,~) ~ 400 - 0 ~ "t. '" ,""o,tool 135' ¡ ::~_~__~:i_~IE_:~:::_:~_!::~--~--~:_~--~_:_:-_I!?~::;--::1 Structure: Pioneer #1 Field: Exploration Well: Pioneer Location: North Slope, Alaska 400 - .......,..........",..............".,,,......,,..............,,,,..................,,,.......,......"..,,, Permafrost -'-"""'-,-"-""",,,""-'"''''''M'''''''''''--'''''''..--.-...... ...........,..................--- Crected by Jones For: T Brassfield 800 - Do!e plotted: 10-Jon-2002 Plot Rlilferenc8 is Pionlil8r #1A VClfsion #1. 1200 - Coordinates are in feot reference slot # 1. 1600 - True V.rtlcol Depths or. r.f".nc. Est.RKB (Doyon # 141). BIU BML\ES .........................._.....INTE.Q..._........-...............................-.......... 2000 - 2400 - Estimated SURFACE LOCATION: 525' FSL, 87' FWL SEC. 11, T9N, R2E, UM 2800 - 3200 - 9 5/8 Csgpt ,Hl K3 ,..-..., -+- Q) ~ 3600 - .......... ...c -+- 4000 - Q. Q) 0 0 4400 - Ü -+- L Q) 4800 ... > Q) :J 5200 ... !.... ~ I V 5600 - 6000 - 6400 - ~ Seq97 Seq95 ~.':,. t88 KOPOL~: s~~:~adCekg P:er 100 ft i 9.00 EOB ~ 8.00 Begin Angle Drop . 6.00 DLS: 2.00 deg per 100 ft 4.00 Seq93t .:, 8 2.00 Seq93t EOD . 0 6800 - Top Dist Zone ~ 0 T/ Dist Zone 7200 - 7600 - LCU ~ 0 LCU 8000 - 8400 - _Tgt-T/Jurassic jJ Tgt-T/Jurossic-7 CsgPt 8800 - B/ J4 Silt 0 0 B/ J4 Silt Distal Nuiqsut Mkr 9200 - TO Ef~D 800 400 400 0 800 Vertical Section (feet) -> Azimuth 0.00 with reference 0.00 N. 0,00 E from slot # 1 .................,........",..................................,.... 5200 - 5400 - 5600 - 5800 - 6000 - 6200 - 6400 - 6600 - ,..-..., -+- Q) 6800 - Q) '+- .......... ...c 7000 - -+- 0.. Q) 0 7200 - 0 ü :.;:: 7400 - L Q) > Q) 7600 - :J L ~ I 7800 - V 8000 - 8200 - 8400 - 8600 - 8800 - 9000 - 9200 - 9400 - 600 ...".........,,,...............,,,.,,.,,.,..,,.. KOP - Sidetrack pt 3.00 DLS: 3.00 deg per 100 ft 6.00 9.00 EOB 10.00 Begin Angle Drop 8.00 6.00 OLS: 2.00 deg per 100 ft 4.00 Seq93t 2.00 Seq93t EOD T / Dist Zone 0 Top Dìst Zone LCU LCU ../ Tgt-T/Jurassic 0 Ll Tgt-T/Jurassic-7 Csgpt B/ J4 Silt 0 0 B/ J4 Silt Distal Nuiqsut Mkr 0 0 Distal Nuiqsut Mkr TO 0 ,tl TO B B 400 200 600 400 0 200 Vertico I Section ( feet) - > Azimuth 0.00 with reference 0.00 N, 0.00 E from slot H 1 O'_.~ '""" ry:'\7 \11 ~i i '':''. " I fi I ~¡ I {~'¡l '- ------------------------------------------- -----------------. Plol R.fer.nce i. Pioneer 11 V4Irllion *1. i ; Coordinales ore in feet I'eference :5lol *1. I , i ,True Vertical Depths 0.. re'er~iiïÎK8 (Doyon 1141). i 'W~ I ; ... .INT~Q .. .......J... t...... I Structu re : Pioneer # 1 Field: Exploration Well: Pioneer Location: North Slope, Alaska! /PHilliPS' f,~~ ~ ~ ,'.'.'.'" ......... ... . ... .. .. ...................................... : Created by jone. For: T Brassfieldl Dote plotted: 10-Jon-2002 Phillips Alaska, Inc. --------------------------------- -------- ---.----.---.. =====:J ~ c:::==:::J c:::::== PROFLE COMMENT DATA == == ----- Point ----- MD Inc Dir TVD No rt h East V. Sect Deg/ ~-J ~ Permafrost 655.00 0.00 0.00 655.00 0.00 0.00 0.00 0.00 9 5/8 Csgpt 3150.00 0.00 0.00 3150.00 0.00 0.00 0.00 0.00 K3 3300.00 0.00 0.00 3300.00 0.00 0,00 0.00 0.00 Seq97 3940.00 0.00 0.00 3940.00 0.00 0.00 0.00 0.00 Seq95 5005.00 0.00 0.00 5005.00 0.00 0.00 0.00 0.00 I I I Seq93t 6425.00 0.00 0.00 6425.00 0.00 0.00 0.00 0.00 T / Dist Zone 6955.00 0.00 0.00 6955.00 0.00 0.00 0.00 ~Ü LCU 7870.00 0.00 0.00 7870.00 0.00 0.00 0.00 0.00 Q Tgt- T / Jurassic 8584.98 0.00 0.00 8584.98 0.00 0.00 0.00 0.00 =t::J B/ J4 Silt 8785.00 0.00 0.00 8785.00 0.00 0.00 0.00 0.00 --- C;~ --- Distal Nuiqsut Mkr 8865.00 0.00 0.00 8865.00 0.00 0.00 0.00 0.00 < ~ TO 9115.00 0.00 0.00 9115.00 0.00 0.00 0.00 0.00 r-- Coordir\Ot.8 ore in feet reference 610t *1. Structu re : Pioneer # 1 Field: Exploration Well: Pioneer Location: North Slope, Alaska /PHILLIP~ ' .,;f,~ ""I .~ -' er.ot.ø b)I jan.. T Brassfield Dole plott.d : 10-Jan-2002 i Plot Reference is Pioneer ilA Version i1. Phillips Alaska, Inc. Vertical Depths ort! r.,reIEit._RKS (Doyon 1141). ~ INTEO 1______---- c:=:== ~ c::====J c:=:==::::J PRO F LE COMMENT DA A -======- c:==:::::;, c:==:::::;, c== ----- Point ----- MD Inc Dir TVD N 0 rt h East V. Sect Deg/-JO KOP - Sidetrack pt 5657.00 0.00 0.00 5657.00 0.00 0.00 0.00 0.00 E08 5992.47 10.06 0.00 5990.75 29.39 0.00 29.39 3.00 8egin Angle Drop 6001.23 10.06 0.00 5999.38 30.92 0.00 30.92 0.00 Seq93t 6429.43 1.50 0.00 6425.00 74.02 0.00 74.02 2.00 EOD 6504.44 0.00 0.00 6500.00 75.00 0.00 75.00 2.00 Top Dist Zone 6959.44 0.00 0.00 6955.00 75.00 0.00 75.00 )0 ~ LCU 7874.44 0.00 0.00 7870.00 75.00 0.00 75.00 0.00 Tgt- T / Jurassic-7 Csg 8589.42 0.00 0.00 8584.98 75.00 0.00 75.00 0.00 a 8/ J4 Silt ::1.::.1 8789.44 0.00 0.00 8785.00 75.00 0.00 75.00 0.00 --=- !;~~- ~:> Distal Nuiqsut Mkr 8869.44 0.00 0.00 8865.00 75.00 0.00 75.00 0.00 ~:;;--r~ :;¿::~ ~ TD 91 1 9.44 0.00 0.00 9115.00 75.00 0,00 75.00 0.00 r-- ). ) Phillips Alaska, Inc. Pioneer #1 Pioneer slot #1 Exploration North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref: Pioneer #lA Version #1 Our ref: prop5067 License: Date printed: 10-Jan-2002 Date created: 10-Jan-2002 Last revised: 10-Jan-2002 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on 303729.000,5904414,OOO,999.00000,N Slot location is n70 8 35,263,w151 34 39.639 Slot Grid coordinates are N 5904414.000, E 303729.000 Slot local coordinates are 0.00 N 0.