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Home My WebLink About197-082Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organization (~one) RESCAN D Color items: DIGITAL DATA, OVERSIZED (Scannable) [] Diskettes No. .[3 Maps: [] Orayscale items: Poor Quality Originals: [] Other: [] Other. No/Type [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds TOTAL PAGES: ORGANIZED BY~ NOTES: BEVERLY BRE~SHERYL MARIA LOWELL Other By: Date: PAGES:~ (at the time of scanning) SCANNED BY: BEVERLY BR~~SHERYL' MARIA LOWELL DATE: ReScanned (done) RESCANNEDBY~ BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ General Notes or Comments about this file: Quality Checked (done) Rev1 NOTSc~nned.~¢~cl ~KA OIL AND GAS CONSERVATION CO~IlSSION TONY KNOWLE$, GOVERNOR 333 W. 7~ AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 September 6, 2001 Fritz Gunkel, Manager Drilling BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519 Re: Cancelled or Expired PTD's. Dear Gunkel: The Alaska Oil and Gas Conservation Commission ("AOGCC") approved the following referenced permit to drills. The AOGCC has a long-standing policy of releasing cancelled or expired permits two years from the date the application was approved by the AOGCC. The following files are scheduled to be released October 1, 2001. Permit to Drill No.'s: 97-047 98-019 99-002 97-056 98-050 99-009 97-082 98-135 97-090 98-154 97-100 98-155 97-121 98-164 97-159 98-167 97-191 98-177 98-210 98-211 98-223 98-236 98-257 98-261 Sincerely, Memorandum State of Alaska Oil ~md Gas Conservation Co~ To: Well File: · ~ q - C~~ DATE Cancelled or Expired Permit Action EXAM2PLE' Point McIntyre P2-36AXX API# 029-22801-95 3l, tqq' 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 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 preexistinl redfiils and or muitilaterals in a well. In order to prevent confusing a cancelled or expired permit an active well or multilateral these case sensitive well identifiers will be changed for expired and cancelled applications for permits to drill. The APl number for this cancelled or expired permit is modified so the eleven and twelfth digits is 9~. 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 described in AOGCC staff memoranaum "Multi-lateral (wetlbore segment) Ddiling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician ~ALASKA~ ..eared rvices rilling BP Exploration / Arco To: Alaska Oil & Gas Conservation Commission Date: September 12, 1997 From: Subject: Terrie Hubble Technical Assistant Permit To Drill ~/97-81 & 97-82, M-05A & M-05AL1 Due to problems encountered while drilling the initial lower lateral, the upper multilateral was not drilled (97'82). We are requesting at this time that you cancel this Permit to Drill. As you will notice however, both targets of this well plan were obtained from the M-05A well bore (97-81). Please let me know if there is any further action required. Thank you for your assistance and patience in this matter. /tlh 6/1 8/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11097 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape --_ B-02A LEAK DETECTION LOG 970527 I 1 __ D-1 EZSV SET RECORD 970521 1 1 -- D-06 TUBING PUNCH RECORD 970528 I 1 . D-6 TUBING CUFFER RECORD 970531 I 1 D-14 ORIENTATED WHIPSTOCK 97051 6 I 1 G-03 TUBING PUNCH RECORD 970529 I 1 M-05 JET CU'I-rER RECORD 970507 I 1 M-5 BACKOFF RECORD 970521 I 1 M-5A/L1 PERFORATION & BACKOFF RECORD 970523 1 1 M-11 TUBING PATCH RECORD 97051 8 I 1 M-11 TUBING PATCH RECORD 97051 9 1 1 -- M-11 GAS LIFT SURVEY 970525 1 1 N- 1 ' PRODUCTION PROFILE 970526 I 1 R- 12 COMPLETION RECORD 970525 1 1 -- W-16 PRODUCTION LOG 97051 7 I 1 W-16 PRODUCTION LOG 97051 8 