The URL can be used to link to this page

Home My WebLink About193-152& ~ OCAT!ON REPORT A_: i No. ~ =: an,~' comment on plugmj~=g, well head .~ev'lew ~--e wej ~ ~ ~, s:a:=s, ~ !oca:icn c!ea~ce - praise loc. clear, co~e. . . ~ ~ , ~ ~ - "f ,. ','.. ~.' ~,.~.~ ~~~x ~ ~,~ ~_ STATE OF ALASKA ~.AS. , OIL AND GAS CONSERVATION .~MN. SION WELL COMPLETION OR REOOMPLETION REPORT AND LOG I1. Status of well Classification of Sen/ice Well Oil r~ Gas ~'~ Suspended r-] Abandoned r~l Service D 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. 93-152 / 301-086 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-103-20197-00 4. Location of well at sudace 9. Unit or Lease Name .-i' 676' FSL, 53' FEL, Sec. 14, T11N, R8E, UM ~ LOCATIO~'I. Kuparuk River Unit At Top Producing Interval ~ ¥~1~111;~[~!j~ ii ~ --~-- ~ 10. Well Number 1393' FNL, 1312' FEL, Sec. 22, T11N, R8E, UM I~4~1~~ i. 2A-19 At Total Depth~~ 11. Field and Pool 1420' FNL, 1576' FEL, Sec. 22, T11N, R8E, UM '.- Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 135 feetI ADL25571 ALK2669 Kuparuk River Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions October 25, 1993 October 30, 1993 May 25, 2001 (P&A'd)I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19, Directional Survey 120. Depth where SSSV set 21. Thickness of Permatros! 9785' MD / 6179' TVD 9157' MD / 5706' TVD YES D No ~]I N/A feet MD 1600' (approx) 22. Type Electric or Other Logs Run N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD I CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 121' 24" 200 sx PFC 9.625" 47#/36# L-80 / J-55 Surface 3957' 12-1/4" 660 sx ASIII & 540 sx Class G 7" 26# L-80 / J-55 Surface 9765' 8-1/2" 225 sx Class G bridge plug @ 9157' in 7" casing 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 7239' * Plugged & Abandoned all perforation intervals. .26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A N/A 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 Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-eeL OIL GRAVITY - APl (con') Press. 24-Hour Rate > AS. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED * This 10-407 is submitted as directed per the 10-403 form approved (Approval #301-086) JUL 1 6 ZO0 Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29, NAME Top of Kuparuk C GEOLOGIC M,~. .... ERS MEAS. DEPTH 9378' TRUE VERT. DEPTH 5870' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time ot each phase. N/A RECEIVED JUL 1 6 2001 Alaska Oil & Gas Cons. Commission Anchorage 31. LIST OF ATTACHMENTS Summary of 2A-19 Sidetrack Plug & Abandonment Operations. 32. I hereby certify, jhat the following is/t~ and correct to the best of my knowledge. Signed ~× ~>'~ ,;-*-~¢-- z. /~..,~-, .~..~:¢ Title Interim Drilling Engineering Supervisor Tom Brockway INSTRUCTIONS Questions? Call Brian Noel 265-6979 Prepared by Sharon AIIsup-Drake General: This form is designed for submitting a complete and correct well completion report and Icg 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 ,. Operations Summary 2A- 19A Rpt Date 05/23/01 12:00 AM 05/24/01 12:00 AM Comments Rig move complete@ 0830 hrs. PJSM & ops on well plan. Rig up circulation lines. Install berms around rig. Off load 350 bbl sea water to mud tnks & pt hard lines to 1500 psi. Pull bpv & vr plug. Annulus pressure 300 / tbg 200 psi. Complete laying flow lines for circulation. Pressure hard lines & cir system to 1000 psi / 5 minutes. Displace well fluids [cir down tbg] taking returns from annulus to flow back tank w/330 bbl sea wtr, 4 bpm / 370 psi. Monitor well dead for 15 minutes. Install bpv, nd tree & set out side cellar area. Mi replacement tree. NU 7 1/16" x 5000 psi bop, install choke / kill lines / hydraulic lines / function rams. Reassembly riser to accomodate shorter cameron well hd system. Complete riser assembly. Recover bpv. Install test plug & reconfigure rams. Test bope as per AOGCC rep to 250 / 3500 psi. Annular to 3000 psi. Recover bpv Make up Idg jt to hanger & pull hanger to floor. Required 95K lbs pull to pull hanger out of bowl, then fell off to 80k lbs string wt [string wt in sw approx 75k lbs]. Pull hanger above observe well static. Circulate w/8.5 ppg sw, @ bottoms up observed 18 ppm gas @ shakers on rig gas system. Continued to circulate w/eratic Iow gas units, sw gas cut. Si, ck csg pressure @ 160 psi, open dhsv w/5k lbs control pressure, @ that time both tbg & csg showed 200 Continued to oberve well static @ 650 psi. pressures slowly increased to 670 psi.. Order out 480 bbl 11.1 ppg mud [cai kill ,,vt 10.7 ppg]. Hauling excess sw to disposal. NOTIFY: John Spaulding [aogcc] of intension to kill well w/11.1 ppf using drillers 05/25/01 12:00 AM Pressure test circulating hose to 2000 psi: START KILL; Pumped 20 bbl spacer followed by kill weight mud of 11.1 ppg. Initial circulating pressure 1050 psi calculated problems holding due to aired up pumps. Complete pooh w/ completion [Id same], pumped second dry slug, fill up correct. Rec 30 of 31 cont line clamps, left in hole one clamp [1 x 5.5 long x .125"]. Rec cont line to spool, recovered chemical cut area [hanging by one 3/4" strip], one 6' pup 05/26/01 12:00 AM Clean / organize floor / PJSM for scrapper run. RIH w/6.125" bit & scrapper on 3.5" dp, tag pbr @ 9243'. Ru to circulate, complete crew change. Cir / condition @ 4 bpm / 1000 psi, unable to work deeper than 9243'. Depth is -sufficient / spacing adequate for space out for setting cibp & whipstock. Pjsm & clean / police floor. Make up cibp to setting tool & trip in on dp. Tag up on pbr @ 9243' rkb Nordic 3. Ck up / down wts of 127k / 113 k lbs. Strap out to setting depth of top of cibp of 9157'. Drop ball & cir down [4 bpm / 1390 psi], increase pressure to 1500 psi when ball hit setting cibp @ 9157'. Pressure test / chart cibp to 3000 psi / 30 min, aogcc notified, not present. Pooh w/setting tool, no damage to same. Pjsm Clean up floor & strap bha components. Make up milling assmby to whipstock, pu / mu mwd tools [orient - scribe] & remaining bha. Operations Summary 2A- 19A 05/27/01 12:00 AM 05/28/01 12:00 AM 05/29/01 12:00 AM 05/30/01 12:00 AM Tih on dp to 9100', ck up / down wts pump on / off of 125/63 k lbs & 143 \ 70 k lbs. Orient whipstock tool face 45 deg left of high side. Circulate down to tag cibp @ 9157', set down 15k over string, set anchor @ 39 deg left of high side. Pick up to n Break cir. Cut window 9138 - 9150 & formation to 9162'. 3100 psi/250 gpm / 2-3 k lbs bit wt / torq 9k fi-lbs in steel / 6k in formation / rpm 80. Ditch magnates in place - rec approx 5 gallons 1/8 to 1/4 .... flat plate like shards. Mud samples @ shaker Cir/cond /sweep hole. Pull mill into csg. Conduct charted F.I.T.; impose 410psi by pumping .4 bbl down dp w/11.1 ppg mud in hole, emw - 12.5 ppg. Bled back 1.6 bbl. FIT rpt e-mailed in. Aogcc notified - no show. Pooh to 8500'. Cut drlg line. Complete pooh. .Lay down / gage mills - all in gage upper mill 6.15". Pu bit, motor & mwd tools as per dir assmby. Conduct surface cks on mwd equip. Complete pu bha & tih 9050'. Orient tools & slide through window [did not take any weight] tag up on pipe tally @ milled td of 9162', no fill. NOTE: on metal shards: cai total metal to rec -- 156 lbs. Have takened four 12 hr magnate "captures" for esti 60, 30, 20 & 3 lbs -- 113 lbs. Drlg - slide 9162 - 9334'. 1st reliable azmuth from survey 9281, bit depth 9331'. Azmuth & inc good started rotating. Rot drlg 9334 - 9353'. ECD increased rapidy to 12.8 emw. Lost 20 bbl mud. Pu off td, work pipe, lower mw to 10.9 ppg & adjust pv / yp to 49 / 22. Cir ecd decreased to 12.1 ppg Sd pumps. Monitor well static. Rot drlg 9353 - 9681' [Well TDed for liner]. Good coarse / target control. No mud losses. Circulate bu, flow ck. Well flowing 6 bph. Circulate & raise mw to 11.0 ppg heavy. OPS after Midnight: Monitor well for 1/2 hr, gaining 2 bph, raised mw to 11.1 & trip to window, well took I 1/2 bbl. Monitor 1/2 hr, gaining 2 bph, si [@0530 hrs] for 40 min gaining 70 psi. bleed off press Pooh to window, noted well flowing 2 bph, tripped to td [ no fill] & raised mw to 11.7 ppg in two circulations, minor gas w/traces of oil to surface. Monitor well taking 1.5 bph. Drop 2.1" rabbit & pooh to window,¢k well taking 1 - 1.25 bph, pump dry slug. Pooh standing back dp. Lay down bha, download mwd data. Pu / Mu 3.5" float equip to liner & trip in hole making up liner to "3' long polish bore w/ 2.75" id ........ " Threads in box of polish bore pull away from body of tool down to ab mod groove. Located a shorter [1.28 vs 2.71 '] 2.75" polish bore nipple. Continue to tih w/liner assmby. Complete tih w/liner assmby filling every 5 stands. Tag up @ td of 9681' on dp tally, no fill Cir cond mud to 11.6 ppg smooth. Ck up wt of 130k & down of 65k lbs. Conduct PJSM on cmt & liner hanging ops. Dowell press test lines to 4000 psi / 10 min & cmt 3.5" liner as follows: Lead w/20 bbl fw, 15 bbl chemical wash, & 40 bbl 13 ppg mud push @ 1500 psi / 4 bpm. Follow w/ 34 bbl [190sx] slurry {15.8 ppg / yield 1.2 / } of class G Gas Block - batched mix Subject: Re: 2A-t9 well kill and P&A ~ _~ Date: Fd, 25 May 2001 14:21:t4 -0700 From: Tom Maunder <tom_maunder@admin.state.ak. us> i~ C..~,"~ _ ~, 5 "~ ~ To: Brian D Noel <bnoel@ppco.com> CC: aogcc_prudhoe_bay@admin.state.ak, us, "Randy L. Thomas" <rlthomas@ppco.com>, ,lames A Trantham <jtranth@ppco.com>, Nordic 3 Company Man <n1433@ppco.com> Brian, Thanks for the information. I will be interested to hear what is determined with regard to the incomplete cut. You had mentioned so other recent chemical cuts that were not completely successful. If you have a listing of these, I would appreciate it. Aside from the information with regard to the cut, ! will not require anything further. Good job to all. Tom Maunder, PE Petroleum Engineer AOGCC Brian D Noel wrote: Here's summary of the well kill completed on 5/24/01, before pulling the tubing and sidetracking: Well parameters: 7" casing, 3-1/2" tubing, single packer, gaslift completion in Kuparuk C/A sand. Pre-rig: pulled rock screen from tubing tail, unable to pump into perfs (sand & rock fill up to tubing tail), eline set bddge plug in tubing at 9255' (packer at g272'), chemical tubing at 9240', open pocket mandrel at 920g'. Pressure tested tubing/casing to 3000 psL Rig operations: Rig moved onto well 5/23/01, circulated seawater around, monitored well - no pressure on tubing or casing. Set BPV, pulled tree, NU and tested BOPE. Pulled BPV and then pulled hanger to floor. Circulated 8. 5 ppg seawater and at bottoms up had 18 ppm methane gas at shakers. Circulated a little longer with low gas readings. Shut well in at approx, lO:30am on 5/24/01 with 160 psi on casing, pump up control line to open SSSV, had 200 psi on both tubing and casing. After 40 rain SI, 650 psi on both tubing and casing. Continued to monitor well while waiting on sufficient mud volume for kill. North slope inspector John Spaulding notified while waiting. Well static with pressure slowly building to 670 psi in 5 hours. Kill weight calculated from shut in pressure = 10. 7 ppg. Well kill: - Used wait & weight method to kill. - At Opm circulated on choke 20 bbl high vis spacer ahead of 11.1 ppg LSND mud (10.7 ppg for kill plus trip margin when drilling sidetrack). - Surface to surface volume = 74 bbls in tubing + 261 bbis in annulus. - initial bottoms up had 10. 