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Home My WebLink About197-236PLUGGING & LOC_%T!0N CLEA_~_~CE REPORT Sta~a cf Alaska 0iL & GAS C.'2/~S~tV~TIOR CCM/fISSION Review ~h~e well file, an~,' c-_,w~e~: on plu~-~g, well head suaUus.~ !ocatlmn c!aa~ca'- ur~e loc. c!e~. co~e. Code STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION coMMisSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil E~ Gas r'~ suspended D Abandoned r~] Service E] ~~~ 2. Name of Operator ~ ~.¥'~a.~ ~ 7. Permit Number Phillips Alaska, Inc.~;~ s~.~'~4~L-~-_~~ 197-236 /301-292 3. Address ~~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 ..-.. --L..,.,.~?.__ ~:: 50-029-22843-00 4. Location of well at sudace 9. Unit or Lease Name 134' FSL, 595' FEL, Sec. 14, T11 N, R10E, UM (asp's: 560490, 5959800) Kuparuk River Unit At Top Producing Interval 10. Well Number 2271' FNL, 1320' FWL, Sec. 13, T11N, R10E, UM 1D-105 At Total Depth 11. Field and Pool 2054' FNL, 3826' FEL, Sec. 13, T11N R10E, UM (asp's: 562509, 5962905) Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Sedal No. RKB 112' feetI ADL 25650, ALK 468 West Sak Oil Pool 12. Date Spudded 13. Date T.D. Reached 14; Da, te¢o.mp., S_usp. Or Aband. ~15. Water Depth, if offshore 16. No. of Completions ,¢~r-~..~¢~'-. I ~'a -- I January 19, 1998 January 22, 1998 I::Jccembef~, 2001/¢'~ (P&A'd) N/A feet MSL 1 17. Total Deplh (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost MD / 4433' TVD 5225' MD / TVD YES F~ No [~][ NA 6093' feet MD 1 744' (approx) 22. Type Electric or Other I'ogs Run GR/Res 23. CASING, LINER AND CEMENTING RECORD SEll-lNG DEPTH MD [ CASING SIZE WT. PER FT. GRADE TOP BO-I-rOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 121' 24" ,9 cu yds High Early 7.625" 29.7# L-80 Surface 6077' 9.875" 570 sx AS III LW, 366 sx AS I, 60 sx Class G set cement retainer @ 5225' 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) N/A N/A N/A * Plugged & Abandoned all perforation intervals. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED retainer @ 5225' 73 sx Class G 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) N/A Plugged & Abandoned Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I N/A Test Pedod > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECE ' - gED N/A Ai~!tka 0il & 6as Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. GEOLOGIC MARKERS NAME Top of West Sak Sand Base West Sak Sand MEAS. DEPTH 5381' 5842' TRUE VERT. DEPTH 3766' 4197' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. N/A RECEivED OEO i 31. LIST OF A-I-rACHMENTS Summary of Sidetrack Plug & Abandonment Operations. 32. I hereby certify that the following i.¢t'~e and correct to the best of my knowledge. S~ ned 'g /'/~-/$'~'~'~"~L~- ~-.~"~'~"' Title Orillin,q En.qineerin.q Supervisor C. Mallary f Questions? Call Todd Mushovic 265-6974 INSTRUCTIONS Prepared by Sharon AIIsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Legal Well Name: 1D-105 Common Well Name: 1D-105 Spud Date: Event Name: ROT - SIDETRACK Start: 10/13/2001 End: 11'/3/2001 Contractor Name: n1433@ppco.com Rig Release: 11/3/2001 Group: Rig Name: Nordic 3 Rig Number: 3 ..:Date: Fr°m;':TO:: i; Hours ;C6de ~oUdbe ~i:~i:!! 10/13/2001 18:00-19:00 1.00 WAITONORDR MOVE WO field wide crew change & clea'rance from security to move on road way. 19:00-23:00 4.00 MOVE MOB MOVE Road r. ig from 1C-102 to 1D105A. 23:00-00:00 1.00 MOVE RURD MOVE Prepare to move-over well, 'load t'ree in cell ar. Unable to move over well due to thermal "cold sink" - need 2 additional feet.. 10/14/2001 00:00-13:00 13.00 WALTON EQIP IMOVE Undabie to move over well due to thrmosphy one [need 2 morer feet], call out cran.e to re move same [0300 hrs], Unable to pull. Call out generators to heat same [0600hrs], add 2nd electrical source @ 0900 hrs. @ 1230 h rs unable to pull same. Pad personnel ck fo r no internal pressure & cut same off w/ cut off tool [cold cut]. Rig accepted for duty 0000 hrs 10/14/2001. 13:00-16:00 3.00 MOVE POSN MOVE Move over / center over well bore. Berm up around rig, spot miscellaneous equip. Rig u p tarps / wind walls. 16:00-18:00 2.00 cMpLT~RURD iABANDN Pull bpv '/ vr plug & prepare to cir well. Ru / press test cir lines to flow back tank. 18:00-20:00 2.00 CMPLTNCIRC ABANDN Pump 85 bbl 1057 diesel down annulus takin g returnes from tbg diverting for recycle, la rge amt.Of crude in returns [ 4 bpm max pre ss 1100 psi]Follow w/ 240 bbl 1007 sea wtr.- Returns cleaned up well. 20:00-21:00 1.00 CMPLTNOBSV ABANDN Monitor well dead, set bpv & rd cir lines. 21:00-00:00 3.00 CMPLTNNUND ABANDN Nd tree / Nu bope. 10/15/2001 00:00 - 00:30 0.50 ABANDI~ NUND ABANDN C o m p I e t e n u b o p e. 00:30-05:00 4.50 WELCTL BOPE ABANDN Pull bpV install 2 way check valve. Test 2 875" pipe rams, annular, choke manifold &-fl oor safety valves to 2500 / 2.50 psi. Test w tnessed by John Crsip, Aogcc. 05:00-07:30 2.50 WELCTLOBSV ABANDN Pull test jt [2.875"], 2 way ck., pUll hanger t o-floor [65k lbs], monitor well, & Id pups un der hanger & hanger. 07:30-08:00 0.50 ABANDNSFTY ABANDN PJSM - tbg '/ esp pump recovery. 08:00-22:00 14.00 ABANDNRTRV ABANDN Pooh w/ 2.875" tbg - esp completion. Spool lng heat trace & pump cable. Lost [unaccou nted for] one 1.5" wide x .125" x 6.5" band s & I clips All trays recovered. Ld 165 jt . s tbg & 10 pups. 22:00-00:00 2.00 ABANDI~rRURD ABANDN Rig down handling gear & clean floor. FI uid lost to hole/24 hrs = 252 bbl sw Current oss rate 25 bbl/hr 10/16/2001 00:00-01:00 1.00 WELCTLEQRP ABANDN Set test plug, change out upper & lower-pip e rams to 4.00". 01:00-02:00 1.00 WELCTLBOPE ABANDN Test upper / lower pipe-rams 250 / 2500 psi. 02:00-02:30 0.50 WELCTLBOPE ABANDN Set wear bushing. 02:30-05:00 2.50 ABANDI~ PULD ABANDN Load pipe shed w/ 170 its 4" dp & strap sam e. 05:00-06:00 1.00 ABANDhOTHR ABANDN Pu / mu bit & scraper. 06:00-10:00 4.00 ABANDI~!TRIP ABANDN "ih w/ bit & scraper, string taking 5 - '25k Printed: 12/6/2001 2:50:20 PM Legal Well Name: 1 D-105 Common Well Name: 1D-105 -Spud Date: Event Name: ROT - SIDETRACK Start: 10/13/2001 ,End: 1.1/3/2001 Contractor'Name: n1433@ppco.com Rig Release: 11/3/2001 Group: Rig Name: Nordic 3 Rig Number: 3 : Date FrOm, TO:HOurS:: ::i:.:~:~s!~:,:::i ?:ii:. :~.:.i:.::i:.:~:;::.i:.:~:i:i!.:.:~ii?::::ili:~i:::, !iiii~C :~:~'i;:ii:~.: 10/16/2001 06:00-10:00 4.00: ABANDI~ TRIP ABANDN lbs on. last 1500' Hole deviation 'up to 56? & dog leg severity to 6?. Run in to 5290', p roposed retainer setting depth 5219'. Strin g taking wt w/ stand all the Way down. 10:00-11:00 1.00 ABANDi~TRIP ABANDN Pick. up single & ok td @ 5290' rkb Nordic 3. When picking up off bottom a hydraulic qu ick connector [1" to. 1.125' od x 2.125" Ion g] fell from TDS to floor-8, bounced in hole. Inspect stack w/ no sighting of same. Well file schematic shows a Baker SC - I · tool" @ 5299' rkb Parker 245 [Nabors 245]. W/ kb correction of -14' this is 5285' rkb Nordic 3. 11:00-12:30 1.50 ABANDNCIRC ABANDN Circulate one hole volume. 12:30-14:30 2.00 ABANDNTRIP ABANDN Pooh, rotating & working pipe-each 1000'. Did not observe any drag or torque~ 14:30-15:00 0.50 ABANDNOTHR ABANDN Drain up stack w/ scraper below bop. While observing, ease top of scraper juxtapose t o top of wear bushing. No recovery . 15:00- 15:30 0.50 ABANDI~ SFTY ABANDN P J S M 15:30-20:00 4.50 ABANDI~TRIP ;ABANDN Ru Schlumberger & make 2 junk basket runs to 5270' rkb wi md w/ 6.5" gage ring {Nor dic 3 depth}. 1st run rec band & small de bris & mangled clip. 2nd run rec small rec ognizable debris of quick disconect. 3rd ru n no recovery 20:00-20:30 0.50 ABAND~TRIP ~,BANDN RD junk basket assmby & Mu retainer to wi t ool string. 20:30-23:00 2.50 ABANDI~TRIP ABANDN Tih w/ retainer. Run strip charts & correlat e to set retainer top @ 5219' rkb Nordic 3. Drop back down & ck retainer on 'depth. Poo h w/ string / visually ck tools ok. 23:00-00:00 1.00 ABANDNTRIP ABANDN LD retainer running tools & pu stinger for ce menting. Fluid lost to well last 24 hrs = 3 75 bbl Total to well since start cps = 627 'b bi 10/17/2001 00:00-03:30 3.50 ABANDNTRIP ABANDN Pu & rih w/ 132 jts + 10 stands of 4' x 14.4 ppf x S-135 pipe. [stinger for retainer atrea dy picked up] 03:30-04:00 0.50=ABANDI~ RURD ABANDN Mu cmt lines ck up / down wts @ 95k & '50k I bs. Sting into retainer @ 5219' 04:00-06:30 2.50 CEMEN'IPUMP'IABANDN PJSM Batch mix 73 sx CI (3 cmt [ .2% _D47, ,3% D65, .5 % Sool & .4% D167] @ 15.8 pp g, yield 1.16 total pumpable slurry 15 bbl. Establish injection rate of 2 bpm / 260 psi, pt lines to 3200 psi. Displace cmt to strin g & disp to below r'etainer w! 57.1 bbl fw. Pressures @ 2 bpm = 250 / 350/ 833 psi. O bserved cmt on formation where large part o f pressure incr'eased occured. 06:30-08:30 2.00 CEMEN'I'OTHR ~,BANDN ~Reverse circulate 325 bbl sw, observed a tr ace of dis- coloured water @ bottoms up. S 3otted 15 bbl of sw treated _w/ 5 gals retarte Printed: 12/6/2001 2:50.20 PM Legal Well Name: 1 D-105 Common Well Name: 1D-105 Spud Date: . . Event Name: ROT- SIDETRACK Start: 10/13/2001 ~End: 11/3/2001' Contractor Name: n1433@ppco.com Rig Release: 11/3/2001 Group: Rig Name: Nordic 3 Rig Number: 3 . · ·: : - ' ~ ' ! ':;' "' ;I : :: ': : i ' :" :';'::: :' ..: :. .......... -:: :::::--:: :- -:-- :, :;:,::: ---.:-:,:::~:t ::: :.:: ~:;~::::~z:~:~: :, ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~ :,~ ..... -: :-,-:.=.:-':~ Date FrOm- To iHours COd~;I SUb: i ~s~ 10/17/2001 06:30-08:30 2.00 CEMEN'IOTHR ABANDN d on bottom. Rig down cmt lines. . 08:30-10:30 2.00 CEMEN3TRIP ABANDN Pooh w/ dp & stinger. 10:30-11:30 1.00 DRILL OTHR PROD Load pipe shed w/remaing bha items & stra p same. 11:30-12:30 1.00 DRILL PULD PROD Pick up / Make up Bha [Whip stock Assmby], orient - scribe tool face surface test mw'd. . 12:30-15:30 3.00 DRILL PULD PROD Continue to Pu bha. 15:30-19:00 3.50 DRILL TRIP PROD Rib w/ Stands to 5150' 19:00-20:00 1.00 DRILL OTHR PROD Ck up / down wts of 112 & 66k lbs @ 7 bpm / 1070 psi. Orient tool face 25? right of h igh side, slaCk off to 3' above retainer main taining tool face 25?. Slack off to retainer [string taking weight], tool face turned to 1 6? right of high side. Top of retainer @ 522 4.77' Slack off 22k lbs & set whipstock an . chor. Pick up to ?70 k lbs verfying anchor set. Set down 30k lbs & shear mill out ass ruby off whip stock assmby. 20:00-21:00 1.00 DRILL 'CIRC PROD Disp hole & mud system to 9.0 PPG ?550 bbl Isnd mud. 21:00-00:00 3.00 DRILL OTHR PROD Milling window in csg from [top] 5205' to 52 12' [inco'mplete, total window to be 1'2 5' Ion g] 7.3 bpm / 1270 psi. Good steady pump pr essure & reactive milling torque. 10/18/2001 00:00-05:00 5.00 DRILL DRLG PROD Complete milling window to 5218' [window 5 205 - 52.18']. Ream window out several time s. Continue to mill ahd to 5231' [upper mill clear of window. Work mill through window several times w/ no drag. Contine to mill f ormation to 5240'. . 05:00-06:00 1.00 WELCTLCIRC IPROD Cir cond hole to clean returns sweep hole. Spot 15 bbl Iow water loss pill in new hole. 06:00-06:30 0.50 WELCTLTRIP PROD iPull up into csg for formation integrity test. 06:30-07:30 1.00 WELCTLOTHR PROD Conduct leak off test to 12.12 ppg emw [Ca I' emw increase = (590 psi)/ (.052 x 3634' t vd) = 3.12ppg emw = 9.0 ppg + 3.12 ppg = 12.12 ppg 07:30-10:30 3.00 DRILL TRIP PROD Pooh w/ milling assmby. 