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED JUN ] 9 '~997 0il & Gas Cons. Ar~ch0ra§e Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received b~-"--"--~ MEMORANDUM TO: ~/~Alaska David Johnstoj~ Chairman THRU: State of Alaska Oil and Gas Conservation Commission DATE: May 22, 1997 Blair Wondzetl, P. I. Supervisor Petroleum inslSectot' FILE NO: AIMIEVEE.doc BOPE Test - Nabors 2ES BPX - PBU - M-05a I1 PTD # 97-0082 Thursday, May 22,1997: i traveled this date to BPX's PBU well M-.05A !1 and witnessed the weekly BOPE test. As the attached AOGCC BOPE Test Report shows the test went welt and there were no failures. The location and rig was clean and all equipment seemed to be in good working order. Summary: ! witnessed the weekly BOPE test on Nabors rig 2ES drilling BPX's PBU well M-05A I1. Nabors 2ES - 5122/97 - test time 2.5 hours - no failures Attachment: AIMIE'V-~..X-~ X Unclassified -.-. .~;.-,i .-,.4.' i i i.-.~-.,i,-.,-.,,-;-- ' Cun~tue~ tdat ~ Ut t~t===ttleQ if doc. removed STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drig: X Drlg Contractor: Operator: Well Name: Casing Size: g. 625" Test: Initial Workover: NABORS Rig No. 2ES PTD# 97-0082 BPX Rep.: M..O5A L1 Rig Rep.: Set @ 9962' PBD Location: Sec. · 1 ~ T. Weekly X Other DATE: 5/'22~7 Rig Ph.# 659-4836 BUTCH McMANIS CHARLIE HENLEY 11N R. 12E Meridian Um. , ,,, , MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) ,, PTD On Location YES Standing Order Posted" YES Well Sign OK Drl. Rig OK Hazard Sec. YiSS FLOOR SAFETY VALVES: Quan. Upper Kelly / IBOP I I Lower Kelly / IBOP .. 1. I Ball Type f . Inside BOP I Test Pressure P/F BOP STACK: Annular Preventer 1 Pipe Rams 1 , ,, Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves 2 Kill Line Valves . , Check Valve Quan. Test Press. 300/3,000 "50o/5,000 '500/5,000 500/5,000 500/'3,000 N/A CHOKE MANIFOLD: No. Valves 14 ~ No. Flanges 32 1 Manual Chokes . ~_~ . Hydraulic Chokes I Test Pressure 500/5,000 Functioned F:uncUoned P/F P P , P P ACCUMULATOR SYSTEM: System Pressure 3,000 ~ P ' Pressure After Closure f,600 [ . ..P '..'. ' MUD SYSTEM: V"~uai Alarm 200 psi Attained After Closure 0 minutes 30 Trip Tank YES YES System Pressure Attained ~" minutes 39 Pit Level Indicators YES YES Blind Switch Covers: Master: YES Remote: Flow Indicator YES YES Nitgn. Btl's: 4 ~2 f00 Meth Gas Detector YES YES · Ps~g. H2S Gas Detector YES YES · , , YES Number of Failures: 0 ,Test Time: ( 2.5'; Hours. Number of valves tested 22 Repair or Replacement of Failed IEquipment w~! be made .with. i"~. , , 0, ,, ~ Notify the Inspector and follow wi.:th ~.~en or Faxed verification to ~r-r', ;~;,-, r~ o .~ - c~ ~ - ~,, ~ "' ~o 5a 3607 or 3687 lthe A,. ~,... ~,omm,.~,un .,fflc....t. , ,.x, .Jo. 276-7542 lnspecto .... rth Slope P,g ..... 6 ,,- h you, ca,i ,~ n,,t ,eturned ,,~ tl,e ,,,opector ,,;,,,m ,,. hou,s ~,,o,~se ,,,,,,[a~ ~h~ P. ,. Supe,,,.~or ,~, ,., 9-,43,, I I I I I I I REMARKS: Distribution: orig-We!! File c - ~pe, .~ c - Database c - Tdp Rpt File c - Inspector ! STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES. X~ NO Waived By: Witnessed By: BOBBY D. FOSTER FI-021L fRev. 12_./94) AIMtEVEE.XLS RIG 2ES ID'bb94~JK MHY l~'~F r.u~ ~ '1 Alaska Oil and Oas Cc>nscrvation Comnfission Anchorage, Alaska May 13, 1997 12:'.3t) NO .U1D Altn: Mr. Blair Wondzell Fax: 1-907-276-7542 ]'r: 'J'om Mnu_llde, r--- ~y Representative Nabors 2 Re: Te,~ting above abandonment plug---M-5 A L I Dear Mr. Wondzell: As requested on the Permit to Drill for tt}e subject well, a pressure test of the abandonment plug and the casing string was conducted. Mr. Doug Amos was contacted for witness, but was not able to be waived the witness rcquircmenL The production casing was cleaned out with a bit. and ~craper to 10200' md, The casing slid abafldonmotlt plug wcrc pressure tcstcd to 2500 psi for 30 minutcs. A copy of thc pressure cha~l, is incl~lded for your recto'ds. Pica.sc contact mc at thc rig (659-4835) or Dr. Winlcm Aubert at BP (564-4825) if fl~rther illformation is needed. ACas~a Off & Gas Cons. Commiss, Ancfl0ra o RIG 2ES 1 .... - ...... 