8 ppg (seawater cut mud), diverted to tank. - After 446 bbls pumped, shut in pressure on tubing = 0 psi, casing = 70 psi. - Made second circulation with 11.1 mud, smooth 11.1 ppg returns, checked shut in pressure on tubing and casing, well dead. 1 of 2 5/25/01 4:21 PM i-(e: ZA-I~ Well Kill arlo ,. · - Monitored well for 30 rain - static at midnight. Current operation: 5/25/01 - Pulled 3-1/2" tubing with no problems. The chemical cut left approx 3/4" circumference of tubing uncut (just enough attached that when pulting hanger to floor, the sea/ assembly and pup with bridge plug pulled free from packer's PBR). Thus exposing casing to formation pressure. As discussed yesterday, since fill level is at tubing tail and unable to pump into formation, plan to set 7" bridge plug at 9170' plus cement back into weilbore after sidetrack liner is run will meet the P&A requirements for 2A-19. ! will fax new P&A drawing reflecting~the missing tubing stub/bridge plug. ~ ~.~~."~ Let me know if you have any questions. Thanks - Brian 265-6979 ITom Maunder <tom maunder@admin.state.ak, us> P--~r~role-~m ~eer Alaska Oil and Gas Conservation Commission 2 of 2 5/25/01 4:21 PIVt FROM~ PHILLIPS AK i FAX HO. : 90?2551535. ! Phillip,s Alaska! ,~ ~C.,,,_ ~oo G Street, Anchc 05-25-k] 1 ge, AK 99501 FAX Number of pages including cover sheet: TO: Phone: Fax phOnc: CC: From' --:~. · /..-' · U~, ~ Wells Group Fax phone: Location: I I I ....... IJ - REMARKS: [--] Urgent I I Inn IIIIII [] For youc review F-! Reply ASAP Please comment .. -- ] 'RECEIVED FROM: PHILLIPS RK ~'H~ r~u. PHILLIPS Ala, a, Inc. A SubSidiary of PHILLIPS PETRC~ _JM COMPANY . OD:$.g~) Lift -. lan<~reLrDummy Vatve 1 (20~201g, OD:5.3901 la.roi/Dummy Valve 2 (4291-4292, OD:$.390) 'j/: ! Lift ........... ~-'t~ landr~l/Oumrny VaJva 3 {6197-6198, OD:5.390} · Gas Lift I~,dr~l/Dummy V~lve 4 (7634-7035, OD:5.300) gas Lift ............... 18fldr¢llDummy Valve 5 '-KRU APl: 50103,~C~!'9700 ~55V Tyl~e'; i TRDP Annular Fluid: R~feren,-a Log.:. " Last Tag;. 9:~6 .... Casing String - SURFACE Descr!@flon Size : SUR. CASING 9.625 . ..... SUR. CA~ING 9.525 Casing $.tring - CONDUCTOR Description ' ' Size CONDUCTOR 16.000 · Casing SIring_~..RODUCT~ION Description Size PROD. CASING 7.000 Tub In g_~.t_ri_n. 9._- T___.U.~! NG Size Top ~__~i't'or~ .... 3..5oo '- ' 0 ~//'929a Perforations s~'mmary wen____ __...Type_: PF~OO Lest W/O: Ref Log. Dale: TD: 9785 flKB Max Hole Angle:' 61. ~.e_g_(~, 5__.Z. 72 2A-19 : Angle (~ TS: 47 dog (~ 9374 .... i ...... A~gle @ TI):. 40 dog ~ 9785 Rev Reason: T_a.,~ fill~, set CR-Loc! . _J ...... "~.;i;~"up.~.~_te_'~-4/"-~o~ ' · . Top. Bottom Thread 0 0 '" 0 3957 TVD ' Wt Grade 0 ' ";~5~]-" L-80' ' .__._2~OJ ...... [....38.00 L-80 Top.. Bottom TVD j Wt 'G~'ade Thr~l' 0 121 '121 .... ~- -~:'50 H-~O " (8731-8732, OD:$.390) Ga,'. LiR ...... land~l/gummy V;dva 6 0D:5.968) PKP, Bottom Th 9765 1'VD ........ Wt ...... Grade [ .......... Ti~read ..... ..... Top o TVD : Wt Grade 6164 , 26.00 L-80 TUBING ........ (0-9298. 0D:3.5oo, IO:2.992] $o8 OD:3.5oo) (9,160~949o) '" NIP ........ (g~87-9288, OD:3.,~OO} (9272-9273, OD:5.938) PBR i B,3ker ........ P~ .s.~..'EHL; NIP J Camco 'D' Nipple NO GO - Se~ 2;?~' ~;R-~'o-~';~fi'ock screen 3/29/01 . -- 3.0oo 3.000 ? 750 2.98~ 2.g.'8~ F,-~g272' ,' 6791 I -~J287 5802 J --~r '5eo9'- sos I ........... " EiVED [ HAY 25 2001 ' . ~ ~Oii & 5781 Interval 'I'VD Zone 'Status 1 Ft jS~'~-ff Date '."~;~:'.e:'::: Comment .... 937~- 940,~ SaTO ~s~ c~ ~ ~6 ~ ' ~-' A~E~F 25" HC ~d'~.~a~in~ no orienl 9460 - ~90 5931 - 5954 A-3 "~'-~ 4 313/94' IPE~'-4 1/2" HSD; 18o deg. phobia! . ~.tj~ulaUons & Tmat~.en~ ' lateral Date Type ........ i .............. Comment ................. o - o 4/24/97 S~le Inhibitor ~ Pum~dl0 Bbls SW W/30 Gal SS-5206 G~S Lift Mandmls~alves ............................. St MD '~Dj Man ~ Man VMfr j VType i VOD Latch Po, [TRO Date Vlv ~ .... ' Mfr ' Type ' I Run Cent 1 2018' 1783~ McM~ FMHO ' DMY ~ 1.0 BK ' '~.'~-~'"~'8I~8/9'~'-- ' ~ 4291~ 2978LMcMuF~ ~b ' ~ ~ I 1.0 ~K .....~.0OO'-I '~' ' ~28/97 ~ ' 6197' 398'~.~Ur~,' EMRO .... [ D~-'! ].0 ....... ~ "0'.~'00 '; 0 8/27/97 4 7634 4791J MoMu~[" ~ ~ ' DM? "? ~ .... ~ .... 0 000 J ~' 8/27t97 ~ ~ ' 8731j 541OJMcMur~J FMHO ~ D~~.0 ' BK 0.000 ~ 0 ' 8/27/97 ' ~-' 9209{ 5744i Came&-I MMM ' ' ' ~'~~5" ' R~. ["O'Ooo J-~- ..... 8/28/g~ other~lugs, equip,u~s)-JEWE~RY "' ... - ........... ~epth ~O Type D~scHptlon .......... "ID 17~4 1628 SS~9 ~Cam~ TRDP-2A-SSA (~ pet CAMCO 312~)' ...... ::.:: ..... .._~ 2,81~" Re: 2A-19 P&A revised proposal Subject: Re: 2A.19 P&A revised proposal Date: Fri, 04 May 2001 17:22:10 -0700 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: Brian D Noel <bnoel@ppco.com> Brian, Thanks for the note. The change proposed is appropriate since you cannot establish an injection rate. Based on the depths you note and the fax I received, placing the bridge plugs will accomplish the initial abandonment. Since you intend to fully cement the liner, this cement will satisfy the cement requirement in the regulations. Please call with any questions. You have approval to proceed as described. Tom Maunder, PE Petroleum Engineer AOGCC Brian D Noel wrote: Per our phone conversation this afternoon on alternative P&A method for 2A-19 producer to prepare for sidetrack: Work done to date - Co//cleaned out ice plug at 2658' and tagged D nipple at 9287'. Slickline pulled rock screen from tubing tail. Unable to inject into well. Rather than abandon perfs with retainer and cement squeeze as proposed in sundry application, agreed to set bridge plug in 3-~/2" tubing pup at +/-9255' (above the production packer) and cut tubing at +/.9245'. Nordic 3 will then pull tubing, set 7" bridge plug at +/.9175', and pressure test prior to sidetracking. E-line work may be done this weekend, but rig won't move onto weft until permit to redrill is approved. Redr//i permit package wilt be sent over on Monday 5/7. Thanks - Brian Tom Maunder <tom maunder@admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission I of 2 5/5/01 10:34 AM FROM: PHILLIPS AK ,~, FAX NO.: 9072651535 05-04-01 04:08P P.O1 Phillips Alaska, !nc. 700 G Street, Anchorage, AK 99501 ~__ III II . _ Ill Ill I FAX Date: Number of page, including cover sheet: .... Ill I' Phone: Fax phone: 7___.- 7(~ (7(2: Wells Group Phone; Fax phone: Location: RECEIVED HAY 0 4 2001 REMARKS: [~] Urgent [--] For your review FI Reply ASAP [-] Please comment ! FROM: PHILLIPS AK FAX NO.: 9072651535 05-04-01 04:08P P.02 PHILLIPS Alaska, inc. A Subsidlap/of PHILLIPS PETROLEt.~4 COMPANY S$$v (17~. I [85, 0D:5.938) G~ Lift ......... ~andml/l~mmy Valve 1 (20192019, Gas Lift --- ~a~,el/Dummy valve ~ 0D:5.3~) Gas Lif~ .andrel/Oummy (6197-6198, Gas LIfl ~andml/Durnmy Valve 4 (7634.7535, 00:5.3~) Gas L!rl · 'andm_VDummy Valve 5 {8731-8732, OD:5.3901 ..- i KRU 2A-19 !andrel/Oummy Valve 6 (~209-9210, 00:5.958) P~IR .............. ~j (925~92~0, OD:3.500) 2A. t9 APl: 501032019700 SSSV Type: Annular Fluid: Reference Log: LaM Tag:. 9398 · L. eSt Tag..D.~.~.~:., .7. ./.6. ~.0. .0 Ca~ing String - SURFACE Size Top 9.6?.5 0 9.62,5 0 Casing Strin9 - CONDUCTOR Si~e Top 16.0o0 0 Casing String -'PRODUCTION Size Top 7.000 0 Tubing $~Hng. TUBING Size Top 3.500 0 Perforations Summary Interval TVD 9378 - 9404 S870 - 5889 9460 - 9490 5931 - 5954 ' StimulatJon~ & Tremtmen~$ Well Type:· PROD OHO Completion: 11/1/93 Leer W/O: Eel Log Date:' TO; '9785 ftKB Max Hole Angle:i6.1..d. eg (~ 5272 Bottom 0 3957 'I'VD 0 2801 Wt 47.00 36.00 BOttOm 121 TVO 121 Wt 62.50 Bottom TVD 9765 6164 Angle (~ 'I='S-~.. 42 deg (~ 937'{ Angl~ ~ TO: 40 de-'~ (~ 9765 Rev Reason:I Tag fill by line Lta~, t Update:. 7/9/00 Grmdo L-BO H,40 Thread Thread Wt Grade Thread 26.00 L-P, 0 8or, om TVD Wt Cradc Thread 9298 5810 9.30 J-55 EUE AB MOD Zone Status Feet'$PF' Date Type Comment . . C-4 26 6 4/13/95 APERF 2.5" HO DP; oO deg. pha.~ing, no orient A-3 30' 4' 3/3/94 iIPERF 4 1/2" HSD: 180 deg. phasing Interval.. Date Type Comment · . 0 - O 4/24~7 Smale Inhibitor Pumpcdl0 ~b13 SW Wt 30 Gal $$-3ZOb . Gas Lift Mandrels/Valves PKR ............. 00:5938) NiP" (9287.9~8B. 00:3.5~0) TUBING OD:3.500, / ~0:~,992) 303 ' (9~7,9~8. 09:3.500) iStn MD ]-VD Man Man V Mfr Mfr Type 1 2018'. l?'e31McMurryI FMHO DMY 1.0 z 4291 ~975. McMurry FMHO DMY 1.0 · 3 6197 3981. McMurry. FMHO' DMY 1.0 4 7634· 4791 McMurr7. FMHO OMY 1.0 ,5 8731. 5410 McMurr~. FMHO DMY 1.0 6 9209......??..4.4' Cam~o MMM OMY 1.5 :Other (plugs,. equip,, etc[~';-~JEi~if['RY ..................... Depth 'I'VD Type Description 0 0 SOS 1784 1628. SSSv Camco'TRDP-2A-SSA (a~ per CAMCO 3/21/2000) 9259 5781 PBR Baker 9272 $791' PKR Baker 'FHL' 9287 5802__ NIP Camco 'D' Nipple NO GO Sz~rI bBo~ sos PULLED 3/2S/98. · 9298 5810 'FrL V Typ'~,' ' Y Om Latcl3 Fort TRO Date 'vIV Run Cerumen' BK 0.000 0' 8/26/97 BK 0.000 0 8/28/97 BK 0.0O0' 0 0/27~97 BK '0.000 O' B/27/37 GK 0.000 O' 8127197 RK 0.000 O' 8f28/97 ., 0.000 2.813 3.000 3.000 2.750 2._°84 2.984 RECEIVED MAY 0 4 2001 Anchorage, PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 J. Trantham Phone (907) 265-6434 Fax: (907) 265-6224 April 5, 2001 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval - 2A-19 Dear Mr. Commissioner: Phillips Alaska, Inc. hereby files this Application for Sundry Approval to commence workover operations on the Kuparuk well 2A-19. If you have any questions regarding this matter, please contact me at 265-6434 or Pat Reilly at 265-6048. Sincerely, ¢ d. Trantham Drilling Engineering Supervisor PAl Drilling JT/skad APR 09 200i Alaska 0il & ¢~as 0~;~,%. i;~'~i~,t-fJi~;,";io~ 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 _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface ~ -d' 676' FSL, 53' FEL, Sec. 14, T11 N, R8E, UM At top of productive interval 1393' FNL, 1312' FEL, Sec. 22, T11 N, R8E, UM At effective depth At total depth 1420' FNL, 1576' FEL, Sec. 22, T11N, RSE, UM 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB feet) RKB 135 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2A-19 9. Permit number / approval number 93-152 k// 10. APl number 50-103-20197-00 11. Field / Pool Kuparuk River Field / Kuparuk River Pool 12. Present well condition summary Total depth: measured 9785 true vertical 6179 Effective depth: measured 9683 true vertical 6101 Casing Length Size Conductor 80' 16" Surface 3916' 9.625" Production 9726' 7" Liner feet Plugs (measured) feet feet Junk (measured) feet Cemented 200 sx PFC 660 sx ASIII & 540 sx Class G 225 sx Class G Measured Depth True vertical Depth 121' 121' 3957' 2800' 9765' 6164' Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 9378'-9404',9460'-9490' 5870'-5889',5931'-5953' 3.5", 9.3#, J-55 @ 9298' MD APR ¢9 200! . . Baker 'FHL' packer @ 9272', Camco TRDP-2A-SSA SSSV @ 1784' 13. Attachments Description summary of proposal __X Detailed operations program _ BOP sketch __ Schematic __X Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic __ ! 14. Estimated date for commencing operation April 17, 2001 16. If proposal was verbally approved Name of approver '~-~'~'~-'\- Date approved 15. Status of well classification as: Oil __X Service __ Gas __ Suspended 17. I hereby cirtify that the foregoing is true and correct to the best of my I~owledge. Signed (,~L--~ Title: Drilling Engineering Supervisor FOR COMMISSION USE ONLY Questions? Call Pat Reilly 265-6048 Prepared b~/ Sharon AIIsup-Drake Conditions of approval: Notify Commission so representative may witness .'