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Home My WebLink About196-143 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. ~'~'~ - I ~..~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy Dianna Vince~Lowell Date: ~si TO RE-SCAN Notes: Re-Scanned by: Bevedy(~)Vincent Nathan Lowell Date: ~ ~f~ /s/ ~ THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03,2001 M P L ATE IA L U W N D E R TH IS M ARK E R C:LORIXMFILM.DOC Memorandum To: State of Alaska Re: Oil and Gas Conservation Commission DATE Cancelled or Expffed Permit Action EXAMPLE' Point McIntyre P2-36AXX API# 029-22801-95 This memo will remain at the from of the subject well fie. 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 i' the treatment of these kinds of applications for permit to ddil. Operators have asked us to adopt formal procedures for this class of permit application in order to prevent future database disparities. If a permit expires or is cancelled by an operator, the permit number of the subject permit will remair. unchanged. The APl number and in some instances the well name reflect the number of preexistin.( redfiils and or muitilaterais 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 ddll. The AP! number for this cancelled or expired permit is modified so the eleven and twelfth digits is 9E The well name for a cancelled or expired permit is modified with an appended xx. These procedures are an addendum to the AP! numbering methods descnbed in AOGCC staff memorandum "Multi-lateral (wetibore segment) Drilling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician TONY KNOWLE$, GOVERNOR August 28, 1996 ALASKA OIL AND GAS CONSERVATION COM~IISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Steve Shultz, SDE ARCO Alaska Inc P O Box 196612 _.Anchorage, AK 99519-6612 Well # Company Permit # Surf Loc Btmhole Loc Point Mclntyre P 1-10 ARCO Alaska, Inc. 96-143 1433~SL, 767'WEL, Sec 16, T12N, R14E, LqVI 2932WSL, 856'WEL, Sec 10, T12N, R14E, UM Dear Mr Shultz: Enclosed is the approved application for permit to drill the above referenced ~vell. 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. Your requested waiver of the diverter system described in 20 AAC 25.035 (7)(b) for this well is approved. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a 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, Commissioner BY ORDER OF THE COMMISSION dlf/encl c: Dept ofFish & Game, Habitat Section- w/o encl Dept of Environmental Conservation- w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan RTE = 42.8' Point Mclntyre 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 034622 4. Location of well at surface i7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1433' NSL, 767' WEL, SEC. 16, T12N, R14E Point Mclntyre At top of productive interval i8. Well'Number Number U-630610 2601' NSL, 1119' WEL, SEC. 10, T12N, R14E P1-10 Attotal depth 9. Approximate spud date Amount $200,000.00 2932' NSL, 856' WEL, SEC. 10, T12N, R14E 08/30/96 :i'J~. Distance Jo nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL365548, 856'I P1-11, 14.57' @ surface 2560 12873' MD / 9177' TVD i18. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 300' Maximum Hole Angle 49° Maximum surface 3466 psig, At total depth (TVD) 8843' / 4350 psig i18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 133# H-40 Weld 115' Surface Surface 115' 115' 260 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 40# L-80 BTC 4396' 41' 41' 4439' 3628' :1415 sx CS III, 430 sx'G', 250 sx CS II 8-1/2" 7" 26# L-80 BTCM 11961' 41' 41' 12002' 8605' 232 sx Class 'G' 8-1/2" 7" 29# 13CR80 NSCC 871' 12002' 8605' 12873' 9178' ,,. ........ 