301~, MHY i$'WF 12'OF MO.UI~ K.UZ ,, TONY KNOWLE$, GOVEFtNOFt ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 May 7, 1997 Paul K. Prince Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit M-05ALI BP Exploration (Alaska) Inc. Permit No. 97-82 Sur. Loc. 3078'SNL, 605'WEL, Sec. 01, T11N, R12E, UM Btmnhole Loc. 3426'NSL, 4067'WEL, Sec. 1 !, T11N, R12E, UM Dear Mr. Prince: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill 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. The permit is for a new segment from existing well M-05A Permit No. 97-81, API 50-029- 20194-01. Production should continue to be reported as a function of the original well identifier. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chair~~ ~) ~ BY ORDER COMMISSION dlffEnclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ..... ALASI',J-, OIL AND GAS CONSERVATION CO,,,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepenl [] Service [] Development Gas I--ISingle Zone 1-1Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 61.1' Prudhoe Bay Field / Prudhoe 5. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028260 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3078' SNL, 605' WEL, SEC. 01, T11N, R12E, UPM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 2175' NSL, 4928' WEL, SEC. 12, T11N, R12E, UPM M-05AL1 At total depth 9~ ApprOximate Spud date Amount $200,000.00 3426' NSL, 4067' WEL, SEC. 11, T11N, R12E, UPM 05/09/97 ~'2.Distan~e to ne~est PropertY lin~113' Distance ~o nearest Well' 14: NUmb~ Of acres in p~Opert'y i5. PrOposed depth (MD an~ TVD) ADL 028,,261, 12.,1,.3' ,,, ] ....... No,, ,,Close,,,A,,,pproac,,,h' ........................... 2560 ........ !,7105',,,,MD/,8825' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AA~'25.035 (e) (2)} Kick Off Depth 10000' Maximum Hole Angle 92° Maximum surface ~3300 psig, At total depth (TVD) 8800' _/43--90 psig 18. Casing Program Setting Depth Size Specifications ~,.Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 29# L-80 BTC-Mod 2858' 9850' 7460' 12708' 8911' 235 sx Class 'G' 6" 4-1/2" 12.~# 'i~'-80 ' STL 4870' 12235; .... 8765' 'i"~'105;" 888'0' Un'Cemented Slottecl Line'i . , 19. To be completed for Redrill, Re-entry, and Deepen Operations. ,:,,,~ ~.. ~ · ~ ,: ~,'.~ :~ ! ~:" ;i'" ~; !i '! '~'i~ ~ "il Present well condition summary Total depth: measured 12702 feet Plugs (measured) i, ':;'."¢' i i !!:-~!'ji' true vertical 9145 feet Effective depth: measured 12629 feet Junk (measured) fill at 12629' MD (02/89) Casing Length Size Cemented MD TVD Structural Conductor 107' 20" 150 cu ft 135' 135' Surface 2667' 13-3/8" 5140 cu ft 2695' 2695' Intermediate 11636' 10-3/4" x 9-5/8" 2722 CU ft 11664' 8420' Production Liner 1545' 7" 1140 cu ft 11145' - 12690' 8298' - 9136' Perforation depth: measured 12207'- 12234', 12361'- 12379', 12392'- 12482'0[ I61N^L true vertical subsea 8713' - 8922' {three intervals) 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid ~ro~ram []Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 ,~C 25.050 Requirements ContactEngineerName/Number: Win/n)Aubert, 564~25 PreparedByName/Number: TerrieHubble, 564-4628 ....... 21.1 hereby certify that the f~go~n~iy~tCJCand correct to the best of my knowledge Paul K. Prince ~"'~'~ ~ ~ ~ Title Senior Dr,i!,!ing En~lineer ........ Date ..... Commission Use Only ............................................. , , ...., ............... Permit Number I ~PI Number ! ~r'o~ Da.t~_ '.. [ s~C0Ve~letter ¢,~- 4~'~. 50-029-20194-60 I ........ ~..'-..//..%~ I f°~..~the[.requirements Conditions of Approval: Samples Required E]Yes J~ No Mud Log Required []Yes ~No Hydrogen Sulfide Measures ~Yes [] No Directional Survey Required J~Yes [] No Required Working Pressure for DOPE E]2M; r-13M; I~5M; 1-110M; I-I 15M Other: Original ~': .... ~ ;::)i~ji,~',:d ~y by order of Dat~--' ~'-~ ,...Approved By David W. Johnston Commissioner the commission7 Form 10-401 Rev. 12-01-85 Submit In Triplicate ]Well Name: IM-5A / M-5AL1 I HAW Multilateral Sidetrack Summary Type of Well (producer or injector): ]Producer- I Surface Location: ] 3078' FNL, 605' FEL, S01, T11N, R12E, UM Sag River: M-5A (lst Lateral) Start M-5A (Lat 1): 3739' FSL, 3908' FEL, S 12, T11N, R12E, UM BI-IL M-5A: 3426' FSL, 4067' FEL, Sll, TllN, R12E, UM Ivishak - Zone 4:M-5AL1 (2nd Lateral) Start M-5AL1 (Lat 2): 12175' FSL, 4928' FEL, S12, TllN, R12E, UM BHL M-5ALI: 1 3426' FSL, 4067' FEL, S 11, T1 IN, R12E, UM I AFE Number: 14PO919.o I I Estimated Start Date: ] 5/9/97 MD Lateral 1: 17,130' MD Lateral 2: 17,105' I Rig: [Nabors 2ES I Operating days to complete: 144 TVD- Lat 1: 8,925' ss TVD - Lat 2: 8,825' ss [Well Design (conventional, slimhole, etc.) I K~ Elev-]61-1' I HAW Multilateral Sidetrack Objective: M-05 is located in the southwestern peripheral area of the NWFB. It was drilled in 1976 and put on production in 1985. Since 1991, the well has been shut in for high WC and TGOR. The replace- ment well M-05A is planned as a high angle multilateral sidetrack targeting Ivishak and Sag River reserves. A long high angle section of 2000' is planned for the Ivishak with 1500' planned for the Sag R. Long sections will maximize production and reserves for the predicted Iow productivity, thin NLOC and large area of the reservoirs. M-05A is expected to drain 210 acres with OIP of 9 MMSTB for both Ivishak and Sag R. Formation Markers Formation Tops Sag River Shublik MD Lateral I 12,235' MD Lateral 2 12,235' TVD (ss) 8710' 12,315' 13,821' 8750' TSAD 12,510' 17,105' 8825' TD Laterals 17,130' 17,105' 8925', 8825' Cement Calculations Lead Cement Tail Cement Casing/Liner Sk / Wt / Yield Sk / Wt / Yield Comments CI G; Tail FW=0; 7" N/A 235 / 15.8 / 1.14 30% excess; Pump time=4+ hr.; TOC = +_11,200' MD (+_1,000' above Sag River) 4-1/2" N/A 450 / 15.7 / 1.19 Class G: 30% excess; Pump time = 4 hr.; TOC 150' above TOL 4-1/2" N/A N/A Slotted liner Volume assumptions: Gauge hole + designated excess; 80' shoe joints; TOC as designated. Casing/Tubing Program Hole Tubular WtJFt Grade Corm Length Top Btm Size O.D. MD/TVD MD/TVD Pilot 8-1/2" 7" 29# L-80 BTC-Mod 2858' 9850'/7460' 12708'/8911' M-SA (Lat 1) 6" I 4-1/2" 12.6# L-80 IBT-Mod 4572' 12558'/8889' 17130'/8980' M-5AL1 (Lat 2) 6" I 4-1/2" 12.6# L-80 STL 4870' 12235'/8765' 17105'/8880' I (slotted) Prod Tubing N/A I 4-1/2" 12.6# L-80 BTC-Mod 12532' 26'/26' 12558'/8889' Logging Program Open Hole Logs: 8-1/2" Hole 6" Hole (Lat 1) 6" Hole (Lat 2) Cased Hole Logs: MWD/GR MWD/GR/Resistivity MWD/GR/Resistivity None planned Mud Program Milling Interval: Gel-free 6% KCI Biozan ' I Density, ppg I FunnelVis, secI YP Gels I pH I HPHTFL, cc 9.8 - 10.0 50 - 65 50 - 60 20-30 / 30-40 9 - 10 <14 Hazards/Concerns Maintain YP 50 - 60 to insure adequate removal of metal cuttings. Insure adequate preparation to eliminate metal entering motor and MWD from mud bypassing solids control equipment. IIntermediate (8-1/2" hole) Section: Gel-free 6% KCI Biozan I Density, ppg I Funnel Vis, sec I LSR YP I Gels I pH I HPHT FL, cc 10.0 I 50- 65 