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is Grid North 0 R ¡ \.;fINAl. ") Phillips Alaska, Inc. Pioneer #l,Pioneer Exploration,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 5657,00 5757.00 5857.00 5957.00 5992.47 6000.00 6001.23 6004.44 6104.44 6204,44 6304.44 6404.44 6429.43 6504.44 6959.44 7000.00 7500.00 7874.44 8000,00 8500,00 8589,42 8589.44 8789.44 8869,44 9000,00 9119.44 0.00 3.00 6.00 9,00 10.06 10.06 10.06 10.00 8.00 6.00 4.00 2.00 1. 50 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Coordinates 0,00 0.00 0.00 0.00 0,00 5657.00 5756.95 5856,63 5955.77 5990.75 0.00 0.00 0.00 0.00 0.00 5998.16 5999.38 6002.53 6101.30 6200.55 0,00 0,00 0.00 0.00 0,00 6300,16 6400.02 6425.00 6500.00 6955,00 0.00 0.00 0.00 0.00 0,00 6995.56 7495.56 7870,00 7995,56 8495,56 0.00 0.00 0.00 0.00 0.00 8584.98 8585.00 8785.00 8865.00 8995,56 0.00 9115.00 R E C TAN G U L A R COO R DIN ATE S 0,00 N 2,62 N 10.46 N 23,51 N 29.39 N 30.70 N 30.92 N 31. 48 N 47.12 N 59.31 N 68.02 N 73,25 N 74.02 N 75.00 N 75.00 N 75.00 N 75.00 N 75.00 N 75,00 N 75,00 N 75.00 N 75,00 N 75.00 N 75,00 N 75,00 N ./ 75.00 N 0.00 E 0.00 E 0.00 E 0,00 E 0.00 E 0.00 E 0,00 E 0.00 E 0.00 E 0,00 E 0.00 E 0.00 E 0.00 E 0.00 E 0.00 E 0.00 E 0.00 E 0.00 E 0,00 E 0.00 E 0.00 E 0,00 E 0.00 E 0.00 E 0.00 E 0.00 E Dogleg Deg/100ft 0.00 3.00 / 3.00 3.00 3.00 0.00 0,00 2.00 2,00 2.00 2.00 / 2.00 2,00 2.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ") PROPOSAL LISTING Page 1 Your ref: Pioneer #lA Version #1 Last revised: 10-Jan-2002 Vert Sect 0.00 KOP - Sidetrack pt 2.62 10.46 23,51 29.39 EOB 30.70 30,92 31. 48 47.12 59.31 Begin Angle Drop 68,02 73.25 74,02 75.00 75,00 Seq93t EOD Top Dist Zone 75,00 75,00 75,00 LCU 75,00 75,00 75.00 75,00 75.00 75.00 75,00 Tgt-T/Jurassic-7"CsgPt B/ J4 Silt Distal Nuiqsut Mkr 75.00 TD All data is in feet unless otherwise stated. from slot #1 and TVD from Est.RKB (Doyon #141) (135.00 Ft above Mean Bottom hole distance is 75,00 on azimuth 0.00 degrees from wellhead. Total Dogleg for wellpath is 20.13 degrees. Vertical section is from wellhead on azimuth 0.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Sea Level) . 6n¡~ì¡J¡L ) ') Phillips Alaska, Inc. Pioneer #l,Pioneer Exploration,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref: Pioneer #lA Version #1 Last revised: 10-Jan-2002 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 5657,00 5657.00 0,00 N 0,00 E KOP - Sidetrack pt 5992.47 5990,75 29,39 N 0,00 E EOB 6001. 23 5999.38 30.92 N 0,00 E Begin Angle Drop 6429.43 6425.00 74.02 N 0.00 E Seq93t 6504,44 6500.00 75.00 N 0.00 E EOD 6959.44 6955.00 75.00 N 0.00 E Top Dist Zone 7874,44 7870.00 75,00 N 0.00 E LCU 8589.42 8584.98 75,00 N 0,00 E Tgt-T/Jurassic-7"CsgPt 8789,44 8785.00 75,00 N 0.00 E BI J4 Silt 8869.44 8865.00 75.00 N 0.00 E Distal Nuiqsut Mkr 9119.44 9115.00 75.00 N 0.00 E TD Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords, Casing ----------------------------------------------------------------------------------------------------------- n/a n/a n/a 5657.00 5657.00 5657,00 O.OON O.OON O,OON O.OOE n/a 5657.00 O.OOE 8589.44 8585.00 O,OOE 9119.44 9115.00 O,OON 75.00N 75,OON O.OOE 9 5/8" Casing O,OOE 7" Csg O,OOE Unlisted NO Targets associated with this wellpath 0 0; GA~- ) Phillips Alaska, Inc. ') DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Pioneer # 1 Drilling Fluid Properties: Spud to surface casing point Density PV YP Funnel Vis Initial Gel 10 Minute Gel API Filtrate pH % Solids 9.5 - 10.2 ppg 16 - 26 25 - 35 50 - 100 10 - 20 15 - 40 7 - 15 9.5 - 10 :I:: 10% Drill out to TD (pilot & Intermediate hole) 9.5 - 11.0 ppg ,/ 6 - 20 5 - 20 35 - 50 2-6 14 - 20 < 6 below 7000' 9.0 - 10 < 11% Twinned Hole (Intermediate shoe to TD) 9.1- 9.4 ppg v- 8 -12 12 - 20 40 - 50 8 -12 12 - 16 <10 9.0 - 10.0 < 8% Drillin2 Fluid System: Equipment list for Doyon 141 should be on file with AOGCC. Drilling fluid practices will be in accordance with the regulations stated in 20 MC 25.033. Maximum Anticipated Sulface Pressure and Casina Design: The following information is used for calculation of the maximum anticipated surface pressures for the planned well: Casing Size 16" 9-5/8" 7" 4-1/2'''' Casing Setting Depth 115' MD / 115' TVD 3150' MD / 3150' TVD 8589' MD / 8585' TVD 9119' MD / 9115' TVD Fracture Gradient 11.0 ppg 14.8 ppg 17.6 ppg 17.6 ppg Expected Maximum Mud Weights: Pore Pressure Gradient 8.33 8.33 8.8 ppg 8.8 ppg Pore Pressure 50 1364 3890 4130 MASP Drilling NA 53 psi 2078 psi 3127 psi ~ 12-1/4" surface hole to 3150' MD / 3150' TVD: 10.2 ppg .,/ 8-1/2" pilot hole to 9115' MD / 9115' TVD: 11.0 ppg (for shale stabilization) ,// 8-1/2" Intermediate Twinned hole to 8589' MD / 8585' TVD: 11.0 ppg (for shale stabilization) 6-1/8" Production Hole to 9119' MD / 9115' TVD: 9.4 ppg .,/ C ~1 ~ G i ~ ) J , I ~. ¡~ ¡J ~ ) Phillips Alaska, Inc. ) Procedure for Calculating Maximum Anticipated Surface Pressure: MASP 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) MASP = [(FG x 0.052) - 0.11] x D Where: MASP = Maximum Anticipated