10:30-12:00 1.50 DRILL PULD PROD Ld down milling assmby. Top mill in.gage@ 6.75" Lower string mill 1/16 under @ 6 ?" Starter '1/8 under @ 6.00" 12:00-14:00 2.00 DRILL ~OTHR PROD Clean floor, replace lights in derrick, flush ' out surface lines & bop checking for metal scards / debris, adjust torq settings on tds & service rig. 14:00-16:30 2.50 DRILL PULD PROD Pu bha #2, program mwd & test same. 16:30-19:30 3.00 DRILL TRIP PROD TIH to 5227', wash ream to td of 5240' did n ot observe window Ck up / down wts of 98 155 k lbs & rot of of 75 k while pumping. 5.8 bpm / 1310 ~psi. Printed: 12/6/2001 2;50:20PM STATE OF ALASKA '~--~' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_X Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _X Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 112 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 V~ ~- / Service__ Kuparuk River Unit 4. Location of well at surface v v 8. Well number 134' FSL, 595' FEL, Sec. 14, T11 N, R10E, UM (asp's 560490, 5959800) 1D-105 At top of productive interval 9. Permit number / approval number 2271' FNL, 1320' FWL, Sec. 13, T11 N, R10E, UM 197-236 V'" At effective depth 10. APl number 50-029-22843 At total depth 11. Field / Pool 2054' FNL, 3826' FEL, Sec. 13, T11 N, R10E, UM (asp's 562509, 5962905) Kuparuk River Field/West Sak Oil Pool 12. Present well condition summary ¢/ Total depth: measured 6093 feet .¢,/ Plugs (measured) true vertical 4433 feet Effective depth: measured 5861 feet Junk (measured) true vertical 4215 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 9 cu yds High Early 121' 121' SUR. CASING 5965' 7-5/8" 570 bbls AS III LW, 366 bbls 6077' 4418' Class G, 60 sx Class G RECEIVED Perforation depth: measured 5382'-5420', 5454'-5520', 5550'-5600', 5630'-5710' OCT i 0 200 true vertical 3767'-3805', 8834'-$896', $924'-3970', $998'-4073' Al--a~a 0il & Gas Cons. C0mmissi0r~ Tubing (size, grade, and measured depth 2-7/8",6.5#, L-80 Tbg @ 5286' MD. Anchorage Packers & SSSV (type & measured depth) Baker SC-1 Gravel pack packer @ 5299' MD, Baker FB-1 sump packer @ 5422' & {5714', Baker isolation packer @ 5427' & 5526' & 5606', RAYCHEM HEAT TRACE (BO'FI-OM DEPTH 2275') @ 37' MD. 13. Attachments Description summary of proposal ._X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: October 12, 2001 16. If proposal was verbally approved Oil __X Gas __ Suspended __ Name of approver Date approved Service Signed(~ ~~ Title: GKA Drilling Engineering Supervisor Date/~ c. R. Mal/ary Prepared by Sharon Allsup-Drake 263-4612 / / co ss oN ONLY Conditions of approval: Notify Commission so e~j~esenta~jve may witness o~%~)--~ ~..~t -~.~'i~ ~r-~%_ ~ Approval n~,~.xt Mecharlical Inte/g~4t~7'-T. ex~t.__ ~_~f j~tlent form reqtlired 10- ..... _Ap_ p_ _ _r_o_ _v e .d_ _by o_r_der o, th e Com mi ssidl;L~.~..~?'] ~ f~/ Commissioner D a__t__e__/_l~/~ / uent form Form 10-403 Rev 06,15/88 · 0RI¢ih, IAL SUBMIT IN TRIPLICATE KRU WEST SAK 1D-105 SUNDRY OBJECTIVE P&A WELL FOR SIDETRACK OPERATIONS (reference attached plugback schematic) P&A WORK USING RIG 1. MIRU Nordic 3. Lay hard line to tree. Pull BPV and VR plug. 2. Circulate well to seawater. Verify well is dead 3. Set BPV. ND tree. NU and test BOP. 4. Screw in landing joint. Pull tubing hanger to rig floor. Pooh laying down all tubing, jewelry, ESP and cable PU casing scraper on DP and run through BP setting depth. . RU Eline and set Cement Retainer at 5229' MD. Test plug and casing to 3000 psi. RIH with DP and sting into cement retainer. Squeeze 15 bbls cement below retainer. TOH. Baker Oil Tools Phillips Alaska'lnc. ' 1.D-105 Date: 9/29/01 YZ..~ 0 ~ oPe~ Hoc& .WEST SAK (1D-105) (Frac-Packed Producer) Current Completion i ARCO Alaska, Inc. 7-5/8" Marker Joint (+/- 50' Above Top Pedoration) Drillers TD @ 6093' MD 3-1/2" Vetco-Gray Tubing Hanger w/2-7/8" L-80 EUE 8rd Mod Pup Joint, ESP Power Cable Penetrator, Heat Trace Penetrator and TEC Wire Penetrator. 2-7/8" 6.5# L-80 EUE 8rd Mod Spaceout Pups as Required for Heat Trace. 16" 62.5# H-40 @ 121' MD Stage Tool @ 2245' MD Raychem Heat Trace @ +/- 2265' MD 2-7/8" 6.5# L-80 EUE 8rd Mod Tubing to Surface (as required). 5' Handling Pup 2-7/8" 6.5# L-80 EUE 8rd Mod Tubing. 2-7/8" x 1" Camco 'KBMM' GLM' @ +/-5189' MD w/Shear Circulating Valve. (pinned for 3000 psi Tbg / Csg differential) 5' Handling Pup 2-7/8" 6.5# L-80 EUE 8rd Mod Tubing. 1 Joint 2-7/8" 6.5# L-80 EUE 8rd Mod Tubing. 6' Pup Joint 2-7/8" 6.5# L-80 EUE 8rd Mod Tubing. . (BOT double box coupling on top providing the port for the Baker Sentry Gauge) 8' Handling Pup 2-7/8" 6.5# L-80 EUE 8rd Mod Tubing Centrilift ESP (components as listed below) w/bottom set @+/- 5286' MD. Centrilift Discharge FPHVDIS. Centrilift Upper Tandem Pump 142FC925 Centrilift Lower Tandem Pump w/Intake 9FCNPSH Centrilift Seal Section: GSFT DB HL PFS Centrilift Motor: 57 HP KMH 1315/26 Directional KOP -- 381' Max Angle = 57 Deg @ 2154' MD Avg Angle Thru W.Sak = +/- 21 Deg Baker SC-1 Gravel Pack Packer @ 5299' MD D-Sand Perfs: 12 SPF 5382' - 5420' Frac and Pack w/Carbolite Baker FB-1 Sump Packer @ 5422' MD Tubing Stub @ 5424' MD Baker Isolation Packer @ 5427' MD B / A4-Sand Perfs: 12 SPF 5454' - 5520' Frac and Pack'w/Carbolite Baker Isolation packer @ 5526' MD A3-Sand Perfs: 12 SPF 5550' - 5600' Frac and Pack w/Carbolite Baker Isolation Packer @ 5606' MD A2-Sand Perfs: 12 SPF 5630' - 5710' Frac and Pack w/Carbolite Baker FB-1 Sump Packer @ 5714' MD PBTD @ 5861' WL (Top of Sump Packer Stuck and Set) 7-5/8" 29.7# L-80 BTC'Mod @ 6077' MD MAC 10/8/99 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 C. R. Mallary Phone (907) 265-6434 Fax: (907) 265-6224 October 10, 2001 Ms. Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501 Subject: 1D-105 Application for Sundry Approval (APD 197-236) Dear Commissioner: Phillips Alaska, Inc. hereby files this Application for Sundry Approval to P&A the current West Sak well 1 D- 105 well. If you have any questions regarding this matter, please contact Todd Mushovic at 265-6974. SincerelY~d~ C. R. Mallary Drilling Engineering Supervisor PAI Drilling CRM/skad RECEtVED OCT i 0 200! AicPa Oil & Gas Cons. Commissior~ AnchOrage DUPLICATE. THE MATERIAL UNDER THIS COVER HAS BEEN -- MICROFILMED ON OR BEFORE JANUARY 03 2001 P L iE-- M ~T E IA L!-~U~N D-W TH IS~ M ARK E RE R Well Compliance Report File on Left side of folder 197-236-0 MD 06093. _ T Name KUPARUK RIV U wS~ 1D,105 502 029~22843200 ~C0 '-T~D _04432_. on Date: ~-3/4/98 Completed Status: 1-OIL Current: Interval Sent Received T/CfD D 8239 L DGR/EW4- TVD L DGR/EWR4-MD ,_~-- SPERRY MPT/GR/EWR4 OH 2/18/98 2/18/98 LFI~L 120-4432 OH 2/18/98 2/18/98 D 'FIliAL 174-6093 OH 2/18/98 2/18/98 D R MWD SRVY SPERRY 0-6093 OH 2/13/98 2/18/98 Daily Well Ops////:?.'~' '= ¥ !'~' / '/'? ;7~/-~(':- Are Dry Ditch Samples Required? yes ~_And Received?~ Was the well cored? yes ~-'~ Analysis Description Recei~s--no~ Samlfl~ Set Comments: Tuesday, April 04, 2000 Page 1 of 1 'ARCO Alaska, Inc. r., Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 1, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-105 (Permit No. 97-236) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on West Sak 1D-105. If there are any questions, please call 265-6890. Sincerely, T. W. Mc Kay ' Senior Drilling Engineer Kuparuk Development TWM/skad RECEIVED - , ,~ O,.-_': 199a ~aska Oil & Gas Cons.~',,ommm~or} Anchorage ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL ~] GAS E~ SUSPENDED ~] ABANDONED~ SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 97-236 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22843 4 Location of well at surface 9 Unit or Lease Name 134' FSL, 595' FEL, Sec. 14, T11N, R10E, UM ! ~''~-'~ ~: i. ~!' ',',' '"~'i Kuparuk River Unit 2271' FNL, 1320' ~L, Sec. 13, T11 N, R10E, UM ~ ' ~- West Sak 1D-105 At Total Depth .} ~~ ~ .... 11 Field and Pool 2058' FNL, 1452' ~L, Sec. 13, T11N, R10E, UM ......... ~, '~-~ KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) ~ 6 Lease D~ignation and Sedal No. West Sak Oil Pool RKB 41', Pad 71'~ ADL 25650 ALK 468 12 Date Spudded 13 Date T.D. Reached 14 Data Comp., Susp. or Aband. ~ 15 Water Depth, if offshore 16 No. of Completions 19-Jan-98 22-Jan-98 04-Mar-98~ NA feet MSL 1 17 Total Depth (MD+~D) 18 Plug Back Depth (MD+~D) 19 Directional Su~ey 20 Depth where SSSV set 21 Thickness of permafrost 6093' MD & 4432' ~D 5946' MD & 4294' ~D YES ~ NO ~ NA feet MD 1744' APPROX 22 Type Ele~dc or ~her Logs Run G~R~ 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~ GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.58~ H-40 SURF. 121' 24' 9 cu yds High Eady 7.625' 29.7~ L-80 SURF. 6077' 9.875' 570 sx AS III LW, 366 sx AS I, & 60 sx Class G 24 Pedorations open to Production (MD+~D of Top and BoSom and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2.875" 5286' 5382'-5420' MD 3767'-3802' ~D 5454'-5520' MD 3834'-3896' ~D 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 5550'-5600' MD 3924'-3970' ~D DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5630'-5710' MD 3998'-4073' ~D SEE A~ACHMENTS ] 2 SPF 27 PRODUCTION TEST Date First Production ~Method of Operation (Flowing, gas lift, etc.) ~9/98J Gas Lift Date of T~t Hours Tested PRODUCTION FOI OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO ~31/98 6 TEST PERIOI: 34 10 186 0~ 310 Flow Tubing Casing Pr~sure CALCU~TED OIL-BBL GAS-MCF WATER-BB[ OIL GRAVITY-APl (corr) Pr~s. 174 -]5 24-HOUR RATE: ]32 41 738 0° 28 CORE DATA Brief description of lithology, porosity, fra~ur~, apparent dips and pr~ence of oil, gas or water. Submit core chips. ORIGINAL 2gaska Oil & Gas Cons. Anchorage Form 10-407 Submit in duplicate I~ev. 7-]-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top West Sak Sand 5381' 3766' Base West Sak Sand 5842' 4197' Annulus left open - freeze protected with diesel. 31. LIST OF A17ACHMENTS Summary of Daily Drilling Reports. Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed C- Title -.,t~,*'~-''~/~5, [/~_f~'~ DATE Prepared by Name/Number Sharon AIIsup-Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 3/27/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-105 WELL_ID: AK8965 TYPE: AFC: AK8965 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:01/19/98 START COMP:02/17/98 RIG:PARKER BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22843-00 01/19/98 (D1) TD: 352' (352) SUPV:DEB 01/20/98 (D2) TD: 3415' (3063) SUPV:GRW 01/21/98 (D3) TD: 4987' (1572) SUPV:GRW 01/22/98 (D4) TD: 6092' (1105) SUPV:GRW 01/23/98 (D5) TD: 6092'( SUPV:GRW 0) 01/24/98 (D6) TD: 6092'( SUPV:GRW 0) 01/25/98 (D7) TD: 6092'( SUPV:GRW o) MW: 8.8 VISC: 324 PV/YP: 22/42 APIWL: 10.8 DRILLING AT 1010' Move rig 30' from 1D-106 to 1D-105. Accept rig @ 1330 hrs. 1/19/98. NU diverter system and function test. Spud in at 121' and drill to 352' MD. MW: 9.4 VISC: 310 PV/YP: 35/51 DRILLING ~ 4350' Drill from 352' to 3415' APIWL: 8.4 MW: 9.1 VISC: 365 PV/YP: 40/50 DRILLING @ 5090' Drill from 3415' to 4805' APIWL: 7.2 MW: 9.2 VISC: 270 PV/YP: 31/46 RUN 7-5/8" CSG Drilling from 4989' to 6092' APIWL: 6.5 MW: 9.4 VISC: 98 PV/YP: 26/42 CEMENTING RIH w/7-5/8" casing. APIWL: 7.0 MW: 9.1 VISC: 48 PV/YP: 13/12 APIWL: 14.5 LAYING DOWN DRILLPIPE Pump first and second stage cement. N/U BOPE. Test BOPE. Drill stage collar and cement from 5783' to 5810' MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED. MOVING TO lC PAD Cleanout cement from 5810' to 5946'. Test casing to 300/3000 psi. Freeze protect well. N/D BOPE. N/U wellhead and test to 5000 psi. Release rig at 0000 hrs. 1/26/98. Date: 3/27/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 REMEDIAL AND COMPLETION OPERATIONS WELL:iD-105 RIG:NORDIC WELL_ID: AK8965 TYPE: COMPLETION AFC: AK8965 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:01/19/98 START COMP:02/17/98 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22843-00 02/17/98 (C8) TD: 6077' PB: 5946' SUPV:DLW SHORT TRIP W/7-5/8" SCRAP MW: 8.7 KCL Turn key rig move well to well from 1D-124 to 1D-105. Accept rig @ 0330 hrs. 2/17/98. N/D tree, N/U BOPE, test BOPE 250/3500 psi. Displace diesel with sea water. RIH with 7-5/8" scraper. 