I 8- 13 I 15-25 / 20-35 I 9- 10 ] <14 Hazards/Concerns I Potential high torque could require lubricant use. I Be alert for lost circulation, differential sticking due to higher MW. Production (6" hole) Sections: Quickdriln (viscosified SW) I Density, ppg I FunnelVis, sec I LSRYP LSRVis pHI APIFL, cc 8.6 - 8.8 55 - 65 14 - 20 > 45,000 8.5 - 9.0 NC Hazards/Concerns I Potential high torque could require lubricant use. B~ alert for lost circulation, differential sticking due to overbalanced MW. Maximize solids control to keep fluid as clean as possible. Max mud weight 8.8 ppg. Directional IKOP: 1.10000' MD I Maximum Hole Angle: Surface Close Approach Wells: Drilling Close Approach Wells: 92°, 88° through targets M-25 and M-30 are approx. 32' away None Well Control Well control equipment consisting of 5000 psi w.p. pipe rams, blind rams, and annular pre- Di- venter will be installed and is capable of handling maximum potential surface pressures. verter, BOPE and mud fluid system schematics on file with AOGCC. Hazards · Gas cut mud is a possibility throughout the intermediate liner section. · Stuck pipe, tight hole, and swabbing have occurred in M-Pad wells through Kingak shale. · Lost circulation through conductive faults is common on M-Pad. Operations Summary 1. Pre-Rig: Kill well with sea water. Squeeze and abandon existing perforations. 10. RU WL and chemical cut tubing. Test all wellhead packoffs to 5000 psi. Freeze protect well. Release pressure from tubing and all annuli. Install and test BPV. Prep for rig. 2. Secure surface close approach wells. MIRU Nabors 2ES. Obtain production handover form prior to rig work. Take on seawater. 3. Pull BPV. Circulate out and recover freeze protection fluid. Install TWC and test from below to 1000 psi. ND tree. 4. NU BOPE and test to 250 / 5000 psi. Test annular to 250 / 2500 psi. Pull TWC. 5. . Pull and LD hanger and 4-1/2" x 3-1/2" tubing. Note: If hanger running threads are unconfirmed, use tubing spear to recover tubing. 6. Set EZSV @ _+10,300' MD. Test 9-5/8" casing against EZSV to 3500 psi. 7. PU whipstock and window milling ass'y (with RA tag) for 9-5/8", 47#/ft casing on 3-1/2" DP. RIH to _+10,300' MD and tag EZSV. Displace hole to milling fluid (which will double as drilling fluid). POH to _+10,300' and set whipstock. Mill window from _+9995' MD. C&C. POOH after ensuring hole is free of metal cuttings. 8. PU 8-1/2" bit, 6~3/4" MWD and steerable BHA. Kick off and drill 8-1/2" hole directionally to TD @ 12,708' MD (8911' TVD). POH, LD BHA. 9. Install a 7", 26 Ib/ft, L-80, BTC-MOD liner with 7" x 9-5/8" packer/hanger. Space out for 150' of lap. Reciprocate liner 20' - 30' during circulation and cementing. Cement liner with 235 sk cement based on 1508' of 8-1/2" open hole x 7" liner annulus plus 30% excess, plus an 80' shoe joint. Total cement volume is 267.9 ft3 or 47.7 bbls. Set liner hanger/packer with 4200 psi. Reverse out clean and POH. 11. 12. 13. 14. 15. 16. 17. 18. 19. PU 6" bit, 4-3/4" MWD and steerable BHA on 3-1/2" DP. RIH and tag 7" landing collar. Drill float equipment and 20' of new formation with existing mud (drill-out FIT). Displace well with new Quickdriln (viscosified sea water). Directionally drill first horizontal lateral to TD @ 17,130' MD (8980' TVD). Condition hole for liner and POH, LD BHA. Install a 4-1/2", 12.6 Ib/ft, L-80, IBT-Mod liner with 4-1/2" x 7" packer/hanger. Space out for 150' of lap. Reciprocate liner. Cement liner with 450 sk cement (95.5 bbls) based on 4422' of 6" open hole x 4-1/2" liner annulus + 30% excess (493.8 ft3 or 87.9 bbls), plus an 80' shoe joint (6.8 ft3 or 1.2 bbls), plus 150' liner lap (14.7 ft3 or 2.6 bbls), plus 150' above liner top (21.3 