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HomeMy WebLinkAbout188-039MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3O-14 KUPARUK RIV UNIT 3O-14 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2025 3O-14 50-029-21802-00-00 188-039-0 W SPT 6420 1880390 1605 2150 2150 2150 2150 110 110 110 110 4YRTST P Adam Earl 6/24/2025 MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3O-14 Inspection Date: Tubing OA Packer Depth 620 2920 2790 2780IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE250625083346 BBL Pumped:2.2 BBL Returned:2.1 Tuesday, July 22, 2025 Page 1 of 1            MEMORANDUM TO: Jim Regg P.I. Supervisor 1 `ecf, C 11t (tet z ( FROM: Adam Earl Petroleum Inspector Well Name KUPARUK RIV UNIT 30-14 Insp Num: mitAGE210607105453 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Cas Conservation Commission DATE: Tuesday, June 8, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 30-14 KUPARUK RIV UNIT 30-14 Sre: Inspector Reviewed By: P.1. Supry SIJ Comm API Well Number 50-029-21802-00-00 Inspector Name: Adam Earl Permit Number: 188-039-0 Inspection Date: 6/3/2021 Packer Depth Well 30-14 Type Inj I W " TVD 6420 PTD 1880390 Type Test SPT'Test psi; 1605 BBL Pumped: `BBL Returned: 1A " Interval 4vRT91 p/F P Notes: MIT IA Pretest Initial 15 Min 30 Min 45 Min 60 Min nbing 2825 2825 - 2825 2825 l IA 770 2000 1940 " 1930 " OA 190 200- zoo ' 200 - — Tuesday, June 8, 2021 Page l of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday,June 15,2017 / i P.I.Supervisor �e � �``20)b SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 30-14 FROM: Lou Laubenstein KUPARUK RIV UNIT 30-14 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 30-14 API Well Number 50-029-21802-00-00 Inspector Name: Lou Laubenstein Permit Number: 188-039-0 Inspection Date: 6/6/2017 Insp Num: mitLOL170607160430 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 30-14 Type Inj W -1TVD 6367 - Tubing 2800 2800 - 2800 - 2800 - PTD 1880390 Type Test SPT Test psi 1592 , IA 800 1910 1840 • 1830 - BBL Pumped: 1.3 ' BBL Returned: 1.2 . OA 600 660 • 660 - 660 Interval 4YRTST P/F P ✓ Notes: SatNES y20 Thursday,June 15,2017 Page 1 of 1 r~ ~~ MEMORANDUM To: Jim Regg e P.L Supervisor ~ ( Z~z~''~ ~ c FROM: Chuck Scheve Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July O1, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 30-14 KUPARLJK RIV LJNTT 30-14 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ Comm Well Name: KUPARUK RN IJNIT 30-14 Insp Num: mitCS090626190557 Rel Insp Num: API Well Number: 50-029-21802-00-00 Permit Number: 188-039-0 ~ Inspector Name: Chuck Scheve Inspection Date: 6/26/2009 Packer Depth Pretest Initiai 15 Min. 30 Min. 45 Min. 60 Min. Well 30-14 Type Inj. G 'I'~ 6367 IA 420 2460 ' 2420 2420 P.T.D 1880390 TypeTest SPT Test psi 1591.75 QA 50 60 60 60 Interval 4YRTST P~ P / Tubing 3250 3250 3250 3250 NOtes' Pretest pressures observed and found stable . ti'a~ ~; ~ a~ ~( f}r. _ '~ .~ ~ ~~ 1 ' ~ h_ - / ~~~~- Wednesday, July O1, 2009 Page 1 of 1 MEMORAI~IDITM • To: Jim Regg r~~7 l~/z~Z~t~ j P.1. Supervisor ' ) FROM: Lou Grimaldi Petroleum Inspector State of Alaska • Alaska OiI and Gas Conservation Commission DATE: Monday, January 12, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 30-14 KUPARUK RIV UNIT 30-14 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv r~~ Comm Well Name: KUPARUK RIV UNIT 30-14 API Well Number: 50-029-21802-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG0901 1 108 141 3 Permit Number: 188-039-0 Inspection Date: 1/11/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We11~30-14 ~ype InJ. ~ W ~ TVD ~ 6367~~! IA I 1130 ~ 3020 ~ ~ ~ 2950 ~ 2930 ~ ~ p ~+ ~ 1880390 ITypeTest ~ SPT ~ TeSt pSl ~ 3020 ~ OA ii 280 ~ 400 j 400 ~ 400 Interval WRKOVR p~F, P ~ TUbing ~ 2400 I 2400 ~ 2400 ~ 2400 T Notes' Pumped 1.5 bbl. Post workover initial test. Good test. ~.>~~~~~ JAN ~ ~ 20U Monday, January 12, 2009 Page 1 of I ~ ~ RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ,~A~I O 5 ZO09 REPORT OF SUNDRY WELL OPERATIO~V$._ ,,;, 4. ~a~ c:r,rts. Commission 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ other Ancht rage Alter Casing ^ Pull Tubing Q Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Ir1C. Development ^ Exploratory ^ 188-039 / 3. Address: Stratigraphic ^ Service ^~ 6. API Number: P. O. Box 100360, Anchors e, Alaska 99510 50-029-21802-00 ' 7. KB Elevation (ft): 9. Welt Name and Number: RKB 58' 30-14 ' 8. Property Designation: 10. Field/Pool(s): ADL 25513 ~ Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Tots! Depth measured 8137' feet true vertical 6891' feet Plugs (measured) Effective Depth measured 8025' feet Junk (measured} 7916' true vertical 6796' feet Casing Length Size MD TVD Surst Collapse Structural CONDUCTOR 110' 16" 110' 110' SURFACE 