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs(measured) ORIGINAL true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner AUG 1 6 1996 Alaska 011 & Gas Cons, Commission Perforation depth' measured Anchorage true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Jim Smith, 564-5026 Prepared By Name/Number'. Kathy Campoamor, 564-5122 Signed SteveShultz Title Senior Drilling Engineer Date ''~O~mmission Use Only Permit Number APl Number Approval Date I See cover letter ~-//~-~ 50- ~;~ ~-- ~ -' ~ ~ ~'~ ~' ~ 'q~ -c'~'-g''O) ~I for other requirements Conditions of Approval: Samples Required [] Yes ~;~ No Mud Log Required [] Yes /~ No Hydrogen Sulfide Measures J:~rYes [] No Directional Survey Required ~Yes [] No Required Working Pressure for BOPE [] 2M; []3M; ~ 5M; [] 10M; [] 15M Other: Original Signed By by order of ,Approved By T!,',l,,nrmnn Form 10-401 Rev. 12-01-85 Submit In Triplicate BP EXPLORAI'iON To: B. Wondzell Date: August 14, 1996 From: J. Smith Subject: Dispensation for 20 AAC 25.035 (7)(b) on PI-10 Well Shared Services Drilling requests your consideration of a waiver of the diverter system identified in 20 AAC 25.035 (7)(b) "Secondary Well Control: Blowout Prevention Equipment (BOPE) Requirements" based upon historical drilling experience on Point Mclntyre 1. There have been 19 wells drilled on Point Mclntyre 1, none of these wells experienced any difficulty with shallow gas in the interval prior to placement of surface casing. Within the last month, two additional wells (P1~23 and P1-06) have drilled through the shallow intervals without any indications of shallow gas. In light of the historical evidence indicating minimal risk due to shallow gas at this location, we conclude that the Pi-10 well on the same pad can be safely drilled without the installation of the diverter system. Sincerely, James E. Smith SSD Engineer ] Well Name: ] P1-10 Well Plan Summary I Type of Well (producer or injector): I Producer Surface Location: 1433' FSL, 767' FEL, Sec. 16, T12N, R14E UM Target Location: 2601' FSL, 1119' FEL Sec. 10, T12N, R14E UM Bottom Hole Location: 2932' FSL, 856' FEL, Sec. 10, T12N, R14E UM AFE Number: [ 2C0099 I Estimated Start Date: 18/30/96 I Rig: ] Doyon #14 Operating days to complete: ] 18 IMD: I 12873' I I TVD: 19177'rkb I IKBE: 142.8, Well Design (conventional, slimhole, etc.): [ Ultraslirnhole Longstring I Objective: [ Kupamk Sand Formation Markers: Formation Tops MD TVD(BKB) Base Permafrost 1947 1853 SV4 4424 3618 9-5/8" casing 4439 3628 Set 9-5/8" casing 10'TVD into SV4 K-15 6513 4993 Lower Ugnu 8352 6203 West Sak 9294 6823 9.5 ppg minimum mud weight required K-10 11892 8533 K-5 11968 8583 HRZ 12082 8658 Kalubik 12241 8763 Kupamk 12302 8803 10.0 ppg minimum mud weight required WOC 12773 9112 TD 12873 9177 100'MD below WOC Evaluation Program: SURFACE MWD directional only PRODUCTION MWD directional first bit in 8-1/2". After first bit: MWD directional with GR-RES-DEN-NEUT to TD CASED HOLE None LOGS Well Plan Summary Page 1 Mud Program: ISpecial design considerations lAn open hole displacement to +/- 10 ppg Flovis polymer/3% KC1 water based mud will be performed above the reservoir at the HRZ Surface Mud Properties: [ SPUD DENSITY Marsh Yield Point 10 Sec Gel 10 min Gel pH Fluid Loss (PPG) Viscosity 8.7 300 40-60 30-60 60-80 9-10 15-25 9.5 150 30-40 20-30 40-60 9-10 < 15 Production Mud Properties: I LSND in upper hole to the HRZ DENSITY Plastic Yield Point 10 Sec Gel 10 rain Gel pH Fluid Loss (PPG) Viscosity 9.2 8-15 20-30 5-15 <30 9-9.5 6-12 10.1 8-15 20-30 5-15 <30 9-9.5 6-12 Production Mud Properties: I 3% KCL from HRZ thru Kupamk DENSITY Plastic Yield Point 10 Sec Gel 10 rain Gel pH Fluid Loss (PPG) Viscosity 10.1 8-15 25-30 12-15 <30 9-9.5 4-6 HTHP<15 Directional: I KOP: 1 300' MD Maximum Hole Angle: Close Approach Well: 49° @ azimuth = 38.5° Four wells:P1-06, P1-07(08), P1-08, PI-16 will remain shut