ft3 or 3.8 bbls). Set liner hanger/packer with 4200 psi. Reverse clean. POH. PU 7" whipstock, 6" bit, 4-3/4" MWD and steerable BHA on 3-1/2" DP. RIH, orient and set whipstock @ +_12,235' MD (8765' TVD). Mill window in 7" casing from 12,230' MD. Kick off and drill 6" second horizontal lateral section to TD @ 17,105' MD (8880' TVD). C&C. Displace well to sea water. Run 4-1/2", STL slotted liner to TD. Drop slotted liner 10' outside 7" window. POH. RIH and retrieve 7"whipstock. PU cleanout BHA for Lateral 1. RIH to TD. Displace hole to sea water and circulate clean. MU 3-3/8" drill pipe conveyed perforating guns, 4 spf, 2-3~8" drill string. Include tools as follows. Absolute pressure firing head Perforating guns & blanks, as per enclosed production specs. Firing Head Adapter Primary Firing Head (Annulus Pressure) XO Space-out joints XO and Below-Packer Safety Joint Bypass Port 4-1/2" Champ Packer (To be set @ xxx' MD / xxxx' TVD) XO Jar PR FAS-FIL Valve to be set at @ xx' MD/xx' TVD to achieve xxx psi underbalance. 3-1/2" DP to surface Note: Once logs have been analyzed and perforation intervals are known the packer depth, fluid height for underbalance, and clean up period will be determined. De- tailed perforating procedure will be specified when above are known. 4 20. 21. 22. 23. 24, , 25. 26. 27. Run a 4-1/2", L-80 IBT-MOD completion assembly (used tbg if available from stores). Note: follow WOA completion guidelines. · 4-1/2" WLEG · 4-1/2", 12.6 Ib/ft, L-80 IBT-MOD 10 ft pup joint · 4-1/2", 12.6 Ib/ft, L-80 IBT-MOD full joint · 4-1/2", 12.6 lb/fi, L-80 IBT-MOD 10 ft pup joint · 4-1/2" x 7" packer · 4-1/2", 12.6 Ib/ft, L-80 IBT-MOD 10 ft pup joint · 4-1/2", L-80 Otis"X" Nipple · 4-1/2", 12.6 Ib/ft, L-80 IBT-MOD 10 ft pup joint · 4-1/2", 12.6 Ib/ft, L-80 IBT-MOD tubing joint · 4-1/2", 12.6 lb/fi, L-80 IBT-MOD tubing with ultra slim hole GLMs GLM depths to be determined later. · 4-1/2", L-80 Tubing Retrievable SSSV @ _+ 2,200' MD · 4-1/2", 12.6 lb/fi, L-80 IBT-MOD tubing to surface · 4-1/2" tubing hanger Space out, test the SSSV and circulate with corrosion inhibitor prior to setting packer. Drop packer setting ball. Pressure the tubing to 4000 psi and set the packer. Note' Set packer prior to ND BOP and NU tree (well is perforated). Close SSSV, install a TWC, and test to 1000 psi. Remove BOPE. Install and test the production tree to 5000 psi. Pull TWC valve. While holding 1500 psi on the tubing, pressure test annulus to 3500 psi for 30 minutes. Bleed pressure from annulus then tubing. Open SSSV and shear the RP on the upper GLM with 2900 psi annulus pressure. Bleed pressure and freeze protect with diesel to 2200' MD. Set BPV. Close the SSSV and secure the well. Release rig. Complete appropriate documentation and hand over to Production. Anadrill Schlumberger' Alaska District 1111 East BOth Avenue Anchorage, AK 99518 (907) 349-4511 Fax 344-2160 DIRECTIONAL WELL PLAN for SHA~RE~ SERVICES DRILLING Nell ......... : M-05AL1 (Pg) Field ........ : Prudhoe Bay, M-Pad Computation..: Minimum Curvature Units ........ : FEET Surface Lat..:' 70.33522962 N Surface Long.: 148.95964534 W Legal Description Surface ...... : 2201 FSL 605 FEL S01 T11N R12E UM Tie-in / KOP.: 2175 FSL 4928 FEL S12 T11N R12E UM Target Start.: 2176 FSL 5044 FEL S12 TIIN R12E ~ Mid Point .... : 2398 FSL 2945 FEL Sll T11N R12E L94 BHL / TGT End: 3426 FSL 4067 FEL Sll T11N R12E UM LOCATIONS - AI~SKA Zone: 4 X-Coord Y-Coord 628231.00 5973278.00 624000.00 5967900.00 623883.97 5967899.59 620700.00 5968070.00 619560.00 5969080.00 PROPOSED NELL PROFILE STATION MEASURED IDENTIFICATION TJB KOP CURVE 25/100 12234.90 TOP SAG RIVER 12234.90 12250.00 12275.00 INCLN DIRECTION VERTICAL-DEPTHS