2305' 9-5/8" 2364' 2225' PRODUCTION 8048' 7" 8107' 6866' Perforation depth: Measured depth: 7792'-7806', 7814'-7834' , 7858'-7878' ti t l d h ' ' ' ' f~t1 ~~G1<~.' JAS! ~ ~ ~UU ~ ' " ' rue ver ca ept : 6603 -6615 , 6621 -6638 ~. i , 6658 -6674 Tubing (size, grade, and measured depth) 2-7/g", L-g0, 7569' MD. Packers 8~ SSSV (type & measured depth) Baker'FHL' pkr, Baker'HB' pkr @ 7507', 7572' Camco'DS' nipple @ 495' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1782 Subsequent to operation 1827 -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas ^ WAG 0 GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: 308-407 Contact Jill Long @ 263-4093 Printed Name Jill Long Title Wells Group Engineer Signature - Phone: 263-4093 Date ~..~ ~ Pre ared b Sharon All u Drake 263-4612 I/ J \ . 7 _ ! Form 10-404 Revised 04/2006 ; ' i ~ • r ~'~ ~ ~~ ~ ~~~ ®c~ ~~Q~ `~~ Submit Ori mat Only . ~ KUP • 30-14 pt,. ConacaPh~ihp~ ~ ~{ 'Well Attributes I M A l S {{~ yAry, j; ,. _ ! Wellhore APl/UWI Yield Name 500292180200 KUPARUK RIVER UNIT i ax Well Status Prod/lnj Type 'ilncl (°) ng e & MD IMD (kKB) TD iACtBM (HKB) PWI 44.50 ~ 2.700.00 8.137.0 ( ... - Well DOng ~O ab r2u n ~^ (Comment H2S (Plxrl) .1$SSV NIPPLE 0 I (Date Annotaton End Date KB-Grd ft ( j R' Release Date __._. l~ti e _i~ _..- _. Stliemetk.AC:u.I I Annotation Depth (kKB) (End Data 4 7/1/2008 Last WO 72/10/2008 An otation 40.00 ~ 5114/1988 (Last Tag: RKB 1,8720 11/14/2008 (Rev Reason: WORKOVER End Date __ - - 12/10/2008 - Casm Strin s ~ ~ - - I I I __ __ Casing Description String 0... String ID ... CONDUCTOR Top (kKe) Set Depth (f... Sat Depih (ND) ...'String Wt... (String ... (Siring Top Thrd FtANGER. 33 I 16 15.062 (Casing Description (String O._ (String ID ... ciiur me ,. ,._ ~ __._ 0.0 Top (kKB) 110.0 Set Depth (f... 110.0 62.50 ~ H-40 Sat Depth (ND) ...'String WL..'Strina ... ~Strina Tom.. TT..n CONDUCTOR, 0-110- NIPPLE, 495 -- SURFACE, g-z.3s4 - GAS LIFT, 7A65 SEAL ASSY, 7,489 PACKER, 7.507--- NIPPLE, 7,519 LOCATOR, 7,557 PBR. 7.560 -- - SEAL ASSY, _ - ],558 ACKER, ),572- PLUG. 7,600 - TIPPLE.7611 SOS, 7,645 TiL, 7.646 IPERF, 7,792-7.806 IPERF, 7,814-7,834 IPERF, 7,858-7,878 4, 7 1/16" x 2 7/8" Hanger (EUE 8 mtl 312" "DS" Nipple- ~mbly Locator ~ 80-32 w/ seal assembly - Packer 4762 - 7" 26# 312" "X" Nipple w/ RHC Plug ---~ -"' --~~~v •- r•,~.,.o, ae~ ~eprn Ir... ~]el Uepih (ND) String N 27/8 2441 ~~ 7,Sfi00 7, 64G_0 ~ 64316 6.50 e reline retrievable plugs, valves, pumps, fish, etc-) ntn CND) Top Inc! I _ - ~ Top (ftKB) 7,560.0 (RKB) (°) Description Comment 6 410 4 34 24 PBR B Run Data ID (in) 7,572.0 , . 6,420.3 . 1 34.21 PACKER aker PBR ,Baker'HB'PACKER - - 6/26/1988 6/26/1988 2.376 I2 376~ 7,600.0 6.443.5 34.16 PLUG IBP SET PRE-WORKOVER 11/29/2008 . 0 000 7,611.0 6,452 6 34.00 NIPPLE Camco'D' Nipple NO GO 6/26/7988 . 2 250 7,645.0 6,480.7 33.98 SOS Baker . 6/26/1988 2.441 7,646.0 6,481.6~ 33.98 TTL I TTL ELMD 7637 SWS 5/13/1988 6/26/1988 2.441 7,9160 __... 6,705J1 _.. __ J 33.61 FISH _ I FISH 19.9' Tool String __ _... 8!1511988 I FISH, 7,916 -- PRODUCTION, 0-8.107 TD, 8,137 l I ~onocoPh~llips Time Log & Summary GNelA+iew Web Reporting ^ ~ ~ O ~i Well Name: 30-14 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 12/5/2008 1:30:00 AM Rig Release: 12/8/2008 9:00:00 PM Time Loys _ Date From To Dur S. Depth E. Depth Phase Code 5ubcode T Comment 12/04/2008 __ 24 hr Summaro RDMO 3F-18, moved Nordic Rig 3 from 3F pad to 30 pad. 18:00 00:00 6.00 0 0 COMPZ MOVE MOB P Move Nordic Rig 3 from 3F-18 to 30-14 9.6 miles . 12/05/2008 Spot rig over well, RU hardline and kill tank, load 9.6 brine in pits, pull BPV, circ out freeze protect diesel, install BPV, ND tree, NU BOP, test ROPE. 00:00 02:30 2.50 0 0 COMPZ MOVE PSIT P Load tree in cellar, spot rig over well, berm up cellar, spot cuttings box, blow down tank and kill tanks. Acce ted Nordic Ri 3 at 1:30 AM 0 1 / 02:30 10:30 8.00 0 0 COMPZ WELCTL OTHR T RU lubricator, pulled master bushings and MU lubricator on tree, IA on vac, screwed into BPV, (pin sheared on BPV retrieving tool, leaving spring, threaded portion of tool and BPV in top of hanger). Fish out springs and washer from the top of retrieval tool. Lubricate in with retrieval tool overshot. Backout BVP and ull out of the wellhead. 10:30 11:30 1.00 0 0 COMPZ WELCTL NUND P RU to displace well to 9.6 ppg brine. Pressure test hardline to 2000 si. 11:30 13:30 2.00 0 0 COMPZ WELCTL CIRC P Circulate 9.6 brine, start pumping 4 bbl @ 800 psi. Pumped 275 bbl. Monitored well for flow. Circulate 1 tubing volume 45 bbl, 2 b m 230 si. 13:30 16:00 2.50 0 0 COMPZ RPCOM NUND P Set BPV, ND tree. 16:00 20:00 4.00 0 0 COMPZ RPCOM NUND P Install test dart, NU 13 5/8" BOP. 20:00 00:00 4.00 0 0 COMPZ WELCTL BOPE P Test BOPE at 250 psi low - 3,800 psi high. Good test. 24 hr notice was given to AOGCC on 12-4-08 at 13:50 hrs. Witness of test was waived by AOGCC Rep John Cris on 12-5-08 at 14:15 hrs. 12/06/2008 Complete BOP test, pull hanger to floor, CBU, POOH LD 2 7!8" completion, PU RIH with new 2 7/8" com letion to 4,260'. 