%~~'k_~'~ Plug integrity __ BOP Test ~)~ Location clearance __ Mechanical Integrity Test__ Subsequent form required 10- ..... A__p_p_r_.o_¥ed by order of the Commission Commissioner Form 10-403 Rev 06/15/88 · Approval n o~/~. SUBMIT IN TRIPLICATE K'RU 2A-19 Producer Proposed P&A PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 9-5/8" 36# L-80 casing set @ 3957' MD Tubing cut +/-9188' MD Cement retainer set in first full joint above the tubing tail @ +/-9236' MD. Abandoned C4 Sand Peds 9378'-9404' Abandoned A-Sand Peds 9460'-9490' 7",26#, L-80 casing @ 9765' MD Last Tag at 9398' MD on 7/6/00 PBTD = 9683' MD TD = 9785' MD P JR 4/9/01 KRU 2A-19 SUNDRY OBJECTIVE P & A WELL FOR SIDETRACK OPERATIONS (reference attached plugback schematic) CURRENT WELLBORE STATUS: Well 2A-19 was drilled and completed in March 1994 as a 3-1/2" single completion producing from the Kuparuk C and A sands. The well was perforated in the A sand. The C sand was perforated from 9378' to 9404' on 4/13/98. Over the next 13 months, a wireline tag indicated the A sand perfs were completely covered. Three separate 1.75" coil tubing clean out jobs were unsuccessful. A video log on 7/11/00 indicated a large hole near the top C sand perf. Well 2A-19 is currently shut in awaiting sidetrack. P&A WORK (Pre-Rig): . RU CTU. RIH with cast iron cement retainer on CTU and set retainer at +/~ 9,236' MD RKB (in first full joint of 3.5" tubing above the tubing tail). Squeeze 15 bbls of 15.8 ppg Class G cement below retainer (4.5 bbl for the tubing volume from the tail to the retainer and the annular volume between fill and the tubing tail. Plus an additional 10.5 bbls into perfs). Unsting from retainer and circulate any excess cement from well bore. Leave well shut-in with initial tubing pressure on wellhead. RDMO CTU. Bleed annulus pressure to 0 psi. Pressure test tubing above cement retainer to 2500 psi for 30 min (chart test). Slowly bleed tubing pressure to 0 psi and monitor pressure for build-up. RU slickline unit. RIH and pull 1.5" DV from mandrel #6 at 9,209' MD RKB, leaving an open pocket. RU E-line unit. RIH and cut tubing at +/-9,188' MD RKB (middle of first full joint of 3-1/2" tubing above the cement retainer). 6. Set BPV and VR plug. Remove well house and scaffolding. PJR 04/09/01 PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY (1784-1785, OD:5.938) Gas landrel/Dummy Valve 1 (2018-2019, OD:5.390) Gas Lift landrel/Dummy Valve 2 (4291-4292, OD:5.390) Gas Lift landreI/Dummy Valve 3 (6197~6198, OD:5.390) Gas Lift landrel/Dumrny Valve 4 (7634-7635, OD:5.390) Gas Uft landrel/Dumrny Valve 5 (8731-8732, OD:5.390) Gas Lift landrel/Dummy Valve 6 (9209-9210, OD:5.968) PBR (9259-9260, OD:3.500) PKR (9272-9273, OD:5.938) NIP (9287-9288, OD:3.500) TUBING (0-9298, 0D:3.500, ID:2.992) SOS (9297~9298, OD:3.500) Perf (9460-9490) KRU 2A-19 APl: ~ 501032019700 SSSV Type: i Annular Fluid:; Reference Log:i Last Tag:i 9398 Last Tag Date:i 7/6/00 Casing String- SURFACE : Well Type: i PROD _ ~ Angle.(~ _-rs_: :~4_2_ _d_e. g_@_ 9374 Orig Completion:~ 11/1/93 .... L Ang_le_ @_T-D:.~40 deg @ 9785__ Last W/O:i ~ R_e_v R_ eas0_n:'_Tag_~l_l by ImO ~_ .... Last__Up_date;~7_/8/00 Ref Log Date:i TD: 19785 ftKB Max Hole Angle:i 61 deg_~_ 5272 Size Top Bottom 9.625 0 9.625 0 ~asin~tring ,COND-UCTOR TVD Wt 0 47.00 3957 2801 36.00 Grade_.~ .... Thread L-80 L-80 Size ~ Top Bottom 121 TVD 121 Wt Grade:, Thread 62,50 H-40 16.000 ; 0 ~asi~ng;!,iPROD~CTION Size ~ Top i Boffom ~ TVD i ~t- '--Grad-~; ~h~d ..... 7.000 0 ~ 9765 6164 i 26.00 Tdbin Strin ;TUBING Size Top : Bottom TVD ] Wt . Gr_ad_e.. !. . T_hread 3.500 0 9298 , 5810 ~_ 9.~30~ ._ _J__-55 !_ _ E_U_E AB MOD P6rfOrations SUmmary: Interval TVD Zone StatusiFeet!SPF! Date l_Type 9378 - 9404 5870 - 5889 C-4 ! 26i 6 J4/13/98! APERF ' 2~.5" HC _Dp.; .60 deg. p_h_as!ng,_n_o orient 9460 - 9490 ', 5931 - 5954 A-3 , 301 4 3/3/94 .'_ IP_E.B_F ,4_1/2"_HSD; ~180.deg: p~h~.s~g ........ :stimulations &:Treatments Interval ~ Date Type 0- 0i 4/24/97 Scale Inhibitor Gas Lift:Mandrels/Valves Stn! MD iTVD, Man i M~n : Mfr i Type 1 2018! 1783' McMurryl FMHO 2 ' 4291i 29781McMurry! FMHO 3 6197i 3981iMcMurryl FMHO 4 7634! 4791i McMurryl FMHO 5 r 8731] 54101McMurryi FMHO 6 ! 9209i 5744 Camco I MMM Comment [ Pumped10 Bbls SW W/30 Gal SSJ5-206 ..... V Mfr VType ' VOD iLatch Port' TRO I Date ' Vlv i i , Run :Commen' ~, , DMY ;I-.0 ' BK o.o00! _ 01 8/28/97-' DMY 1.0 BK 0.0001 0, 8/28/97 DMY 1.0 ~ BK '0.000i 01 8/27/97 ' DMY 1.0 ~BK--0.000'. 0] 8/27/97 ' DMY 1.0 BK '0.0001'- 0~ 8/27/97 : .... DMY 1.5 ~ RK ':0.000 b/ 8/28/97 i .... Other (PlUgs; equiP,;: etc.) - JEWELRY _ Depth iT VD Type i Description ...... o~, o sos 1784 i 1628 ! sssv Camco 'TRDP-2A-SSA (as~)er CAMCO 3/21/2000~ _ 92591 5781 PBR Baker 9272i 5791 PKR i Baker'FHL' · _ . 9287'~ 5802 NIP ' Camco 'D' Nipple NO GO 9297i 5809 SOS 'PULLED 3/25/98. 92981 5810 TTL ID 0.000 2.813 3.000 3.000 2.750 2.984 2.984 · STATE OF ALASKA .... ALAS . OILAND GAS CONSERVATION COMk. ~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. ' Development __~ 135' RKF 3. Address: Exploratory ___, 7. Unit or Property: P.O. Box 100360 Stratagrapic ~ Anchorage, AK 99510-0360 Service ~ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 676' FSL, 53' FEL, Sec 14, T11N, R8E, UM 2A-19 At top of productive interval: 9. Permit number/approval number: 1393' FNL, 1312' FEL, Sec 22, T11N, RSE, UM 93-152 At effective depth: 10. APl number: 1415' FNL, 1506' FEL, Sec 22, T11N, R8E, UM 50-103-20197-00 At total depth: '11. Field/Pool: 1420' FNL, 1576' FEL, Sec 22, T11 N, R8E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 9785 feet Plugs (measured) None true vertical 6179 feet Effective Depfl measured 9683 feet Junk(measured) None true vertical 6101 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 200 Sx PFC 121' 121' Surface 3916' 9-5/8" 660 Sx AS III & 3957' 2800' 540 Sx Class G Production 9726' 7" 225 Sx Class G 9765' 6164' Liner Perforation Depth measured 9378'-9404', 9460'-9490' true vertical 5870'-5889', 5931'-5953' Tubing (size, grade, and measured depth) 3.5", 9.3 Ib/ft, J-55 @ 9298' Packers and SSSV (type and measured depth) Packer: Baker FHL @ 9272'; SSSV: Camco TRDP-2SSA @ 1784' 13. Stimulation or cement squeeze summary Perforate "C" sand on 4/13/98. Intervals treated (measured) 9378'-9404' ' t-~, ~ '~'~ ' ~ "I ' ~ Treatment description including volumes used and final pressure ~*~ !"'~) I ;" Pefforated well w/ 2.5" gun w/ DP charges at 6 spf, fp was1875 psi. k-- ' 'x""- ¢ 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas~Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 646 1555 481 1398 305 Both Sands Subsequent to operation 1595 5761 763 1390 322 15. Attachments MIT form 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _~ Oil _X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed. CJ~/~~~~-, . Tifle: Productlor~ Engineering Supervisor Date ¢/~;~/~ ~ WELL JOB SCOPE " JOB NUMBER 2A-1 9 PERFORATE, PERF SUPPORT 0408981957.1 DATE DAILY WORK UNIT NUMBER 04/13/98 PERFORATE-ADD C SAND PERFS 2128 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 (~) Yes ('~ NoI (~) Yes (~ No BARTZ JONES FIELD AFC# CC# DAILY COST ACCUM COST Signed ESTI MATE KAWW R K 230 DS28AL $15,480 $15,480 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 420 PSI 1875 PSI 1400 PSI 1400 PSII 10 PSI 0 PSI DALLY SUMMARY SWS (BARTZ & CREW)PERFORATED C SANDS W/2.5", DP, 6 SPF, 60 DEG PHASE FROM 9378' TO 9404' IN2 RUNS. DSO RETURNED WELL TO PRODUCTION. TIME LOG ENTRY 07:45 SWS (BARTZ & CREW) MIRU 09:15 HELD TGSM, SECURED RADIO SILENCE. MU GUN & PT LUBRICATOR TO 3000#. LRS MIRU. 10:15 PUMP 10 BBLS DIESEL & FREEZE PROTECT FLOWLINE, PUMP 30 BBLS DIESEL DOWN TUG. RIH W/20', 2.5", DP, 6 SPF, 60 DEG PHASED, NOT ORIENTED GUN. CORR TO GR/CBT LOG 11-4-93 & PERFED FROM 9384' TO 9404'. 12:00 POH & LD GUN, ALL SHOTS FIRED. MU GUN, PT LUBRICATOR TO 3000#. RIH W/6', 2.5" GUN & CORR AS ABOVE. PERFED FROM 9378' TO 9384'. 13:00 ~...~f~:lS POH & LD GUN, ALL SHOTS FIRED. SWS & LRS RDMO & RELEASED. DSO RETURNED WELL TO PRODUCTION. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $160.00 $160.00 APC $250.00 $250.00 LITTLE RED $2,420.00 $2,420.00 SCHLUMBERGER $12,650.25 $12,650.25 TOTAL FIELD ESTIMATE $15,480.25 $15,480.25 ' ' STATE OF ALASKA AL,k~J~, OIL AND GAS CONSERVATION COMMIS,-,,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate X Plugging Perforate Repair well Other ~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service N, R8E, UM N, R8E, UM Ny R8E, UM 9785 feet 61 79 feet 4. Location of well at surface 676' FSL, 53' FEL, Sec. 14, T11N, R8E, UM At top of productive interval 1393' FNL, 1312' FEL, Sec. 22, Tll At effective depth 1415' FNL, 1506' FEL, Sec. 22, Tll At total depth 1420' FNL, 1576' FEL~ Sec. 22, Tll 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) Effective depth: measured 9 6 8 3 true vertical 61 01 RKB 135 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2A-19 9. Permit number/approval number 93-152 10. APl number 50-103-20197-00 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None feet Junk (measured) None feet OIRlC INAL Casing Length Size Structural Conductor 80' 1 6" Surface 3916' 9 - 5 / 8" Intermediate Production 9726' 7" Liner Perforation depth: measured 9460 '-9490' true vertical 5931 '-5953' Cemented Measured depth True vertical depth 200 Sx PFC 121 ' 121 ' 660 Sx AS III & 3957' 28O0' 540 Sx Class G 225 Sx Class G 9 7 6 5' 61 64' Tubing Pressure Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 9298' Packers and SSSV (type and measured depth) Pkr: Baker FHL @ 9272'; SSSV: Camco TRDP-2SSA @ 1784' 13. Stimulation or cement squeeze summary Fracture stimulate "A" sands on 9/10/97. Intervals treated (measured) 9460'-9490' Treatment description including volumes used and final pressure Pumped 295 M lbs of 20/40 and 12/18 ceramic proppant into formation, fl:) was 7100 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 7 4 4 964 470 1360 283 Subsequent to operation 1 8 7 0 3539 1338 1372 319 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~.v,t,~ ~7"~ Form 1/¢'-l¢04¢ ¢t'e~ 0"~15~ Title Wells Superintendent~. . Date /'~ -" " '" ~ I ¢ "" "- - ~',, ¢--. ~'"~ i;; ~UBMI¢ IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT ,~' WELL SERVICE REPORT ~ ~ K1 (2A-1 9(W4-6)) WELL JOB SCOPE JOB NUMBER 2A-19 FRAC, FRAC SUPPORT 081 9971452.1 DATE DAILY WORK UNIT NUMBER 09/10/97 PUMP "A" SANDS REFRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 3 (~) Yes ('~) NoI (~ Yes O No DS-GALLEGOS JOHNS/? ,,,---.,, ESTIMATE KD1467 230DS28AL $1 85,669 $209,827 Initial ~'bcl Press Final Tbq Press Initial Inner Ann Final Inner Ann Initial Outer~n'n I Final (:~ter'Ann 1053 PSI 3000 PSI 500 PSI 1 000 PSI 300 PSII 400 PSI DAILY SUMMARY PUMPED "A" SANDS REFRAC WITH 294,962 # PROPPANT , TO 13# PPA 12/18 AT PERFS. LEFT 30,000 # PROPPANT IN TUBING. TIME LOG ENTRY 07:00 MIRU DOWELL FRAC EQUIP, HOT OIL TRUCK AND APC VACUUM TRUCKS. 09:20 HELD SAFETY MEETING, DISCUSSED JOB PROCEDURE. 10:05 PUMPED BREAKDOWN STAGE WITH 320 BBLS FLUIDS TO 15 BPM AND 4651 PSI. SHUT DOWN FOR ISIP AND PULSE PUMPIN'S. 10:55 PUMP DATA FRAC AND ,':-LUSH WITH 300 BBLS FLUIDS, 5 TO 15 BPM AND 4523 PSI. SHI ? ~"). W~.~ ~:C'~ Cl OSURE CALCULATIONS. 12:11 PUMP 420 BBLS FLUIDS FOR PAD AT 5 TO 15 BPM AND 4400 PSI. 12:50 PUMP 15,000 # TO 2 PPA 20/40 PROPPANT TO 4413 PSI. 13:03 PUMP RAMP UP FROM 2 TO 10 PPA 12/18 PROPPANT, 15 BPM AND 4546 PSI. 13:42 PUMP FLAT 10# PPA STAGE OF 12/18 PPA 12/18 PROPPANT. 14:18 RAMP TO 12# PPA 12/18, TOTAL 12/18 PUMPED 294,162. 14:45 PUMPED 13,338 # OF 10/14 PROPPANT, WENT TO FLUSH AND WELL PRESSURED OUT, LEAVING 30,000 PROPPANT IN TUBING AND 294,994 # PROPPANT INTO PERFS. MAX. 7100 PSI. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $850.00 APC $7,000.00 $14,600.00 ARCO $400.00 $400.00 DOWELL $176,469.00 $182,488.00 HALLIBURTON $0.00 $6,374.00 LI"'FI"LE RED $1,800.00 $5,115.00 TOTAL FIELD ESTIMATE $185,669.00 $209,827.00 AOGCC Individual Well Geological Materials Inventory DATA DATA_PLUS 93-i52 T 3900-9758, OH-CDR/CDN R DIRE~.~ ............ L 8500-9652 L 3900-97~0 L 9200-9740 L 3900-9740 93-152 ~CDN-LWD/DC 93-i-~2~ P'C~DR-E/LWD/DC 93-152 ~DR-LWD/DC 93 I~2 ~CE'~ L 8500-9676 Page- I Date' 10/!3/95 RUN DATE_RECVD CMPS 04~25~94 · ±/ ~-~I :~.~ 11/22/93 CMPS 04/25/94 CHPS 04/25/94 CMPS 04/25/94 11/22/93 Are dry ditch samples required? yes ~~And received? ..... yes-. no Was the well cored? yes ~_~_Analysis & descriptio~--~ee~ived? yes no Are well tests required? Well is in compliance yes in,tie! Received? ---yes.. no ARCO Alaska, Inc. Date: April 22, 1994 Transmittal #: 9069 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. and return one signed copy of this transmittal. c~.~ \~q 2E.17 q.'b--\~!'' 2A- 19 q"b' !qd~ 2A-24 Receipt Acknowledged: Please acknowledge receipt DISTRIBUTION: LIS Tape and Listing: 04-05-94 DSI Run in 7 inch casing--repeat passes LIS Tape and Listing: -- 04-07-94 CDR/CDN-2 Bit Runs w/QRO Processing LIS Tape and Listing: 01-11-94 Main and Repeat Passes Bob Ocanas 94114 93502 93520 Date: State:of~! .a, .S....~.,a.--j~:!:.!:-? .. ARCO Alaska, Inc. Date: April 22, 1994 Transmittal #: 9067 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. Please acknowledge receipt and return one signed copy of this transmittal. ,,¢,.,,1.,./2A- 19 ,,'"CDR 10-31-93 3900-9750 c~/'"(' 2A-19 ' ,-~::; DN 10-31-93 3900-9750 2A-19 ,/'CDR Enhancement 10-31-93 9200-9750 q,~.. ~,~.uf 2E-17 ...,Dipole Shear Sonic Imager 12-27-93 8580-9070 c[~,qd( 2A-24 ¢-Dipole Shear Sonic imager i 1-09-93 8050-9475 Acknowledged: .4~ ~,..~,~~ Z~ Date: Catherine Worley(Geology) DISTRIBUTION' D&M Drilling NSK State of Alaska (+Sepia) STATE OF ALASKA ALA~,~, OIL AND GAS CONSERVATION COMM~o'"~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [~ GAS [~] SUSPENDED [~ ABANDONED [] SERVICE [~ 2.ameofOperator 0 R [ G/[\~A L , Permit Number ARCO Alaska, Inc 93-152 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20197 4 Location of well at surface ~ · 9 Unit or Lease Name 676' FSL, 53' FEL, SEC 14, T 11N, R 8E, UM KUPARUK ~IV~ AtTop Producing Inte~al ' =/~¢ ¢~ { -~;~~~'"~ 10 Well Number 1393'FNL, 1312'FEL, SEC22, T11N, R8E, UM ~i:~ ~ ~.. 2A-19 At Total Depth . 1~' Field and Pool - . . 1420' FNL, 1576' FEL, SEC 22, T11 N, R8E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. KUPARUK RIVER RKB 135', PAD 94' GL ADL 25571 ALK 2669 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. ~ 15 Water Dep~, if offshore 16 No. of Completions 25-Oct-93 30-Oct-93 03/04/94(COMP)~ NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+~D) 19 Directional~Su~ey~ 20 Dep~ where SSSV set 21 Thic~ess of permafrost 9785' MD, 6179' TVD 9683' MD, 6101' TVD - YES ~ NO ~ 1784' feet MD 1600' APPROX ~ Type Electric or Other Logs Run CDR, CDN, CET, CBT, GCT 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~ GRADE TOP ~ HOLE SIZE C~~ -- 16. 62.5¢ H-40 SURF 121' 24" 200 SX CMT 9.625 47¢/36~ L-80/J-55 SURF 3957' 12.25" 660 SX ASlII, 540 SX C~SS G CMT 7. 26¢ L-80 SURF 9765' 8.5" 225 SX CLASS G CMT 24 Pedorations open to Production (MD+TVD of Top and BoAom and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER S~ (MD) 3-1/2' 9.3~ J-55 9298' 9272' 9460'-9490'4 SPF MD 5931'-5953' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production JMe~od of Operation (Flowing, gas li~, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO I TEST PERIOD E 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, porosi~, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NA RECEIVED APR - 8 1994 Alssk~ ON & 6as Cons. ~mmissk~! Anchoraflo Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 130. 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 OF KUPARUK C 9378' 5870' NA 31. LIST OF A-FFACHMENTS REPORT OF OPERATIONS, 2 COPIES OF DIRECTIONAL SURVEY 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. Signed c.~~//~ ~ ~ Title INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg 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 ARCO ALASKA INC. DAILY OPERATION& PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 2A-19 NORTH SLOPE KUPARUK RIVER- KUPARUK RIVER ADL 25571 ALK 2669 50-103-20197 93-152 ACCEPT: 10/24/93 10:00 SPUD: 10/25/93 01:00 RELEASE: 03/04/94 06:00 OPERATION: DRLG RIG: PARKER 245 WO/C RIG: NORDIC 1 10/25/93 (1) PARKER 245 TD: 925'( o) 10/26/93 (2) PARKER 245 TD: 3975' (3050) o) 10/27/93 (3) PARKER 245 TD: 3975'( DRILL 12.25" HOLE 16"@ 121' MW: 9.7 VIS: 84 MOVE RIG F/2A-20 TO 2A-19. ACCEPT RIG @ 2200 HRS 10/24/93. NU DIVERTER. FUNCTION TEST SAME. DIVERTER TEST WAIVED BY AOGCC REP JOHN SPAULDING. MU BHA. ADJUST NAVI-DRILL & ORIENT TOOLS. C/O COND F/115'-121'. DRILL & MWD SURV 12.25" HOLE F/121'-925'. RIH W/HOLE OPENER 16"@ 121' MW:10.1 VIS: 86 DRILL & MWD SLrRV 12.25" HOLE F/925'-1966'. SERV RIG & TOP DRIVE. DRILL & SURV 12.25" HOLE F/1966'-3975'. CIRC HOLE CLEAN. MIX & PMP DRY JOB. POOH 18 STDS TO 2325'. NO TIGHT SPOTS. CIRC HI-VIS SWEEP @ 2325'. LARGE AMT OF CUTTINGS OVER SHAKERS UNTIL REACH BU. CONT POOH. PULLING TIGHT F/2015'-1856'. PMP OUT OF HOLE F/1856'-1292' POOH TO HWDP. RIH & HIT BRIDGE @ 1292'. POOH TO PU HOLE OPENER. LD ANADRILL TOOLS & MOTOR. MU HOLE OPENER ASSY. RIH TO 1275' & HIT BRIDGE. WASH PIPE DOWN. Nil BOP'S 9-5/8"@ 3957' MW:10.1 VIS: 52 WASH & REAM F/1280'-1481'. FRIH-WASH 56' TO BTM-NO FILL. CIRC & COND MUD & HOLE F/7"-SLUG. POH TO 1954' CIRC @ 1954'. POH-PUMPED OUT F/1610'-1280'. FIN POH. LD STAB & H/O. RU CASERS. HOLD SAFETY MEETING. RAN 36 JTS 9-5/8" 36# J-55 & 59 JTS 9-5/8" 47# L-80 CSG. WASHED & WORKED CSG IN HOLE F/1415'-1757'. PU HGR & LANDING JT. CIRC & COND MUD & HOLE W/CSG ON BTM @ 3957'. PUMPED TOTAL 740 BBLS @ 6 BPM-350 PSI-RECIP CSG. FLUSHED CMT LINE W/20 BBLS WATER. TEST LINES TO 3500 PSI. SET & CMT'D 9-5/8" CSG W/SHOE @ 3957' & FC @ 3869'. DOWELL CMT'D PUMPING 50 BBLS WATER AHEAD, 660 SX AS III(228 BBLS)LEAD & 540 SX CLASS G(ll0 BBLS)TAIL. DISPLACED W/20 BBLS WATER & 269 BBLS MUD. FULL RETURNS THROUGH OUT JOB-STOPPED RECIP W/90 BBLS DISP PUMPED. CIRC 30 SX 11 PPG CMT TO SURF. PLUG DOWN & JC @ 0230 HRS. PLUG BUMPED & FLOATS HELD. LD CMT EQUIP & LANDING JT. ND DIVERTER-WASH OUT ANN & VALVES. INSTALL PACK-OFF. SCREW ON 11"-3000 PSI BRADEN HEAD W/14,000 FT/LBS. NU 13-5/8"-5000 PSI BOP'S. Gas Cons. Commission Anchorage WELL: 2A-19 API: 50-103-20197 PERMIT: 93-152 PAGE: 2 10/28/93 (4) PARKER 245 TD: 5553' (1578) 10/29/93 (5) PARKER 245 TD: 8980' (3427) 10/30/93 (6) PARKER 245 TD: 9350'( 370) 10/31/93 (7) PARKER 245 TD: 9785' ( 435) DRILLING 9-5/8"@ 3957' MW:10.0 VIS: 41 FIN NU BOP'S. LD 8" DC'S OUT OF DERRICK. RU TEST EQUIP. TEST ALL BOPE TO 300/3000 PSI. NO FAILURES. TEST WAIVED BY JOHN SPAULDING W/AOGCC. BLOW DOWN CHOKE & KILL LINES. SET WEAR BUSHING. PU 8.5" BHA, ORIENT TOOLS, INSTALL RA SOURCE, & SURF TEST MWD. RIH TO 3571'. CUT DRILL LINE. FRIH. TAGGED UP @ 3869'. CIRC 10 MIN. TEST 9-5/8" CSG TO 2000 PSI FOR 30 MIN. HELD. DRILL PLUGS, FC @ 3869', CMT, FS @ 3957' & 10' NEW HOLE TO 3985'. CIRC & COND MUD. RAN EMW TEST. PRESS TO 590 PSI W/8.7 PPG MUD. EMW=12.7 PPG @ 2814' TVD. CIRC & COND MUD. RAISE MUD WT TO 10.0 PPG. DRILL 8.5" HOLE F/3985'-5553'. SLIGHT SHOW OF OIL & GAS IN TOP OF COLVILLE SAND. DID NOT CUT MUD WT. DRILLING 9-5/8"@ 3957' MW:10.4 VIS: 44 DRILL 8.5" HOLE F/5553'-6861'. SERV RIG. DRILL 8.5" HOLE F/6861'-8980'. RAISED MUD WT TO 10.7+ W/12 BBL LCM. HOLE SEEPING MUD @ 8800' ABOUT 1 BPM LOSS(MUD WT 10.7+ IN & 10.5 OUT). CUT MUD WT TO 10.5 PPG & REDUCED PMP RATE TO 94 SPM. CONT DRILLING & DROPPING ANGLE W/HOLE SEEPING. MIXED LCM-TOTAL 16 BBLS. CUTTING MUD WT TO 10.4 PPG @ 0600 HRS. HOLE STILL SEEPING MUD. DRILLING 9-5/8"@ 3957' MW:10.6 VIS: 48 DRILL F/8980'-9111'. CBU. SLUG DP. 4OOH W/5 STDS. WELL FLOWING-OBSERVE WELL-GAINED 30 BBLS. RIH. CBU-NO GAS. POOH. LD LWD TOOLS, MWD, & TURBINE. PU NEW BHA, LWD TOOLS, INSTALL RA SOURCE & TIH SLOW TO SHOE. FILL PIPE. SERV RIG. FRIH SLOW. CIRC & COND MUD. LOG W/LWD F/9001'-9111'. MIX LCM-35 BBL IN SYSTEM. MUD WT 10.6 PPG. 100% RETURNS-NO MUD LOSS. DRILL 8.5" HOLE F/9111'-9350'. NO MUD LOSS. POH TO RUN 7" CSG 9-5/8"@ 3957' MW:10.9 VIS: 48 DRILL 8.5" HOLE F/9350'-9785'. CBU. SLUG DP. POH W/20 STDS DP. HOLE TIGHT & SWABBING THRU KUPARUK SAND. PMP OUT F/9580'-9480'. HOLE NOT TAKING CALC FILL-GAINED 10 BBLS W/20 STDS OUT WELL NOT FLOWING. RIH-NO FILL. CBU-GAS & OIL TO SURF W/2200 STROKES-CIRC GAS OFF. MIX LCM & RAISE MUD WT TO 10.9 PPG. MADE 20 STDS SHORT TRIP. PUMPED 4 STDS OUT. HOLE TIGHT F/9400'-8600'_ HOLE FILL OK. CBU. NO GAS CUT MUD. DROP SURV. PMP 4 STDS OUT-POH TO RUN 7" CSG. RECEIVED APR - 8 1994 ~i~ska Uil & Gas Corm. Commission Anchorage WELL: 2A-19 API: 50-103-20197 PERMIT: 93-152 PAGE: 3 11/01/93 (8) PARKER 245 TD: 9785'( 11/02/93 (9) PARKER 245 TD: 9785'( 11/06/93 (10) DOWELL TD: 9785 FREEZE PROTECTING 7"@ 9765' MW:10.9 VIS: 46 o) FPOH. LD BHA. RU CASERS. HOLD SAFETY MEETING. RAN 234 JTS 7" 26# L-80 AB MOD BTC CSG. SET & CMT'D 7" W/SHOE @ 9765' & FC @ 9683'. DOWELL CMT W/225 SX CLASS G CMT RECIP W/GOOD RETURNS THROUGH OUT JOB. PLUG DOWN & J~ @ 1130 HRS. PLUG BUMPED & FLOATS HELD. PRESS UP ON CSG TO 3500 PSI. LOST 100 PSI IN 30 MIN-9-5/8" BTC CMT HEAD ADAPTER LEAKING. OBSERVE WELL-WELL FLOWING BACK PRETTY STRONG. PU BOP. LANDED CSG W/200,000 ON SLIPS. CUT OFF. ND BOP'S. MADE FINAL CUT. SET PACK-OFF. SET DIVERTER IN SUB BASE. NU 11"-3000 X 7-1/16"-5000 PSI TBG HEAD. TEST SAME TO 3000 PSI-OK. FREEZE PROTECT 9-5/8" X 7" ANN @ 0600 HRS. RIG RELEASED 7"@ 9765' MW: 10.9 VIS: 0 0) FIN FREEZE PROTECTING WELL W/175 BBLS WATER & 70 BBLS DIESEL. INTIAL PRESS=-500 PSI @ 3.5 BPM. FINAL=850 PSI @ 3.5 BPM. 37.22' RT TO LOCK DOWN SCREWS ON TBG HEAD. LD 276 JTS 5" DP IN MOUSE HOLE. FIN INJ MUD-FREEZE PROTECT 2A-24. RELEASED RIG @ 1430 HRS 11/01/93. MOVE RIG F/2A-19 TO 2E-07. 7"@ 9765' DO ARCTIC PACK JOB. 02/03/94 (11) NORDIC 1 TD: 9785 PB: 9683 WARM UP RIG 7"@ 9765' MW: 0.0 NaC1/Br WARM UP RIG. MOVE NORDIC CAMP TO 2A PAD. UNLOAD TBG & COMPLETION EQUIP. 