ANGLE AZIMUTH TVD SUB-SEA 8714.90 8660.00 60.00 267.00 8764.90 8710.00 60.00 267.00 8764.90 8710.00 63.67 268.02 8772.03 8717,13 69.75 269.58 8781.91 8727.01 Prepared ..... : 17 Apr 1997 Vert sect az.: 267.38 KB elevation.: 54.90 f= Magnetic Dcln: +2B.346 (E) Scale Factor.: 0.99991868 Convergence..: +0.97969094 4560.96 5305.31 S 4322.68 W 4560.96 5305.31 S 4322.68 W 4574.27 5305.89 S 4335.98 W 4597.22 5306.36 S 4358.93 W 624000.00 5967900.00 624000.00 5967900.00 623986.71 5967899.20 623963.78 5967898.33 END 25/100 CURVE TARGET START ******* 12300.00 75.85 271.01 8789.30 8734.40 4621.06 5306.23 S 4382.80 12325.00 81.95 272.38 8794.11 8739.21 4645.51 5305.50 S 4407,31 12350.00 88.06 273.70 8796,28 8741.38 4670.28 5304.18 S 4432.17 12356.56 89.67 274,04 8796.41 8741.51 4676.79 5303.74 S 4438.71 12356.56 89.67 274.04 8796.41 8741.51 4676,79 5303.74 S 4438.71 623939.91 5967898.05 623915,40 5967898.36 623890.52 5967899.25 623883.97 5967899.59 623883.97 5967899.59 TOP S:-IUB LI K 13820.59 B9,67 274.04 B804.90 8750.00 6130.90 5200.51 S 5899.07 W 622422.18 5967977.82 (Anadrill (c)97 M05ALiP9 3.0C 3:36 PM P) TOOL DL/ FACE 100 14R 14R 14R 25.00 13R 25.00 12R 25.00 12R 25.00 12R 25.00 HS 25.00 ~S 25.00 HS 0.00 M-05AL1 (Pg) STATION IDENTIFICATION CURV£ 10/lO0 TARGET MIDPOINT END 10/100 CURVE 4-1/2" LINER PT TD TOP SADLEROCHIT COWC TOP HOT TOP ZONE 3 Apr 1997 PROPOSED WELL PROFILE MEASURED INCLN DEPTH ANGLE ..... 15545.41 89,67 15545.41 89.67 15600,00 89.34 15700.00 88.75 15800.00 88.19 DIRECTION VERTICAL-DEPTHS AZIMUT~ TVD SUB-SEA 274.04 8814.90 8760.00 274.04 8814.90 8760.00 279.49 8815.37 8760.47 289.48 8817.05 8762.15 299.46 8819.73 8764.83 SECTION COORDINATES-FROM DEPART WE~ 7844.03 5078.90 S 7619.57 7844.03 5078.90 S 7619.57 7897.87 5072.47 S 7673.76 7993.31 5047,49 S 7770.44 8082.19 5006.14 S 7861.31 15900.00 87.70 15993.22 87.29 17105,11 87,29 17105.11 87,29 17105.11 87.29 309.46 8823.33 8768.43 8161.81 4949.66 S 7943.61 W 318.78 8827.41 8772.51 8225.56 4884.90 S 8010.39 W 318.78 8879.90 8825.00 8918.40 4049.47 S 8742.23 W 318.78 8879.90 8825.00 8918.40 4049.47 S 8742.23 W 318.78 8879.90 8825.00 8918.40 4049.47 S 8742.23 W 8949.90 8895.00 9009.90 8955.00 9024.90 8970.00 Page 2 ALASKA Zone 4 X Y 620700.00 5968070.00 620700.00 5968070.00 620645.71 5968075.50 620548-62 5968098.82 620457.07 5968138.61 TOOL DL/ FACE 100 94R 0.00 94R 0.00 93R 10.00 93R 10.00 93R 10.00 620373.83 5968193.67 620305.95 5968257.28 619560.00 5969080.00 619560.00 5969080.00 619560.00 5969080.00 93R 10.00 10.00 0.00 0.00 0.00 > O > (Anadrill (c)97 M05AL1P9 3.0C 3:36 PM P) -SHARED SERVIG;ES DRILLING i iiiiii /4nadr~ ]] $ch]u¢ber#er ii i iii i i i iii M-OSALCt (Pg) VERTICAL SECTION VIE i iiii iii IIIllll[ I I Section at' 267 38 · : · - ............ ~ ITVO Scale.: 1 inch = 800 feet J /~_ ~/ ": F '~ .," , I , ,i,. '-' :'T--.-r.j, '..'. i' i Ioep Scale.: linch 800 feet ......... _~_._ · ...... ~. ,~..-,.; i Drawn ..... : 17 Apr 1997 O- , I ~ .... ~---.-, '~ ' Marker Identification MD BKB SECTN INC[ I ' F'- ,.. , A) KOP CURVE 25/100 t2235 8765 4561 60.( " I , ._.~'~:::> , B) END 25/~00 CURVE :~2357 8796 4677 B9.f ..... · ............... - .... ......... ; C) TARGET START ~****~* 12357 8796 4677 nu ~ ...... : - .':'. i.~'U''i~l~'~, ..... ,i . ., " D] CURVE 10/:100 15545 88:15 7844 89.1 · ~ ; ~ E) TARGET MIDPOINT ***~ t5545 8815 7844 Bg.~ , '. F) END t0/100 CURVE 15993 8827 8226 87.; O- ~. ' i .... i G) 4-:~/2" LINER PT 17:105 8880 8918 '~% . i i H) TO 17:105 8BBO B91B 87.~ , _..¢,..~. ,- : 12::: -l~-r~q~l~5-~-- - = ~ ...; , ...... I &.._L ..... 4F'~:~,~--.'-----, .... :::::i::;': '"'""""'""'""",' ~~~ ' -' ' ':' "~::::::::: ~_ .. .._~, .. · ..... i .:. .... ! . ; { I ....... i "' I 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 8400 8800 9200 9600 Sec t J on Depart Ute .