00:00 01:00 1.00 0 0 COMPZ WELCTL ROPE P Cont testing BOPE, RD test e ui ment. 01:00 02:30 1.50 0 0 COMPZ RPCOM OTHR P Pull BPV, BOLD's. Pais;: 1 of ~~ • '~ Time Logs Date From To_ Dur S Depth. E...Depth Phase Code Subcode T Comment __ _ __ 02:30 03:30 1.00 7,539 7,539 COMPZ RPCOM CIRC P Unseated hanger at 80K and pulled to rig floor, up weight 77K, CBU at 5 b m - 1,170 si. 03:30 16:30 13.00 7,539 0 COMPZ RPCOM PULD P LD landing jnt and hanger, RU control line spooler, POOH LD 2 7/8" tubing, strapping and tallying same. Up wt = 73 K#, down wt = 40 K#. Retreived 30 bands (previous completion tally recorded 29 bands RIH) form SSSV control line. OOH with the 2-7/8" completion. Chem cut at 7540' was incomplete,. only cut about 1/2 of the circumference. _Pulled the seal assembl out of the PBR at 756 ' 16:30 18:30 2.00 0 0 COMPZ RIGMNT SVRG P Slip and cut drill line. Tighten ODS brake blocks to brake band and check links e. 18:30 00:00 5.50 0 4,260 COMPZ RPCOM RCST P MU FHL packer and seal assem_„_jX,. start PU and RIH with 2 7/8" completion to 4,269', up wt 52K, down wt 52K. 12/07/2008 RIH with 2 7/8" completion to +/- 7,000', set storm packer and tested, ND BOP, ND tubing head, CO pack-offs, NU tubing head and test pack-ofFs, NU BOPE and test, MU landing nipple and cont PU and RIH, locate lower PBR. 00:00 03:00 3.00 4,260 7,049 COMPZ RPCOM RCST P Cont PU and RIH with 2 7/8" com letion from 4,260' to 7,049'. 03:00 04:30 1.50 7,049 7,142 COMPZ RPCOM DHEQ P CO elevators, PU 3 jnts 3 1/2" DP, MU storm acker, RIH and hang off string with storm packer set at 93', up weight 70K, down weight 63K, RU and test storm acker x 7" cs at ~__ ~~ 1,500 si for 5 minutes ood test stand back 3 1/2" DP. 04:30 06:30 2.00 7,142 7,142 COMPZ RPCOM NUND P Drain BOP stack, ND 13 5/8" BOP and rack back on stum . 06:30 18:00 11.50 7,142 7,142 COMPZ RPCOM OTHR P Start to remove tubing head, casing was starting to raise. Obtained long studs to backoff tubing head and control casing growth. Removed tubing head, casing raised 2", removed casing packoff. Cut the casing down 2", install new casing ackoff. Replace tubing head. Pressure test void to 3000 si. 18:00 21:30 3.50 7,142 7,142 COMPZ RPCOM NUND P NU BOPE, test the breaks at 250/3500 si, RD test a ui ment. 21:30 22:30 1.00 7,142 7,142 COMPZ RPCOM PACK P MU storm packer retrieving tool on 3 1/2" DP, RIH 93' and engage storm acker, POOH LD same. 22:30 00:00 1.50 7,142 7,560 COMPZ RPCOM RCST P CO elevators, cont PU and RIH with 2 7/8" completion, locate lower PBR at 7 567' ORKB up weight 73K, down wei ht 65K, PU out of PBR. ~'az~~ ~ csf 3 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment _____ 12/08/2008 __ _ za hr Summary Reversed circ 228 bbls down IA, spotted corrosion inhibitor between packers, set FHL packer, spaced out, MU hanger, spotted inhibitor in IA, landed hanger, tested tbg and IA, sheared SOV, ND BOP, NU tree, freeze rotected well, RDMO 30-14. 00:00 02:30 2.50 7,560 7,560 COMPZ RPCOM CIRC P Reverse circulated 228 bbls clean brine down IA to clean annulus at 2 bpm - 350 psi, pump 5 bbls inhibited brine down tubing followed with 49 bbls brine to spot inhibitor between acke~s at 2 b m - 350 si. 02:30 03:30 1.00 7,498 7,498 COMPZ RPCOM PACK P Drop ball and locate upper PBR at 7,489', ressure urp to 2,500 psi and set FHL acker. Shear out of P_BR and space out 2', MU pups, hanger and landing joint, upper mule shoe at 7,497.67' MD ORKB. 03:30 04:30 1.00 7,498 7,498 COMPZ RPCOM CIRC P RU and pump 140 bbls corrosion inhibited brine down IA at 3 bpm, 480 si, drain BOP stack. 04:30 07:30 3.00 7,498 0 COMPZ RPCOM DHEO P Land hanger, up weight 70K, down weight 65K, RU and test tubing to 3.,000 psi for 15 minutes on chart, bleed tubing to 2,000 psi, test IA to 3,000 psi on chart for 30 minutes bled tubing and IA to 0 psi, pressured up IA to 1300 psi and sheared SOV in GLM. 07:30 14:00 6.50 0 0 COMPZ RPCOM NUND P Install BPV, ND BOPE. Install test dart NFU tree. Test ptubing packoff to 5000 si, tree to 5000 si. 14:00 17:30 3.50 0 0 COMPZ RPCOM FRZP P RU Little Red, test lines to 2K. Pump 100 bbls of diesel down the IA at 2 bpm - 1,000 psi, taking returns up the tubing. Allow the well to u-tube. 17:30 18:30 1.00 0 0 COMPZ RPCOM RURD P Blow down all circ lines and RD same, set BPV. 18:30 20:00 1.50 0 0 COMPZ RPCOM OTHR P Secure well, install flanges and ua es. 20:00 21:00 1.00 0 0 COMPZ MOVE DMOB P Contact DSO, back rig off well, remove T-Mats and liner, clean out cellar box and well site. Nordic Rig 3 released at 21:00 hrs. I'~o~ 3 of 3 30-14 Pre and Post Rig Workover Summa DATE SUMMARY 10/16/08 TPOT/PPPOT -PASSED, IC T -PASSED, IC PPPOT -FAILED, FU TION TESTED T LDS (PRE RWO) 11/14/08 TAGGED @ EST. 7868' RKB. MEASURE BHP (a~7835' RKB: 4735 PSI. BROACHED TIGHT AREA FROM SURFACE TO 650' WLM. IN PROGRESS. 