02/18/98 (C9) TD: 6077' PB: 5946' SUPV:DLW PERFORATE W/TCP/GUNS MW: 8.7 KCL Clean out with 7-5/8" scrapers to 5936' Circulate well change over to brine completion fluid. Pump acid pickle for drill pipe. P/U 4.5" TCP/guns. 02/19/98 (Cl0) TD: 6077' PB: 5946' SUPV:DLW RIH W/BAKER 7-5/8" SUMP P MW: 8.7 KCL Continue to RIH w/4.5" TCP/guns. Fire guns, all shots fired. RIH to clean out. 02/20/98 (Cll) TD: 6077' PB: 5946' SUPV:DLW SET PACKER MW: 8.7 KCL RIH w/sump packer assembly. Stuck coming up work free and down hole to 5861' Stuck and set packer w/ top 8 5861' RIH with cleanout BHA. Reverse circulate complete hole volume. Run 2-7/8" sump packer. 02/21/98 (C12) TD: 6077' PB: 5946' SUPV:DLW PULSE FRAC MW: 8.7 KCL Set packer @ 5714'. RIH with frac and pack screen assembly. Set isolation packers and test each. 02/22/98 (C13) TD: 6077' PB: 5946' SUPV:DLW POOH CHANGE BAKER SAND PO MW: 9.3 KCL Pre-job safety meeting. Started frac on A2 zone. Break down formation had flow from annulus 2 bpm while pumping 15 bpm dowm work string. Started frac A3 zone. Breakdown at 15 bpm 3700 psi had returns from annulus of 5 bpm. Channel behind pipe. Fraced A3 zone. Date: 3/27/98 02/23/98 (C14) TD: 6077' PB: 5946' SUPV:DLW 02/24/98 (C15) TD: 6077' PB: 5946' SUPV:DLW ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 OOH W/BAKER TOOLS MW: 9.2 KCL RIH to frac B/A4 zone 5454'-5520' Impulse frac. Data frac. Frac & pack B/A4 zone. Frac 'D' zone 5382'-5420' Unable to frac zone. RIH W/3.5" DP MW: 9.2 BRINE Test BOPE @ 250/3000. Choke line valve did not test. Replace 3" choke line valve. Test choke line and floor valves @ 250/3000. RIH with chemical cutter and make chemical cut in 4.5" blank pipe 12' up from screen @ 5363' 02/25/98 (C16) TD: 6077' PB: 5946' SUPV:MC RIH W/WASHOVER PIPE MW: 8.8 Tag top of packer @ 5305' Latch into and release packer w/packer retrieving tool. POOH. No fish. Tool never latched into packer. RIH with assembly. Wash into top of packer @ 5305'. Latch into and release packer w/retrieving tool. PU off bottom - hole swabbing. CBU, oil in returns. POOH. LD retrieving tool and fish. 02/26/98 (C17) TD: 6077' PB: 5946' SUPV:MC ON BOTTOM W/OVERSHOT FISH MW: 8.8 Washed over top of fish rotating through hard spots @ 5362' Field safety time out. Tagged fish. Unable to slide over fish. POOH w/overshot. No fish. Apparently rotated off. 02/27/98 (C18) TD: 6077' PB: 5946' SUPV:MC RIH W/FB-1 PACKER ON 3.5" MW: 8.8 Tag top of fish 9' in on kelly @ 5353' Latch onto fish w/overshot and attempt to rotate out of packer without success. RIH w/chemical cutter. Work chemical cutter into top of 4.5" blank pipe @ 5353'. Make cut 10" above seal bore @ 5413' 02/28/98 (C19) TD: 6077' PB: 5946' SUPV:MC POOH W/ SC PLUG MW: 8.8 Tag and latch onto fish @ 5353'. POOH w/fish. Packer top 5416'. RIH w/packer. Tag fish 18' in on the kelly @ 5413' Set packer @ 5411' PU above perfs and shut in to perform flow test on D-sand. 03/01/98 (C20) TD: 6077' PB: 5946' SUPV:MC RU DOWELL TO FRAC MW: 8.8 Tag SC plug @ 5409' Latch plug and pull free. RIH with 3.5" PH6 work string and mule shoe assembly. Work mule shoe through packer and 4 1/2" stub below. Snap into packer @ 5411' Snap out of packer. RIH w/Baker frac pack assembly. 03/02/98 (C21) TD: 6077' PB: 5946' POOH W/FRAC PAC ASSY. MW: 9.2 BRINE Continue to RIH to Frac "D" Zone. Latch into FB-1 Packer @ 5411' Set SC-1 Packer @ 5288' Perform Prac Pack on "D" Date: 3/27/98 SUPV:MC ARCO ALASKA INC. Page: 4 WELL SUMMARY REPORT Zone. Shut down pumps. Well flowing. Shut-in and check pressures. Build 9.2 ppg kill weight fluid on location. Circulate well to 9.2 ppg kill weight brine. Well dead. 03/03/98 (C22) TD: 6077' PB: 5946' SUPV:DW RUN ESPCOMPLETION/RAYCHEM MW: 9.2 KCL POOH stand back 46 stands. R/U to run 2-7/8" completion. P/U and run 2-7/8" tbg. 03/04/98 (C23) TD: 6077' PB: 5946' SUPV:DW RIG RELEASED 0230 HRS. MO Rig moved to 1D-118 rig on well, N/U. MW: 8.8 03/05/98 (C24) TD: 6077' PB: 5946' SUPV:DW RIG RELEASED AT 0230 HRS MW: 8.8 Freeze protect well bore. Change lines to "U" tube diesel to tubing balanced at 2500' Clean pits and blow down lines. End of WellSummary for Well:AK8965 ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-105(W4-6)) WELL 1 D-105 DATE 02/22/98 DAY 1 JOB SCOPE FRAC, FRAC SUPPORT DAILY WORK PUMP "A-2 & A-3" SANDS FRAC & PACK OPERATION COMPLETE I SUCCESSFUL YESI YES Initial Tbg Press I 0 PSI I DALLY SUMMARY KEY PERSON DS-GALLEGOS JOB NUMBER 0221981400.1 UNIT NUMBER SUPERVISOR JOHNS Final Tbg Press I Initial Inner Ann 0 PSII 0 PSI Final Inner Ann0 PSI I Initial Outer 0AnnpsI I Final Outer Ann 0 PSI IPUMPED "A-2" SANDS FRAC WITH 34024 # 16/20 PROPPANT BEHIND FRAC SCREEN. JOB SCREENED OUT EARLY. PUMPED "A-3" SANDS FRAC WITH 117810 # 16/20 PROPPANT BEHIND FRAC SCREEN. TIME 00:20 00:40 02:58 03:00 04:11 05:13 07:27 07:32 LOG ENTRY RIG UP DOWELL , LITTLE RED AND APC SUPPORT. HELD SAFETY MEETING ON RIG FLOOR , DISCUSSED RECENT ACCIDENTS AT KUPARUK. PRESSURE TEST TO 5000 PSI. PUMP IMPLUSE TEST WITH 20 BBLS DIESEL , 17 BPM AND 4500 PSI. PUMP BREAKDOWN 13 BPM AND 2000 PSI. PUMP DATA FRAC AND FLUSH , 130 BBLS FLUIDS 3765 PSI. PUMP 24 BBLS PAD, 5 TO 15 BPM AND 1560 PSI. PUMP 40692 # PROPPANT WITH HEC GEL TO 4.7 PPA. PLACED 340244f PROPPANT BEHIND FRAC SCREEN IN "A-2" SANDS. 08:00 SCREENED OUT EARLY, REVERSED OUT PROPPANT FROM WELLBORE. 09:50 START "A-3" FRAC, WITH IMPLUSE TEST, 20 BBLS DIESEL. GETTING RETURNS FROM BACKSIDE. SUSPECT CHANNELING IN CEMENT JOB. 11:11 PUMP BREAKDOWN WITH 20 BBLS FLUIDS. 13:19 PUMP SECOND IMPLUSE TEST, TO EVALUATE PROBLEM. NORDIC RIG TESTED FRAC TOOL AND PACKER OK. 13:32 PUMP DATA FRAC 14:31 PUMP PAD, WITH 30 BBLS. 14:38 PUMP 130129 # PROPPANT, WITH 117810 # PROPPANT BEHIND FRAC SCREEN. 15:35 SCREENED OUT TO WELL BORE AND REVERSED PROPPANT. 15:38 PULLING FRAC TOOL FOR INSPECTION. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-105(W4-6)) WELL 1D-105 DATE O2/23/98 JOB SCOPE FRAC, FRAC SUPPORT DALLY WORK PUMP "A-4&B" & D" DAY OPERATION COMPLETE I SUCCESSFUL 1 YES I NO InitialTbgPress IFinalTbgPress IlnitiallnnerAnn 0 PSI 0 PSI 0 PSI DALLY SUMMARY KEY PERSON DS-GALLEGOS JOB NUMBER 0221981400.1 UNIT NUMBER SUPERVISOR JOHNS Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSII 0 PSII 0 PSI PUMPED 122,592# 16/20 PROPPANT TO 8 PPA BEHIND FRAC SCREEN IN A-4 & B SANDS. NOTE: ATTEMPTED TO PUMP INTO "D" SANDS BUT IT WOULD NOT TAKE ENOUGH FLUID RATE TO FRAC. BAKER TESTED THEIR FRAC TOOL AND DECIDED THAT THE "D" SANDS FRAC SCREEN IS PACKED OFF WITH FORMATION SAND OR PROPPANT? TIME LOG ENTRY 07:00 MIRU DOWELL FRAC EQUIP, APC SUPPORT 09:00 HELD SAFETY MEETING ON NORDIC RIG FLOOR 10:38 PRESSURE TEST TO 4970 PSI 10:39 PUMP IMPULSE TEST WITH 20 BBLS DIESEL, 13 BPM & 3200 PSI 11:42 PUMP BREAKDOWN WITH 300 BBLS HEC, 15 BPM AND 4200 PSI. FLUSH WITH 51 BBLS DIESEL. 13:03 PUMP DATA FRAC WITH 150 BBLS HEC, 15 BPM 2854 PSI, FLUSH WITH 45 BBLS DIESEL. 14:19 PUMP 86 BBLS HEC PAD, 5 BPM 1561 PSI. 14:30 PUMP 122,592 # OF 16/20 PROPPANT TO A-4 & B SANDS, BEHIND FRAC SCREEN. 15:25 SHUT DOWN FRAC, SCREENED OUT, RIG REVERSED OUT SLURRY FROM TUBING. 16:30 START IMPULSE TEST ON "D" SANDS, TOOK MINIMUM FLUIDS AND PRESSURED UP TO MAX 5000 PSI. ATTEMPTED BREAKDOWN STAGE ONLY TAKING 1 BPM AT 5000 PSI. 19:00 BAKER TESTED THEIR FRAC TOOL AND DECIDED THAT THE "D" SANDS IS PACKED OFF BEHIND THE FRAC SCREEN WITH EITHER FORMATION SAND OR FRAC PROPPANT? ABORTED FRAC ON "D" SANDS. 23:00 RIG DOWN MOVE OFF OF 1 D-105 ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-105(W4-6)) WELL 1 D-105 DATE O3/O2/98 JOB SCOPE FRAC, FRAC SUPPORT DALLY WORK "D" SAND FRAC DAY OPERATION COMPLETE SUCCESSFUL 2 YES YES Initial Tbg Press J Final Tbg Press I Initial Inner Ann 50 PSII 150 PSII 10 PSI DAILY SUMMARY KEY PERSON DS-GALLEGOS JOB NUMBER 0221981400.1 UNIT NUMBER SUPERVISOR CHANEY Final Inner Ann Initial Ou'ter Ann I Final Outer Ann 15 PSI 0 PSI I 0 PSI "D" SAND FRAC COMPLETED THRU FLUSH & DEHYDRATED SLURRY TO COMPLETE GRAVEL PACK. INJECTED 92985 LBS OF PROP IN THE FORM W/8.4# PPA OF #16/20 @ THE PERF'S. MAXIMUM PRESSURE 4500 PSI & F.G.(.68). TIME 04:30 LOG ENTRY MIRU DOWELL FRAC EQUIP & APC VAC TRUCKS. HELD SAFETY MEETING (28 ON LOCATION) 08:30 PRIMED UP LINES AND PT'D HIGH PRESSURE LINES TO 5000 PSI. 09:10 PUMP IMPULSE TEST W/DIESEL @ 18 BPM. SLURRY VOLUME PUMPED 20 BBLS. MAXIMUM & ENDING PRESSURE 4500 PSI. S/D AND OBTAINED ISIP OF 904 PSI. STOOD-BY FOR 1 HOUR. 10:10 11:10 12:20 13:15 PUMP BREAKDOWN W/50# HEC - 3% KCL & DIESEL @ 20 TO 15 BPM. STEPPED RATE DOWN AND OBTAINED EARLY ISIP OF 847 PSI W/F.G. @ (.67). CRANKED BACK UP AND FLUSHED W/DIESEL S/D AND OBTAINED ISIP OF 1199 PSI W/F.G. @ (.68). MAXIMUM PRESSURE 4500 PSI AND ENDING PRESSURE 2600 PSI. TOTAL SLURRY VOLUME PUMPED 351 BBLS. MONITORED WHTP AND PULSED TO PICK CLOSURE TIME. CLOSURE TIME OF 4 MINS @ 1168 PSI. PUMP DATAFRAC W/50# HEC - 3% KCL & DIESEL @ 5 TO 15 BPM. SLURRY VOLUME PUMPED 196 BBLS. MAXIMUM PRESSURE 2800 PSI AND ENDING PRESSURE 2500 PSI. S/D AND OBTAINED ISIP OF 1190 PSI W/ F.G. @ (.68). MONITORED WHTP FOR CLOSURE. CLOSURE TIME OF 15 MINS @ 1126 PSI. PAD VOLUME = 40 BBLS. PUMP FRAC W/50# HEC - 3% @ 5 TO 15 BPM. COMPLETED THRU FLUSH. SLOWED RATE DOWN AT THE END AND DEHYDRATED SLURRY AND COMPLETED GRAVEL PACK. PUMPED 93730 LBS OF #16/20 PROP. INJECTED 92985 LBS OF PROP IN THE FORMATION W/8.4# PPA OF #16/20 @ THE PERF'S. LEFT 745 LBS OF PROP IN THE WELLBORE. MAXIMUM AND ENDING PRESSURE 3200 PSI. 14:00 15:00 R/D COMPLETED AND FRAC EQUIP CLEAR OF NORDIC. REVERSED OUT TBG W/SW USED 100 BBLS (2.5 TBG VOLUMES). STARTED R/D EQUIP. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE i ARCO ALASKA~ iNC. KRU / iD-!05 500292284300 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/12/98 DATE OF SURVEY: 011998 MWD SURVEY JOB NUMBER: AKMM80096 KELLY BUSHING ELEV. = 111.50 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. .00 .00 -111.50 0 0 N .00 E .00 .00N 120.00 120.00 8.50 0 0 N .00 E .00 .00N 184.00 184.00 72.50 0 15 S 36.00 E .39 .IlS 277.00 277.00 165.50 0 31 S 63.00 E .35 .47S 380.67 380.61 269.11 3 13 N 62.76 E 2.84 .64N .00E .00 .00E .00 .08E -.05 .58E -.07 3.60E 2.53 471.41 470.98 359.48 6 49 N 59.98 E 3.98 561.36 559.99 448.49 9 45 N 46.67 E 3.88 650.71 647.61 536.11 12 49 N 38.43 E 3.86 743.89 737.54 626.04 17 23 N 37.00 E 4.92 833.29 821.64 710.14 22 12 N 38.96 E 5.44 4.51N 10.53E 9.58 12.41N 20.71E 21.79 25.38N 32.38E 39.04 44.61N 47.20E 63.26 68.43N 65.87E 93.43 920.69 900.72 789.22 28 5 N 38.39 E 6.73 1011.79 979.24 867.74 32 47 N 35.83 E 5.35 1104.08 1055.20 943.70 36 24 N 34.36 E 4.03 1199.34 1130.76 1019.26 38 34 N 35.07 E 2.32 1293.94 1202.52 1091.02 42 43 N 35.75 E 4.40 97.43N 89.06E 130.41 134.26N 116.83E 176.46 177.15N 146.93E 228.83 224.80N 179.95E 286.79 275.00N 215.66E 348.37 1390.20 1270.49 1158.99 47 24 N 34.16 E 5.01 1484.42 1332.22 1220.72 50 43 N 33.64 E 3.54 1579.36 1390.53 1279.03 53 28 N 34.64 E 3.02 1867.69 1556.54 1445.04 56 12 N 33.49 E 1.00 2153.92 i714.41 1602.91 56 50 N 33.75 E 23 330.86N 254.66E 416.47 389.93N 294.35E 487.64 451.92N 336.40E 562.54 647.21N 468.39E 798.24 846.02N 600.58E 1036.99 2436.77 1872.97 1761.47 54 57 N 34.96 E 75 1039.35N 732.71E 1271.14 2723.99 2038.69 1927.19 54 33 N 32.76 E .64 1234.11N 863.40E 1505.67 3005.54 2203.52 2092.02 53 46 N 31.66 E 42 1427.22N 985.06E 1733.85 3288.50 2367.62 2256.12 55 19 N 31.91 E .56 1623.13N 1106.47E 1964.23 3569.28 2526.73 2415.23 55 39 N 35.48 E 1 05 1815.58N 1234.80E 2195.54 3856.15 2687.25 2575.75 56 17 N 32.81 E 80 2012.30N 1368.20E 2433.21 4140.63 2847.57 2736.07 55 5 N 32.19 E .46 2210.48N 1494.46E 2668.15 4423.04 3007.32 2895.82 56 0 N 33.15 E 43 2406.49N 1620.17E 2900.99 4520.37 3063.57 2952.07 53 22 N 32.86 E 2.71 2473.10N 1663.43E 2980.41 4615.37 3123.22 3011.72 48 48 N 32.12 E 4.85 2535.43N 1703.15E 3054.30 4710.75 3188.90 3077.40 44 7 N 32.24 E 4.92 2593.94N 1739.96E 3123.41 4804.47 3258.49 3146.99 39 57 N 32.48 E 4.45 2646.94N 1773.54E 3186.14 4897.98 3332.51 3221.01 35 20 N 32.72 E 4.92 2695.05N 1804.30E 3243.23 4993.30 3412.87 3301.37 29 38 N 30.88 E 6.07 2738.52N 1831.33E 3294.40 5089.76 3497.97 3386.47 26 30 N 28.57 E 3.45 2777.91N 1853.87E 3339.68 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA INC. KRU / 1D-i05 500292284300 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/12/98 DATE OF SURVEY: 011998 MWD SURVEY JOB NUMBER: AKMM80096 KELLY BUSHING ELEV. = 111.50 FT. OPERATOR: ARCO ALASKA iNC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 5185.68 3584.94 3473.44 23 22 N 30.34 E 3.35 2813.13N 1873.72E 3380.01 5280.69 3672.69 3561.19 21 42 N 32.13 E 1.90 2844.27N 1892.58E 3416.38 5376.47 3761.78 3650.28 21 22 N 32.06 E .34 2874.05N 1911.26E 3451.53 5468.68 3847.72 3736.22 21 8 N 32.27 E .26 2902.35N 1929.05E 3484.95 5562.35 3935.09 3823.59 21 7 N 31.99 E .11 2930.95N 1947.02E 3518.71 5657.34 4023.70 3912.20 21 5 N 32.42 E .17 2959.90N 1965.25E 3552.91 5750.57 4110.85 3999.35 20 30 N 31.55 E .70 2987.98N 1982.79E 3586.01 5844.50 4198.93 4087.43 20 8 N 31.59 E .38 3015.78N 1999.87E 3618.62 6030.75 4373.91 4262.41 19 55 N 31.17 E .14 3070.27N 2033.11E 3682.40 6093.00 4432.43 4320.93 19 55 N 31.17 E .00 3088.42N 2044.09E 3703.60 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3703.60 FEET AT NORTH 33 DEG. 29 MIN. EAST AT MD = 6093 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 33.54 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 6,093.00' MD SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA .PAGE 3 ARCO ALASKA INC. KRU / 1D-105 500292284300 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/12/98 DATE OF SURVEY: 011998 JOB NUMBER: AKMM80096 KELLY BUSHING ELEV. = 111.50 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES POR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 -111.50 1000.00 969.29 857.79 2000.00 1630.12 1518.62 3000.00 2200.25 2088.75 4000.00 2767.09 2655.59 .00 N .00 E .00 129.14 N 113.11 E 30.71 30.71 738.91 N 529.07 E 369.88 339.17 1423.41 N 982.72 E 799.75 429.87 2112.88 N 1433.02 E 1232.91 433.16 5000.00 3418.70 3307.20 6000.00 4345.00 4233.50 6093.00 4432.43 4320.93 2741.36 N 1833.02 E 3061.30 N 2027.68 E 3088.42 N 2044.09 E 1581.30 348.40 1655.00 73.70 1660.57 5.57 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 ARCO ALASKA INC. KRU / iD-105 500292284300 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/12/98 DATE OF SURVEY: 011998 JOB NUMBER: AKMM80096 KELLY BUSHING ELEV. = 111.50 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN t00 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -111.50 111.50 111.50 .00 211.50 211.50 100.00 311.51 311.50 200.00 411.50 300.00 1.64 N .00 N .00 E .00 N .00 E .21 S .15 E .43 S 1.13 E 5.46 E .14 .00 .00 .00 .01 .13 .00 .00 .01 411.64 512.28 511.50 400.00 613.78 611.50 500.00 716.70 711.50 600.00 822.37 811.50 700.00 932.97 911.50 800.00 7.49 N 14.94 E .78 .64 19.42 N 27.40 E 2.28 1.50 38.39 N 42.48 E 5.20 2.93 65.27 N 63.33 E 10.87 5.67 102.06 N 92.68 E 21.47 10.60 1050.52 1011.50 900.00 1174.70 1111.50 1000.00 1306.26 1211.50 1100.00 1452.12 1311.50 1200.00 1614.74 1411.50 1300.00 1787.51 1511.50 1400.00 1966.52 1611.50 1500.00 2148.60 1711.50 1600.00 2329.71 1811.50 1700.00 2503.88 1911.50 1800.00 2677.09 2011.50 1900.00 2849.55 2111.50 2000.00 3019.04 2211.50 2100.00 3189.84 2311.50 2200.00 3365.71 2411.50 2300.00 151.71 N 129.27 E 212.22 N 171.12 E 281.86 N 220.57 E 369.32 N 280.59 E 475.39 N 352.56 E 591.99 N 431.64 E 715.70 N 513.71 E 842.31 N 598.11 E 967.52 N 682.48 E 1084.39 N 764.20 E 1201.98 N 842.72 E 1320.14 N 918.75 E 1436.48 N 990.78 E 1554.25 N 1063.58 E 1676.77 N 1140.52 E 39.02 63.20 94.76 140.62 203.24 276.01 355.02 437.10 518.21 592.38 665.59 738.05 807.54 878.34 954.21 17.55 24.18 31.56 45.87 62.62 72.77 79.00 82.08 81.11 74.17 73.21 72.46 69.48 70.80 75.87 3542.29 2511.50 2400.00 3719.63 2611.50 2500.00 3899.85 2711.50 2600.00 4077.60 2811.50 2700.00 4252.33 2911.50 2800.00 1797.40 N 1221.93 E 1916.85 N 1306.65 E 2042.86 N 1387.90 E 2166.73 N 1466.92 E 2288.00 N 1543.26 E 1030.79 1108.13 1188.35 1266.10 1340.83 76.59 77.33 80.23 77.74 74.74 4430.46 3011.50 2900.00 4597.40 3111.50 3000.00 4741.86 3211.50 3100.00 4871.98 331i.50 3200.00 2411.63 N 1623.52 E 2523.90 N 1695.89 E 2612.01 N 1751.38 E 2682.16 N 1796.03 E 1418.96 1485.90 1530.36 1560.48 78 . ± 66.94 44.46 30.12 SPERRY-SUN DRILLING SERVICES ANCHOraGE ALASKA -PAGE ARCO ALASKA iNC. KRU / iD-i'35 500292284300 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/12/98 DATE OF SURVEY: 011998 JOB NUMBER: AKMM80096 KELLY BUSHING ELEV. = 111.50 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 4991.70 3411.50 3300.00 2737.81 N 1830.89 E 1580.20 19.71 5104.84 3511.50 3400.00 2783.74 N 1857.07 E 1593.34 13.14 5214.61 3611.50 3500.00 2823.03 N 1879.52 E 1603.11 9.78 5322.46 3711.50 3600.00 2857.34 N 1900.79 E 1610.96 7.85 5429.85 3811.50 3700.00 2890.50 N 1921.58 E 1618.35 7.39 5537.06 3911.50 3800.00 2923.22 N 1942.19 E 1625.56 7.22 5644.26 4011.50 3900.00 2955.93 N 1962.73 E 1632.76 7.20 5751.26 4111.50 4000.00 2988.18 N 1982.91 E 1639.76 7.00 5857.89 4211.50 4100.00 3019.71 N 2002.29 E 1646.39 6.63 5964.37 4311.50 4200.00 3050.91 N 2021.40 E 1652.87 6.48 6070.74 4411.50 4300.00 3081.93 N 2040.16 E 1659.24 6.37 6093.00 4432.43 4320.93 3088.42 N 2044.09 E 1660.57 1.33 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ..... ~. Tyl~'e of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Other _X Change approved program _ Pull tubing _ Variance _ Perforate _ ESP change-out 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__X RKB 41 feet , 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk River Unit 4. Location of well at surface 8. Well number 134' FSL, 595' FEL, Sec. 14, T11N, R10E, UM 1D-105 At top of productive interval 9. Permit number / approval number 2271' FNL, 1320' FWL, Sec. 13, T11N, R10E, UM 97-236 At effective depth 10. APl number 50-029-22843 At total depth 11. Field / Pool 2058' FNL, 1452' FWL, Sec. 13, T11 N, R10E, UM Kuparuk River Field / West Sak Oil Pool 12. Present well condition summary Total depth: measured 6093 feet Plugs (measured) true vertical 4432 feet ORIGINAL Effective depth: measured 5714 feet Junk (measured) true vertical 4077 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor ~0' 16" 9 cu yds High Early 121' 121' Surface 6036' 7.625" 570 bbls AS IIILW, 366 bbls 6077' 4073' Class G, 60 sx Class G Production Perforation depth: measured 5382'-5420', 5454'-5520', 5550'-5600', 5630'-5710' ~ECE!V true vedical 3767'-3802', 3834'-3896', 3924'-3970', 3998'-4073' ~..:' ~.; ..~., --:- Tubing (size, grade, and measured depth 2.875", 6.5¢, L-80 @ 5286' MD 0il & Gas Cons, Anchorage Packers & SSSV (type & measured depth) Baker SC-1 Gravel Pack packer @ 5299' WLM, Baker FV-1 sump packer @ 5422' WLM, No SSSV Baker Isolation packer @ 5427' WLM & 5526' WLM & 5606' WLM, Baker FB-1 sump packer @ 5714' WLM 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __X Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic __ 14. Estimated date for commencing operation 15. Status of well classification as: October 13, 1999 16. If proposal was verbally approved Oil __X Gas__ Suspended __ Name of approver Date approved Service __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mark Chambers 265-1319 Signed Title: Drilling Team Leader Date Randy Thomas Prepared by' Sharon Allsup-Drake FOR COMMISSION USE ONLY Conditionsf~.(~Joroval: Notify Commission so representat~e may witness , I Approval..~no. _,.,r O,,j~ ~"~ Plug integrity__ BOP Test ~Z' Location clearance__, ~;; ~'~ /~//~! (~.9~ Mechanical Integrity Test Subsequent form required 10- t~ he Commission ORIGINAL SIGNED BY Commissioner Date Robert N. Chdstenson Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE West Sak 1D-105 GENERAL WORKOVER PROCEDURE PRE-RIG WORK: 1. RU Slick Line Unit. RIH and pull Shear Valve from GLM @ 5189' leaving an open pocket. 2. Set BPV in tubing. 3. Prepare Location for Nordic Rig 3. GENERAL WORKOVER PROCEDURE: 1. MIRU Nordic Rig 3. Lay hard-line to tree. Pull BPV and VR plug. 2. Load pits with 8.7 ppg filtered 3% KCL kill weight brine. Displace tubing and annulus with kill weight brine. SI well and monitor pressure to ensure well is dead. Set BPV. 3. ND / NU and test BOPE. 4. Screw in landing joint. POOH standing back 2-7/8" tubing and spooling up ESP Cable and Heat Trace. 5. Load, strap and drift 3-1/2" x 2-7/8" workstring. 6. RIH w/clean@ut assembly PU 3-1/2" x 2-7/8" workstring off rack. 7. Clean@ut to PBTD and POOH laying down workstring. o RIH w/2-7/8" tubing, GLM's, Isolation Assembly and Heat Trace (isolation assembly will consist of Baker Seal assembly, 2-7/8" Hyd 511 tubing as required and Baker '80-40' Snap Latch Assembly to isolate the D-Sand for future well testing). 9. Snap into Baker SC-1 Packer @ 5299' MD. 10. Snap out of SC-1 Packer, spacout, and land tubing hanger. RILDS, install two-way check and test tubing hanger. 11. ND/NU/Test 12. Freeze protect with diesel to +/- 2000' TVD. Lower Limit: 5.0 days Expected Case: 6.0 days Upper Limit: 8.0 days No problems encountered. Problems pulling ESP completion or cleaning out to PBTD. MAC 10/1/99 WEST SAK (1D-105) (Frac-Packed Producer) Proposed Completion Alaska, Inc. 3-1/2" Vetco-Gray Tubing Hanger w/2-7/8" L-80 EUE 8rd Mod Pup Joint, ESP Power Cable Penetrator, Heat Trace Penetrator and TEC Wire Penetrator. 1 Joint 2-7/8" 6.5# L-80 EUE 8rd Mod Tubing. 2-7/8" 6.5# L-80 EUE 8rd Mod Spaceout Pups as Required for Heat Trace. 16" 62.5# H-40 @ 121' MD Stage Tool @ 2245' MD Raychem Heat Trace @ +/- 2265' MD Directional KOP = 381' Max Angle = 57 Deg @ 2154' MD Avg Angle Thru W.Sak = +/- 21 Deg 2-7/8" 6.5# L-80 EUE 8rd Mod Tubing to Surface (as required). 7-5/8" Marker Joint (+/- 50' Above Top Perforation) Drillers TD @ 6093' MD 5' Handling Pup 2-7/8" 6.5# L-80 EUE 8rd Mod Tubing. 2-7/8" x 1" Camco 'KBMM' GLM run open @ +/-5189' MD w/Shear Circulating Valve. (pinned for 3000 psi Tbg / Csg differential) 5' Handling Pup 2-7/8" 6.5# L-80 EUE 8rd Mod Tubing. 