Surface Pressure FG = Fracture Gradient at the casing seat in Ib/gal 0.052 = Conversion factor from Ib/gal to psi/ft 0.11 = Gas Gradient in psi/ft (above 10,000' TVD) D = True vertical depth to casing seat in ft from RKB OR 2) MASP = FPP - (0.11 x D) Where: FPP = Formation Pore Pressure at the next casing seat MASP Calculations 1. Drilling below 16" Conductor Casing MASP = [(FG x 0.052) - 0.11] x D = [(11.0 x 0.052) - 0.11] x 115' = 53 psi ./ OR MASP = FPP - (0.11 x D) = 1364 - (0.11 x 3150') = 1018 psi 2. Drilling below 9-5/8" Surface Casing MASP = [(FG x 0.052) - 0.11] x D MASP = [(14.8 x ~52) - 0.11] x 3150' MASP = 2078 psi OR MASP = FPP - (0.11 x D) = 4130 - (0.11 x 9115') = 3127 psi 3. Drilling below 8-1/2" Intermediate Casing MASP = [(FG x 0.052) - 0.11] x D MASP = [(17.6 x 0.052) - 0.11] x 8585' MASP = 6913 psi OR MASP = FPP - (0.11 x D) = 4130 - (0.11 x 9115') = 3127 psi / ( 1 ~ ^t~ ) Phillips Alaska, Inc. Casing Design Performance Properties Size ) Weight Grade Connection 16" 63 ppf B PEB 9-5/8" 40 ppf L-80 BTC 7" 26 ppf L-80 BTC-M 4-1/2" 12.6 ppf L-80 BTC Internal Yield Collapse Conductor Casing 5750 psi 3090 7240 psi 5410 8430 psi 7500 psi Tensile Strength Joint 979 M 667 M 304 M Body 916 M 519 M 267 M / Casing Setting Depth Rational: 16" @ 115' MD RKB Conductor casing to provide sufficient anchor and fracture gradient for diverter system. Surface casing to provide good anchor for BOPE and sufficient fracture gradient and well control while drilling pilot hole and twinned wellbore into reservoir. 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 istargeted below the 7", a leak off tesLw.i1l not be done. ÞeJ.Q..v~'L~_~,bQg~/The shoe of this casing will be set immediately into the top of the o~ective 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. 9-5/8" @ 3150' MD RKB 7" @ 8589' MD RKB Well Proximity Risks: None Drillina Area Risks: Shallow Hazards: See attached explanation Drilling Risks: Drilling risks in the Pioneer #1 area are surface interval clays, intermediate interval sloughing shales, and lost circulation/breathing potential through the reservoir. Surface clay problems will be counteracted with fluid chemistry and rheology. 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. See attached mud weight versus depth graph for the offset wells Lookout #1, ARCO Spark #lA, Rendezvous "A", and Rendezvous #2. Annular Pumping Operations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted Class II 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 Pioneer #1 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. ( PAl may request approval to inject or dispose of fluids in the Pioneer #1 9-5/8" x 7" annulus at a later date. This request would be made after sufficient data is available to meet the requirements of AOGCC's 20 MC 25.080. 0 I~ 'ì ¡,(~I c!'lJA' H'i G i\ ,1 L i ) Phillips Alaska, Inc. ) Geoloay: Anticipated geologic markers, depth uncertainty, fluid properties, and pore pressures are as follows: FORMATION DEPTH (ss) UNCERTAINTY POSSIBLE FLUID EST. PORE TYPE PRESSURE, Dsi Permafrost 520' 150' 225 K3 3165' 100' Possible Oil or Gas 1370 Sequence 97 3805' 100' 1650 Sequence 95 4870' 150' 2150 Sequence 93t 6290' 150' 2830 Base Turbidites absent Disturbed/Pebble Shale 6820' 200' 3070 LCU 7735' 100' 3560 Top Jurassic 8450' 100' Probable Oil and/or 3890 Gas Base J4 Silt 8650' 100' 3980 Distal Nuiqsut Marker 8730' 100' 4015 / TD 8980' 4130 Formation Evaluation: Anticipated logging, coring and testing for this well is as follows: I. Logging Surface Interval (0 - Surface Casing setting depth) LWD: GR/Res/Dipole Sonic /~~ 6/'>WAA...'!.,¡-"", ..{h 8-1/2" Pilot Hole (Surface Casing setting depth to TD) / L WD: GR/Res/Density /Neutron/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/PEX/Dipole Sonic/CMR (Contingency: MDT/RSWC/VSP) Coring Full Diameter 2.5" Core in Upper Jurassic (1 - 2, 60' cores) Potential Rotary Sidewall Cores (wireline conveyed) in the event full core operations are unsuccessful II. III. 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 :; 'G.NÁL \ Phillips Alaska, Inc. \) 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. IV. 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. If commingling is chosen, production logging will be performed during the flow test to determine the productivity of the individual zones. ORIG Nt- ) Phillips Alaska, Inc. Pioneer #1 Drilling Hazards Summary .) ~Z.~,1,1.~" Hole I ~"...,~,LR" Casina Interval Event Gas Hydrates Risk Level Low Clay Balling Medium Abnormal Pressure in Surface Formations Lost Circulation Low Medium ,p- ~L",~~~",,,&,,,Ji,:ul18,~~ Hole Event Lost circulation Risk Level High) Hole swabbing on trips Low Directional Control Medium Sloughing Shale, Tight Hole Medium Abnormal Reservoir Pressure Hydrogen Sulfide gas Low Low Mitiqation Strateqy Monitor well at base of permafrost, increased mud weight, managed fluid rheologies, decreased circulating times, controlled drilling rates, low mud temperatures Maintain planned mud parameters, Increase mud weight, use weighted , sweeps, reduce fluid viscosity, control ROP. / Diverter drills, increased mud weight Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries, port collar, controlled runninq speeds. / M itiqation Strateqy Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, Pre- planned LCM pills, lost circulation material. Reduced trip speeds, mud properties, proper hole filling, real time equivalent circulating density (ECD) monitoring, weiqhted sweeps. BHA design, on-sight geologic review and advisement of potential slump blocks. Increased mud density and fluid composition according to plan, controlled trip speeds, sweeps, ECD monitorinq. Well control drills, increased mud weight, continqencies for top set casinq strinq. H2S drills, detection systems, alarms, standard well control practices, mud scavenqers Oi/G/^t.1- ) Pioneer #1 WELLBORE SCHEMATIC and CEMENT DESIGN 16" C~nductor 'I Casing at I 115' MD / RKB Mf!