11/15/08 ATTEMPTED LOCKOUT SSSV @ 1788' RKB. OPENED HYDRAULICS ONLY. IN PROGRESS. 11/22/08 ARRIVE LOCATION. CALL IN FOR SNOW REMOVAL, ON STANDBY UNTIL IT ARRIVES. WILL RESUME IN A.M. 11/23/08 RAN FLAPPER ISO SLEEVE & MADE TRIAL PASS THRU SSSV. HUNG UP UNDER FLAPPER. WORKED FREE AND ATTEMPTED CLOSURE TEST OF SSSV (FAILED) W/FLAPPER ISO SLEEVE; PULLED SLEEVE. IN PROGRESS 11/26/08 GAUGED TBG 2.34" TO 1788' RKB. SET BAKER FVLD FLAPPER ISO SLEEVE Cad 17$$' RKB,, OAL = 91"/ FN OD= 2.334"! OD BODY = 2.3"/ ID THRU SLEEVE= 1.993"/ USE 2 7/8" K-3 SPEAR TO PULL. DRIFTED ISO SLEEVE TO VERIFY FLAPPER ISOLATED WITH 1.82" SWAGE TO 1830' SLM. NO TROUBLE ENCOUNTERED. JOB COMPLETE. 11/27/08 SET 1.69" IBP AT 7590'. TESTED IBP BY PUMPING WITH LITTLE RED. IBP FAILED TEST. 11/28/08 PULLED IBP FROM 7590' ELM. RE-SET 2.34" X 91" FVLD ISO SLEEVE @ 1788' RKB. (PULL WITH 2 7/8" K-3 SPEAR/ MIN iD THRU SLEEVE= 1.993"). JOB COMPLETE. READY FOR E-LINE. 11/29/08 SET IBP AT 7600'. PLUG PASSED DRAWDOWN TEST AND PASSED 2500 PSI PRESSURE TEST. PUNCHED HOLES IN TUBING FROM 7509'-7511'. COMUNICATION BETWEEN IA AND TUBING WAS CONFIRMED.. 11/29/08 TAG TOP OF SLEEVE @ 1760' SLM.DUMP BAIL ON IBP FROM 7575' SLM TO 7566' SLM. JOB COMPLETE 11/30/08 SHOT STRING SHOT FROM 7530'-7542'. CUT TUBING AT 7539.5' WITH 1.75" OD CHEMICAL CUTTER. WHILE PULLING OUT OF HOLE BECAME STUCK ON SURFACE SAFETY VALVE. PULLED SLEEVE ACROSS SSSV OUT OF HOLE WITH TOOLSTRLNG. 11/30/08 RESET FVL SLEEVE Ca)_ 1760' SLM (OAL=91" MIN ID 1.993") DRIFTED 1.81" CENT TO 1773' SLM NO HANGUPS.BLED TBG AND IA TO FLOWLINE THEN UTUBE.INSTALLED CIW "H" BPV JOB COMPLETE. 12/1/08 REMOVE BPV.UTUBE TBG X IA.READY FOR BPV TO BE INSTALLED 12/4/08 RDMO 3F-18, moved Nordic Rig 3 from 3F pad to 30 pad. 12/10/08 PULLED BPV. _PULLED B&R C7 7520' RKB. PULLED SOV AND SET DV @ 7465' RKB. MIT IA 3000 PSI, GOOD. IN PROGRESS. 12/11/08 PULLED RHC PLUG Cad 7518 RKB. BAILED METAL DEBRIS AND SAND FROM 7566 TO 7575' WLM. IN PROGRESS. 12/12/08 BAILED FILL TO IBP @ 7600' RKB. RAN EQUALIZING SLEEVE; PRESSURE INCREASED FROM 800 TO 1200 PSI. LOST SPANGS, STUCK_ DROPPED CUTTER BAR (118" OAL). LEFT 31' TOOL STRING Ca) 7575' WLM. RECOVERED ALL WIRE. IN PROGRESS. p 12/13/08 RECOVERED CUTTER BAR AND TOOL STRING @ 7533' WLM. BAILED FROM 7566 TO 7569' WLM (REC. FINE SANDS); METAL MARKS ON BULL NOSE. IN PROGRESS. 12/14/08 PULLED 1.69" IBP @ 7564' WLM. TAGGED @ 7842' WLM. COMPLETE. • ALASSA OIL A1~TD GAS C011TSERQ~TIOI~T COMI~IISSIOIQ Jill Long Wells Groups Engineer ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, 30-14 Sundry Number: 308-407 Dear Ms. Long: SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 2D0~ ~~. n3~1 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ,day of November, 2008 Encl. • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 10, 2008 ~+. Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7'h Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 30-14 (PTD# 188-039). Injecting well 30-14 has been waivered for water injection only since December 2007 due to an inner annulus pressure increase while injecting MI. Between July and October of 2007 a series of inner annular build up rate tests were performed in an attempt to pinpoint the specific location of the communication; however, the exact location was not detected. The point of communication could be at some point along the tubing but it is suspected to be the packer. The purpose of the proposed workover will to pull the existing 2-7/8" tubing string and replace it with a new 2-7/8" tubing string and a stack packer completion. Attached is a proposed schematic along with a general workover procedure. If you have any questions or require any further information, please contact me at 263-4093. Sincerely, `. l (J / Jill ~ .Long Wells Engineer CPAI Drilling and Wells --~ ~ ~., y ~ .~ ~~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ;, , „ , APPLICATION FOR SUNDRY APPRO~/i~-L 20 AAC 25.280 ~C Q~~ ..~ ,a~ ~ ~o~ ~,~~ .