1 joint 2-7/8" 6.5# L-80 EUE 8rd Mod Tubing. Baker '80-40' Snap Latch Seal Assembly w/2-7/8" Hydril 511 Pin down and 6' crossover pup installed on t 2-7/8" 6.5" L-80 Hydril 511 Tubing to Snap Latch Assembly (as required). Baker '80-32' Seal Assembly (10' w/2-7/8" Hydril 511 Box up). Note: Packer and Perforation depths are wireline correlated to AAI MWD Log 2/28/98. There is an 11' difference between Nordic 2 drill pipe and wireline. Nordic 2 shows top of SC-1 Packer @ 5288' MD drill pipe. Baker SC-1 Gravel Pack Packer @ 5299' MD D-Sand Perfs: 12 SPF 5382' - 5420' Frac and Pack w/Carbolite Baker FB-1 Sump Packer @ 5422' MD Tubing stub @ 5424' MD Baker Isolation Packer @ 5427' MD B / A4-Sand Perfs: 12 SPF 5454' - 5520' Frac and Pack w/Carbolite Baker Isolation packer @ 5526' MD A3-Sand Perfs: 12 SPF 5550' - 5600' Frac and Pack w/Carbolite Baker Isolation Packer @ 5606' MD A2-Sand Perfs: 12 SPF 5630' - 5710' Frac and Pack w/Carbolite Baker FB-1 Sump Packer @ 5714' MD PBTD @ 5861' WL (Top of Sump Packer Stuck and Set) 7-5/8" 29.7# L-80 BTC Mod @ 6077' MD MAC 9/29/99 WEST SAK (1D-105) (Frac-Packed Producer) Current Completion Alaska, Inc. 7-5/8" Marker Joint (+/- 50' Above Top Perforation) Drillers TD @ 6093' MD 3-1/2" Vetco-Gray Tubing Hanger w/2-7/8" L-80 EUE 8rd Mod Pup Joint, ESP Power Cable Penetrator, Heat Trace Penetrator and TEC Wire Penetrator. 2-7/8" 6.5# L-80 EUE 8rd Mod Spaceout Pups as Required for Heat Trace. 16" 62.5# H-40 @ 121' MD Stage Tool @ 2245' MD Raychem Heat Trace @ +/- 2265' MD 2-7/8" 6.5# L-80 EUE 8rd Mod Tubing to Surface (as required). 5' Handling Pup 2-7/8" 6.5# L-80 EUE 8rd Mod Tubing. Directional KOP -- 381' Max Angle = 57 Deg @ 2154' MD Avg Angle Thru W.Sak = +/- 21 Deg 2-7/8" x 1" Camco 'KBMM' GLM @ +/-5189' MD w/Shear Circulating Valve. (pinned for 3000 psi Tbg / Csg differential) 5' Handling Pup 2-7/8" 6.5# L-80 EUE 8rd Mod Tubing. 1 Joint 2-7/8" 6.5# L-80 EUE 8rd Mod Tubing. 6' Pup Joint 2-7/8" 6.5# L-80 EUE 8rd Mod Tubing. (BOT double box coupling on top providing the port for the Baker Sentry Gauge) 8' Handling Pup 2-7/8" 6.5# L-80 EUE 8rd Mod Tubing Centrilift ESPCP (components as listed below) w/bottom set @+/- 5286' MD. Centrilift Discharge FPHVDIS. Centrilift Upper Tandem Pump 142FC925 Centrilift Lower Tandem Pump w/Intake 9FCNPSH Centrilift Seal Section: GSFT DB HL PFS Centrilift Motor: 57 HP KMH 1315/26 Baker SC-1 Gravel Pack Packer @ 5299' MD D-Sand Perfs: 12 SPF 5382' - 5420' Frac and Pack w/Carbolite Baker FB-1 Sump Packer @ 5422' MD Tubing Stub @ 5424' MD Baker Isolation Packer @ 5427' MD B / A4-Sand Perfs: 12 SPF 5454' - 5520' Frac and Pack w/Carbolite Baker Isolation packer @ 5526' MD A3-Sand Perfs: 12 SPF 5550' - 5600' Frac and Pack w/Carbolite Baker Isolation Packer @ 5606' MD A2-Sand Perfs: 12 SPF 5630' - 5710' Frac and Pack w/Carbolite Baker FB-1 Sump Packer @ 5714' MD PBTD @ 5861' WL (Top of Sump Packer Stuck and Set) 7-5/8" 29.7# L-80 BTC Mod @ 6077' MD MAC 10/1/99 FROM: CPF1 PROD FRX NO. : 90? 659 ??49 10-06-99 09:43A P.el To: Blair Wondzell Fax: 276,~7542 ~ Vol h...cxch From: Tony Long Date: 10/06/99 Re: 1D-105 Proposed Gaslift Completion Pages: 3 + cover CC: [Click here and type name] [] Urgent X For Review [] Plea~e Commc~t ~ Please Reply [] Please Recycle Blair, As requested I am sending the Westsak producer 1D-105 7-5/8" casing and cementing details to aid in your anaJysis of the proposed temporary continuous gaslift completion. A,~ to your questions on the expected surface gasl~ injection and produced fluid temperature we directly measured the ~xFected gaslJff Jnj~zCion tmmp~rature but h~d to estimate the produced fluid tempe~tum. We -~r- C.\~ ~,~Q¢.=,'~",¢¢ currently do not have anyWestsak producers on gas lift and the ESP tubing completions are heat traced through the permafrost. The expected surface gaslift injection temperature is 35_ degm:~e, s F. This value was measured from the current gaslift header at the 10 drillsite and the ambient temperature was ~25degrees F. The gaslifl is heated at the CPF but is not reheated at the ddllsite. The estimated expected produced fluid temperature is 40 degrees F. The reservoir temperature varies from 70 -75 degrees. Tony Long ARCO Alaska, Inc. Kuparuk CPF-1 Production Engineer (907)-659-7493 FROM: CPF1 PROD FRX 'l NO.: 907 659 7749 WELL H I S TO .P,.~_ H A N C)_OS/~ 10-06-99 09:44M Wel~ iD.tOG G~? 5ITP YY.F.J~ INFQ.BMATION To Production TO Dnllin~ X AFE Number AK ~98~ Orillem TD 6og2' SICP o psi PBTD/Top of fill or Junk 5~4s' Date l'e~ged 16' Ca.~i~i Prose. I~PV In~talleM: Yes X No BHP Oownhole Plugs: Yes X No P,.~ker fluid Tubi~ fluid 3% KCL We~t 8,7 ~pg .._ RKB 40.55' KOP 300' Avg Ho~ Angle Max angle of 56,04 ~ 2154' Nolo Angle ¢~ TO 19.9,..'3 Cohd. Surf. LINER: Tubing: Well Head ~' sEE f. mm Ia TCP NOS _Daep_.~n f2 $3~2' 5420' 4-112' 43C 12 sPf t2 5454' SB2~' t 2 5550' 5600' t2 5630' $71D' .- CASING/TUBING DAT.~ Size Wt. Gra~e Conn. 16' 6~' 58~ H-40 Welded ~2~' ?-,5/8' Zg.?m L.~0 STC-m 6077' Ri~t relea,~ed subsequent to f~ well ¢,',mp~'etfott ns required on SLale Odlling ~erm~t: -.-.-.--~ Ve~~ No Ir no, spe¢-i~, remaining opemt~: HGR _C, DMPLJ~TION INFOE, JyJATION M~r/Type/S~e../dummy er OdficelLa[ch AB~ Vetco O~. Tubinj~.tteneer WI 2.?18' L-aO EUE 8rd ~ P..u..~. Jetta, ._LMD) ENVIRONMEN,_TAL SIT~: IN~E,~[1,O, Ei Locath)n dea~. P GLM :~.7/~' X 1" Camco 'KBMIVf' (Open ~oCket) R~ych~wl Heat Trace Cable attached 10.00' down lmm Ihe top ofj_oint ~$. Z. 271' b~low hanger Bake' DL~char~- Sen~ot Gauqe replac~l coUar I~tween ej pu.p ~n~ joint #t. $23Z Baker Inl31~e Sense? Gauo~e instellmt 3' bek~w Oischa erg)~ 52,35' Gaugie on 6' p, up, ESP Cenl~iR Pum~,.A.'~Sy 4.72 OD I~SP o,~. tibia ;ump m__r.,,y ;~1~ FPMTAR 1.1 142 s~sge ~. ~ 3 OD ESP CenUl~itl Tendon Se<il Section GST3 OB I=F,~ ,~. 13 OD ESP Cen~r~liR PCESP Motor $7 HP 1315/~) 5.620" OD Don~d L. Wesler Drilling Dept. Rap, P~odu~oWOper Dept. Rep. · .GE.b/ER. AL !N[ORMATtON I=EJ~FOI:b~TIONS 5246' 5260' 5267~ 527~' 52~6' 90 bb~s dles~ balanced on ~op of main<) ar, d ennulus, t-~o~ flue{/w~h 9 ~, ppg 3% KCL I~nne from ale;S01 cap lo PBTD, ( 2500' diesel cap ) Attached tubiMg detail 99tfO ~.~e?~So r Dot FROM: CPF1 PROD FRX HO. : 907 659 7749 10-06-99 09:44R P.03 ARCO Alaska, Inc, Cementing Details Well#; 1D-105 Field: West sak, Kuparuk oate'~ .... 1/24/98 casing size Hole Diameter KOP & Angle Shoe Depth LC Depth I % washout 7-5/8" 9-7/8" 300'- 56* 6077' 594_61.J. Centralizers State type used, intervals covered a..n._d, spacing. ....... 61 Gemoco Bow Spring Centralizers: O.n.~ on each of 1mt 17 joints, 1st 3 on stop rincjs in middle of float jo!.nt__~._;._.One on coupling f¢[.every 3rd ieint to surface, with one on stop ring in middle of joint on each side of Gemoco.,stage collar. Mud Weight ;PV(prior cond) [PV(after cond) IYPi'pri~r co~'~)''' YP(after cond) 9.8/9,3 30 24 I ............ 80 ............. 30 Gels before Gels after Total VolUme Circulated ............... 30/70.. ...... 15/2.8 ...... Stage 1' 800 B,b.!s I St, a¢.e 2: 20.0,,Bbls Spacer Type Volume Weight _.W.. ater ........ 50 Bbls / 40._B.b. Is ..... 8.34 ppg Lead Type I Mix water tamp No. of sacks Weight Yield Cement AS III LWI -75* F 210 _~x/360 Sx 10..5_ppg 4.42,.,cfs Additives: Class G + 3,5% D44 + 0,6% D46 + 30% D53 + 1,5% D79 + 50% D124 + 1,5% $1 Cement Class G & AS II -75'F ] 366 sx/60 sx 15.8/16,7 1,16 / 0,93 Additives: Stage 1: Cla~ G + 0'12% D46"'~- 0.3% D65 + 0.55% D156 + 1% S1 St,.a, ge 2:_A, rctic se_ti .. ~iSpiacement Rate(before tail at shoe) Rate(tail around shoe) Str, Wt, Up 6.5 BPM 6,0 BPM 280K Reciprocation ler~'{~- ....... Recipl:ocation speed Str. W-t.~'~V~n- ....... -15' --20 FPM 120K Theoretical Displacement Actual Displacement Str. Wt. in mud '273 Bbls / 103 Bbls 273 Bbls / 104.§ Bbls 154.6K Calculated t°'P °f cement I CIP Bumped plug tFIoats held Cemented to Surface 0732: 1/2._4_ ................... Y_e._s ... Yes .......... 'Remarks: Include whether full returns were obtained, reciprocation throughout operation an.d..~n.y' other pertinent information, Stafle'~l' Had full returns throu~lhout job. ,,Reciprocated pipe until cmt. reached shoe. 3um..p_ed piu9 and open_e~.?t_age collar w/2200 psi. Circulated 100 b, bl cement to surface. ,,, Stage #2: Got'l.0_:0_..ppg cement back after 249 b_b!.!e_a_d- s!ur.ry pumiced. Had 10.5 ppg cement in returns after 283 bbls ?.!u. rr)/pumped, Switched to tail and ¢ispla_c_.e..d.._C,e,_rnent.. ................... Bumped plu~ and closed st_a~le collar ~ 0950 psi, _ ~. ....... -,, ---- ,,. ,~, ........................................ Cer~ent ~-~pany .......... IRig Contractor tsignature Dowell ,.,[. Parker R1¢.~.2._45 ............ I G.R.. Whidock FROM: CPF1 PROD FRX NO.: 907 659 7749 10-06-99 09:44~ P.04 CASING I TUBING ! LINER DETAIL 7_.,5/8" ~ace/Producfion Ca~inq ARCO Alaska, Inc, Subsidiary of Atlantic Richfield Company West Sak, Kuparuk WELL: ID-10S DATE: '112'1198 1 OF 2 # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH 4O.55 52 J~,s Joint 'B ' Joint 'A ' 75 Jts 13 Jts I Jt RKI3 to Landing Ring .... VETCO-Gra¥ Fluted Mandrel Casing H..anger 7-5/8", 29.7#, L-80, ABM-BTC Cesin~t-4/924¢143 7-5/8", 29.7#, L-80.~,..ABM-BTC Casing - Baker Locked Gemoco 754 Cementing Stage Collar 7-5/8"~ 29,7,.~, L-80, ABM-BTC ,,.C.,asin~ - Baker Locked 7-5/8", 29.7#, L-80, ^BM-BTC Casing-4FIT~91 ,Marker Pup Jr: 7-5/8", 29..7,#, L-8_0, ABM-BTC Casing Marker Pup Jr; 7-5/8", 29.7#,._~L,.80, ABM-BTC Casin_g 7-5/8", 29.7#, L-80, ABM-BT_C Cas,!,n~H4f4-~16 Gemoco Insert Shut-Off Baffle 7-5/8", 29.7#, L-80, ASM-BTC Cas, in~l--#3 Gemoco Float Collar 7-5/_8'_'.,.29,7#, L-80, ABM-BTC Casinq - Baker Locked--~2 7-5/8", 29.7#, L-80, ABM-BTC Ca. sin~--4fl Gemoco Float Shoe 2.15 2159.97 42.64 2,80 37,08 3083,64 21.07 20.85 535.18 42.71 1 Jt 1 Jt 1,40 42.50 42.61 1.50 TD = $092' MD (-15' Ra~h_O/e' I~akerLock to Top of Baffle Collar Joint (LC)~ _plus Staqe Collar to Jts 'A' & 'B' 61 Bow Sprin,¢[ ,,Centralizers Install a Centralizer on the fi_.r~, t 17joint.$ (3 S. top ~ings, 17 Centralizers), .Install a Centralizer on everjf 3rd joint to Surface, Install a Centralizer on a Stop.. PJ'ng o..n_. BakerLock Jts 'A' & 'B' Run Double-Pup Marker Joint between Jts #16 & #17. Run Stage Collar & BakerLock Jts 'Il' & 'B' between Jts #91 & #92. Run Fluted Casing HapFer on Top or Jt #I43. Leave..7...Jts in the Shed (J~..#144 thru #150) PAGES DEPTH TOPS 40.55 42.70 2202.67 2245.31 2248.11 2285.19 5368.83 5389.90 5410.75 5945.93 5945.93 5988.64 5990.04 6032.54 6075.15 6076.65 : _ _ :: ~.. Remarks: String. Weights with Blocks:280K# Up, 120K¢ On, 76K# Blocks..Ran 145 joints of casing.:...plus Marker Joint. Drifted casing with 6.750" plastic rabbit. Used Arctic Grade APl Modified No Lead thread co.m__pound on all connections (National = BOL 2000.}. Made up connections to base of.,t..riangle, st_amp. Parker Ffig #245 Dri/lin~/.Su~ervisor; G,R. Whitlock O I::1 I I--i-- I IM G WELL LOG TRANSMITTAL To: RE: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 1D-105, AK-MM-80096 February 18, 1998 The technical data listed below is being submftted herewith. Please address any problems or concerns to the attention of: Jim Galvin. Sperry-Sun Drilling Services. 5631 Silverado. Way, #G, Anchorage, AK 99518 1D-105: 2" x 5" MD Resistivity & Gamma Ray Logs' 50-029-22843-00 2" x 5" TVD Resistivity & Gamma Ray Logs' 50-029-22843-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 I~11 I__1__ I IM 13 S I:: I::! ~./I C I:: S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 February 18, 1998 RE: MWD Formation Evaluation Logs 1D-105, AK-MM-80096 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin. Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22843-00 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company 13-Feb-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-105 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey' Window / Kickoff Survey: Projected Survey: 0.00' MD n/a' MD 6,093.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company TONY KNOWLE$, GOVERNOR ~LASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 19. 1997 Michael Zanghi Drilling Superintendent ARCO Alaska. Inc. P O Box 100360 Anchora,,e AK 99510-0360 Re: West Sak l D- 105 (C7) ARCO Alaska, Inc. Permit No 97-236 Sur. Loc.: 134'FSL. 595'FEL. Sec. 14; T11N, R10E, UM Btmhole Loc: 2083'FNL. 1433'FWL, Sec. 13, T11N, R10E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required bv law fi'om other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. 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 max; be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. · Chairman ~.~.~ BY ORDER OF THE COMMISSION dlffenclosures cc: Department of Fish & Game. Habitat Section xv/o encl. Department of Environmental Conservation w/o encl. · ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill lb TypeofWell Exploratory FI StratigraphicTest Fl Development Oil X Re-Entry Deepen Service r~ Development Gas FI SingleZone X Multiple Zone Fl 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 71' feet Kuparuk River Field 3. Address 6. Property Designation West Sak Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25650, ALK 468 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 134' FSL, 595' FEL, Sec. 14, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2230' FNL, 1338' FWL, Sec. 13, T11N, R10E, UM West Sak 1D-105 (C7) #U-630610 At total depth 9. Approximate spud date Amount 2083' FNL, 1433' FWL, Sec. 13, T11 N, R10E, UM 1/21/98 $2O0,O0O 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1D-02 6051' MD 2083' @ TD feet 18' @ 120' feet 2560 4372' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 400' feet Maximum hole angle 55.8° Maximum surface 1464 psig At total depth 1925 psig ('I'VD) 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 77' 41' 41' 118' 118' +_.200 CF 9.875" 7.625" 29.7# L-80 BTC MOl-:. 6010' 41' 41' 6051' 4372' 600 Sx Arcticset III & 320 Sx Class G & 60 sx AS I 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feetORIGINAL Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural sCu°r~dacUeCt°r RECEIVED Intermediate Production Liner DEC ~0 Perforation depth: measured true vertical A/asEa Oil & Gas Cons Corrlrrljss[O'~ Annhn,o,.~, - 20. Attachments Filing fee X Property plat [] BOP Sketch [] Diverter Sketch X ....... ~)~illing program X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report [] 20AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signe'd~, '~'~ ~'~//~ ~.~~/~/ Title Drilling Superintendent Date Commission Use Only Permit Number I APl number I Approval date .... ., I See cover,attar for ~'.~-.2...~ 50- 0 .~----¢' ~...~_.~2' C.~,~ /_.~ ."/~"*,~'~' other requirements Conditions of approval Samples required F Yes [~ No Mud Icg required F Yes '~ No Hydrogen sulfidemeasures }---[Yes [~No Directional surveyrequired [~]Yes E~ No Required workingpressureforBOPE [~]2M ~] 3M ~] 5M [~ IOM ['~ 1SM Other: 0ri¢,inal Signed By by order of Approved by ~JS. vid W. Johnston Commissioner the commission Date I=nrm 1~3-401 Rev. 7-24-89 Submit in triplicate Drill and Case Plan for West Sak 1D-105 (C7) Frac-Packed Producer General Procedure: , Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. . Spud and directionally drill 9-7/8" hole to desired target through West Sak interval. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. , Run and cement 7-5/8" 29.7# L80 BTC-MOD casing to surface, displace cement with mud. Perform stage job and top job as required. NOTE: Stage (DV) tool to be installed +/- 200 ft TVD below the base of permafrost interval. , Nipple down diverter and install wellhead. Nipple up BOP stack and pressure test same to 3,000 psi. . . Pick up 6-3/4" mill tooth bit, 4-3/4" drill collars, and 3-1/2" drill pipe. Trip in and drill out stage collar. Clean out to PBTD..~ Shut in BOP's and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. . Swap well over to non-freezing completion brine. Filter brine to desired level. Trip out. 10. Nipple down BOP stack. Install production tree and pressure test same. Set back pressure valve. 11. Secure well and release rig. TAB, 12/01/97 Page 1 Completion Plan for West Sak 1D-105 (C7) Four-Stage, Single-Trip Frac-Pack Job, Frac-Packed Producer General Procedure: Well Preparation 1. Move in / rig up completion rig. . Pull back pressure valve, nipple down tree and install 11" 5M WP BOP stack and pressure test same. . Trip in with 6-3/4" bit and scraper on 3-1/2" workstring, and RIH to PBTD. Pressure test 7-5/8" 29.7# L80 BTC-MOD casing. Perform casing wash and displace well to filtered brine. Pickle workstring as required. Filter brine to desired level. Trip out. . Rig up E-line unit, and make correlation run as required with GR/CCL to correlate logs for perforating. . Make up Baker sump packer on E-line. RIH and set same below A2 sands (bottom pay sands). Space out and set sump packer to position TCP guns accurately on next trip in. POOH with E-line. . Pick up TCP perforating gun string to perforate all West Sak intervals in one trip. Trip in with 3-1/2" workstring, and sting into sump packer seal bore. Locate TCP guns on depth. Set TCP packer above West Sak. . Use diesel cap and/or void tubing to achieve desired underbalance. Pressure up on annulus and fire guns. , Release packer and reverse out to clean brine. Kill well as required. TOH with TCP gun string. . Pick up gravel pack assembly, including wire-wrapped screens, gravel pack and isolation packers, blank pipe, frac-pack crossover tool, and other jewelry and trip in hole on 3-1/2" workstring. Screens and packers should be spaced out to allow for isolated frac-packs on the following four West Sak intervals in one trip: Stage 1: A2 Stage 2: A3 Stage 3: A4 + B Stage 4: D Page 2 Stage 1 10. Locate gravel pack string into seal bore of sump packer. Sting lower screen seal assembly and snap-latch into sump packer. Set gravel pack packer and all isolation packers. Rig up and pressure test frac equipment at surface. 11. Position frac-pack crossover tool as required. Perform data frac for Stage 1. 12. Using 16-20 mesh carbolite proppant, proceed to frac Stage 1 with the specified volume of proppant. 13. Shift crossover tool, and gravel pack Stage 1. 14. Shift gravel pack tools, and reverse out excess proppant and frac fluids. Stage 2 15. Re-position frac-pack tools to frac-pack Stage 2 interval. Rig up and pressure test frac equipment at surface. 16. Position frac-pack crossover tool as required. Perform data frac for Stage 2. 17. 18. Using 16-20 mesh carbolite proppant, proceed to frac Stage 2 with the specified volume of proppant. Shift crossover tool, and gravel pack Stage 2. 19. Shift gravel pack tools, and reverse out excess proppant and frac fluids. Stage 3 20. 21. Re-position frac-pack tools to frac-pack Stage 3 interval. Rig up and pressure test frac equipment at surface. Position frac-pack crossover tool as required. Perform data frac for Stage 3. 22. Using 16-20 mesh carbolite proppant, proceed to frac Stage 3 with the specified volume of proppant. 23. Shift crossover tool, and gravel pack Stage 3. 24. Shift gravel pack tools, and reverse out excess proppant and frac fluids. Page 3 Stage 4 25. Re-position frac-pack tools to frac-pack Stage 4 interval. Rig up and pressure test frac equipment at surface. 26. Position frac-pack crossover tool as required. Perform data frac for Stage 4. 27. Using 16-20 mesh carbolite proppant, proceed to frac Stage 4 with the specified volume of proppant. 28. Shift crossover tool, and gravel pack Stage 4. 29. Shift gravel pack tools, and reverse out excess proppant and frac fluids. 30. Release frac-pack running tools and trip out of well. At this point, the flow conduit inside the screens from the sump packer to the upper packer should be free of sand and any plugs. Rathole should be available below sump packer. 31. Circulate well to clean brine. TOH with workstring. Change rams to 2-7/8" and pressure test same unless VBR's are available. 32. Pick up Centrilift ESP on 2-7/8" production tubing. 33. Run in well with ESP pump with power cable and data gathering information wire attached to tubing. 34. Attach Raychem heat trace cable to tubing at pre-determined depth to position bottom of heat trace below permafrost, and spaced out correctly to avoid surface splicing of heat trace cable. 35. Position ESP at desired depth, set tubing hanger and run electrical penetrators through same. 36. Make surface electrical connections as required, and set back pressure valve in tubing hanger. 37. Nipple down BOP stack, and nipple up production tree. Pressure test production tree. Secure well. 38. Release rig and turn well over to production. Page 4 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS West Sak 1D-105 (C7) Drilling Fluid Tyl3e Extended Bentonite Slurry Drilling Fluid Properties: Property Density Plastic Viscosity Yield Point Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to TD Initial 8.8-9.0 ppg 35-70 8-15 10-25 10-30 8-15 8.0-10.0 4-6 % Spud to TD Final 9.5-10.0 ppg 35-70 8-15 10-25 10-30 5-7 8.0-9.5 8-12% Drilling Fluid System: Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Mud Hoppers with Mixing Pumps *Spud mud should be adjusted to a FV between 200 - 250 sec/qt to drill gravel beds. Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Only one hole section will be drilled in this well. This single hole section will be drilled using a diverter system only for well control. A combination surface / production casing string will be run at total depth (TD). This combination surface / production casing will be cemented to surface using a stage (DV) collar. The stage collar will be placed approximately 200 feet TVD below the base of the permafrost interval. Page 1 MASP (Maximum Anticipated Surface Pressure): Since a separate string of surface casing is not planned for the West Sak 1D-105 (C7) well, there is no surface casing to be drilled out below requiring a BOP stack to be utilized. The combination surface / production hole to be drilled from surface through the West Sak pay zone can safely be drilled using a diverter system only for well control purposes. Based on actual well test data from the nearby WS1-01 well, expected reservoir pressures in the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/fi, or 8.2 to 8.8 ppg EMW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.6 ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 3,740' MD/TVD. Experience in the area has proven that these zones can be safely drilled using a diverter system only for well control purposes. The rig diverter system will be filled with water or mud and function tested prior to spudding the well. Since the combination surface / production casing will not be drilled out, leakoff test and MASP calculations are not necessary for drilling ahead. However, MASP calculations for cased hole operations are in order. Calculating MASP based on the highest recorded reservoir pressure from the WS1-01 well, and assuming a gas gradient of 0.11 psi/ft from the West Sak to surface, the following MASP can be computed: MASP = (4,184 ft)(0.46 - O. 11 psi/fi) = 1464 psi Based