{,",W.,:.':.',~.. ~ Base of ~¡ permafrost ~¥ ~~*1 655' MD mi¡;; I I; I ,~ :;.>r~ ~~ ¥* ;1 i *.i J 9-5/8" Surface Casing at 3,150' MD Top of Cement at / 7,700' MD 7" Intermediate Casing at 8,589' MD 4-1/2" Production Liner @ 8,439' MD to 9,119'MD I it ; llit({: ~~~ ij t,.',&,...: ~~ ~ l' <1 I )i\ )j '~k *. t~; t~ ì~ :j! ~~ '"l1it ~f S1:': 1r;~ ;,:~ ~i, ~~-~ ~ Lí.......,...',.:..¥.:.:.' ~" I 11 ~t" I Î I I ~~ 12-1/4" H, I ri Mr ~ I l I I] Wt ~::Ù *~ 8-1/2" Hole ~¿ ~ ~~;~ ~~ I , ~ ~ ft J;t .\~~ ~~ D/j'f. III lø .;.~:f ." t~ ~;;: ~ ¡~ ,t; ~. ~ ,~ ;~.~ ,.. ;; it. ~T ,\!; IL. 6-1/8" Hole Conductor Casing Size / Hole Size Depth: Top 01 Cement Excess Calculated: Volume Calculations: (11511) (181 cl) (0.7854 cl/ll) 1(0.93 cl/sx) Slurry Volume: 181 cf Slurry Weight 15.7 ppg Slurry Yield 0.93 cl/sx Surface Casing Stage 1: Volume (655 If) (1,695 If) (1,795 cl) (800 II) (363 cl) (0.3132 cl/lf) (0.3132 cl/ll) 1(4.44 cflsx) (0.3132 cf/ll) 1(2.40 ells x) Lead Tall shoe Joint vol 34 cf + '} 16" in 20" hole 115' MD R.J5B Surface /' 100% (2.00) = 181 cf or 200 sx Arctic Set 1 200 sx rounded excess 9-5/8" in 12-1/4" hole (5.00) = 1,026 cl (1.45) = 770 cl 404 sx (1.45) = 363 cl 166 sx System: Lead (Arctic Set 3 Lite cement + 9% D44 (NaCI) + 30% D53 (gyp) + 50% D124 (spheres) + 1.5% S1 (CaCI2) + 1.5% D79 (ext.) + 0.4% D46 (deloam.) Tall (LiteCrete @ 12.0 ppg) Lead Slurry Volume: 1,795 cf Slurry Weight 10.7 ppg Slurry Yield 4.44 cl/sx Thickening Time 6.0+ hours Tall Slurry Volume: 363 cf Slurry Weight 12.0 ppg Slurry Yield 2.40 cl/sx Thickening Time 3.5 - 4.5 hours Intermediate Casing Size / Hole Size Depth: Top 01 Cement Excess Calculated: BHT (Static): Volume around 7 (889 If) shoe Joint vol 17 cf + (197 cl) (0.1268 cl/ll) 1(1.17 cl/sx) System: (Class G cement + 1% D800 + 0.2% D46 + 0.3% D65 Slurry Volume: 214 cf Slurry Weight 15.8 ppg Slurry Yield 1.17 cl/sx Thickening Time 3.5 - 4.5 hours Production Casing Size / Hole Size Depth: Top 01 Cement Excess Calculated: BHT (Static): or 410 sx Arctic Set 3 Lite or 170 sx Class G 7" In 8-1/2" hole 8,589' 7,700' /" 75% 1600 F 1300 F BHT (Circ): excess (1.75) = 197 cl 183 sx or 190 sx Class G 4-1/2" In 6-1/8" hole 9,119' ,,/ 8,350' 50% 1600 F 1300 F BHT (Circ): excess (1.50) = 75 cl (75 cf) 1(1.20 cflsx) Volume around 4-1/2" Vol. Between liner & Int. shoe Joint vol 7 cf + Volume of 200' above liner System: (Class G cement w/Gasblok + 0.1 gps D47 (deloam.) + 3% D53 (Gyp) + 0.75% D65 (disp) + 1 gps D135 + 2 gps D600 + 0.1 % D800 (ret.) 20 sx 68 sx 40 sx (530 If) (0.0942 cl/ll) Slurry Volume: 133 cf Slurry Weight 15.8 ppg Slurry Yield 1.20 cl/sx Thickening Time 3.5 - 4.5 hours or 130 sx Class G Cement volumes and blends are estimates only and subject to change before 0 ~l ~ c:;iti(4~. Z ' .)' 1:"'(1 ,t . \ ¡ \. .'.~~ ' ~. - Pioneer #1 Proposed Completion Schematic ) ~ PHILLIPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY r ~ 1 I ~ r 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" Cameo 'X' nipple wI 3.813" profile set at +1- 500' MD, 4-1/2" x 6' L-80 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ * ~ ~ ~ ~ ~ ~ EUE8RD pup installed above and below 16" 65# H-40 @ ~ ~ ~ ~ ~~ ~ ~ ~ ~ +1- 115' MD ~ ~ ~ ~ ~ ~ ~ ~ 4-1/2" 12,6# L-80 EUE8RD tubing to landing nipple ~ ~ ~ ~ ~ ~ I ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 4-1/2" x 1" Cameo 'KBG-2' mandrels wI DV's and RK latch, 6' L-80 handling pups ~ ~ ~ ~ ~ ~ ~ ~ installed above and below. Spaced out w/4-1/2", 12.6#/ft L-80 EUE8rd tubing as ~ ~ ~ ~ ~ ~ ~ ~ needed. ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ I ~ ~ ~ ~ ~ ~ ~ ~ ~ Depths are ~ ~ ~ ~ based on est ~ ~ ~ ~ ~ ~ ~ ~ rig RKB ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Surface csg. ~ ~ ~ ~ ~ ~ ~ 9-5/8" 40,0# L-80 BTCM ~ ~ (+1- 3150' MD 13150' rvD) ~ ~ 4-1/2" x 1" Cameo 'KBG-2' mandrel wI shear valve and latch pinned for 3000 psi ~ ~ ~ ~ shear (casing to tubing differential), 6' L-80 handling pups installed above and ~ ~ ~ ~ below. ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ I ~ ~ ~ ~ ~ ~ ~ ~ 1 joint 4-1/2" 12.6# L-80 EUE8RD tubing ~ ~ ~ ~ ~ ~ ~ ~ 4-1/2" Cameo 'X' nipple wI 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 locator sub ~ j +- 4-1/2" Baker GBH-22 casing seal assembly wI 12' stroke, 4-1/2" L-80 EUE8RD box up Intermediate csg. 7" 26,0# L-80 BTCM (+1- 8589' MD 18585' rvD) 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,S" 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 Production Liner 4-1/2" 12.6# L-80 EUE8rd (+1- 9119' MD/9115' rvD) ... ~ 3-~" 9.3 ppf L-80 EUE rd may be substituted for the 4-~" ~' BJD~ DNA ., ) ) ~ ~ PHILLIPS PETROLEUM COMPANY To: Jerry Veldhuis Tom Brassfield A TO-792 ATO-1550 From: Kathy Heinlein ATO-1346 Subject: Pre-Drill Seismic Pore Pressure Prediction for Pioneer #1 CONFIDENTIAL Date: January 31,2002 Summary Seismic velocity data was used to predict pore pressures likely to be encountered in the Pioneer #1 proposed well location. A local compaction trend and a local velocity to pressure gradient translation trend model were established using control from the Rendezvous #2 offset well. The local compaction trend and translation trend model established from the existing wells was applied to velocities from the NPR99E 3D seismic survey to predict pore pressures. The predictions show no apparent shallow hazards or large pressure "..--' anomalies at the proposed well location. Seismic ProcessinQ: The accuracy of seismic geopressure analysis depends critically on the accuracy of the input velocity field. The velocities used here were generated using Phillips' A VEL program, an automated high-resolution velocity analysis program developed by ARCO Exploration and Production Technology. This process produces a very accurate velocity field defined at every sample in time and laterally along each seismic line. The output RMS velocities were smoothed over 9 COPs to minimize instabilities in the velocity field that might result from noise, lack of signal or variations in COP fold. : 7,'GNAL ) ) Pressure Prediction Procedure: Phillip's PPFG software (developed by ARCO Exploration and Production Technology) was used to calculate the predicted pore pressures. The Rendezvous #2 well was used to establish both a local normal compaction trend line and a local velocity vs. pressure translation trend model (slope = -4.5e-5, intercept = 152). This trend is similar to trends observed in other area wells (Rendezvous A, Spark #1A, Clover A, Lookout #1, Moosestooth C, W Fish Creek #1). Procedure 1.) A Normal Compaction Trend Line (NCTL) was determined for each seismic line. The individual NCTLs matched the NCTL model developed at the Rendezvous #2 well (slope = -4.5e-5, intercept = 152). 2.) The difference between interval transit times (ITT), recorded by wireline sonic logs (ð T) in the existing wells or by seismic velocities in the proposed wells, and the Interval transit times predicted by a downward extension of the NCTL were measured. These values are the travel time differences, ðð T. 3.) A translation trend model was established by comparing transit time differences (ðð T) to mud weights. This model calculates pressure gradients (PP) using the equation PP = C2*ððT**2 + C1*ððT + CO Where C2 = 8.01 e-5, C1 = .0019, CO = .465 4.) Fracture gradients were calculated using the Eaton Method. Inputs are the bulk density, the calculated pore pressure gradient profile, and a Poisson's Ratio profile (from a West Cameron model). : ;' , ; .At. ~ ) ) Rendezvous #2: Figure #1 is the pore pressure gradient calculation for the Rendezvous #2 well. The left side is the wireline sonic DT (black curve) with the NCTL (red line). The right side is the pore pressure gradient calculation (blue curve) and the actual mud weight (green curve). Casing points and lithology changes are as labeled. Note the predicted pressure at 7300 ft is slightly higher than the actual pressure as measured by mud weight. This change reflects a decrease in velocity due to the presence of a kerogen-rich shale. Although it appears as an increase in pressure it is instead a lithology effect, and is noted on the seismic lines used for this analysis. Similarly, a silt zone begins at approximately 8150 ft. The NCTL used is based on shales containing only minor amounts of silt. Because silts are slower than shales, the velocity of the silty layer is lower than the velocity predicted for low silt shales at the same depth. The velocity difference generated by the lithology change shows up on the plot as a false increase in pressure. Seismic Pore Pressure Prediction (No Shallow Hazards Observed): Pressure gradients were predicted at each well location from 3D seismic velocities. Predicted Pore Pressure Gradient Displays in Depth: Figure # Seismic Line Well Name 2 IL49417 PIONEER 1 4 XL 10391 PIONEER 1 Predicted Pore Pressure Gradient Displays in Time with Migrated Time Overlay: Figure # Seismic Line Well Name 3 IL49417 PIONEER 1 5 XL 10391 PIONEER 1 Warmer colors indicate higher predicted mud weights (pore pressure gradients). Seismic velocities indicate the potential of a high pressure zones on in line 49417 (8200 ft - 8800 ft SSTVD, CDP 10305 - 10365) (Figure 2) and on xline 10391 (8000 ft - 9000 ft SSTVD, CDP 49350 - 49395) (Figure 4). The apparent pressure increases at these depths are most likely due to lithology effects within the Kingak shale. It should also be noted that the normal compaction trend used for the pressure modelling is based upon shales above the Kingak and might not be applicable within the Kingak. There is not enough well data available to accurately measure compaction trends within the Kingak. Pore Pressure Gradient Prediction at Proposed Well Locations: Figure # Seismic Line Well Name 6 IL 49417, XL 10391 PIONEER 1 J ¡~¡ , G : i~ A L ) ) Conclusions: 1.) There are no apparent shallow hazards at the Pioneer #1 proposed well location, and no observed areas of overpressure at depth. 