03/03/94 (12) NORDIC 1 TD: 9785 PB: 9683 WARM UP RIG 7"@ 9765' MW: 0.0 NaCl/Br 03/04/94 (13) NORDIC 1 TD: 9785 PB: 9683 RIH W/3-1/2" COMPLETION 7"@ 9765' MW: 0.0 NaCl/Br ACCEPT RIG @ 06:00 HRS 03/03/94. MOVE RIG OVER 2A-19. NU BOP STACK. TEST BOPE TO 250/3000 PSI HI. TEST WITNESSSED BY JOHN SPAULDING OF AOGCC. RU SCHLUMBERGER. PERF A SAND F/9460'-9490' W/4-1/2" HSD HANS @ 4 SPF. ASF. FIN LOADING PIPE SHED W/3-1/2" TBG, STRAP & DRIFT. RU TBG TONGS & FLOWLINE. MU TAILPIPE & BAKER 7 X 3-1/2" FHL RETV PKR W/PBR. RIH W/J-55 COMPLETION. R F.. C F.. i¥ F-. D /~PR -8 1994 Aiaska Oil & Gas Cons. OolTimissio~ Anchorage WELL: 2A-19 API: 50-103-20197 PERMIT: 93-152 PAGE: 4 03/05/94 (14) NORDIC 1 TD: 9785 PB: 9683 RIG RELEASED 7"@ 9765' MW: 0.0 NaCl/Br SERVICE RIG. CONT RIH W/3-1/2" SINGLE COMPLETION. MU CAMCO TRDP 2SSA-TEST CONTROL LINE TO 5000 PSI. MU WKM TBG HGR. DROP BALL & LAND TBG. PRESS UP TO 2500 PSI & SET BAKER FHL PKR @ 9272'. SHEAR PBR @ 23K OVER STRING WT W/1000 PSI. TEST ANN TO 2500 PSI. TEST TBG TO 3000 PSI-OK. SHEAR OUT BALL @ 3900 PSI. SET BPV-SET BACK BOP. NU TREE. TEST TBG HGR. PULL BPV. SET TREE TEST PLUG & TEST TO 5000 PSI. PULL PLUG. DISPLACE ANN W/DIESEL FOR FREEZE PROTECTION. SECURE WELL. RIG RELEASED @ 1800 HRS 03/04/94. SIGNATURE: DATE: RECEIVED APR - 8 199~ /~i~ska. Oil & 6. as Cons. Commissior~ Anchorage SUB. SURFACE DIRECTIONAL SURVEY ~-~UIDANCE [~ONTINUOUS F~OOL Company _ Well Name Field/Location RECEIVED APl:! -8 1994 Oil & Oas Oons. 6ommis: Anchorage ARCO ALASKAm INC. · 2A-19 (676'FSL. 53'FEL. SEC.14, T11N~ R8E. UR) KUPARUK. NORTH SLOPE. ALASKA . Job Reference No: 93515 Logged By: SARBER Date 11/4/93 Computed Ely;. SINES · SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA INC, 2A - 19 RECEIVED Gas Cons, Commissio~ Anchorage KUPARUK RIVER NORTH SLOPE, ALASKA SURVEY DATE' NOV-4-1993 ENGINEER' G. SARBER METHODS OF COMPUTATION TOOL LOCATION: MINIMUM CURVATURE INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 73 DEG 4 MIN WEST COMPUTATION DATE- lO-NOV-93 · PAGE ARCO ALASKA INC. 2A - 19 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY- NOV-4-1993 KELLY BUSHING ELEVATION' 135.00 FT ENGINEER' G. SARBEI:~ INTERPOLATED VALU~ FOR EVEN 100 FEET OF MEASURED DFJ:)TH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 100.00 200.00 300.00 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 0 O0 -135 O0 99 76 -35 199 76 64 299 75 164 399 58 264 499 11 364 598 16 463 695 41 56O 790 51 655 882 41 747 0 0 N 0 0 E 24 0 11 N 89 24 W 76 0 13 N 65 14 W 75 I 29 N 89 16 W 58 4 36 S 77 40 W 11 6 19 S 80 4O W 16 10 13 S 88 56 W 41 15 54 S 85 20 W 51 20 19 S 74 52 W 41 25 26 S 70 32 W 0 O0 0 12 0 4O 1 18 6 8O 16 31 29 69 51 93 82 47 12~ 79 0. O0 0 25 0 12 0 75 2 97 2 29 2 85 5 25 5 81 5 89 000N 0 01N 0 10 N 035N 0 60S 2465 3 625 4.41 S 9.73 S 21.95 S 120 0.00 E 0.13 W 0 0.45 W 0 1 33W 6 93W 6 16 31 W 16 29 93 W 30 52 95 W 53 83 25 W 83 62 W 122 0 O0 N 0 0 E 13 N 86 6 W 46 N 77 34 W 38 N 75 22 W 95 S 85 5 W 49 S 81 26 W 15 S 83 6 W 13 S 85 15 W 81 S 83 20 W 60 S 79 41W 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 1900 972.12 O0 1061.07 926 O0 1149,81 1014 O0 1237 66 1102 O0 1323 33 1188 O0 1406 08 1271 O0 1486 56 1351 O0 1564 64 1429 O0 1639 39 1504 O0 1708 56 1573 837 12 26 46 07 27 29 81 27 39 66 29 27 33 32 52 08 35 17 56 37 32 64 39 55 39 43 42 56 48 42 S 71 7 W S 71 49 W S 72 30 W S 73 18 W S 74 24 W S 75 8 W S 74 56 W S 73 7 W S 72 27 W S 72 46 W 165 91 211 60 257 70 305 46 357 O0 413 09 472 39 534 84 601 23 673 39 4.58 0.89 0.74 O. 94 I. 72 2.33 2.66 2.72 2.72 3.41 36 52 S 162 31 W 166.37 S 77 19 W 5O 65 79 93 108 123 140 160 181 97 S 205 10 S 249 18 S 295 46 S 344 15 S 398 31S 456 60 S 516 36 S 579 94 S 648 67 W 211.89 S 76 5 W 56 W 257.91 S 75 23 W 20 W 305.63 S 74 59 W 72 W 357.17 S 74 50 W 88 W 413.29 S 74 50 W 25 W 472.62 S 74 53 W 27 W 535.08 S 74 46 W 66 W 601.43 S 74 32 W 51 W 673.55 S 74 20 W 2000 O0 1771 54 1636 54 52 47 2100 2200 2300 2400 2500 2600 2700 2800 2900 O0 1830 O0 1887 O0 1941 O0 1993 O0 2043 O0 2093 O0 2143 O0 2193 O0 2244 73 1695 03 1752 66 1806 08 1858 75 1908 98 1958 96 2008 73 2058 63 2109 73 54 38 03 56 23 66 57 49 08 59 35 75 59 42 98 59 57 96 60 5 73 60 15 63 57 48 S 73 17 W S 72 50 W 831 S 72 38 W 914 S 72 33 W 998 S 72 9 W 1083 S 72 0 W 1169 S 72 3 W 1256 S 72 21W 1343 S 73 13 W 1429 S 71 58 W 1515 751 02 62 26 O1 76 96 41 02 75 81 3 98 3 67 3 O0 1 99 1 69 1 21 1 O1 0 43 0 46 0 89 204 54 S 722.79 W 751.17 S 74 12 W 228 252 277 303 330 357 383 409 434 05 S 799.88 W 831 75 S 74 5 W 69 S 878.76 W 914 68 S 958 70 W 998 78 $ 1040 39 W 1083 38 S 1122 40 W 1170 08 S 1204 64 W 1256 68 S 1287 07 W 1343 29 S 1369 93 W 1429 82 S 1452 12 W 1515 37 S 73 57 W 10 S 73 51W 83 S 73 43 W O1 S 73 36 W 45 S 73 29 W 04 S 73 24 W 77 S 73 22 W 83 S 73 20 W 3000 O0 2299.29 2164 29 56 44 3100 3200 3300 3400 3500 3600 3700 3800 3900 O0 2353.39 2218 O0 2406.15 2271 O0 2458.07 2323 O0 2508.73 2373 O0 2560.21 2425 O0 2612.55 2477 O0 2663.81 2528 O0 2716.96 2581 O0 2770.30 2635 39 57 45 15 58 28 07 59 8 73 59 S1 21 58 2 55 58 54 81 59 2 96 57 24 30 58 9 S 72 8 W 1599 53 S 72 33 W 1683 S 72 38 W 1768 S 72 38 W 1854 S 72 50 W 1940 S 75 15 W 2025 S 75 31W 2111 S 75 30 W 2196 S 74 34 W 2281 S 74 55 W 2366 62 57 03 24 95 09 87 53 O8 1 . 40 1 O1 0 65 0 66 0 76 1 16 I 32 1 32 1 74 1 37 460 70 S 1531.76 W 1599 54 S 73 16 W 486 511 537 562 586 608 629 651 673 24 S 1611 88 W 1683 64 S 1692 19 S 1774 83 S 1856 67 S 1939 14 S 2021 54 S 2104 66 S 2186 97 S 2268 94 W 1768 51W 1854 82 W 1940 15 W 2025 61W 2111 76 W 2196 52 W 228! 11W 2366 63 S 73 13 W 57 S 73 11W 03 S 73 9 W 25 S 73 8 W 96 S 73 10 W 10 S 73 15 W 89 S 73 21W 56 S 73 24 W 13 S 73 27 W RECEIVED COMPUTATION DATE' lO-NOV-93 PAGE 2 ARCO ALASKA INC. 2A - 19 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' NOV-4-1993 KELLY BUSHING ELEVATION' 135.00 ET ENGINEER' G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG ~IN 4000 O0 2823 38 2688.38 57 48 4100 4200 4300 4400 4500 4600 4700 4800 4900 S 74 40 W 2450.79 O0 2876 O0 2929 O0 2982 O0 3036 O0 3089 O0 3142 O0 3196 O0 3250 O0 3305 54 2741.54 57 51 S 74 30 W 2535.46 76 2794.76 57 47 S 74 13 W 2620.09 91 2847.91 57 53 S 73 55 W 2704 79 11 2901.11 57 53 S 73 44 W 2789 46 19 2954.19 57 59 S 73 41 W 2874 20 59 3007.59 57 34 S 73 33 W 2958 74 49 3061,49 57 11 S 73 5 W 3042 97 90 3115.90 56 59 S 72 56 W 3126 88 30 3170.30 57 7 S 72 50 W 3210 78 1 . 30 0 86 0 49 0 37 0 31 0 2O 0 22 0 26 0 33 0 31 696 16 S 2349,91 W 2450 86 S 73 30 W 718 741 764 788 812 835 86O 884 909 65 S 2431 56 W 2535 51S 2513 72 S 2594 36 S 2675 14 S 2757 98 S 2838 14 S 2919 71S 2999 41S 3079 08 W 2620 54 W 2704 85 W 2789 19 W 2874 31W 2958 O0 W 3043 23 W 3126 42 W 3210 54 S 73 32 W 19 S 73 34 W 89 S 73 35 W 57 S 73 35 W 31 S 73 35 W 86 S 73 35 W 09 S 73 35 W 99 S 73 34 W 89 S 73 33 W 5000 O0 3359 56 3224 56 57 7 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 3413 O0 3463 O0 3512 O0 3561 O0 3611 O0 3664 O0 3717 O0 3770 O0 3823 60 3278 96 3328 55 3377 28 3426 23 3476 18 3529 36 3582 49 3635 65 3688 60 57 59 96 60 56 55 60 55 28 60 47 23 58 24 18 57 53 36 57 55 49 57 53 65 57 54 S 72 50 W 3294 78 S 73 26 W 3378 S 75 36 W 3465 S 75 30 W 3552 S 75 21W 3639 S 72 18 W 3726 S 7I 42 W 3811 S 71 29 W 3895 S 71 9 W 3980 S 7O 43 W 4065 92 24 56 81 40 21 87 55 19 0.23 0.26 0 84 0 76 0 67 1 56 1 64 I 66 1 56 0 31 934 20 S 3159 68 W 3294.89 S 73 32 W 958 981 1003 1025 1048 1075 1101 1128 1156 89 S 3240 55 S 3323 37 S 3408 35 S 3492 65 S 3576 02 S 3656 79 S 3736 93 S 3817 64 S 3897 11 W 3379,02 S 73 31 W 45 W 3465 36 S 73 33 W 08 W 3552 71 S 73 36 W 59 W 3639 99 S 73 38 W O1 W 3726 60 S 73 39 W 63 W 3811 38 S 73 37 W 98 W 3896 02 S 73 34 W 24 W 3980 68 S 73 31 W 27 W 4065 29 S 73 28 W 6000 O0 3876 62 3741 62 58 6 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 3929 O0 3982 O0 4038 O0 4094 O0 4150 O0 4207 O0 4263 O0 4318 O0 4374 45 3794 58 3847 19 3903 60 3959 9O 4015 03 4072 12 4128 96 4183 86 4239 45 58 7 58 57 25 19 55 36 60 55 44 90 55 48 03 55 55 12 55 58 96 56 3 86 55 59 S 70 28 W 4149 92 S 70 19 W 4234 74 S 69 58 W 4319 35 S 68 59 W 4402 27 S 68 43 W 4484 62 S 68 40 W 4567 02 S 68 31W 4649 53 S 68 21 W 4732.05 S 68 9 W 4814.71 S 67 56 W 4897.30 0 31 0 29 0 31 0 82 0 0 0 0 0 0 82 8O 29 17 2O 20 1184 86 S 3977 26 W 4150 O0 S 73 25 W 1213 1242 1271 1301 1331 1361 1391 1422 1453 39 S 4057 07 S 4136 41S 4214 20 S 4291 24 S 4368 45 S 4445 92 S 4522 68 S 4599 68 S 4676 23 W 4234 94 W 4319 69 W 4402 70 W 4484 70 W 4567 75 W 4649 73 W 4732 77 W 4814 67 W 4897 79 S 73 21W 38 S 73 17 W 29 S 73 13 W 62 S 73 8 W 02 S 73 3 W 54 S 72 58 W 07 S 72 54 W 75 S 72 49 W 39 S 72 44 W 7000.00 4430 88 4295.88 55 43 7100.00 4487 7200.00 4544 7300.00 4601 7400 O0 4658 7500 O0 4714 7600 O0 4771 7700 O0 4827 7800 O0 4884 7900 O0 4941 37 4352.37 55 33 32 4409.32 55 77 4466.77 54 50 77 4523.77 55 47 79 4579.79 55 58 28 4636.28 55 19 94 4692.94 55 24 98 4749.98 54 58 28 4806.28 56 39 S 68 46 W 4979 83 S 69 47 W 5062 S 69 31W 5144 S 69 8 W 5225 S 69 49 W 5307 S 69 31W 5390 S 69 33 W 5472 S 72 23 W 5555 S 71 41W 5637 S 73 49 W 572O 19 24 91 91 60 94 3O 42 05 0 3O 0 56 0 58 0 52 0 61 0 63 0 71 1 17 1 16 1 58 1484 59 S 4753.52 W 4979 96 S 72 39 W 1513 1541 1570 1599 1628 1657 1683 1709 1733 39 S 4830.84 W 5062 98 S 4907.91 W 5144 89 S 4984.49 W 5226 77 S 5061.41 W 5308 50 S 5139.10 W 5390 57 S 5216.32 W 5473 86 S 5294.41 W 5555 09 S 5372.57 W 5637 78 S 5451.43 W 5720 35 S 72 36 W 44 S 72 33 W 16 S 72 30 W 21 S 72 28 W 95 S 72 25 W 35 S 72 22 W 73 S 72 21W 86 S 72 21W 49 S 72 21W COMPUTATION DATE: lO-NOV-g3 PAGE ARCO ALASKA INC. 2A - 19 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: NOV-4-1993 KELLY BUSHING ELEVATION: 135.00 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 8000 O0 4996.62 4861 62 55 58 8100 O0 5052.57 4917 57 56 41 8200 O0 5106.61 4971 8300 O0 5160.50 5025 8400 O0 5214.65 5079 8500 O0 5269.35 5134 8600 O0 5327.43 5192 8700 O0 5389.70 5254 8800 O0 5454.97 5319 8900 O0 5521.99 5386 61 57 27 50 57 23 65 57 7 35 55 57 43 53 13 70 50 17 97 48 31 99 47 21 9000 O0 5592 15 5457 15 44 23 O0 5664 O0 5737 O0 5811 O0 5885 O0 5961 O0 6O37 O0 6114 O0 6179 67 5529 59 5602 3O 5676 99 5750 28 5826 49 5902 12 5979 03 6044 67 43 15 59 42 50 30 42 4 99 41 30 28 4O 35 49 40 10 12 40 13 03 40 13 9100 9200 9300 9400 9500 9600 9700 9785 S 73 34 W 5803 33 S 73 24 W 5886 S 73 28 W 5970 S 73 15 W 6054 S 73 2 W 6138 S 72 44 W 6222 S 72 50 W 6303 S 72 36 W 6381 S 70 51W 6457 S 69 47 W 6531 1.25 21 1.37 1780 35 1.21 1804 59 0.91 1828 66 0.67 1853 37 0.42 1877 76 1.13 1901 98 1.99 1924 71 2,73 1948 83 2.36 1974 S 68 50 W 6602.91 S 68 48 W 6671.56 S 74 10 W 6739.92 S 79 54 W 6807.29 S 82 59 W 6872.97 S 82 38 W 6937.83 S 83 38 W 7001.65 S 86 11 W 7064.71 S 86 11 W 7118.16 2 32 1 37 1 31 2 29 3 14 2 32 1 O1 0 O0 0 O0 1757 05 S 5531 40 W 5803 76 S 72 23 W 75 S 5610 62 S 5691 79 S 5772 20 S 5852 86 S 5932 96 S 6010 94 S 6085 85 S 6157 08 S 6226 82 W 5886 50 W 597O 20 W 6O54 65 W 6139 64 W 6222 38 W 6304 15 W 6382 03 W 6458 84 W 6532 63 S 72 23 W 75 S 72 24 W 98 S 72 25 W 04 S 72 26 W 75 S 72 26 W 14 S 72 26 W 36 S 72 27 W 10 S 72 26 W 27 S 72 25 W 1999 29 S 6293.46 W 6603 39 S 72 23 W 2024 2O46 2061 2070 2079 2087 2092 2096 30 S 6357 61W 6672 52 S 6422 30 W 6740 59 S 6488 14 W 6807 90 S 6553 96 W 6873 14 S 6619 25 W 6938 28 S 6683 49 W 7001 36 S 6747 85 W 7064 02 S 6802 61 W 7118 10 S 72 2O W 48 S 72 2O W 8O S 72 22 W 35 S 72 28 W 11 S 72 34 W 84 S 72 39 W 80 S 72 46 W 20 S 72 52 W RECEIVED '. C:-' qO ~,,,~, .