on this calculation for MASP, it will only be necessary to test the BOP equipment to a maximum of 3,000 psi. Following the cementing of the 7-5/8" combination surface / production casing in this well, the BOP stack will be installed and tested to 3,000 psi. The stage collar will then be drilled out and the well cleaned out to PBTD. At that time, the casing will be pressure tested for 30 minutes at a surface pressure of 3,000 psi as well. The 7-5/8" 29.7# L80 BTC-MOD casing to be used has a burst rating of 6,890 psi; 70 % of this burst rating is 4,823 psi. Following the clean out operation with the completion rig, a frac-pack completion will be installed, after which the ESP pump, power cable, heat trace and production tubing would be installed. Page 2 Drilling Area Risks: Drilling risks in the West Sak 1D-105 (C7) area are limited to lost circulation and potential borehole instability in and below the permafrost formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous Drill Site 1D drilling results, 10.0 ppg mud should be more than adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation. ARCO has drilled through the West Sak formation many times in nearby Kuparuk wells. For this reason, AAI requests that the requirements listed in 20 AAC 25.033 (e) and 20 AAC 25.061 (a) (pertaining to predicted overpressured strata and seismic refraction / reflection analysis, respectively) be waived for the drilling of West Sak 1D-105 (C7). Well Proximity Risks: The nearest existing well to West Sak 1D-105 (C7) is KRU 1D-02. As designed, the minimum distance between the two wells would be 18' at 120' MD. Annular Pumping Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of an existing well on DS-ID. That annulus will be left with a non-freezing fluid during any extended shut down (>4 hr) in pumping operations. The West Sak 1D-105 (C7) surface casing / production tubing annulus will be filled with diesel and/or non-freezing brine after setting the 2-7/8" production tubing and prior to the completion rig moving off of the well. TAB, 12/01/97, Rev. 1 Page 3 C.eo~e~ ~ ~ For: T McKAY D~te pl~ted : 2~-0ct-97 Plot Reference is WS 10-105/C7 Version ~. 250 250 500 750 lOOO 125o 1500 i750 2000 2250 2500 RKB ELEVATION: 112' Structure : Pod 1D Well: Field : Kuparuk River Unit Location : North Slope, Alaska 3OO 0 30O I I I I I TD LOCATION: 2083' FNL, 1433' FWL SEC. 13, T11N, RIOE East (feet) -> 600 900 1200 1500 1800 TD - Casing Base West Sak San~l.. TARGET - Top West Sak Sands End Angle BroF 33.54 AZIMUTH 3499' (TO TARGET) KOP TVD=400 TMD=400 DEP=0 ***Plane of Proposal*** 5.00 BEGIN TURN TO TARGET TVD=520 TMD=520 DEP=5 9.42 14.15 18.99 25.91 DLS: 5.00 deg per 100 ft 28.85 33.81 58.77 43.75 48.7,3 53.71E0C 1-VD31,372 TMD=1541 DEP=504 TARGET LOCATION: 22.30' FNL, 1558' FWL SEC. 1.3, T11N, RIOE B/ PERMAFROSTTVD=1654 TMD=2042 DEP=918 Permafrost MAXIMUM ANGLE 55.77 DEG in Turn to Target 2100 2400 ~ ~ 5300 5000 2700 Sends Drop 2400 2100 I18OO TARGET TVD=3891 TMD=55,39 OEP=3499 NORTH 2916 EAST 1933 SURFACE LOCATION: 134' FSL, 595' FEL SEC. 14, T11N, RIOE 1500 1200 9O0 600 3o0 ° 2750 3000 5250 3500 3750 4000 4250 4500 BEGIN ANGLE DROP TVD=3044 TMD=4513 T/ UGNU SNDS -rVD=3064 TMD=4548 D~P-~:~989%-% 51-~4~040'"' '"''~,,. ;~1.4o N,k, 36.40 DLS: 5.00 deg per 100 ft 31.40 26.40 END ANGLE DROP TVD=,3599 TMD=5228 DEP=5592 ~, 21.40 T/ W SAK SNDS TV0=3740 TM0=5378 DEP=3444~ R ~ CI 0 TARGET ANGLE DEC 20 DEG Alaska 0ii & Bas Cons, Commi io Anchorage I i i i f i i i i I i i i 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 5000 5250 3500 3750 Vertical Section (feet) -> Azimuth 33,54 with reference 0.00 N, 0,00 E from slot #105 /k I z c..~ot~a ~ ~,,ch For: T McKAY Dote plotted : 28-0ct-97 Plot Reference is W$ 1D-103/C7 Version Coord?notes ore in ~eet reference slot ~105. rme Verficol Depths~RKB (Po~k~ ARC0 ALASKA, Irtc. Structure : Pad 1D Well: C7 Field : Kuparuk River Unit Location : North Slope, Alaska 28O 26O 240 220 2OO 180 160 140 ~2o ,.,,_ 100 -~ 80 0 Z 80 East (feet) -> 80 60 40 20 0 20 40 60 80 100 120 140 160 180 200 220 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 200 ,' 21OO 2000 , / ,' 1899.99 1800 1700 1600 1500 1400 1300 ~300 /'1200 2600 1500 1900/' /' ,, ,' / /' / / ,., / / / / / / ,, / / / . / 800 / ,, ," ?/1100 / / 2500 ,, ! / ! / 1700/ ' "' 300 [. ,," /'1000 / / ,' /' / / / 1 2400 / ,,,~,,,,, 100 (~'~ 1100 'k '~ 1000 300 8OO .' I00 ../' 400 i 2300 300 '"., 900 ." ', 300 ~" '~,,800 "%700 '",%.600 ';8 300 700 .. #"i200 i i i i i i I 8'0 610 4'0 2'0 0 2'0 2200 f ' I I i I i 4o ~'o ia ,oo East (feet) -> i 12O 28O 260 240 22O 2OO 180 160 i 40 120 1 O0 40 F 20 ~ 4o ! ~o , , , [ 80 I I I I 140 160 180 200 220 Z 0 m IOe0~ b~ ~;~c~ For: T MeKAY D~te pl~tted : 28-Oct-g7 Plot Reference is WS ID-105/C7 Version C ~ord~tes are in feet reference slot ~105. lTme Vertical Oept~s are ref~ence ~8 (Park~ ~245). Structure : Pad 1D Well: [ Field : Kuparuk River Unit Location : North Slope, Alaska 2000 1900 1800 1700 1600 1500 1400 1300 1200 '*- 1100 1000 ,4.-- 0 Z 9oo 800 700 600 500 400 300 200 1 O0 East (feet) -> 0 1 O0 200 5500 400 500 600 700 800 900 1000 11 O0 1200 1300 1400 1500 1600 420 /'2600 , · 41 O0 / / 4000 / ,,,' ; 3900 ¢' ,,,' 3800 / /'2500 3700/' ,, 5600/' ,'" / /' 3500 / /' / ,"2400 3400 / ,," / 55oo / / / /2300 / 3200/ ,, iI " "~2200 3~oo/ ,/ / / / 3000 ." ,"21 O0 / / / 2900 .'" ,,'" / /'2000 30O0 O0 F i 900 L tl 800 ~1700 b i600 1500 1400 i1300 1200 / 2800 I 2800 .'" ,'"' ," ,," 700 ,/'4500 11 O0 2700 / / /4300 P lOOO / / /X oo ! --, 90O ,,' ,,' /4oeo / ,,' ,,' 400 ~ b ,' / ,,/"3900 l 2500 / /'1700 ~ ~ ,,/ ,,,,' / ./,/38 O0 .~J 800 ," .." / .47oo ,'d~1- 2400 ~' ,,' _/ / /./v i / /'1600 /2200 //~600 ./..//.¢~600 J-700 ,;' ,,,' ~ ..45oo ..-'~5oo 25500 / / /"2100 / "" [ 600 21 O0/' ,' / ,/"3000 /'/" t 400 ;,; ,,,'" 400 L 2ooo," 43oo,' /~8oo ..../2ooo / ~oo,..' ,~"2o~ ~oo ," ," / _ ? 200 ,~oo ;' .i'~¢o"o~ 50o , 100 0 1 O0 200 300 400 ,500 600 700 800 900 1000 1100 1200 1,300 1400 1500 1600 East (feet) -> ARCO ALASKA, Inc. Pad 1D C7 slot #105 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT by Baker Hughes INTEQ Your ref : WS 1D-105/C7 Version #4 Our ref : prop2221 License : Date printed : 28-Oct-97 Date created : 17-Apr-97 Last revised ~ 28-0ct-97 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 30 18.908 Slot location is nT0 18 2.634,w149 30 36.255 Slot Grid coordinates are N 5959798.676, E 560490.871 Slot local coordinates are 134.00 N 595.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath PGMS <0-8365'>,,1,Pad 1D TOTCO Survey,,WS-8,Pad 1D PGMS <O-8930'>,,5,Pad 1D PGMS <0-7502'>,,4,Pad 1D PGMS <0-8070'>,,3,Pad 1D PGMS <0-9783'>,,2,Pad 1D PGMS <O-8610'>,,6,Pad 1D MSS <3311-8200'~,,7,Pad 1D WS 1D-106/D6 Vers.#3,,D6,Pad 1D WS 1D-109/D4 Vets. #2,,D4,Pad 1D WS 1D-115/E3 Version #4,,E3,Pad 1D WS 1D-117/E7 Version #4,,E7,Pad 1D WS 1D-121/G5 Version #3,,G5,Pad 1D WS 1D-130/H4 Version #4,,H4,Pad 1D PMSS <O-?????>,,H4,Pad 1D WS 1D-118/E5 Version #4,,ES,Pad 1D WS 1D-119/F4 Vers.#3,,F4,Pad 1D WS 1D-124/G3 Version #3,,G3,Pad 1D WS 1D-120/F6 Vets. #3,,F6,Pad 1D WS 1D-129/J3 Version #3,,J3,Pad 1D WS 1D-133/J5 Version #4,,JS,Pad 1D WS 1D-135/G7 Version #4,,GT,Pad 1D Closest approach with 3-D Minimum Distance method Last revised Distance 4-Aug~92 80.5 16-0ct-96 4-Aug-92 4-Aug~92 4-Aug~92 4-Aug~92 25-0ct~97 25-0ct-97 8-0ct-97 8-0ct~97 28-0ct-97 28-0ct-97 23-Oct-97 27-Oct~97 28-0ct-97 28-Oct-97 6-Oct-97 22-0ct-97 6-0ct-97 22-0ct-97 22-Oct-97 22-0ct-97 736.4 377.1 257.1 136.6 18.0 497.0 617.0 30.0 75.0 189.5 224 1 315 0 540 0 539 9 240 0 285 0 405 0 300 0 525 0 585 0 660.0 825.0 400.0 20.0 20.0 240 0 120 0 20 0 400 0 400 0 450 0 540 0 560.0 400.0 400.0 400.0 400.0 400.0 400.0 400.0 300.0 300.0 400.0 Diverging from M.D. 825.0 400.0 400.0 5761.2 400.0 5920.0 20.0 400.0 400.0 450.0 540.0 560.0 ,oo.o 400.0 400.0 400.0 ,oo.o 400.0 400.0 A~q~g°~ Oil & GaS 300.0 400.0 A~chora~e West Sak 1D 105 (C7) Proposed COrn'pletion Diagram Four (4) Stage Frac-Pack 2-7/8" Production Tubing 16" Conductor Casing @ 80' Raychem Heat Trace (through permafrost) Weatherford Gemoco 754HO 7-5/8" DV Stage Collar Stnd. Grade BTC Threads (set +/- 200' TVD below permafrost) Power Cable for ESP Centrilift Camco 2-7/8" Gas Lift Mandrel with 1" side pocket Arctic Lift 3500 psi Shear circulating valve pre-loaded in GLM (circulate well for freeze protection purposes) ESP Pump Section Centrilift ESP Gearbox Centrilift ESP Motor Section Centrilift D Sand Frac-Pack Assembly with Screen Baker Oil Tools B + A4 Sands Frac-Pack Assembly with Screen Baker OII Tools A3 Sand Frac-Pack Assembly with Screen Baker Oil Tools A2 Sand Frac-Pack Assembly with Screen Baker Oil Tools 7-5/8" Combination Surface/Production Casing, 29.7# L-80 BTC-MOD (Cemented to Surface) ARCO Alaska, Inc. TAB, 12/01/97, Rev.1 KUPARUK'~RIVER UNIT - WEST '~AK OPERATIONS 20" DIVERTER SCHEMATIC 6 l4 3 2 1 I 5 HCR i DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVEFITER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20"- 2000 PSI ANNULAR PREVENTER. TWM, 9/15/97 I 8 , 7 6 5 I L_ > 13 5/8" 5000' 'SI BOP STACK Sak Operations - Producer ACCUMULATOR CAPACITY TEST West 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. ?_ ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. I ! I BOP STACK TEST Wells 1. FILL BOP STACK AND MANIFOLD WITH WATER. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PS! AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILLAND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE UNES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PS! LOW AND 3000 PSI HIGH. TESTAS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOTA FULL CLOSING POSITIVE SEAL CHOKE. 8, OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. .TEST BOTI'OM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND AU. VALVES ARE SET IN THE DRILUNG POSITION. 11. TEST STANDPIPE VALVES TO 3000 PS! FOR 3 MINUTES. 12_ TEST KELLY COCKS AND INSIDE BOP TO 3000 PS! WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILMNG SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACCOMODATE 3-1/2' TO 6' OR 4-1/2' TO 7' PIPE ODS AS APPROPRIATE. 1. 16' - STARTING HEAD 2_ 11' - 5000 PSI HORIZONTAL TUBING HEAr_, 3. 11' 5000 PSI X 13-5/8" 5000 PSI DOUBLE STUDDED ADAPTER/SPACER SPOOL 4. 13-5/8" - 5000 PSI X 13-5/8' - 5000 PSI SPACER SPOOL 5. 13-5/8' - 5000 PSI PIPE RAMS 6. 13-5/8' - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 7. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 8. 13-5/8' - 5000 PSI ANNULAR TWM, 9/22/97 " pi C PIT C:~ , o.s. '- 2~ ~ 22 2~ ~ 14.1~ ~ , ,,~ I% ~CINITY MAP ~ ~ 117 , ~ SCALg: ~" = ~ MILE , 119 i I 120 i 121 . , I ~ 5 , I 124 ; ~T LN : i j 129 ~ 155 , i ~6. _ ~ o~ , LEGEND si[ SHE~ ~ 2 FOR NOTES ~O LO~TION INFOR~TION 0 EXlSnNG coNoucroRs ~ LOUNSBURY ~EA · 10 ~ULE XX UNIT' ARCO ~ ~s~ s~x ~.~s~ ~ - ~ co~ouc~o.s AS-BUILT CADD FILE NO. J J ORANNG NO: J~EET: J~ LK~10410 g/o2/g7 CEA-D1DX-~104D10 ~ ~ 2 2 REV I 2~,TE BY I CK I APP I DESCRIPTION 1 ig/02/97 AJR i PC I ! AS~O~LT PER KSB~ KO7082ACS iV 0 TES 1. COORDINATES SHOWN ARE A.S.P. ZONE 4, N.A.D. 27. ELEVA UONS SHOWN ARE BRITISH PETROLEUM MEAN ...CEA LEVEL. ALL DISTANCES SHOWN ARE TRUE. 2. BASIS OF LOCATIONS AND ELEVA DONS ARE D.S. l-O ~40NUMENTS PER LHD AND ASSOCIA FEE. CONDUCTORS ARE LOCATED WITHIN PROiT?ACFED SECTIONS ~4 & 23, TOWNSHIP 11 NORTH, RANGE 10 EAST, U.M. DA FE OF SURVEYS: 8/25, 29 & 30/'97, FIELD BK L97-24, pp. 52 - 45, 68 - 7,.7. DRILL SITE 1-D GRID NORTH IS ROTATED 00' 01' 05" WEST FROM A.S.P. ZONE 4 GRID NORTH. SEE DRAWING NSK-3.5-1 FOR AS-BUILT LOCATIONS OF CONDUCTORS //1 THROUGH //8. ~"~9r-'~'''' A "-'-, ~x'-'*'r- ~'~, ~a :~: ........