2.) By comparison with the West Fish Creek #1 and Rendezvous #2 wells, pore pressure gradient increases predicted by seismic analysis between 7000 ft and 10000 ft are likely due to local seismic velocity changes caused by kerogen and silt lithologies rather than by high fluid pressures. It is likely that mud weights will range between 10.5 to 11.3 ppg in this interval. 3.) Seismic velocities indicate the possibility of high pressure zones near the td location of Pioneer #1 between 8000 ft - 9000 ft SSTVD. The apparent pressure increases at these depths are most likely due to lithology effects within the Kingak shale, and do not indicate a true increase in pressure. If there are any further questions, please contact feel free to contact me. Kathy Heinlein (907) 263-4761 c= G ~AL <::) ::Jr:-J ~JÇ:"- a ~:~<) l.::"'-... '0-. --. ..... '¿'.-'::-' (~~ ~Hll~PS" ~~~ ~ r~ h-~ ~erC~ ~ PHILLIPS PETROLEUrv1 CO~.~PAi\lY Pore Pressure and Fracture Gradient System 01/30/02 K, Heinlein Project: NPRA Well: Rendezvous 2 NCTL: 152-4.5e-5 Rendezvous 2 DIP'. (DeUn setb MSLI ~ "~~=;-~i; ~~m.- -==- -- p ----- ----- 1000 '.. .. .. - -. - :.- -"~"_~',-..'.'-- .~. -=- ... . -. - .'" m_...'_," - ---- ------~ " . - (J --. - - ------ - --- ------- .---- ~~._---------- - ----~-- ------- -- --------- '---_._--~ - ~-~.:~-~~---~ ---~ (" -- , -- - .---- -- - -"-- - 2000 ----- -----'-- ' -- --- .-- _..~-~ -,--- C,j'-- -~ . - -.=...-..:.-....-. -;.....- ----- - .---- ~ ._-~~_._~;~.~.=~ '.~~:.m:.m~m.._~m.~m_.~.mm..mmmm~.~_..mm. ~ FEEl MSl -..----1000 ~-- 2000 ---- - ---' ---------- .------~ --- 6000 5000 - -- - - --- ~ ----"--- - -- -.. _0_-- -------- -- 6000 6000 .. -.- ----------4- -..::.~ =-=::.::::. ~~ =- :-:..... - n' - --..¿::.-- u. -~ ----- -- -~~-~~G~~~~-~=~'~~--~~~-'~~~ ( -~-~---_..~------- u- ~"];::c.==--=-c- - -~~ n 8())) --- ---~- 1000 -1000 8000 8650 40 60 80 100 120 140 160 180 8 IICTL Inter'C.,tli GL = 15Un LDp'illlmlc ~1o'1 = -41'''21-81 ~ Cull' DlpII M Miele f Flow + Repnt Forllltion Tnt )( Drll Stell TNt l!. ProlluotiDI Prelurl 1:1 LIIIc-8If Tilt I!:I LOIt Ciroulltiln Zlnel - For.dln Tip .. StIIú Pipe Looldiol "I, SidelrlDlI Locldion x Freeflrll 10 14 -- -- - 8650 15 16 12 PPG ---9-152-4505T _pprc (Sonic HCTL: 152-45E-S.uDEF, Top Trend Model: OFF .sHORE_TEXAShiORTH_SEA) - Mud Wei¡M: DRILLERS _REPORT 11 13 Figure 1 c) -¿:ro.'] 1!i2r&:...l-L~---, ""'¿'-- ~. -=. --.... ~;.'- :L---, ¡---- PHiLL~PS PETROLEUiv'i CCHviPANY Project: NPRA Well: Pioneer 1 NCTL: 152-4.5e-5 Pore Pressure and Fracture Gradient System 01/31/02 K. Heinlein Pioneer 1: PPG Predicted from Seismic (Inline 49417) (depth) 1I2-4101'_HI I'IUHtI:H 1 ~- NE ~11 i~ ~1 ~ ~~~1~~~~~~ ~~~~AA1~ ~~~A 1 A~~' A~~ 1 ~AAA 111 ~~~~~~A~ll~~~~AI~ ~2 44144444444444444455555555g555g555~5!5628K666666666666166 1 90 11 233445566118899001122334455661188 90Õ11223344566611 89 0 5 0 5 0 ~ . ~ 0 5 0 5 0 5 0 ~ 9 ~ 9 .~ 9 ~ 9 ~ 9 ~ ~ ~ S 1 9 ~ J : 9 ~ 9 ~, 9 ~ . ~9 ~ ~ ~ 9 ~ 9 ~ 9 ~ 9 ,!? 9 !? 9 !? . ~ 9. 9, ... ... .~~ . þ;- ~ .i;~~"q~'~~Þc~~ 3000.0 r.-" D 4000.0 E P T H lilt 6000.0 8000.0 9000.0 -~ ~ ~£_~~ -- -,,4 10000.0 8.00 8.50 9.00 9.50 10.00 10.50 11.00 11.50 12.00 12.50 13.00 m~:: . 14.50 ~:: ~ 16.50 !c..o...~..-..-..::-.....~-.'. :~: ~~~. 18.50 19.00 ~ ~ Figure 2 <:::) ::t:J '-c--=--- r;c~~ ..~.....~ ."""""..- 'JI -.J~.- ~.~ :t~ .~ ~ PHILLIPS PETROLEUM COrv1PANY Project: NPRA Well: Pioneer 1 NCTL: 152-4.5e-5 Pore Pressure and Fracture Gradient System 01/31/02 K. Heinlein Pioneer 1: PPG Predicted from Seismic (lnline 49417) (time) 'IU..-J-,"-' lei...:.... PDHR 1 -- CDP Spacing = 110 ft 8.00 8.50 9.00 9.50 10.00 10.50 11.00 11.50 12.00 12.50 13.00 13.50 14.00 - 14.50 ~ 15.00 ~ ~.cc:i 15.50 ~ 16.00 = 16.50 !.=-."".~.'.'...-.'..':..... ::: ~~:c 18.50 19.00 '-' .~ Figure 3 C~" -== 8!l;¡"j..: -- ~. , -- ~ "'" '- .r:._- r--- PHilLiPS PETROLEUrv¡ COMPANY Project: NPRA Well: Pioneer 1 NCTL: 152-4.5e-5 Pore Pressure and Fracture Gradient System 01/31/02 K. Heinlein Pioneer 1: PPG Predicted from Seismic (Xline 10391) (depth) 112-4501' -PPQ PIOHEfR 1 m- CDP NW 333333333333333333333333333333333333 ~ ~ ~t t~~33 ~ ~ 3 33 3~~~~~ ~~~~~~~5i" ~~ ~ ~~ 5 0 5 0 5 0 5 0 ~ ç ~ ç 5 0 5 0 5 0 5 0 5 0 5 0 Lî jJ.i 9 ~ 0 5 0 5 0 NI 2000.0 3000.0 : 4000.0 P T H " 5000.0 6000.0 7000.0 8000.0 9000.0 10000.0 CDP Spacing = 110 ft 8.00 8.50 9.00 .,90~0 10.50 11.00 11.50 12.00 12.50 13.00 13.50 14.00 14.50 15.00 15.50 16.00 - 16.50 17.00 Ij¡~ "-- -" Figure 4 L() I CI> «"""L() a::a;~ ~~c\¡ .Q ~ "tic.... .~ == ¡:: QCI>ü è:3=z E (1) ..... ø > tJ) ..... C "1100 () .. .- ;¡:~ "C lI:t <'is CI... '- 11;:'" C) ø:.?: () () 1- (.) .a It"" 0 It¡~ <'is .'"" '- ..IIIIII! LL. 1.Il.I c: ....I "'C :§ () C.~ [:1: <'is:r: ~.... () ~ LIU '- [L. ~ (II) ø C:L.. ~ .,... Q. ..J C\ .,..1 () 52 1- .... :IC; 0 ~ c:L" Q. 0 CD E "';:; - - ,... 0') M 0 ,... Q) .5 X - "2 E () "(j) (J) E e .... -c Q) - 0 :c ~ a.. (!J a.. a.. ,... 