~ 1. Type Of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Pertorate ^ Waiver ^ Other ^ Alter casing ^ Repair well Q Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing Q Pertorate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 188-039 ' 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21802-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Y2S ^ NO ^~ 30-14 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25513 RKB 58' Kuparuk River Field /Kuparuk Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8137' 6891' 8025' 6796' 7916' Casing Length Size MD ND Burst Collapse CONDUCTOR 110' 16" 110' 110' SURFACE 2305' 9-5/8" 2364' 2225' PRODUCTION 8048' 7" 8107' 6866' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7792'-7806', 7814'-7834', 7858'-7878' 6603'-6615', 6621'-6638', 6658'-6674' 2-7/8" J-55 7646' Packers and SSSV Type: Packers and SSSV MD (ft) Baker'HB' pkr @ 7572' SSSV @ 1788' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ ` 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat November 22, 2008 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ~ ~ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jill Long @ 263-4093 Printed Name JIII Lonq .. Title: Wells Group Engineer Signature Phone 263-4093 Date ~ ~' 1 Co mission Use Onl Sundry Number. Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ l Other: 3~~ ~~S ~ ~~~~ ~~~ ~~`.: ~~~ `~L! ~ ~C= ~r"~` Subsequent Form Required: y~ Approved by: OMMISSIONER APPROVED BY THE COMMISSION ~/+ ~~ (~ Date: v Form 10-403 Revised 06/2006 a Submit in Dupl~~t ~ g "~ J ' Kuparuk 30-14 Injector General Workover Procedure Pre-Riq Work 1. Apply for Sundry approval 2. Set plug in D nipple at 7,611' RKB. 3. Perform positive pressure test to 2,500 psi and drawdown test prior to dump bail. 4. MIT-IA to 3,000 psi. 5. Dump bail CaCO3 on plug. 6. Run catcher sub. Pull Dummy valve from GLM #5. Leave the pocket open. 7. Load the well with 9.6 ppg brine. 8. Set BPV. 9. Prepare wellsite for rig arrival. General Workover Procedure 1. Verify Sundry approval has been acquired 2. MIRU Nordic 3. Pull BPV. Ensure well is dead. Set HP-BPV. ND tree. MU and run plug off tool. 3. NU and pressure test BOPE to 250/3,800 psi (The last SBHP measurement was 4,203 psi on 8/11/08 at mid-pert depth. Prior to rig arrival, a plug will be set in the nipple below the seal assembly and the well loaded with 9.6 ppg brine. Because of this, kill weight fluid should not be needed; however, in the event that the plug fails, the estimated mud weight needed at mid-pert would be 12.2 ppg, Assuming a 125 psi overbalance, the mud weight would need to be 12.5 ppg. The calculated maximum possible surface pressure assuming a gradient of 0.1 psi/ft is 3,539 psi.) 4. Pull plug off tool/BPV. 5. Pull 2-7/8" tubing/completion. 6. Run storm packer. Change out casing packoffs. Pull storm packer. 7. Run new PBR with a stack packer on new, 2-7/8" tubing. 8. Circulate in corrosion inhibited brine and then set the packer. 9. Shear the PBR. Space out and land tubing hanger. 10. Pressure test the tubing and inner annulus to 3,000 psi. 11. Set TWC and ND BOPE. 12. NU tree and test tree 13. Remove TWC, freeze protect, and set BPV 14. RDMO Workover rig Post-Riq Work 1. Pull BPV, ball and rod, and SOV. Install dummy valve. 2. Pressure test tubing and IA to 3,000 psi 3. Pull the catcher sub, bail out CaCO3. Pull plug from D nipple at 7,611' RKB. 4. Return to injection. • • ,,~,,'` Well: 30-14 API: 50-029-21802-00 1"~'11'~f~5 Field: Kuparuk PTD: 188-039 2008 RWO PROPOSED COMPLETION WELLHEAD Lift threads: 2-7/8" EUE 8rd Tbg box BPV: 2.5" Type N BPV Profile Model: CIW KRU Gen 4 NEW COMPLETION A: Nipple: 2.313" DS Nipple CONDUCTOR 16", 62.58 ppf, H-40, welded 110' MD SURFACE CASING 95/8', 36 ppf, J-55, BTC 2,364' MD PRODUCTION CASING 7", 26 ppf, J-55, BTC 8,107' MD TUBING 2'/a', 6.5 ppf,J-55, 8rd-MOD AB Mod IPC 7,646' MD PERFS 6/12/1989 A-3: 7,792'- 7,806' MD 6,603'- 6,615' TVD A-2: 7,814'- 7,834' MD 6,621'- 6,638' TVD .6/24/1988 A-1: 7,858'- 7,878' MD 6,658'- 6,674' TVD B: Gas Lift Mandrels No. MD TVD TYPE 1 7,500 6,360 1" KBMG C: PBR Seal Assembly D: Baker FH Packer E: Nipple: 2.313" X- at least 1 full joint above the seal assembly F: Seal Assembly (without seals) G: Nipple: 2.25" D (currently in hole and will remain) Last Tag: 08/11/2008 Tag Depth: 7,872' SLM Fill: ~6' fill above btm pert TD: 8,107' RKB Last Updated: 11-Nov-08 Updated by: JWL ConocoPhiilips CONDUCTOR, 110 SSSV, 1 ]88 - --- - GAS LIFT, 2.797 GAS LIFT, 5.068 GAS LIFT. GAS LIFT 7.151 GAS LIFT KUP Yelltare APVUWI (Field Name 'Wal 500292180200 IKUPARUK RIVER UNIT '~INJ omment IN2S IPPm) (Date (Annotation iSSV: TROP Last WO: lnnotation (Depth (ftKe) (End Date Annotation -ast TaD: 7.872.0 8/11/2008 Rev Reason: TAG FILL 2,79J.0 GAS LIFT 5,068.0 GAS LIFT 6,468.0 GAS LIFT 7,572.0 -7,611.0 7,645.0 to ?5400 psi to get through SSSV. FMHO/1/DMY/BK/// Comment: WI PKG STA 1 FMHO/1/DMY/BK///Comment WI PKG STA2 HB' had to pump up 30-14 epih (ftKB) 8,137.0 telease Data 5/14/1988 rte 8/15/2005 30-14 I 12.0(6/12/1989 2 1/8" EnerJeY 60 deg. ph 30-14 12.0 6/12/1989 2 1l8" EnerJeY 60 deg. ph 30-14 8.0(624/1988 4.6" Csg Gun' 45 deg. ph PBR. 7.560 7,572 NIPPLE. 