- $ 1.,,~zl- Anchorage COMPUTATION DATE: lO-NOV-93 PAGE 4 ARCO ALASKA INC. 2A - 19 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: NOV-4-1993 KELLY BUSHING ELEVATION: 135.00 FT ENGINEER: G, SARBER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 1000 2000 3000 4000 5000 6000 7000 8OOO 9000 0 O0 972 O0 1771 O0 2299 O0 2823 O0 3359 O0 3876 O0 4430 O0 4996 O0 5592 O0 -135 O0 12 837 54 1636 29 2164 38 2688 56 3224 62 3741 88 4295 62 4861 15 5457 0 0 12 26 46 54 52 47 29 56 44 38 57 48 56 57 7 62 58 6 88 55 43 62 55 58 15 44 23 N 0 0 E S 71 7 W S 73 17 W 751 S 72 8 W 1599 S 74 40 W 2450 S 72 50 W 3294 S 70 28 W 4149 S 68 46 W 4979 S 73 34 W 5803 S 68 50 W 6602 0. O0 165 91 02 53 79 78 92 83 33 91 0. O0 4.58 3.98 1.40 1 30 0 23 0 31 0 30 1 25 2 32 0 O0 N 36 204 46O 696 934 1184 1484 1757 1999 52 S 162.31W 166 54 S 722.79 W 751 70 S 1531.76 W 1599 16 S 2349.91 W 2450 20 S 3159.68 W 3294 86 S 3977.26 W 4150 59 S 4753.52 W 4979 05 S 5531.40 W 5803 29 S 6293,46 W 6603 0.00 E 0 O0 N 0 0 E 37 S 77 19 W 17 S 74 12 W 54 S 73 16 W 86 S 73 30 W 89 S 73 32 W O0 S 73 25 W 96 S 72 39 W 76 S 72 23 W 39 S 72 23 W 9785.00 6179.03 6044.03 40 13 S 86 11 W 7118.16 0'.00 2096.02 S 6802.61 W 7118.20 S 72 52 W RECEIVED , :~!,~, ,.,P. & G~s Cons. Oomm]ssior, Anchorage COMPUTATION DATE- lO-NOV-93 PAGE 5 ARCO ALASKA INC. 2A - 19 KUPARUK RZVER NORTH SLOPE, ALASKA DATE OF SURVEY' NOV-4-1993 KELLY BUSHING ELEVATION' 135.00 FT ENGINEER' G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IOO FEET FEET FEET DEG MIN 0 O0 135 24 235 24 335 27 435 56 536 14 637 59 741 34 847 95 958 49 0 O0 -135.00 135 O0 235 O0 335 O0 435 O0 535 O0 635.00 735.00 835.00 935.00 0 0 0.00 0 11 100.00 0 18 200.O0 2 46 300 O0 5 18 400 O0 7 15 500 O0 12 31 600 O0 17 36 700 O0 23 8 800 O0 26 23 N 0 0 E N 77 17 W N 56 27 W S 81 51W S 78 12 W S 83 25 W S 89 50 W S 81 17 W S 71 46 W S 7O 45 W 0 O0 0 22 0 5O 2 48 9 86 2O 54 36 80 63 64 100 33 147 36 0 O0 0 19 0 14 1 54 3 O4 1 99 3 86 5 49 6 O3 5 33 0.00 N 0.02 N 0 0.17 N 0 0.23 N 2 1,25 S 9 3,04 S 20 3,67 S 37 5,82 S 64 14.95 S 100 30.45 S 144 0 O0 E 0 O0 N 0 0 E 24 W 0 57 W 0 66 W 2 92 W 10 55 W 20 35 W 37 75 W 65 33 W 101 76 W 147 24 N 84 39 W 6O N 73 32 W 67 N 85 9 W O0 S 82 49 W 77 S 81 35 W 53 S 84 23 W 02 S 84 52 W 43 S 81 31 W 93 S 78 7 W 1070 63 1035 O0 1183 1296 1413 1535 1661 1793 1940 2107 2287 29 1135 94 1235 89 1335 60 1435 64 1535 93 1635 86 1735 45 1835 44 1935 O0 1000 O0 1100 O0 1200 O0 1300 O0 1400 O0 1500 O0 1600 O0 1700 O0 1800 900 O0 27 22 O0 27 25 O0 29 22 O0 33 23 O0 36 8 O0 38 53 O0 43 26 O0 50 43 O0 54 49 O0 57 21 S 71 45 W 198.07 S 72 21W 249.95 S 73 16 W 303.94 S 74 32 W 364.51 S 75 18 W 433.84 S 73 43 W 510.49 S 72 27 W 597.05 S 73 3 W 704.53 S 72 47 W 837.73 S 72 40 W 987.36 0.92 0,75 0 93 1 83 2 5O 2 72 2 69 3 7O 3 64 2 O4 46 74 S 192 82 W 198.40 S 76 22 W 62 78 95 113 133 159 191 229 274 76 S 242 75 S 293 48 S 351 46 S 418 64 S 492 10 S 575 10 S 678 86 S 805 47 S 948 16 W 250 17 S 75 28 W 74 W 304 96 W 364 96 W 434 94 W 510 67 W 597 28 W 704 71W 837 54 W 987 11 S 75 0 W 68 S 74 49 W 05 S 74 51W 73 S 74 50 W 25 S 74 33 W 68 S 74 16 W 85 S 74 5 W 46 S 73 52 W 2482 66 2035.00 1900 O0 59 37 2682 2881 3065 3255 3451 3643 3833 4021 4209 05 2135 O0 2000 73 2235 70 2335 32 2435 76 2535 68 2635 60 2735 87 2835 84 2935 O0 2100 O0 2200 O0 2300 O0 2400 O0 2500 O0 2600 O0 2700 O0 2800 O0 60 5 O0 58 32 O0 57 24 O0 58 44 O0 58 56 O0 59 16 oo 57 36 O0 57 55 O0 57 49 S 72 0 W 1155 O0 S 72 13 W 1327 46 S 72 13 W 1500 28 S 72 24 W 1654 67 S 72 36 W 1815 77 S 73 53 W 1984 84 S 75 36 W 2148 53 S 74 38 W 2309 86 S 74 40 W 2469 31 S 74 12 W 2628.42 1 . 29 0.55 0.73 1.49 0.64 O. 87 1.34 1.50 1.29 0.48 325.75 S 1108.16 W 1155 05 S 73 37 W 378.93 S 1272.25 W 1327 430.07 S 1437.34 W 1500 477.51S 1584 27 W 1654 525.75 S 1737 99 W 1815 575:69 S 1899 52 W 1984 617.49 S 2057 90 W 2148 659.19 S 2213 84 W 2309 701.06 S 2367 743.78 S 2521 48 S 73 25 W 30 S 73 21W 67 S 73 14 W 78 S 73 10 W 84 S 73 8 W 54 S 73 18 W 90 S 73 25 W 78 W 2469.38 S 73 30 W 09 W 2628.51 S 73 34 W 4397.92 3035 O0 2900.00 57 53 4585.84 3135 4770.82 3235 4954.75 3335 5141 34 3435 5346 13 3535 5545 06 3635 5733 22 3735 5921 38 3835 6110 5O 3935 O0 3000.00 57 39 O0 3100.00 56 59 O0 3200.00 57 9 O0 3300.00 59 43 O0 3400.00 60 49 O0 3500.00 57 58 O0 3600.00 57 56 O0 3700.00 57 56 O0 3800.00 58 6 S 73 45 W 2787.70 S 73 36 W 2946 79 S 72 57 W 3102 41 S 72 50 W 3256 78 S 74 48 W 3414 27 S 75 26 W 3592 83 S 71 50 W 3764 67 S 71 23 W 3924 O1 S 70 39 W 4083 29 S 70 19 W 4243.64 0 31 0 22 0 32 0 27 0 95 0 72 1 62 1 67 0 29 0 29 787 87 S 2674 16 W 2787.81 S 73 35 W 832 877 922 968 1013 1060 lllO 1162 1216 60 S 2826 53 S 2975 98 S 3123 58 S 3274 48 S 3447 45 S 3612 75 S 3763 63 S 3914 39 S 4065 84 W 2946 91 S 73 35 W 84 W 3102 36 W 3256 11W 3414 09 W 3592 42 W 3764 66 W 3924 37 W 4063 53 S 73 34 W 88 S 73 32 W 38 S 73 31W 99 S 73 37 W 86 S 73 38 W 15 S 73 33 W 38 S 73 27 W 62 W 4243.69 S 73 21 W COMPUTATION DATE: lO-NOV-93 PAGE 6 ARCO ALASKA INC. DATE OF SURVEY: NOV-4-1993 2A - 19 KELLY BUSHING ELEVATION- 135.00 FT KUPARUK RIVER NORTH SLOPE, ALASKA ENGINEER- G. SARBER INTERPOLATED vALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE ~EASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG 6294 35 4035 O0 3900 O0 55 36 6471 6649 6828 7007 7183 7357 7535 7712 7888 73 4135 87 4235 71 4335 31 4435 72 4535 97 4635 99 4735 44 4835 58 4935 O0 4O00 O0 4100 O0 4200 O0 4300 O0 4400 O0 4500 O0 4600 O0 4700 O0 4800 O0 55 44 O0 55 49 O0 56 2 O0 55 41 O0 55 4 O0 55 18 O0 55 43 O0 55 20 O0 56 40 8068 36 5035 O0 4900 O0 55 55 8252 8437 8612 8769 8918 9059 9196 9331 9465 70 5135 45 5235 54 5335 72 5435 92 5535 30 5635 48 5735 83 5835 27 5935 O0 5000 O0 5100 O0 5200 O0 5300 O0 5400 O0 5500 O0 5600 O0 5700 O0 5800 O0 57 23 O0 57 5 O0 52 37 O0 48 SS O0 46 26 O0 43 11 O0 42 52 O0 41 40 O0 41 2 S 69 0 W 4397 63 S 68 41 W 4543 71 S 68 24 W 4690 69 S 68 7 W 4838 43 S 69 2 W 4985 85 S 69 33 W 5130 92 S 69 28 W 5273 31 S 69 20 W 5420.32 S 72 23 W 5565 55 S 73 44 W 5710.51 S 73 17 W 5859 91 S 73 19 W 6014 76 S 72 55 W 6~70 10 S 72 53 W 6313 75 S 71 18 W 6434 96 S 69 35 W 6545 54 S 68 37 W 6643 78 S 73 56 W 6737 52 S 81 38 W 6828.34 S 82 45 W 6915.45 0.82 0.80 0.18 0.20 0 34 0 61 0 52 0 62 1 16 I 53 I 24 0 98 0 43 I 25 2 65 2 36 2 15 1 27 2 6O 2 73 1269 74 S 4210 35 W 4397.64 S 73 13 W 1322 1376 1431 1486 1537 1587 1638 1686 1731 73 S 4346 62 S 4484 56 S 4621 76 S 4759 32 S 4895 72 S 5028 97 S 5166 96 S 5304 12 S 5442 92 W 4543,71 S 73 5 W 15 W 4690.70 S 72 56 W 86 W 4838.49 S 72 47 W 16 W 4985.99 S 72 39 W 41 W 5131.12 S 72 34 W 91 W 5273.60 S 72 29 W 98 W 5420.69 S 72 24 W 17 W 5565.98 S 72 21W 27 W 5710.96 S 72 21 W 1773 21 S 5585 62 W 5860 33 S 72 23 W 1817 1862 1904 1941 1978 2014 2045 2065 2076 32 S 5734 41S 5882 90 S 6019 48 S 6135 86 S 6239 17 S 6331 89 S 6419 02 S 6509 25 S 6596 05 W 6015 71W 6170 93 W 6314 50 W 6435 70 W 6545 65 W 6644 99 W 6738 10 W 6828 73 W 6915 15 S 72 25 W 48 S 72 26 W 13 S 72 26 W 35 S 72 26 W 98 S 72 24 W 30 S 72 21W O9 S 72 19 W 81 S 72 24 W 76 S 72 32 W 9596.74 6035.00 5900.00 40 10 9727.34 6135.00 6000.00 40 13 9785,00 6179.03 6044,03 40 13 S 83 30 W 6999.59 S 86 11 W 7081.90 S 86 11 W 7118.16 1.01 0. O0 0. O0 2087.05 S 6681.40 W 6999.78 S 72 39 W 2093.54 S 6765.47 W 7081.98 S 72 48 W 2096.02 S 6802.61 W 7118.20 S 72 52 W RECEIVED C:~a$ ~ COrllrll[SSiOr~ uOBS. Anchorage ARCO ALASKA INC. 2A - 19 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING OCT LAST READING PB1-D 7" CASING TD COMPUTATION DATE: lO-NOV-93 PAGE 7 DATE OF SURVEY: NOV-4-1993 KELLY BUSHING ELEVATION: 135.00 FT' ENGINEER: G. SARBER INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION : 676' FSL, $3' FEL, SEC14 T11N R8E MEASURED DEPTH TVD BELOW KB FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 3957.00 2800.45 2665,45 686.58 $ 2314.81 W 9650.00 6075.70 5940.70 2090.21 S 6715.59 W 9683.00 6101.14 5966.14 2091.63 S 6736.90 W 9765.00 6163.76 6028.76 2095.16 S 6789.73 W 9785.00 6179.03 6044.03 2096.02 S 6802.61 W RECEIVED Sas Cons. Commission Anchorage ARCO ALASKA INC. 2A - 19 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER COMPUTATION DATE: lO-NOV-93 PAGE 8 DATE OF SURVEY: NOV-4-1993 KELLY BUSHING ELEVATION: 135.00 FT ENGINEER: G. SARBER ************ S-FRATIGRAPHIC SUMMARY ************ SURFACE LOCATION = 676' FSL, $3' FEL, SEC14 TllN R8E MEASURED DEPTH 1-VD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 9785.00 6179,03 6044.03 2096.02 S 6802.61W FINAL WELL LOCATION AT 'rD' TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 9785.00 6179.03 6044.03 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 7118.20 S 72 52 W RECEIVED G~s Cons, Commissio~ Anchorage DIRECTIONAL SURVEY COMPANY FIELD ARCO ALASKA INC. KUPARUK RIVER WELL 2A- 19 COUNTRY USA RUN I DATE LOGGED 4 DEPTH UNIT FEET REFERENCE 93515 - NOV - 19 Afl interpretations are opinions based on inferences from electrical or other measurement~ and we cannot, and do not .............. guarantee the accuracy or correctness of any interpretations, and we shall not. except in the casa of grosa or wilfull negligence on our part. be lie, bls or responsible for any' lose, costs, damages or expenses Incurred or su~ained by anyone resulting from any interpretation made by any of our ol?'lcer~, agent~ or employees. Theae Intarpretation~ are also subject to our General Terms and Conditions as set out In our current price ~chedula. 2A-19 ~'FSL, 53'FEL, SEC.14, T11N, RSE, Ulq) NORTH GO00 liEF 93515 60OO 400O SCALE = I / 2000 IN/FT HORI~. .,TAL PRO,.]ECTIOII 2OOO -2000 -4000 -6OOO sou~-8000 -10000 WE~T -8000 -6OOO -400O -2000 20OO 4OOO RECEIVED 6000 · ' · I d .;,, T /~;-~$i.',a Oil & iJa,.$ Goos. ColFlrniss~o, Anchorage ' 2A-19 ~'FSL, 53'FEL, SEC.14, T11N, R8E, UI4) VERT[Co... PROdECT~ON -4000 -2000 0 0 2000 4000 6000 8000 10000 12000 ,.;.!.i*~ ~..i.i...i-.-i..'...i.*i-.i*..i.!.-i..i*--!...i. !'~:.i.!,-i*..i*-i-,.!..i...!.i..i.-i ..... i,.i.l-i .... iii .... ii-!.i ..i..!..i...~ .... i..i..~.~ .... i.;.!.~ .i ii ~ ~ i ...... ;;:; ::::.u.:..;..:.; ;.::.;..;..:.'.;.;,:.;.;:.;.;:: ~i~-~.-~i*~i~ii-:-~.~..i.i .... ~..;.i-:. ~-'~.~ :::: ....... i:_;.i ..... i.!..i...i .... :...i...i..i ..... !...!...i.:..!;.:~.,2~,; ..... ;..i...i..: ...... i...:.!...~..'...! .... :..i .... i,.i...i...i ...... : ...... !...:...i..~...:,.: .... ;..;...: ......... : ............ .. .... ,:~--:-~:~--:~ ~*:-:---~ -i-q:-'4--'~i-i~ i ~: i i-i-i-;r-' !,-i--! ....... i---i*--'---:-i--'---~---:---' -~--i-.i-.-'-~--'---'--i'--i:--l'--i::;-:-.~i,~--i-.: ..... i--~--i--!-- -i---i--i--: ..... ~"~'VE;~zCAC"iSEC?Z'ON ..... ::' ~';: ;f :* i'; i" i"("i'!'t i'i'"U~-:!'i"('!"'i i~'i i "i'~:!-:;~ ! ~ i'i:l'i {!( "i i'i'i" i i~","i'i'i'i' !'i !-(, i'i i:: ..... -:--~:--i .... ~--.!---:~ ...... :--!---h-.~ ..... '.--,--,.-,--,-.,-.-,--,-.,--,--'---,--,---,---,--,-.,,---'--,--,-,-..,--,---,..-,---, ,..-,--,-.-,-..---,.-,--,..-,-.,.--,---,.-., .... h--!-.+.i ..... i.~.: ........ ;-;-;; -;-!J-! ...... :---i,.-i-q- -!-!--i; -!-ii---i. i--i-.-;-i ..... !-!--i-;- -i.--i.i-i i--;,-!.i'-:i-..i--! ~.~..~.--~ .... ?--!.-?;.:-?.?~ :~ ...... ... : .:. · ............ :. ........ !.i;-;; -?.~i.~...~.,i.~..i:.~d ~.:..?.: ............ . ?!!';' !!'!'i =':"i'!'i 'ii~ iii!"'?'?i ? '?:'! ? i! ii !! :'! i'~ ! i! ..... ~' i'i ??-~ : :, : ~ ......... .L.-::}.:,.~..[.L-I,.-L-L.-~..Lh..~...~ ..[.} ................ L ~ . .J .... :.. LL.~ ~ ..... ~. ,.C[ : ~ : ~ ~ 5 ~ j 5 ~ ~ ~ i ~ i i i ~ ~ ~ ~ ~ 5 ~ ~ ! ! ~ ! ! ~ J i ! "~ i i-~-' !-~ [ /!'/-/ '/i';~/' '~ ;;;"~' ;';';'"; ...... ;?';'": ~';':~- ;"~";'; .... :-;';"i'u~';";'"?" ?:":'; !::';: :':~';'~";'?'' ,':~;: ;"' ;; : : ~' ' ~ ' ' ~ : :.;.~.F.;..u.,; ..... ;...F.F.~ -..FF.~ .F.:...F,; ..... ~..~...~..:.,...;...~...~...~ ..... ;...~.F..; :.-;..~..; ;.~..;.~ .... :,.,~..: : .~:...;.;.: .... : ; : .... ~ . ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ..... '-: ::::..: :: i:'; ~.~ -:~-~,-¢.-.~..~?--~- -~.;-;~ ~ ~--~ --~.??.~.~ ~ ~.;- ~ ~ ~ , ~ ~ ~ ~ .: .. : , ,: : ~:;¢,~.;...~ ;...~.¢..,~.:.~..~..~; .;.;..~...¢..~.~; .~;.~{ .~;:: .~ . ;; .;.;: :.:~. :.:: .... :--~-;--:--J.-~--;---;---;---I ....... ~--.h..~ ...... h--;..~..~..;--.;...;...; ...... ;...;..;...; ..... ;~;.~...;_~..;..~..;..~; .,.;..~ ..... ~.., :-:] ~: ~ L ]" '; .... : ' : ..... i ~ .... ~ ~ ~ ;' ': ;'"~"~ ..... d"~ ........ ~"~ ............ ~ ' ; ': "? ; ";' '; '': ' ..... ~"? .... ~'?"i ..... ~'"~"'i'"~ .... ????'~'~"~'"~'~ .... ?:?~' ':"~"~ ;':?: .... ;:';" :;'~'~ .... ; : '~":: : ...... :':::]::':"'':::,:.:::;f:~:~;:'";'':':":":'"~(::::: .... ::'::'~ ;1~(~{::~'':': ::':":~.~ :'":;~;:;; ..... ~'': ..... ~ .... : ~ ..... : : : : : ......... - -; ..... ~-- ..... ! ..... ;.-: ..... : ...... !.-.: ..... ~--~.:.' ~--!--¢-.?.~ ...... :.? ....... :: :: ::. ~:~ .:~ ::~ ~:~ 2~:: ::i~ :.:.~:. 25300 · 7 rr PROJECTION ON VERTICAL PLANE 73.00 253.00 SCALED IN VERTICAL DEPTHS HOFIIZ SCALE = 1 / 2000 IN/FT MEMORANDL I State ( Alaska Alaska Oil and Gas Conservation Commission TO: David Jo~ Chairmad~ DATE: March 3, 1994 THRU: Blair Wondzell, ~'-~'~ FILE NO: ~1~I?,'~, P. I. Supervisor FROM: John Spa.ulding, ,L~.~.