in until the P 1-10 has run surface casing. There are no deep close approaches Casing/Tubing Program: Hole Size Cs#/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MDfrVD MD/TVD 30" 20" 133# H-40 WLD 115' GL 115/115 12-1/4" 9 5/8" 40.0# L-80 BTC 4396' 41'/41' 4439'/3628' 8 1/2" 7" 26.0# L-80 BTCM 11961' 41'/41' 12002'/8605' 7" 29.0# 13CR80 NSCC 871' 12002'/8605' 12873'/9178' TBG 4.5" 12.6# 13CR80 NSCT 12161' 41'/41' 12202'/8737' Well Plan Summary Page 2 Cement Data: Casing/Liner Lead: Sxs/Wt/Yield Tail: Sxs/Wt/Yield 9-5/8" shoe at 4439'MD 11 shoe at 12873'MD 1415/12.2/1.92 **250% excess lead in perma, 30% excess to top of tail none 430/15.8/1.15 **30% excess tail & plan 750'TVD fillup which is 1143'MD 232/15.8/1.14 Top Out Job (if necessary) 250/14.95/0.96 Comments Cold Set III & Class "O TOC- 11302' +/- (1000'MD above Kuparuk) Top Out--CSII Name Contacts Office Home Pager James E. Smith Adrian Clark Drilling Eng. Drilling Supt. 564-5026 345-8660 564-4720 275-4015 Drilling Hazards/Risks The original reservoir pressure is 4350 psi at 8800' ss. The expected reservoir pressure is 4200 psi at 8800' ss. Abnormally pressured formations are not expected in this well. Tight hole has been experienced in the lower Sagavanirktok, below the surface casing shoe. This has caused stuck pipe incidents and bit/BHA balling Gumbo problems. ReP's in this section are typically very fast and care must be taken to ensure the hole does not become overloaded with cuttings. Well Control: Well control equipment consistin0 of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handlin0 maximum potential surfaco pressures. A request for dispensation of the diverter requirement is requested for this well. Diverter, BOPE and mud fluid system schematics on file with AOGCC. Well Plan Summary Page 3 o o . ° o 7. 8. 9. 10. PI-lO Operations Summary MIRU drilling rig. NU riser and flowline. Spud well and drill 12-1/4" hole to 300' md. Kick off and build angle to 49° on 36.5° azimuth by 3232'MD. Hold angle and azimuth to 4439' MD surface hole TD (3628'TVD). Set 9-5/8" casing and cement same to surface. Test casing to 3000 psi for 30 minutes. Nipple up BOP's and test same to 5000 psi. Note AOGCC witness or waiver on the morning report. PFU 8 1/2" BHA, drill 20' new hole and perform LOT. Drill ahead and hold 49° to 12873' MD (TD). Displace mud to 10 ppg 3% KC1 before top of Kuparuk. If LWD logs were not obtained while drilling the 8-1/2" hole, run wireline open hole logs. Make a cleanout run if the hole is tight. POOH and lay down drill pipe. Run 7" L-80 and 13 chrome casing and cement same, displacing with seawater. Test casing to 3500 psi for 30 minutes. Run 4-1/2" chrome tubing and completion assembly. ND BOP and NU tree assembly. Test tree assembly to 5000 psi. Displace tubing to diesel, freeze protect the annulus. Set packer, test tubing. Test annulus. Secure well, release rig. Well Plan Summary Page 4 ;618 ~000 ~500 203 ,500 883 '1300 VERTICAL VIEW SCALE 500 ¢t;. / DIVISION TVD REF: VELLHEAD VERTICAL §ECTION REF: WELLHEAD 577 0,00 e 0 MD TIE IN 0.00 ~ 800 MO KOP / :;TART OF BUILD ~'.88 ~ ~BB ~ START OF CraVE ~ &O0/lO0 6.02 ~ 700 MD 9,00 ~ 860 MD 2TART OF BUILD B 2,50/t00 14.00 B ~060 MD ~g. O0 e 1260 MD ~4.oo e ~4~o ~ 36,26 ~ ~376 MD 39,54 ~ a576 MD 4a,35 e Z776 H~ 45, i9 e 2976 MD ~~ EN5 [( CURVE 1 8169 3688 TVD ]~PX- ShoPed Semvlces ]3miLtlng / .................. % ALcskc Store PLcne: Zone4 WELLPLAN FEASIBILITY STUDY / ' \ ~--,-~/----~2:::::::~ ================================== Pt Hoc : PM 1 Th,splan is for feasibility purposes only ' ,." "/ ) HALL]BURTON it has not yet been certified] '~ i ,(: ~ ,' ...... : !..., .,' it P 1 - 10 As-BulL~ '"x ................... ./' P 1 - 10 Wp3 Est HORIZONTAL VIEW (TRUE NORTH) SCALE 500 f't, / DIVISION 