//~'~N O.~' ............. ;~LOJJ ,,~ o,~ '..; ~s-~o~5 ..."..-,-- '.?d'"'.. ..... '"': :REVI OATE t £ CK i2 ig/~7/97! AJ~ ! pc IS. lB DESCRIPTION AS-BUILT PER KSB~ KgT082ACS 21 WEST SAK-1 THIS SURVEY VICINITY MAP SCALE: I" = I MILE Weft A.$.P.s LA TITUOE LONGITUDE L_IN~SEC'L_IN~SEC' t PAD O.G. No. 'Y' 'X' 0/5 0/5, ELEV. ELEV. S;c. 14, T. 11 N., R. IOE. F.S.L.F.E.L., 105 5,959,798.99 560,490.57 70' 18' 02.657' 149' ,.70' ,,76,263' I34' 595' 70.5' 62,0' 106 5,959,768.93 560,490.67 70' 18' 02.34~" 149' 30' :76,268' 104' 595' 70.4' 62.~' 109 5,959,72.7.89 560,490.60 70' 18' 01.898' 149' 30' .76.280' 59' 596' 70.4' 62.7' S. ;c. 23, T. 11 N., R. I O £. f:'.N.L.F.E.L. 115 5,959,605.93 560,490,68 70' 18' .00.718' 149' $0' :76.306' 61' 597' 70.4' 65.4' 117 5,959,57.7.95 5~0,490.65 70' 18' 00.42.,7' 149' .70' J6,314" 91' 597' 70.4' 6J. 4'I 118 5,959,558.95 560,490.68 70' 18' 00,276' 149' 30' .76,316' ~06' 597' 70.4' 63,4'1 119 5,959,513.86 560,490.72 70' 17' 59.8,52' 149' .70' .76..]26' I5I' 598' 70.8' 120 5,959,499.01 560.490.77 70' 17' 59.686" 149' .70' .76,327' 166' 598' 70.6' 66.0' 121 5,959,483.89 560,490.67 70' 17' 59.5,:78' 149' 30' .76.3:75' 181' 598' 70.5' 66.0 124 5,959,39:7.96 560,490.70 70' 17' 58.653' 149' 30' 36,355' 271' 599' 70.3' 65.0' ~29 5,959,273.92 560,490.79 70' ;7' 57.472' 149' 30' :76..780' ,791' 600' 70.:7' 68,2' 130 5,959,259.09 560,490.81 70' 17' 57.326' 149' 30' :76. J83' 406' 600' 70.5' 68.2' 133 5,959.21J. 89 560,490.68 70' I7' 56.882" 149' 30' :76.397' 451' 600' 70.4' 69,0' 135 5,959,1.79,02 560,490.80 70' 17' 56.146' 149' 30' 36.412' 526' 601' 70.5' 69.4' SUR VEYOR °S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STA FE OF ALASKA AND THAT THIS PLA T REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THA~ ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF AUGUST $0, 1997. .~ LOUNSBURY &: ASSOCIATES, INC. E~NEERS PLANNERS SURVEYORS ARCO Alaska, LK6104~0 9//02/97 AREA' 10 MODULE- XX DRILL SITE 1-D WEST SAK PHASE I - WELL CONDUCTORS AS-BUILT CEA-D1DX-6104D10 IS~EET:2 oj'. 2 IREv: UNIT' D1 ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor December 9, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 ORIGINAL Re: Application for Permit to Drill West Sak 1 D-105 (C7) West Sak Phase lA Development Well, Kuparuk River Unit Dear Sirs: RECEIVED D£C 10 199 Alaska Oil & Gas Cons. Anchorage ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the West Sak interval from 1D pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak sands in the vicinity of 1D pad. The well is designed as a producer well using a frac-pack completion technique for reservoir stimulation and sand control purposes. 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 bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Note the 40 acre spacing requirements governed by the West Sak pool rules. 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the West Sak sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU well.s which have penetrated the West Sak sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at WS 1D-105 (C7), such as shallow gas. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany There have been eight (8) Kuparuk wells and several West Sak wells drilled from KRU 1D pad, and no occurrences of shallow gas or other hazards have been observed. There is a gas sand at approximately 2,100' TVD which is present, but has not caused any past problems in the existing wells which penetrated this sand using a diverter system only. An exception to the requirements set out by 20 AAC 25.033 (e) and 25.061 (a) are hereby requested for this APD because of this regional experience. A prediction of the maximum downhole and surface pressures which may be encountered however are included in this APD per 20 AAC 25.035 (d) (2). 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. An exception to the requirements detailed in 20 AAC 25.005 (c) (8) is thus requested. Please note that the anticipated spud date for this well is January 21, 1998. If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Tom McKay at (907) 265-6890. ~.Sincere Thomas A. Broc Operations Drilling Engiffber Attachments: CC; West Sak 1D-105 (C7) Well File Tom McKay ATO-1202 Keith Lynch ATO-1228 Ike Bellaci ATO-1260 Cliff Crabtree NSK6 RECEIVED DEC 10 i9 Z Naska Oil & .3a~ Cons. Cor~i~ss~o~ Anchorage · WELL PERMIT CHECKLIST COMPANY /~'/"(--,¢ WELL NAME .2~,_~¢"' /4-//<:2.~'' PROGRAM: exp [] dev./~redrll [] serv [] wellbore seg E; ann. disposal para req FIELD& POOL <'//r~,¢~//,~'O INIT CLASS ~/")~ /-' ~/'/ GEOLAREA ~r'~',¢;::~ UNIT# /'//~/'"~ ON/OFF SHORE 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 drilling 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 ........... ~Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N ENGINEERING APPR DATJ~ 14. Conductor string provided ................... ~) NN 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... ,,, N 17. CMT vol adequate to tie-in long string to surf csg ........ 18. C~MZ will cover all known productive horizons .......... (~1'~ 19. Caoing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... Y N 22. Adequate wellbore separation proposed ............ : ~:~ N 23. If diverter required, does it meet regulations .......... (~ N ~r~v,/' 24. Drilling fluid program schematic & equip list adequate ..... N 25. BOPEs, do they meet regulation ..... _. . ...._..~ ..... 26. BOPE press rating appropriate; test to "~,¢F'ZFL..~ psig 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... /N__. 29. Is presence of H2S gas probable ................. Y GEOLOGY APPR DATE. 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N ,,,,/~,,)f'~'/~ 31. Data presented on potential overpressure zones ....... ~N ' ¢ ; 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............ .J Y N 34. Contact name/phone for we,eklyprogress reports ....... / Y N lexp~oratory only] REMARKS GEOLOGY: ENGINEERING: COMMISSION: JDH ~¢~'-'- RNC ~ ' '"' co Comments/Instructions: HOW/lit - A\FORMS\chekhst rev 09/97 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history_ file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Tue Feb 10 10:45:48 1998 Reel Header Service name ............. LISTPE Date ..................... 98/02/10 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/02/10 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MM-80096 P. SMITH G. WHITLOCK 1D-105 500292284300 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 10-FEB-98 MWD RUN 2 AK-M~-80096 P. SMITH G. WHITLOCK 14 lin 10E 134 595 .00 111.50 70.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 16.000 118.0 PRODUCTION STRING 9.880 6093.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 3. ALL GAMMA RAY DATA (SGRC) HAS BEEN CORRECTED TO PROPER CALIBRATION FACTORS. 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM MIKE WERNER OF ARCO ALASKA, INC. ON 09 FEBRUARY, 1998. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6093'MD, 4432'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE RPD RPM RPS RPX GR FET ROP $ START DEPTH 131 0 131 0 131 0 131 0 138 5 173 0 174 5 BASELINE CURVE FOR SHIFTS: STOP DEPTH 6049.0 6049.0 6049.0 6049.0 6056.5 6049.0 6092.5 CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH --- BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 1 174.0 4988.0 2 4988.0 6093.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD AAPI 4 1 68 RPX MWD OH/~M 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 ROP MWD FT/H 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max DEPT 131 6092.5 GR 12.6043 126.564 RPX 0.4369 2000 RPS 0.4774 2000 RPM 0.5073 2000 RPD 0.3195 2000 ROP 1.8265 606.924 FET 0.1016 13.8871 Mean Nsam 3111.75 11924 65.3604 11837 38.9714 11837 57.437 11837 89.8676 11837 106.284 11837 238.183 11837 0.53074 11753 First Reading 131 138.5 131 131 131 131 174.5 173 Last Reading 6092.5 6056.5 6049 6049 6049 6049 6092.5 6049 First Reading For Entire File .......... 131 Last Reading For Entire File ........... 6092.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SI/MMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 131.0 4944.5 RPM 131 . 0 4944 . 5 RPS 131 . 0 4944.5 RPX 131.0 4944.5 GR 138 . 5 4952 . 0 FET 173 . 0 4944.5 ROP 174 . 5 4987 . 0 $ LOG HEADER DATA DATE LOGGED: 21-JAN- 98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.06 DOWNHOLE SOFTWARE VERSION: CIM 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 4988.0 TOP LOG INTERVAL (FT) : 174.0 BOTTOM LOG INTERVAL (FT) : 4988.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .3 MAXIMUM ANGLE: 56.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): TOOL NUMBER P0891CRG6 P0891CRG6 9.880 9.9 SPUD MUD 9.10 MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHIO4) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 320.0 8.5 4OO 7.7 5.000 3.870 5.000 4.500 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 1 AAPI 4 1 68 RPX MWD 1 OHMM 4 1 68 RPS MWD 1 OHMM 4 1 68 RPM MWD 1 OHMM 4 1 68 RPD MWD 1 OHMM 4 1 68 ROP MWD 1 FT/H 4 1 68 FET MWD 1 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 28.6 Name Min Max Mean DEPT 131 4987 2559 GR 12.6043 126.564 63.022 RPX 0.869 2000 46.4576 RPS 0.8046 2000 69.0068 RPM 0.7608 2000 108.878 RPD 0.3195 2000 129.038 ROP 1.8265 606.924 264.816 FET 0.1016 3.011 0.361715 Nsam 9713 9628 9628 9628 9628 9628 9626 9544 First Reading 131 138.5 131 131 131 131 174.5 173 Last Reading 4987 4952 4944.5 4944.5 4944.5 4944.5 4987 4944.5 First Reading For Entire File .......... 131 Last Reading For Entire File ........... 4987 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 4944.5 6049.0 RPD 4944.5 6049 . 0 RPM 4944.5 6049 . 0 RPS 4944 . 5 6049 . 0 RPX 4944 . 5 6049 . 0 GR 4952 . 0 6056 . 5 ROP 4989 . 0 6092 . 5 $ LOG HEADER DATA DATE LOGGED: 22-JAN-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.06 DOWNHOLE SOFTWARE VERSION: CIM 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 6093.0 TOP LOG INTERVAL (FT): 4988.0 BOTTOM LOG INTERVAL (FT) : 6093.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 19.9 MAXIMUM ANGLE: 29.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY P0891CRG6 EWR4 ELECTROMAG. RESIS. 4 P0891CRG6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 9.880 9.9 SPUD MUD 9.20 320.0 8.5 400 7.2 4.900 3.070 3.600 2.600 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 2 AAPI 4 1 68 RPX MWD 2 OHMM 4 1 68 RPS MWD 2 OHMM 4 1 68 RPM MWD 2 OHMM 4 1 68 RPD MWD 2 OHMM 4 1 68 ROP MWD 2 FT/H 4 1 68 FET MWD 2 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 40.6 Name Min Max Mean DEPT 4944.5 6092.5 5518.5 GR 23.9188 121.116 75.5367 RPX 0.4369 55.2737 6.34327 RPS 0.4774 66.9479 7.01049 RPM 0.5073 82.1847 7.00904 RPD 0.4972 72.6297 7.11028 R0P 5.5955 466.26 122.275 Nsam 2297 2210 2210 2210 2210 2210 2208 First Reading 4944.5 4952 4944.5 4944.5 4944.5 4944.5 4989 Last Reading 6092.5 6056.5 6049 6049 6049 6049 6092.5 FET 0.2779 13.8871 1.26611 2210 4944.5 6049 First Reading For Entire File .......... 4944.5 Last Reading For Entire File ........... 6092.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/02/10 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 98/02/10 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File