~/(,_n._ SUBJECT: Petroleum Inspector ab91ccbd.doc BOPE Test Nordic 1 Arco KRU 2A-19 Kuparuk River Field PTD ~.~ - ! .5-Z. Thursday March 3,1994: I traveled to Arco's KRU Well 2A-19 Kuparuk River Field to witness the initial BOPE Test on Nordic Rig 1. As noted on the attached AOGCC BOPE Test Report there were no failures noted. This rig will be doing completions and will not be picking up the Kelly so we did not test the upper or lower Kelly valves. The rig has been stacked for about 4 months and came out in excellent shape. Summary' I witnessed the the BOPE Test at Arco well 2A-19 on Nordic Rig 1, test time 3 hours, no failures. Attachment: AB9LCCBD STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Drlg: OPERATION: XX× Workover: DATE: 3/3/94 Dflg Contractor: NORDIC Rig No. 1 PTD # 93-152 Rig Ph.# 659-7115 Operator: ARCO Rep.: KARLA LENZ , , , Well Name: 2A-19 Rig Rep.: LANCE JOHNSON Casing Size: 7" Set @ 9776' Location: Sec. 14 T. 1 1N R. 8E Meridian U.M. Test: Initial XXX Weekly Other Test MISC. INSPECTIONS: FLOOR SAFETY VALVES: Quan. Location Gen.: OK Well Sign OK Upper Kelly / IBOP NA Housekeeping: OK (Gen) Drl. Rig OK Lower Kelly / IBOP NA Reserve Pit NA Ball Type 1 , Inside BOP BOP STACK: Quan. Annular Preventer 1 Pipe Rams Pipe Rams NA Blind Rams 1 Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Test I 250/3500 P Pressure P/F 250/3500 P 1 250/3500 P Pressure P/F Test 250/3500 P Pressure 250/3500 '250/3500 P 250/3500 P 250/3500 P 250/3500 P CHOKE MANIFOLD: No. Valves 12 No. Flanges 33 Manual Chokes 1 Hydraulic Chokes I ACCUMULATOR SYSTEM: System Pressure Pressure After Closure MUD SYSTEM: Visual Alarm 200 psi Attained After Closure Trip Tank OK OK System Pressure Attained · Pit Level Indicators OK OK Blind Switch Covers: Flow Indicator OK OK Nitgn. Btl's: Gas Detectors OK OK 250/3500 Funcaoned Funcaoned P/F P p' 2950 P 2350 P Master: minutes 28 soc. 1 minutes 39 sec. XXX Remote: XXX 2EA. @2000 Psig. Number of Failur~s: O f ,Test Time: 3 '~Hours. Number of valves tested 18 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Excellent Test Distribution: orig-Well File c - Oper./Rig c - Database - e - Trip Rpt File c - Inspector STATE WITNESS REQUIRED3" YES XXX NO 24 HOUR NOTICE GIVEN YES XXX NO Waived By: Witnessed By: John H. Spaulding FI4)21L (Rev. 2/93) ABgLCCBD.XL$ ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 January 10, 1994 Phyllis Billingsley ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Dear Ms Billingsley: The Commission is compiling statewide drilling statistics for 1993. Attached is a list of outstanding Permits to Drill issued to your engineering group (permits for which no form 10-407 has been received by this o.ffice). Please review this list to determine if any of the wells were ddlled in 1993. If so, please note the well name, total measured depth, and class (development, service or exploratory). If any wells were drilling as of 12/31/93, estimate the depth at 12:00 midnight. We would appreciate your reply by the end of January if possible. Thank you for your cooperation with this project. If I may be of any assistance, please call me at 279-1433. Yours very truly, Robed P Crandall Sr Petr Geologist encl jo/A:RPC:\drlstats 1/o4/94 OPERATOR ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA INC ARCO ALASK~ INC ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA INC ARCO ALAS K~ ARCO ALASKA ARCO ALASKA INC ARCO ALAS K~ INC ARCO ALASKA INC ARCO AnAS K3k ARCO ALASKA INC ARCO ALAS K3k INC ALASKA WELLS BY ARCO PERMIT 93-0166-0 93-0152-0 93-0151-0 · 93-0163-0 93-0144-0 93-0188-0 93-0179-0 93-0169-0 93-0104-0 93-0189-0 93-0174-0 93-0175-0 93-0187-0 93-0195-0 93-0196-0 93-0193-0 92-0040-0 WELL NAME KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPkRUK RIV UNIT KU~UK RIV UNIT KUPARI3K RIV UNIT KUPARUK RIV UNIT KUPARIIK RIV UNIT KUPARUK RIV UNIT KYJPAI[IJK RIV OlqIT KUPARUK RIV I~IT KUPARUK RIV UNIT KIJPAR[JK RIV UNIT KIJPARUK RIV UNIT KUPARUK RIV IJNIT KUPARUK RIV UNIT KIJPARUK RIV UNIT 2A-18 2A-19 2A-20 2A-22 2A-24 2E-04 2E-05 2E-06 2E-07 2E-08 2E-17 2E-18 3M-23 3M-24 3M-25 3M-26 3R-16 2 ARCO Alaska, Inc. Date: November 23, 1993 Transmittal #: 8940 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2A- 19 Directional Survey 11-04-93 93515 2A-20 Directional Survey 11-04-93 93516 Acknowledged: DISTRIBUTION: D&M ?:State'of~Alask~ (2copies) · ?_.' '; . Anchorage ARCO Alaska, Inc. Date: November 19, 1993 Transmittal #: 8929 RETURN TO: ARCO Alaska, Inc. ATTN: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. receipt and return one signed copy of this transmittal. /2A-19 ~Cement Evaluation Log 11-04-93 ~,2A-19 /Cement Bond Log CBT 11-04-93 2A-20 ,~Cement Evaluation Log 11-04-935'~ 2A-20 ~:~- ement Bond Log CBT 11-04-93 d'2A-24 ,xCement Evaluation Log 11-08-93 ~,,2A-24 ~3ement Bond Log CBT 11-08-93 Acknowledge' ~/~'~ ~ Date' Drilling ~state~of Alaska(+sepia)~ NSK Please acknowledge 8500-9676 8500-9652 9900-11431 9900-11407 7600-9570 7600-9544 ALASKA OIL AND GAS CONSERVATION COMMISSION October 13, 1993 A. W. McBride Area Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Re: Kuparuk River Unit 2A-19 ARCO Alaska, Inc. Permit No: 93-152 Sur. Loc. 676'FSL, 53'FEL, Sec. 14, TllN, R8E, UM Btmhole Loc. 1393'FNL, 1571'FEL, Sec. 22, TllN, R8E, UM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALA~51',;A OIL AND GAS CONSERVATION COMMISS, . PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill D lb Type of Well Exploratory [] Stratigraphic Test r-] Development Oil X Re-Entry [] Deepen [] Service r"] Development Gas ~] Single Zone X Multiple Zone [] 2,. Name of Operator 5. Datum Elevation (DF or KB) 1 0, Field and Pool ARCO Alaska, Inc. RKB 135', Pad 94' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25571, ALK 2669 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 2o AAC 25,025) 676' FSL, 53' FEL, SEC. 14, T11N, RSE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1318' FNL, 1325' FEL, Sec. 22, T11N, RSE, UM 2A-19 #U-630610 At total depth 9. Approximate spud date Amount 1393' FNL, 1571' FEL, Sec. 22, T11N, RSE, UM 1 1/1/93 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2A-07 9776' MD 1571' ~ TD feet 18.2' ~ 450' MD feet 2560 6153' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300 feet Maximum hole angle 57.66° Ma~imurnsur~ace 1723 psig At total depth (TVD) 3291 psig 18. Casing program Setting Depth size Specifications Top Bottom Quanti~ of cement Hole Casing Weight Grade Coupling Length MD -I-VD MD 'rVD (include stage dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 12.25" 9.625" 47.0# L-80 BTC 2959' 41' 41' 3000' 2329' 290 Sx Arcticset III & HF-ERW 760 Sx Class G 12.25" 9.625" 36.0# J-55 BTC 1085' 3000' 2329' 4085' 2910' HF-ERW 8.5" 7" 26.0# L-80 BTCMOE 9735' 41' 41' 9776' 61 53' 160 Sx ClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Intermediate Production S E P 5 0 1993 Liner Perforation depth: measured Alaska 0il & Gas Coils. ~omrnis true vertical Anchorage 20. Attachments Filing fee X Property plat [] BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements X . 21" (~~;211~t the f°reg°ing is true and c°rrect t° the best °f mY kn°wledge Signe_~~... ~.¢,'~/', ~/J'~O~" i,~l~,'l//'fl, Title Area Drilling Engineer Date Commission Use Only Permit Uumber<~.~- ,,/...~.~?.. I - ,,2. <:::~ /~:~' 7 IAppr°val date/~ ..., ~.. ~,.~/ [ See cover letter fOrother requirements Conditions of approval Samples required r~ Yes 1~ No Mud Icg required D Yes [] No Hydrogen sulfide measures ~ Yes [~ No Directional survey required '~ Yes [] No Required working pressure for BOPE D 2M ~, 3M [] 5M [] 10M [~ 15M Other: by order of Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triolicate · . . . . . . . . 10 11 12 13 14 15 16 17 18 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 2A-19 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4085')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (9776') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test to 3500 psi. ND BOPE. NU tubinghead & full opening valve for cased hole logging. Secure well and release rig. Run cased hole cement evaluation. ND full opening valve & NU tree assembly. Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. · $ E P Alaska Oil & Anchorage DRILLING FLUID PROGRAM Well 2A-19 Spud to 9-5/8" surface casing Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 9.0-10.0 15-25 15-35 50-80' 5-15 15-4O 10-12 9.5-10 ___10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD 11.2 10-18 8-12 35-50 2-4 4-8 4-5 thru Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1723 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 2A-19 is 2A-07. As designed, the minimum distance between the two wells would be 18.2' @ 450' MD. The wells would diverge from that point. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 225 sx of cement followed by arctic pack upon' completion of fluid pumping. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. REC 'I¥ D S E P ,~ 0 7993 Alaska Oil & 6as Cons. Anchorage Created by : jones For: M ELMS Date plotted : 28-Sep-95 ~:Plot Reference is 19 Version #5. iCoordinotes ore in feet. reference slot #19. iTrue Vertical Depths ore reference wellhead. Baker Hughes INTEQ AR C 0 ALASKA, Inc, TD LOCATION: 1395' FNL, 1571' FEL SEC. 22, T1 1N, RSE ,350 ~ 0 .. 35o 1050 _ 1400_ - 1750_ _ 2100_ _ 2450_ - 5150_ _ 5500_ Structure : Pad 2A Well : 19 Field : Kuparuk River Unit Location : North Slope, Alaska ¥ - - W e s f Scale ! : 200.00 7200 6800 8400 6000 5600 5200 4--~ O0 4400 400-0 3600 3200 2800 2400 2000 1600 1200 800 400 0 400 I I ! I I I I I I I i I I I I ! i 1 I I I t I I I I I I I I I I I I I I I I ~ TARGET LOCATION: I i5i8' FNL, 1.525' FEL RKB ELEVATION: 1,55' SEC. 22, T11N, RSE TARGET TVD=5847 ~ KOP IVD=300 TMD=500 DEP=O TMD=9576 i .},.00 DEP=6849 SOUTH 1994 ViEST 6552 I 9.oo ~, ~5.oo ,U,LD ; OEC/,OO' S 73.07 DEG W 2~.oo 6849' (TO TARGET) x,,x27.00 33.00 39.00 B/ PERMAFROST TV0:1485 TMD=i578 DEP=412 T/ UGNU SNDS ~/D=1610 Th,iD=1744 DEP=520 45.00 ~%"%.