8/14/96 6:'01 pm SURVEY REP WELLHEAD CRITICAL PO]NT DATA MD Inc Azh TVD N/S TIE IN 0 0.00 O,DO 0 0 N 0 E KOP / ST/~RT 800 0,00 0,00 200 0 N 0 E DF BUILD 8 1,00/ 1 O0 F~ START OF 500 3,00 0,00 500 8 N 0 E CURVE 8 8DO/tOO Pt START OF BUILD 860 9,00 45,00 ~ 37 N 80 E 8 2.50/100 ¢± END OF 3UILD 1860 34,00 45.00 1781 294 N 877 E Base 1947 34,00 45,00 1853 389 N 311 E START DF 8176 34,00 45.00 8043 419 N 408 E CL~VE ~ 1,50/100 Pt END OF QJRVE 3838 48,84 36,47 ~ 951 N 850 E SV4 4484 48,84 36,47 3618 1673 N1384 E UG4A (K-15) 6513 48,84 36.47 4993 8938 N8318 E Lower* UGNU 835P 48,84 36.47 68613 4051 N3141 E W, 2ck 9894 48,84 36,47 6883 4681 N3563 E K-10 11898 48,84 36,47 8533 6194 N4786 E K-5 / 11968 48.84 36.47 8582 6~40 N4760 E T, FRZ 18082 48,84 36.47 8&58 6.309 N 4811 E Katub;k ~8241 48,84 3G.47 8Z63 6406 N4888 E START OF ~8851 48,84 36,47 8769 6411 N4886 E CLRVE 8 8.50/1 O0 Pt T, Kupscuk 18302 48,97 38,16 8803 6448 N 4910 E Tar_qet 1 18313 49,00 38.51 8810 6448 N 4915 E (18/-21/95) ~ 18773 49,00 38.51 9118 6780 N 5131 E 3748 48,84 8 6513 MD UG4A (K-15) CASING PO]NT DATA OD MD Inc Az; TVD N/S g 5/8 In 4439 48,84 36.47 3688 1688 N 1390 E 7 in 1L::~7'3 49,00 :38,51 9177 6779 N 5178 E lID I)epth(¢t) Toot Code PI-IO Wp3 0-12873 20,03 BPHN-PBD 5186 48,84 ~ 8358 MD Lowe¢ UGNU 5835 48,84 8 9894 MD V, Sak ITc~,qet Na~e TVD NS EW E~id X E~id Y Tcrget 1 (1~1/95> 8810 6448 N 4915 E 6Z~050 6001185 -- - /%. /%. : I~.&~- I I I t I I I I I I 500 0 500 1500 8000 8500 3000 3500 4000 4500 5000 5500 6000 6500 5O0 -50O '~%x~4~1 ~i~ I¢4ZID~ t 77 TVD 0 500 1000 15(](] P000 PSO0 3000 3503 4000 4500 5000 5500 6000 6500 7C)00 7500 8000 8500 go00 9500 Ft TVD g177.41 MD ~8873.23 VS 8530.65 N/S 6779.4~ N E/~ 5177,98 E Date Rotted C~eated By Checked By Approved By Date VERTICAL SECTIEN PLAN5 37,37 · WELL PERMIT CHECKLIST COMPANY ~r~ LL NAMEK/~-~,,v'.~. -/~ PROGRAM: exp [] dev.~/redrl, [] serv [] wellbore seg [-lann. disposal para req [] ADMINISTRATION 1. Permit fee attached ....................... ~.Y I~N 2. Lease numberappropriate. .................. I.yY./N 3. Unique well name and number ................. N 4. Well located in a defined pool ................. { Y I N 5. Well located proper distance from drlg unit boundary ..... I'YI N 6. Well located proper distance from otherwells ......... I._Y__ I N 7. Sufficient acreage available in drilling unit .......... t .Y.. [ N 9. Operator only affected party..!yyy~~ N 10. Operator has appropriate bond in force. N 11. Permit can be issued without conservation order N 12. Permit can be issued without administrafve approval. · · l N 13. Can permit be approved before 15-day wait ..... ; . . tN REMARKS ENGINEERING GEOLOGY 14. Conductor string provided .................. 15. Surface casing protects all known USDWs ......... 16. CMT vol adequate to circulate on conductor & surf csg 17. CMT vol adequate to fie-in long sl~ing to surf csg ....... 18. CMT will cover all known productive hodzons ......... 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 abndnmnt been approved 22. Adequate wellbore separafon proposed ............ 23. If diverter required, is it adequate ................ 24. Ddlling fluid program schemafc & equip list adequate 25. BOPEs adequate ........................ · 26. BOPE press rating adequate; test to ~'~o"~ 27 ...................... ~. .............. -.,,, ~ .... ~ ,.,-,~ ......... 29. ~s presence of H2S gas probable ............... :31. Da~ presented on potenUal overpressure zones ....... :32. Seismic analysis of shallow gas zones ............. ~k~. ~ condi~on survey (i! off-shore) ........... ~.. Conl:aet nam~phone for weekly pro, ross reper~ .... r~~ only] GEOLOGY: ENGINEERING: COMMISSION: S EW~ ,9,~'Z3, DWJ JDH ._~d" JDN TAB Comments/Instructions: HOW/lib - A,'~FOR~ist rev 4~J6