7,611 SOS. 7,645 TTL. 7,646 IPERF, 7,]92-],806 '- IPERF. - 7,814-7,834 - 7 E58-7 878 FISH.7,916- PRODUCTION, _ 8,107 \ iD, 8,137 30-14 PTD 188-039 notice of O~igh pressure pilot installation and tes~ Regg, James B (DOA) Page 1 of 1 From: NSK Weli Integrity Proj [N1878@conocophillips.com) Sent: Wednesday, March 26, 2008 7:54 AM 11P~,`~ ~Z~/~ To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Prod Engr Tech Subject: 30-14 PTD 188-0~ notice of OA high pressure pilot installation and test Jim, Operations installed and function tested the OA high pressure pilot (HPP) and placed the well on injection 3/24/08. The pilot tripped at 970 psi. ~ It will be added to the MISC list for April SVS testing and notice wil{ be given to the slope inspectors during testing. Perry Klein Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1244 ~~ APR t~ ~ 2~~~ 3126!2008 . . Regg, James B (DOA) From: Sent: To: Subject: NSK Problem Well Supv [n1617@conocophillips.com] Monday, October 22, 2007 9:38 PM Regg, James B (DOA) Emailing: MIT KRU 30-14 10-21-07.xls ~tl11 \ Dl'2.-?~ù1 O:Jq _\Vc ,fl <t>/.. ),0 \0 L ~ \, ~ Attachments: MIT KRU 30-14 10-21-07.xls MIT KRU 30-14 1O-21-07,xls (23... «MIT KRU 30-14 10-21-07.xls» Jim, Enclosed is a MITIA and MITOA for 30-14 PTD # 188-039, produced water injector. MJ submitted a request for administrative approval to continue injection with T X IA comm that references the enclosed MITs. You should receive the request in the mail shortly. The MITIA was performed first. Once the MITIA was complete the IA pressure was bleed to the OA for the MITOA. Let me know if you have any questions. Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com SCANNED NOY (} 1 2007 . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us -z\ 01 r7 . (()\1: "I \ <-., tfß¿ Cî OPERA TOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparukl KRU /30-14 10/21/07 Greenwood None Packer Depth Pretest Initial 15 Min. 30 Min. WellbO-14 I Type Inj. I W TVD I ./ 6,420' Tubinq 2850 ~850 2850 2850 Interval 0 P.T. D. h 880390 Type test I P Test psil 1605 Casing 2450 3000 3000 3000 P/F P Notes: MITIA for AA aplication. Not witnesed. OA 360 360 360 360 Wellbo-14 I Tvpe Ini. I W TVD I ./ 6,420' Tubing 2850 2850 2850 2850 Interval 0 P.T.D.!1880390 I Type test I P Test psil 1605 Casing 3000 2100 2100 2100 P/FI P Notes: MITOA for AA aplication. Not witnesed. OA 360 /1500 1450 1450 Weill I Type Inj. I TVD I Tubing Interval p.T.D.1 I Tvpe test I Test psil Casing P/F Notes: OA Weill I Type Inj.1 TVD I Tubing Interval P.T.D.I I Type test! Test psil Casing P/F/ Notes: OA Weill I Type Inj.1 TVD I Tubing Interval p.T.D.1 I Type test! Test psil Casing P/F Notes: OA Weill I Type Inj. TVD I Tubing Interval p.T.D.1 I Type test I I Test psil Casing P/F Notes: OA D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 ./ v M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT KRU 30-1410-21-07.xls MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor 0ì' -' <-,!.ILt;; , ",.... / ;I ..-"tl." ",.,;/.7', /1/'>' jf 1./..--;, '1-" - ~ '-'''+''' DATE: Monday, June 26, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 30-14 KUPARUK RIV UN1T 30-14 v~q¡" 0 õq FROM: John Spaulding Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ,\ßi2- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 30-14 API Well Number 50-029-21802-00-00 Inspector Name: John Spaulding Insp Num: mitlS060620065216 Permit Number: 188-039-0 Inspection Date: 6/17/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i 30-14 I --~ 6420 I IA 2260 3420 3420 3420 ¡Type Inj. I W ! TVD I I I--- P.T. I 1880390 iTypeTest I SPT I Test psi 1605 I OA I 340 440 440 440 I ;/ - . ¡--- Interval 4YRTST P/F P Tubmg i 2750 2750 2750 2750 I Notes This is a waivered well. Took I bbl diesel to reach test pressures, Monday, June 26, 2006 Page 1 of 1 MEMORANDUM ) State of Alaska ) Alaska Oil and Gas Conservation Commission TO: Jim Regg ~ác It \ ßlt» P.I. Supervisor ( t DATE: Monday, October 24, 2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 30-14 KUPARUK RIV UNIT 30-14 OJ q% -' O'D \ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv :.JBf;.., Comm Well Name: KUPARUK RIV UNIT 30-14 Insp Num: mitCS051018080400 Rei Insp N urn NON-CONFIDENTIAL API Well Number 50-029-21802-00-00 Permit Number: 188-039-0 Inspector Name: Chuck Scheve Inspection Date: 10/17/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 30-14 Type Inj. w TVD 6420 IA 2040 3010 3000 3000 P.T. 1880390 TypeTest SPT Test psi 1605 OA 380 420 420 420 Interval OTHER P/F P Tubing 2450 2450 2450 2450 Notes Annual test performed for internal waiver complience for tubing x IA comunication. Pretest pressures were observed for 30+ minutes and found stable. Well demonstrated good mechanical integrity during this 30-minute test. ~CANNE[> NOV 1 7. 2005 Monday, October 24,2005 Page 1 of I ). STATE OF ALASKA ) ALJ.