20- Q) Q) c: 0 ã: ) ) 8~8~~~~~~~~~~~~~~~~~~~~ it oQ oQ ~ ~ ~ ~ ;: ;: ~ ~ ~ ~ = = ~~I~i~,~; i ~1iiiÍJ ""1 IE ~ ::::: Z ""Ø)U')CÐQ f ~I 0 é ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ QIIIA.I-Z:€ LO ~ :::s C> ü: r::: Q ~ ~ II b.Ð C .0 = c. 00 =- Q U ~ ~ C QI ¡~ i~ þ~ ,~,! l' Lo'" . I ~1;: \! Ii ~ :J.:J --- ~ ---- ~ r-- ("PHIL~PS'" ~ :~:;~~::u~~~~~~;:~t~?~V:~~i:nt System 01/31.02 K. Heinlein Project: NPRA Well: Pioneer 1 NCTL: 152-4.5e-5 Pioneer 1 (lnline 49417 at Xline 10391) DEPTH (0GIm $dkl MSL) MSL my MSL 100:1- ~ . ( -~- --.n - . -----:-~ =~- 1000 -~: : t~~-.~-~~ =--_:-~~--- _n __~__n~ -:- ~-~Q-'-'" --~-- -' - ---'~>.:- -'=' .--'--- -. ~--==~~~~==~-~~~~~ .'_:~~ _:~. --'=~ _.J -.. - . -- _. - ---------- - - -- 2000 - . ...- )--:~ -_:_::--:~~~~ =--':;:=;:~--:--u~n_,_~~~-~.~~~~:m ... - .:~ ~~-{.~:= .<-~ ~~~-.~ ~:u ----'-_un n - - - - ~.. -- _n --.--- ~~~~~~..~---~. - . . j~ --.:~'-.~-:~-<~-~-.::~:~ .:_- - ----- -. -. - --- . 300J - --- - ---- ------ ----- __n - ---- --- - --- --------- - --. -.----- 3000 ----- -- --- ------ - _n- -- - - --- ------------- -- - --.----.------ --- - --. - - - -- - --- ----------------------------- ------------ - - ---------- -----,.-------- .--- -.--------------------------------- -- -- ------------ n - -- -~=-~.-:------- ------__~.__9______------_:"'_-_.. - --. ----------- - 4000 4000 ------------ ----- - -- --~.~ :....-: -:.--~ ~~~.-=-.- ___--n___- --------Ö -. .n - -.. n. ._n __n -- ~ _n - - .--. ------ '.--= --- --=::: ~=~..:_:...:.....:... - n _n -. - - - --- --- ---------- ----- -----.----------------------- -------- - -- - --- - -------- -- - - -- - - - - - --- - --- - sooo ;-,'" 5000 - - - - - --- - - --- . - - -- .--- -- --- - - ___on ___on - ----- ----- -------- -- - --. --------- --.------ ---- - -- .-- - - - ------------------------------------ --- -- n_--___.-- - - - - -- - - ---- ---- -------- -- ------- --- - --.- --- --- .-- --- (D. -- - n _u -- - -- --- 6000 - _:- --_:__.._--_u_------------~ 6000 ---- -------------------.- ------- - - - --------- ------ -_u_- ----------- - - - - --- - - - - - - - . --.-- -- --- - ...- --- - ---------------- ------ ---- ------------ ------------ ------- --------- 700:1 - 7000 -- - -- -- -- - -- - --- --- - 8000 - 9000 ~O GO 80 NCTL Interoept at GL = 152 Logarlthmio Sllpe = -Ue-15 -ø-152-450ST PPG -G-1~2-';'5ÕST)~G - '- Figure 6 , ) ') ~ lr.~~~ PHilliPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY Box 100360 Alaska 99510-0360 February 12, 2002 RECEIVED FEB 1 ~ 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Alaska Oil & Gas Cons. CommisSion Anchorage Re: Application for Permit to Drill: Surface Location: Target Location: Bottom Hole Location: Pioneer # 1 (Exploratory Test) 525' FSL, 87' FWL, Sec 11, T9N-R2E X=303729, Y=5904414 ASP4 NAD27 600' FSL, 87' FWL, Sec 11, T9N-R2E 600' FSL, 87' FWL, Sec 11, T9N-R2E Dear Commissioner: 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 ,r 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. v The proposed casing progra!)l will utilize a 9 5/8" surface casing string, 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) have been submitted previously. "-.~, ~ ..' ''''\ ~ !' ¡ .'~" ') } 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. 6) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 7) Seismic refraction or reflection analysis as required by 20 AAC 25.061(a). 8) 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 log generation and sample catching are planned. The following are PHILLIP'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 (20 AAC 25.071) Dave Bannan, Geologist 263-4733 / The anticipated spud date for this well is March 19, 2002. If you have any questions or require further information, please contact Tom Brassfield at (907) 265-6377 or Paul Mazzolini at (907) 263-4603 Sincerely, JI1<-l':) - _. ./:11/ Tom Brassfi~~~ Senior Drilling Engineer cc: CONFIDENTIAL - Pioneer #1 Well File Paul Mazzolini ATO-1570 Andy Bond ATO-1310 RECE\VEO fEB 1 ~ 200/ A\asKa 0\\ & GaS cons. comm\ss'on ~"'~ f'i \ i\ ' /._~\ . Î . !.~.~ \ J) ) Phillips Alaska, Inc. P. O. Box 102776 Anchorage, AK 99510-2776 :" . ,,:..;. ',', .: ~: ,'. ,",,", '.':"', '.: . . '. ,'. . .. ,.. ,', .'",'" '.' ;'.:." :: .~,:: ~~ ;:.:~:./:" ':~:: ~ .~': :','-::':., ' " " " "" ':, /:'):>:N~:.::::~R,;Ëi,ò'.)):Òlit~$":::~Ä.lW:::N.6.:'::'(1:~iit$'::' . ,. " '. " ',', .'.'.", ", . , , . , . , , :.:") , . " , :,¡:':ø'.:,f.:~Ø:¡:ill::'~:;:'~:.:.3:'::::::,: .",.,:.;. , . .,' .,' , , ,. . ". P~ÿ.:. , .. .. .$T{I,~~'~O 0 .:. , ,.. . ':~995Q1:~S:~::9' "'.' ToÙièótdéi Óf: : . ...., . , , . . .. .. . . .. " ,.. .. pTATR:C)F~KA ÄOGCC . . ., . ... ...: :33* .~ i :: 7.~t:I, AYE~~:i' :,~ Äl'1q~Q~Ø~,:.. :'" . " , "'" """" ,,' " ,... .,... ~~~,,;*+*~~:*:";*t"'io,d,::oo~ :: Date': :' Amquih . ., ...,,,. ... .... . . ';vÒip:;ift~~ ~Q: 'd~¥r::.: " . ,.. .., .. . . . . '" ,. , .,. . .. ..,. . . . . ,.. ,. ,. .., ., ., .. ,. . .. ", ',' ',' .'. ,. .. '.....',"",',..' ,.', ~.,..:::::.:: .,,::,::.:,:"::... . ,:,i::: ., ",,:':\.::¡:;:::';:':,:,:~:"'::a~;Ji>:~Î~'+r:::,:':; ;.~~;~~2~~t~üt:;1:to~~;j~~ioLÚ~~i;;~i:~~1ë;;i;J!i:¿:~~c....._J:.~:_L._...~:"~~.:._:.~-,.~,:;.::~:..,:,,.;~;.::.::::..,:,. ......_....~~;:::.,._-_.....:_:~:~~:L:Lj¿j,~;~;:.;:;::~.,..