(Anaar,]]l (c)97 1,105a. tP9 3.0C 3:5! ~ P) - 'q 0 F SHARED SERVICES DRILLTNG ! ! ii ii iii iii i i i iii Anadr~ I/ Schlumberger i M-O5AL (Pg) VERTICAL SECTION VIEW :- Section at: 267.38 · ' i : : · I' · F ".. ~ TVDScale.: 1 inch = lO0 feet I ', ~ , . . ..- ,,.,,;-xIDeP Scale.: I inch : tO0 feet ~- ' I ''~' IDrawn ..... : ~7 Apr 1§§7 I ' " ~'~ ce~ ' ~ J ~ ..... ' .... ' .... ~ ~apk~P Ia~ntiflcation ~ BKB SECTN INCL , j ', : B) END 25/100 CURVE 12357 8796 4677 ............ ~ , ....., .q. ,I " D) CURVE t0/100 15545 8B15 7844 89.f j E] TARGET ~IDPOINT ~ ~5545 88~5 7844 Bg. ; ~ ', F} END 10/100 CURVE 15993 8827 8226 87. ..... · ~ : Gl 4-1/2" LINER PT 17~05 8880 89~8 87.~ ~ ', I H) TO J7~05 8880 BglB 87.; . ~.~.~ , - , .. .I I I i I I I I I -- i m i m I I I I I i I m . I i I I I I I i i i I I i i I I I I I I I I . ' ~ ~ '' ~ i I j co.6 - e~s~ ............. . ~ : 4400 4450 4500 4550 4600 4650 4700 4750 4800 4850 4900 4950 5000 5050 5100 5150 5200 5250 5300 Sect ion De~,flC,~ure , , (~adr~ll (c)97 ~5~P9 3.0C 3:52 PM P) 0 II 0 )~ ,,iii 0 Anadr.i ]] Sch]umber£er M-O5AL! (P9) PLAN VIE CLOSURE 9635 fee[ a[ Azimuth 245 15 SHARED SERVICES DRILLING iii ii DECLI SCALE DRAWN )4arker A) KOP 8) ENO C) TARGET D) CURVE E) lARGEl F) END G) 4-~/2' H) TO 1 NATION.' +28.346 (E) · 1 inch: t200 feet · 17 Apr t997 ; ..... i ...... j KB / Idehtification MI) N/S E/W . ...... .._ ..... , ............ i.. , .... ! · CURVE 25/100 12235 5305 S 4323 N -.. ,, · , ' ; · 25/100 CURVE 12357 5304 S 4439 W . [ '. . -~ JET START N~K 12357 5304 5. 4439 W , . i. ' ,, tE lO/tO0 15545 5079 S 7620 W ,. 10/100 CURVE 15993 4885 S 80t0 W [ . // 12' LINER PT . 17105 · 4049 S 8742 W 17105 4049S 8742, - i ! ii i / .... ' _ I I ' ,,,:,, ,! - ; ': : ' : ~ T~r)!dCart [Point) ' ......... -: ~---~ -.. ..- . .' i , i I , ; I ' ! ~ I ~ ' ' 10200 9600 9000 8400 7800 7200 6600 6000 5400 4800 4200 3600 3000 2400 1800 1200 600 0 600 <- NEST' EAST -> i ii mi A~adri]] (C}97 1405~1P9 3.0C 2:54 PM P} WELL PERMIT CHECKLISToo.~.YZf/ w~,,,, NAME /~)~_.~' /'~ '~~ ~ / 2ROG~: expo der O ~ed~[O se~vO wel[bo=e se~ ann d~sp pa~a =eqO ~ ~ ~oo~ J~l~c~ ~ c~s~ ~ I- o ~ ? ~o~ ~ ~ ~ //~,~o o~/o~ s~o~ ADMINISTRATION 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 drlg unit boundary. 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling 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 ....... ENGINEERING REMARKS DATE 15. Surface casing protects all known USDWs ......... Y ~t- 16. CMT vol adequate to circulate on conductor & surf csg. . Y 17. CMT vol adequate to tie-in long string to surf csg . . . Y 18. CMT will cover all known productive horizons ...... .~ ~ 19. Casing designs adequate for C, T, B & permafrost .... '~ N 20. Adequate tankage or reserve pit ............ ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved..~y----N---~//~ ~ 40 ~ 22. Adequate wellbore separation proposed ......... ~ N 23. If diverter required, is it adequate ......... .~~ ~ 24. Drilling fluid program schematic & equip list adequate ~ N 25. BOPEs adequate .................... 4 Y~ N 26. BOPE press rating adequate; test to ~--~--~ psi~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... ~ N ~ ~ 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N// _ 31. Data presented on potential overpressure zones ..... Y /N ~ 32. Seismic analysis of shallow gas zones ......... ./ N ~ ~ 33. Seabed condition survey (if off-shore) ....... ./. Y N ' - - ' 34. Contact name/phone for weekly progress reports . . ./< . Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: JDH ~ mcm Comments/Instructions: HOW/dlf - A:\FORMS\cheklist rev 01/97