~ 51.00 ~B/ W SAK SNDS TVD=2710 TMD=3711 DEP=2146 5/8" CSG PT TVD=2910 TMD=4085 DEP=2462 __'%~ K-lO TVD=5i35 T,',ID=4505 DEP=2817 I SURFACE LOCATION: 676' FSL, 53' FEL SEC. 14, T11N, RSE 1200 - _2000 RECEIVED 3sso_ MAXIMUM ANGLE ~ 57.66 DEG 4200 _ K-5 TVD=4335 TklD=6749 DEP=4713 4550 _ _ 5250_ CEGIN At~GLE DROP TVD=5268 Tt.40=8493 DEP=61'~"'"'-... ~,,% 54.00 - 50.00 560o_ '% 46.00 'I'ARG~T (EOD) TVD=5847 TMD=9376 DEP=6849 x"x,x' 42.00 _ 5~5o_ TARGET ANGLE a/ KUP SNDS TVD~6000 '[UD=9576 D[~=6977 - ~0 DEG *~ / 7" csG PT TVD:615a TMD:977S DEP=710S $3o-9_ I I I I I I I I I I I i I I i I t I i t I I i I I i I I i I I i I i i I i I I I i i I 350 0 350 700 1050 1400 1750 2103 2450 2800 5150 3500 3850 4209 4550 4900 5250 5600 5950 6300 6650 7000 Scale 1 : 175.00 Vertical Section on 253.07 azimuth with reference 0.00 t.,I, 0.00 E from slot #19 SE p 3 0 199 '~laska u~l ~, ud~ ~uns. uommiss · Anchorage 7350 450 400 ARCO ALASKA, Inc. Structure : Pad 2A Well : 19 / 20 Field : Kuparuk River Unit Location : North Slope, Alaska <- West Scale 1 ' 50.00 550 500 250 200 150 100 50 0 700 1700 O0 ,/ o0 I I I I 9OO iO0 500 2O 0 850 _8OO _750 A 700 _~5o 0 _6OO _550 _500 Casing Design / Cement Calculations 30-Sep-93 Well Number: Surface Csg MD: Surface Csg TVD: Production Csg MD: Production Csg TVD: Top of West Sak, TMD: Top of Target, TMD: Top of Target, TVD: Estimated Pressure: Surface Casing Choice: Production Csg Choice: Production Casing Frac. Pressure 2A-19 4,085 ft 2,910 ft 9,776 ft 6,153 ft 2,276 ft 9,376 ft 5,847 ft 3291 psi 3,500 psi Maximum anticipated surface pressure Estimated BH pressure at top of target zone TVD surface shoe = {(13.5'0.052)-0.11}*TVDshoe =[ Estimated Pressure= Top of Target, TVD = Overbalance, psi= Anticipated Mud Weight =[ 2,910 ft 1,723 psiJ 3,291.0 ppg 5,847 ft 100 psi 11.2 PPgl Surface lead' Top West Sak, TMD = 2,276 ft Design lead bottom 500 ft above the Top of West Sak = 1,776 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 556 cf Excess factor = 15% Cement volume required = 640 cf Yield for Permafrost Cmt = 2.17 Cement volume required =l 290 sxJ Surface tail: TMD shoe = 4,085 ft (surface TD - 500' above West Sak) * (Annulus area) = 723 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4110 cf/If Cmt required in casing = 33 cf Total cmt = 756 cf Excess factor = 15% Cement volume required = 869 cf Yield for Class G cmt = 1.15 Cement volume required =1 760 sxJ Casing Design / Cement Calculations 30-Sep-93 Production tail- TMD = 9,776 ft Top of Target, TMD = 9,376 ft Want TOC 500' above top of target = 8,876 ft Annulus area (9" Hole) = 0.1745 (TD-TOC)*Annulus area = 157 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.2148 Cmt required in casing = 17 cf Total cmt = 174 cf Excess factor = 15% Cement volume required = 200 cf Yield for Class G cmt = 1.23 Cement volume required =1 160 sxJ TENSION - Minimum Design Factors are: T(pb)=1.5 and T(js)=1.8 Surface (Pipe Body): Casing Rated For: Tension (Pipe Body) = Dead Wt in Air- Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body)= Design Factor =[ Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 Production (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body)= Design Factor =[ Production (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 1086000 lb 4,085 ft 47.00 Ib/ft 191995.0 lb 32120.2 lb 159874.8 lb 1161000 lb 4,085 ft 47.00 Ib/ft 191995.0 lb 32120.2 lb 159874.8 lb 604000 lb 9,776 ft 26.00 Ib/ft 254176.0 lb 42755.0 lb 211421.0 lb 2.9J 667000 lb 9,776 ft 26.00 Ib/ft 254176.0 lb 42755.0 lb 211421.0 lb RIECEIV u' Alaska fJJl & Casing Design / Cement Calculations BURST - Minimum Design Factor = 1.1 Surface Casing: Burst = Maximum surface pressure Casing Rated For: Max Shut-in Pres = Design Factor--L Production Csg: 1. Design Case ~ Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure = Outside Pressure = Net Pressure = Design Factor =1 COLLAPSE- Minimum Design Factor = 1.0 Surface Casing 1, Design Case - Lost circulation and Fluid level drops to 2000' TVD with 9.0 Cf Mud 2. Ext. Pres=Mud Wt*0.052*TVD-(2000'TVD of 9# Mud) Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ Production Csg 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =! 30-Sep-93 6870 psi 1722.7 psi 4.01 7240 psi 7068 psi 2848 psi 4221 psi 1.71 4750 psi 0.580 Ib/ft 752 psi 6.3J 5410 psi 0.580 Ib/ft 3568 psi 1 .si Alaska .0~1 .& was buns, Casing Design / Cement Calculations 30-Sep-93 Surface Casing Choices OD ID Ib/ft Grade Metal X-Section I 9.625 8.681 47 L-80 13.5724 sq. in. 2 9.625 8.835 40 L-80 11.4538 sq. in. 3 9.625 8.921 36 J-55 10.2545 sq. in. 4 10.750 9.950 45.5 J-55 13.0062 sq. in. Jt Strength Body Strength Collapse Burst 1161000 lb 1086000 lb 4750 psi 6870 psi 979000 lb 91 6000 lb 3090 psi 5750 psi 639000 lb 564000 lb 2020 psi 3520 psi 931000 lb 715000 lb 2090 psi 3580 psi Production Casing Choices OD ID I b/ft Grade Metal X-Section Jt Strength I 7.000 6.276 26 L-80 7.5491 sq. in. 667000 lb Body Strength Collapse Burst 604000 lb 5410 psi 7240 psi RECEIVED s E P ,~ 0 199~ Alaska Oil & Gas Cons. 6ommisstoo Anchorage ..... KUPARUK RIVER 20" DIVERTER SCHEMATIC 6 3 I_-I , f2 F DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION . , UPON INmAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT3HAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) RECEIVED 1. 16" CONDUCTOR 2. SUP-ON WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 21300 PSI BALL VALVE 4. 20' - 2(X)0 PSI DRILUNG SPOOLWlTH TWO 10' OUTLETS. S E P 5 0 199J Alaska 0il & Gas Cons. CommiSsib, Anchorage 5. 10- HCR BALL VALVES WITH 10' DIVERTER UNES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROl I ;=n TO ACHIEVE DOWNWIND DIVERSION 6. 20' - 2000 PSI ANNULAR PREVENTER 7 6 5000 SI BOP STACK , ~CCUMUI.A'I'O~ CAPA~ ~ IS 45 SECONDS ~ TIME AND 1200 PSI REMAINING PRESSURE. 5 4 I 2 1 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOI.D-DOWN SCREWS ARE FULLY ~. ~INE DEPTH 'FHAT 7EST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK. DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR ~ AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. ~m=n TO ZERO PSI. 5. OPEN ANNULAR P~EVENTOR AND MANUAL KILL AND CHOKE UNE VALVES. 8. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE UNES. CONTINUE TESTING ALL VALVES, UNES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING PosmvE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTI'OM PIPE RAMS. TEST BoTrOM RAMS TO 250 PSI AND 3{XX) PSL 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TESTTO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING PosmoN. 12. '~EST KELLY COCES AND INSIDE BOP TO 3000 PSI W/TH KOOM~ PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILUNG SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DALLY. 1. 16' - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13..5/B' - =--~r'?-,~-- I=~ SPACER SPOOL 4. 13-5/8" - 5000 PS~ PIPE RAMS 5. 13-r'J~ - ~ P~ DRLQ S~ WI CHOKE AND KILL UNES PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/~' - 5000 PSI ANNULAR ** CHECK LIST FOR NEW WELL PERMITS ** ITEM' APPROVE DATE (2) Loc [ 2 ~hru (3) Admin [z~]~ ~_~ 9. ['9 t~ru 10. ? 11. [10 & 13] 12. 13 .~, (4) Casg ~ [~'/b 14. [18 thru 22] ! 15. [23 thru 28 (5) BOPE 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Company 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4.' Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ Does operator have a bond in force ................................... Is a conservation order needed ....................................... .. /~ I s adm i n i st rat i ve approval needed .................................... ~ Is lease n~nber appropriate ......................................... ~ Does well have a unique name ~ ntrnber ....... /~ ,, Is conductor string provided ......................................... ~ Lease & Well YES NO /,, Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams $ descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... REMARKS (6) Other .~C~ ~,d~.//~.~ [29 thru 31] (7) Contact ~/~ ~ [323 (8) Addl 29. 30. 31. 32. 33. geo 1 ogy' eng i nee r i nq' DWJ'~~ MTM J RAD . rev 6/93 jo/6.011 FOR EXPLORATORY $ STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone n~nber of contact to supply weekly progress data ...... Additional requirements ............................................. Additional INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE MERIDIAN: / / / remarks' UM SM WELL TYPE' Exp/Dev Redrill Inj Rev o -rz ~o 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. ******************************* ******************************* RECEIVED A!sska Oil & (;as Cons. Commission Anchorage IS Ta~e 'Ver'i~icat~on T, istin~ :hlumberger .A].~sk.a Computi["~ Center T r3 :~ u FSI,: KEI,I.,V 18q" $.TPI?iL: 2A-I,.9 S01,03201~700 SC~,~£~U~BERGER ~:~!Egb SERVICES 7-AP~-94 ~ I T R U N 3 14 676 53 135.00 I 3b. UO 9.-$. O0 PAGE: iS Ta~e verJ,.f.].cat~on [.~ist].~o :blumberger AlasKa Computing Center ,P,-APR-1904 13:4:7 PAGE: De~tb snJ.~ted ~,nd cl,,!pped curves: all bit runs merged. [, [..',:t~ d TOOt, CURV~: S~.[.~I' DAT!x (i,.'tFASI:R~;.:r) PEP'TN) 3~'75 0 ~ ~,,, ~,, .... 7~ ....... 95b~.5 9,~64.a 9363.5 933%.0 9282,0 91 9785.0 ~7~5,0 .......... F(~f.tiVAl.,.[.,;b!I' U~IbP. I~'TF,,D DEPT~i .......... 9%78,5 9565,5 946,1 .0 9376,5 936.0,5 9331 .0 5~ 9. e,,. ?. 0 9153.5 9!03.0 :hltlmberger AlasKa Comt:,'uti. r'~ Celt. er 903 ~. 0 9~36 9030,0 9029 895 1.0 8949 8~25,0 8923,5 8~64,5 8862.0 8~ 1 o. n 8~00 8651,0 ~64~ }.~59 4,5 ~159~, 100.0 99 CDR 1 3075, . . .... - CD~? ? 9 !, 1, 1 C D ~,,: ! 3975 # bis $ 13:47 13:47 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 [ S T 8 r,' e V e r i f i c a t, ~ o n L ii.. s t. ! n q :hlu!n:eerger Atast<a Computfna Ce~'t:er PAG~ :' turves and log header data for each bit run fn separate LOG HEAD.E~ D~"I"A ~TE I.~OGCCD: $ 0 F' 'F w A P E ~ ~D DRII.,LER (E".[']: TOP I.,(.~IC '[NT~,iPVA~ (F:i'); P()~,i' ].~C[,it,~hwIC~?~ (DEC) fJRrbl.~gP5 CAI, T;'.:(.; DiLt-"T~-,~ (F~): SI'OP DEPTH '",T;','; 31.-0CT-93 FAST 2.4 9785.0 3000.0 975~. 0 61 ,0 8.50O 3957 f i, .,les. IS w~e Vertf!.cat:i, on L.i. stir~ 8- A FR,,,.!. 994 13:4'/ 150o0 2.25O 2 , 04:0 1.. 0 0 0 ~:':~IT ~t'l,;~',; 2 D~I!.,LED INTRt~:'V~[., 9111 - 9785 FT d ,'~i~E ~h:(;,[,,~ AT T~ = 4.0 I"~G AT 9'185 F'T T~ ~,'~gl.,6 AT 1.6:26 ~.'~'~C? 30, !993 S 66.0 65.0 ** PAT.It FOg',~aT' $[..I~.L!FTC.~T IS Tape Ve,ri.f:]cat:ion l,,istlnq -hl. umberqer AlasK:a Co~put,.!n¢~ Cent;er P A G'g: P E ~, ! b'T 619 l, ~1. 4 00 00 00 , 2 I I 4 6 fi 0000000000 a~O~ 1,~1 G/C3 6191!4 O0 000 O0 0 2 ~,, 1. 4 68 0000000000 PEF [~,~' !, ~,~' / E 61.911.4 O0 ('~00 O0 0 2 1 i 4 68 0000000000 DCA[, I.,Wl I~.~ f, lgll. 4 O0 0(}0 00 0 2 1. I 4 68 000000000(} NPHI I,wl P[~-8 619114 O0 000 O0 0 ? I I 4 68 0000000000 ~TR LW1 (::~["~ 619114 O0 000 O0 0 2 1. I 4 68 0000000000 PSR !.~ t,~ 1 G ¢! ;~ ~ (319114 00 00() 00 0 ~ ! 1 4 68 0000000000 DER 1,¢~ 1. () H ~, ~.f 6:1. 91 ~.. 4 00 000 O0 0 ~ 1, I 4 68 0000000000 GR I,,~ I GA, PI 61911,4 O0 000 O0 0 2 1 1 4 68 0000000000 HEN[ I.,W1 CPa 61.91, 14 (3() 000 O0 0 2 I, 1 4 88 0000000000 D E [,:~ T. 383 ~. 50 o P i'l[? ~.~ o h W ! - 99 q. 250 P E F'. L N 1 - 999. ~ 50 D C g 5.1,, :~ i. ~P H r, 1.., ~,~ 1 - 909.250 t~ ~a. L W 1 1000.000 P S R. ~,,~ ~ 1 - 999.250 D E R. L ~ I. . . - , ......... -099.250 NEFA . GR I...,~,1 999 250 Ea~,,A Lwl [~Wl 4 198 * * E ~\I [..) ('.) [;' ,~) g T .g * * 0.679 2.197 -999.250 -999.250 FT[.,~ h~A~E : EDIT .002 SwP, vic~ : FLTC VERSION : FTLF TfPZ iS Tal3e Veri, f.~catJon :hlumberger ,~],,asKa Computi,.no Center 13:4,.7 PAGEI Curves and 1. o<:~ header data fei" each bit' run tn seoarate DKPTM i FTLF L D ~ G T ct'~ 9~ 1'1 0 ,..., .,,, IJ O (; H [{', A D E ~ I] A 'r A. DATE I.)O'~NflO~aE SOFTWarE VERSION: ~IOTTO}.: BIT VEND()R TOol,,, CODE TOOL C . R R ,,.~ o I, 31-OCT-93 2.4 9785,0 3900.0 9758,0 61..0 GS, 55 l',t D ,<; (.~ 49 R b; (.; 6 0 0 7 5O0 3957.0 10,60 !50.~ 2.250 2,940 files. 66.0 bS.n [STar, e Verificat, ion Listi. n9 :hlumberger Alaska Computlr:~9 Center ~r~",A PP,- !9 9 4 13:47 ATP.IX O ~i.i ~i S 'r '"'!J Y; 2.65 0 !'.,~ ~ C O ~ R ~.; C T I (7;1 '?~ ( I ~,,~ ); 6IT R~.J~,~ 2 I,')~',I:LLED IN'TKRVAL ~1.!1 - 9785 FT k'~Ol.,,E :~i,,~Gi.,E .a.T TD = 40 f.:~EG AT 9785 FT ~qtXI'~'1~,'t HUL~ ,~f&GEL : 61,05 DEG AT 52flf~,1,9 FT T D ui~..;LL AT 16:26 gCT 30, 19~3 !1) rli~',DEP e bOG 'IYPE CL~.SS ~i(.,~P Nt.iP45 Sk~'p E.bEa Ct.jDE (HEX) DVFT FT 6!,o114 no 900 Od n 3 1 i 4 68 onocoOoo00 R~f..IP L~2 G/C'~ 6i911~ n~, 900 nV n 3 1 1 ,I 69 OOO0000OOO pF~' ~,;~2 B~J t F.: aiOll4. Od, oni~ qO n 3 ]. 1 4 67 OOi,,aO00000 DC~L l,~,~ ia 619114 00 ~00 O0 0 3 ] i 4 6a OOO0000OOn AlasKa ComPut~Rq Center P~G~: 10 DATA ** O E P T. 9 7513. <,i 00 i'd P H ~. ! ,, ~,q 2 -. ¢ 99.250 GP.T,,,~,~2 -999... 250 ATR.LW2 2.4.1,9 PSR.LW2 -999. ,?,,50 DER.Lw2 H E':: I~1 A. L, w 2 -999.250 H E F A. h w 2 - 999.250 -999.250 2.678 0,679 2.!97 * * E ~ i':) 0 F '!3 A T ~4 * .* SERVICE V E R S I (3 [:,,,~ DAT~: ~hX RFC SIZE FTDF m'?PE I_,AS~ FILE: INC.,Ki_IPARUK RIVEP T'T [,i ]. 2A-Ig,50-13U-20197-00 Tape Vert..k.tcation bJ. st.i. nm :hlumberger Al. asks ~,omputinq Center' PA~