__:,~~::~:.._.:_:_~~:>:,.:.._....L::.;::33.,.;.:0':'~_.~_._.::::~;.::~L:\,:'~:~~;L~t~;j~\t~~_;~fft~~~~:;::~:.;t;,j:.::..:,::;.:;.~L:~__- '..' _:;:;-~, III 0 0 0 0 .0 . l. ~ ~ III I: 0 H :Pi 0 L. 2, b 2 I: 09 90000118 \ .. ) ') TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LEITERlPARAGRAPHS TO BE INCLUDED IN ~SMI1TAL LEITER WELL NAME r;~ J I CHECK 1 ST ANDARD LETTER DEVELOPMENT CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-(9) DEVELOPMENT REDRILL PILOT HOLE (PH) , ~ EXPLORATION ~ ANNUL~R D~OSAL ~NO INJECTION WELL ANNULAR DISPOSAL L-J YES INJECTION WELL RED RILL ANNULAR DISPOSAL THIS WELL' "CLUE" The permit is for a new weUbore segment of existing well ~ Permit No, . API No. . '. Production should continue to be reported as a function of the original API number stated above. . In accordance witb 20 AAC 25.005(1), all records, data and logs acquired for' the pilot hole mu'st be clearly differentiated in botb name (nameoD PrE?'" plus PH) , and API number (50 -701. 0) from records, data and logs acquired for wel~ (na, n permit). . Annular disposal bas ~ot been requested... Annular Disposal, of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. '. . ANNULUS <-> YES + SP ACING EXCEPTION <;L1p~v4/ ~~: Enclosed is tbe approved application for permit to drill the above referenced well. The permit is approved ,sùbJect to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to tbe spacing exception that may occur. .ø~J~~.~'~"- ~ ~ "--7k tue-/I ~-I &- /Õ~; ð~ri~ ~) ..A¿>d£-4"/'~!y )1'LLlA.*ð-h / ~ ~ .;4o-n,c.-,,~ </Iv..- b~ tf ~ c.&-Y~d. .~o '-r~. -dJ. Templates are located m drive\jody\templates /"'7 WELL PERMIT CHECKLIST COMPANY fL.-I/.;$ WELL NAME (:¡'71.e.Ly / FIELD & POOL ,() 11 TNIT CLASS E ,X'P ( ( tJ / ~ I::>LA=" \ ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . ~N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . N 3. Unique well name and number. .. . , . . . . . , . . . . , . . if 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . N 5. Well located proper distance from drilling unit boundary. . . ." . 6. Well located proper distance from other wells.. . . . . . . . . N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . N rJ"/ .;; / 8. If deviated, is wellbore plat included.. . , , . , . . . . . , ., M V L1 -h L~~ i-LK./í "r /íÆ.il-ý '7; -r N ') :r, tu-è//.. 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . þ DATE 12. Permit can be issued without administrative approval.. , . . . . 3. /. 02-13. Can permit be approved before 15-day wait.. . . . . . . . . . ENGINEERING 14. Conductor string provided. .' . . . . . . . . . . . . . . . . . ~ N <)Þ-;t@Ii'5'.TVD t:" ." "!J / /~ _I /~ . / '. ¡l 15. SUrfacecasingpro.tect, sallknownUSDWs. . . . . . . . . . . . N f/~:~~ iA~ "'""5t- ~ tV1 I' r¡;,")ý<-C.- ~V 7~~""f7.~ 16. CMT vol adequate to circulate on conductor & surf csg. . . . . N {/ Li. :7 Dw ;, . ~ (/ 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y .~ " 18. CMT will cover all known productive horizons. . . . . . . . . . æ N 19. Casing designs adequate for C, T, B & permafrost. . . . . . . ¡<j) N 20. Adequate tankage or reserve pit.. . .. . . . . . . . . . . . . ~ N D" vyov'- l't \ 21. If a re-drill, has a 10-403 for abandonment been approved. . . -¥-N- tJlA 22. Adequate wellbore separation proposed.. . . . . . . . . . . . .¥--tV" J.11A. 23. If diverter required, does it meet regulations. . . . . . . . . . IN 24~ Drilling fluid program schematic & equip list adequate. . . . . N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . . N 1-- L . AP~R P~TE 26. Bo.PE pres~ rating ap~ropriate; test to 5000 psig. N ,,/llvt e,.t.;1 'fe<; l ~ )C.?OO r ~ (. MSP= '5 ¡ 27 f ç;,. 'JZù1.. ßof £ þ<;t =. SODD ~~. \.LLúlr 3/~IOt. 27. Choke mamfold complies w/API RP-53 (May 84). . . . . . . . N It.), h/J ~I 28. Work will occur without operation shutdown. . . . . . . . . . .@N I:J¥." ((~'O~ 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y ~ GEOLOGY 30. Permit can be issuedw/o hydrogen sulfide measures. . . . . ~.. N ~ . lul) /. () ~.( ~¡( ~)v14Y. "_H' æ / 31. Da~a ~resented. on potential overpressure zones. . . . . . ,"" ,~..L-*~'::'- - /) ~ ~~. .,.,... t?¿7 $£-. e. ....~c.:.. t.... 'f"Ýci .' 32. Seismic analysIs of shallow gas zones. . . . . . . . . . . . . Y Â'6?1.L- ¿)b~ ~ " AP~:ß.' DATE. 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . AH1 ..' ":- N .. /) . / . /.l) - ~ . I- 02- 34. Contact name/phone for weekly progress reports [exploratory onlylC[Æ .--:-; ~ p-r~~-e,t/ uS; - "'-?77 ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . .' . . . . . Y N '1 ' -I. . I {-) j,. -/-. APPR DATE (B) will not contaminate freshwater; or cause drilling waste. .. Y N 1L0 tiA.-\.Vl., IA. (c/¡v (Vt S I'J...£J<;4.- ( V'P (-I., {J.l' ç {..( d tt.- "(ú( <; {..{ h-1...f , to surface; 1/ (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: ==?#- :~"t ~ ~~; 63)Ò? 10 <- JMH ~1 If- ~7JC2- PROGRAM: EXP/Dev - Redrll - Serv - Wellbore seg - Ann. disposal para req - GEOL AREA 5?7' /) UNIT# ;<//1- ON/OFF SHORE ()~ €t<rr t"-?-í ~; 'J tlu<J/ ( ( Comments/Instructions: AtJ6' ~S~~ A~-¿~ .. . , ) tG~CtE.&/. A.JGU/'OG>v S(,~/L .¡-<CfJUi'~ ~t-n- C'()~'VC.4-,," XJ-/'-t:J-é ~"J T, ..-Æ~......(,/ () . G:\geology\templates\checklist.doc