\okA OIL AND GAS CONSERVATION COMMISSION RepairWell 0 Pull Tubing 0 Operat. ShutdownO RECEIVED Stimulate 0 Other APR3- 4 2005 Waiver 0 TiáT¡e E;xteRsjo.Q Go . AlaSKa UII (5( ~Cons. Commiston Re-enter Suspended Well ^ n oraoe 5. Permit to Drill Numb~r: Exploratory 0 1880390 Service 0 6. API Number: 50-029-21802-00 REPORT OF SUNDRY WELL OPERATIONS Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 1 00360 7. KB Elevation (ft): RKB 59' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: 1. Operations Performed: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING Perforation depth: Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 9. Well Name and Number: 30-14· 10. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool measured 8137' feet true vertical 6891' feet measured feet true vertical 6276' feet Length Size MD 110' 16" 110' 2305' 9-5/8" 2364' 8048' 7" 81 07' Plugs (measured) Junk (measured) TVD Burst Collapse Measured depth: 7792-7806', 7814-7834', 7858-7878' true vertical depth: 6603-6614',6621-6638',6657-6674' SC,A~'B~E[:) /\Pft .1 4 2005 Tubing (size, grade, and measured depth) 2-7/8", J-55, 7646' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'HB' pkr= 7572' sssv= SSSV sssv= 1788' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Oil·Bbl Gas-Met Water-Bbl Casinq Pressure 1390 1700 TubinQ Pressure 2310 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: OilO GasO WAG0 WDSPLO GINJO WINJO 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Signature Sundry Number or N/A if C.O. Exempt: Brad Gathman/MJ Loveland @ 659-7224 Brad Gathman Title ~"/ Phone Problem Wells Supervisor ? 907 -659-7224 Date 3 - -5 ð ,- òS'"" Prepared by Sharon Allsup·Drake 263-4612 RBDMS BFL APR 0 4 2005 Submit Original Only Form 10-404 Revised 04/2004 ., I r I; ):. ) 30-14 ) DESCRIPTION OF WORK COMPLETED - SUMMARY Date Event Summary 3/21/2005 TAGGED TD @ 79111 RKB (EST. 33' OF RAT HOLE) . SET 2.25 CSA-2 PLUG @ 76111 AND PERFROM POSITIVE TEST ON PLUG TO 3000 PSI. INTIAL TBG/IA/OA--2450/650/50 TEST TBG. TO 3000 PSI-IA-660-OA-50. HOLD FOR 15 MIN. TBG. LOST 20 PSIIA AND OA REMAINED THE SAME. GOOD TEST. BLEED TBG. DOWN TO 300 PSI AND MONITOR FOR 10 MIN. TBG.INCREASE 30 PSI. CONTACT CO REP (GOOD TEST) BLEED IA DOWN TO 300 PSI. BLEED OFF LUBRICATOR AND BEGIN RIGGING DOWN. 3/23/2005 Prep for BH weld, Energize IC PO P seal, Initial T 11/0= 250/250/100 Bleed down IA x OA, pull VR plugs and install N2 purge jewelry. Pull internal checks on IC PO and test void, install external valves. Energize IC PO P seal with McEvoy sealant. Still need: 31 gravel removed from cellar, IA and OA fluids levels modified to meet welding requirements 3/25/2005 BH weld prep- complete, FiIIlA x OA with diesel, Vac out FL's to 31 below weld point. Cellar is supersucked out to 3' below weld point. ready for welding 3/26/2005 BH weld - complete, Initial T/I/O= 01010 Rig up and purge N2 across IA x OA while making three weld passes around Bradenhead as per procedure. 3/27/2005 MITOA post BH weld - passed, InstalllA x OA VR plugs, normal up annuli jewelry, Install WH floorkit. Pressure up OA with diesel to 1800 psi, start MITOA T/I/O= 010/1800,15 minute reading T/I/O= 010/1720,30 minute reading T/I/O= 010/1700, bleed down OA. MEMORANDUM TO: Camille Taylor Chair State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 28, 2002 SUBJECT: Mechanical Integrity Tests THRU: Tom Maunderz,,-r-~,-- · ,~r~(~~,.,-, _ PAl P.I. Supervisorf~'~ ~'' -Il I~,,'-O '>'''-''' ~30 multiple FROM: John H. Spaulding KRU Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. we,I 30-14 I Type,nj.I G"I T.V.D. I 6420 I Tubi"g'l 3700 I 3700 I '37b0 I 3700' I lntervall 4 P.T.D.I 1880390 Imypetestl P I'mestpsil' 1605 I casingl 150,0 I 2080 I 20'80 1..2080 I PIE ! P_. Notes: we,,I 30-16AI Type,nj.IGi ¥.v.~,. i~, l:ru~,n"! 3~2~ I ~o I ~,~o I~..o l,nterva,I 4 P.T.D.I 188o43o ITyPe~est!,, P 'lTestpsil 1581 I C. asingl ~8~0 I ,254O 1'2~0 I 2520 I" P/F, I _P Notes: P,T.D.I 1880290 ITypetestI P ITestpsil 1598 I'Casingl 2075 I 2450 I 2450' I 2~,50 I. pIF I E Notes: " Well P.T.D.I Notes: P'.T.D. Notes: IType ,nj. I .... i'T-v-D'- I I Tu~,,, I I I I 'l"nter~a'l -I:Ype test! ' I TestpsiJ' I CasingI ' ' I . I ' . I ... I P/F' I'". . l, e,nJ.I I' T.V.O. I I Tu~in, I 'I I ' I ' I'nte~va'l'' TypetestJITestpsi l ICasing'l I , , I 'I . . I P/F ,I., Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. $ = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test dudng Workover O= Other (describe in notes) Test's Details Page 2 of 2. As noted on the preceeding test report forms, no failures were observed. Jon Arend (APC) was the PAl company rep. M.I.T.'s performed: _3 Attachments: none Number of Failures: _.0 Total Time during tests: 2 cc: none MIT report form 5/12/00 L.G. 020628-m it(2) kru 30 js.xls 7/16/2002 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 59' feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__X Kuparuk River Unit 4. Location of well at surface 8. Well number 1062' FNL, 2035' FWL, Sec. 22, T13N, R9E, UM (525673, 6021757) 30-14 At top of productive interval 9. Permit number / approval number 1423' FSL, 909' FEL, Sec. 22, T13N, R9E, UM 188-039/ At effective depth 10. APl number 50-029-21802-00 At total depth 11. Field / Pool 1242' FSL, 736' FEL, Sec. 22, T13N, R9E, UM Kuparuk River Field / Kuparuk River Oil Pool 12. Present well condition summary Total depth: measured 8137 feet Plugs (measured) true vertical 6890 feet Effective depth: measured 7911 feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 80' 16" 175 sx AS 1 80' 1 10' Surface 2331' 9.625" 900 sx AS ~ & 300 sx C~ass G 2364' 2225' Production 8047' 7" 550 sx TLW, 200 sx Class G 8107' 6864' Perforation depth: measured 7858' -7878', 7814' - 7834', 7792'- 7806' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, J-55 tubing @ 7646' Packers & SSSV (type & measured depth) Baker 'HB' @ 7572' MD. Baker'FVLD' @ 1788' MD. "~¢"::"'~' ":' ~:~:: :';': '"~i:~!!~'~'::~; 13. Stimulation or cement squeeze summary .;;i ?' ,?C'.,~ ~!'?~.': Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casin~ Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run _ \/ Daily Report of Well Operations __X Oil _ Gas _ Suspended _ Service _Water Injector_~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Peter Nezaticky 659-7224 Signed /~~~~~ Title: Wells Team Leader Date ~ ~--/~/~,~_. Peter Nezatick~l Prepared by Sharon AIIsup-Drake 263-4612 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Alaska, 'rnc. KUPARUK RIVER UNIT WELL SERVICE REPORT I{1 (30-1Zt (WZl-6)) WELL JOB SCOPE JOB NUMBER 30-14 ANN-COM M 0727021646.19 DATE DAILY WORK UNIT NUMBER 07/28/02 CEMENT TOP JOB DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR I YESI YES DS-CULPEPPER NEZATICKY FIELD AFC# CC# DAILY COST ACCUM COST Signed ESTIMATE WCW.K02.KR9 $6,400.00 $6,500.00 9.30 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann Final Outer Ann 0 PSI 0 PSI 0 PSI 0 PSII 0 PSI 0 PSI DALLY SUMMARY PUMPED 2 BBL OF ARTIC SET 1 CEMENT INTO THE SURFACE PIPE X CONDUCTOR ANNULUS.[WH Maintenance] TIME LOG ENTRY 12:15 DS ON LOC. MIRU 12:20 START MIXING ARTIC SET I CEMENT @ 15.8 PPG. 12:30 PUMPED 1 BBL OF CEMENT INTO THE SURFACE PIPE X CONDUCTOR ANNULUS. 12:35 MOVE TO NEXT WELL PROD, CASIN~ -- Gas Lift Mand~e[/Durnmy Gas L~ft Mandrel/Dummy Gas E~ft Mandrel/Dummy Gas Lift Mandrel/Dummy Gas Lift Mand~e~ummy Ped Ped SSSV T Annular Fluid: 6137 EKB CONDUCTOR Size Bottom TVD 2.875 0 7646 6482 Thread Thread Thread EUE 8RD AB MOD Interval TVD Zone Comment 7792 - 7806 6603 - 6614 A-3 2 1/8" EnerJet' 60 deg. 7814 - 7834 6621 - 6638 A-2 2 1/8'~ EnerJet' 60 deg. 7858 - 7878 6657 - 6674 A-1 4 1/2~ Csg Gun' 45 deg. VlV Comment Description ID Baker *FVLD'; 7/11/00 - SL & EL had to pump up panel to ?5400 psi to get 2.312 ~ SSSV. Baker 2.376 Baker 'HB* 2,376 2.250 Baker 2.441 2.441 Depth I Description SUNDRY NOTICE 10-404 Phillips Kuparuk Well 30-14 Annular Cement "Top-Job" July 28, 2002 Phillips Alaska, Inc., Kuparuk well 30-14 top of cement between the surface pipe and conductor (9 5/8" x 16") was measured at 5 feet below grade. Arctic Set I cement (15.8 ppg) was pumped into the annular void (1 bbl) via a hose, filling from the bottom-up. The cement top was brought to the surface of the conductor casing. The State Inspector was notified of the cement job and waived attendance, but will inspect the wellhead post cementing. The field Well Service Report is attached. MICROFILMED 10/12/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ,, 1. Status of Well Classification of Service Well OIL E~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 88-39 3~ Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21~02 4. Location of well at surface 9. Unit or Lease Name 1062' FNL, 2035' FWL, Sec.22, T13N, R9E, UM KuDaruk River Unit At Top Producing Interval 10. Well Number 1423' FSL, 909' FEL, Sec. 22, T13N, R9E, UM At Total Depth 11. Field and Pool 1242' FSL~ 736' FEL, Sec.22, T13N, R9~ UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 58' RKB~ ADL 25513 ALK 2554 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband.~ 115. Water Depth, if offshore 116. No. of Completions 05/07/88 05/13/88 ,,04t¢44¢8e,~ ¢¢- Z} ~ N/A feet MSL 1 17. Total Depth (MD+TVD) !18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8137 'MD/6890 'TVD 8025 'MD/6796 'TVD YES ~ NO []I 1 7~ feet MD 17nn, f ~nnrn~ 22. Type Electric or Other Logs Run D IL/GR/SP/SFL/FDC/CNL/Cal , CET, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# FI-~0 $,-rf !!0' 2~.'' !75 s.v. AS ! 9-_~/R" ~¢;.~# .I-~ .c;,,rf 2364' !2-!/4" 900 sx AS !!! & 300 cx AS II Top -;r~b, ,.,/1~ ~-~ ~ I j ~ ,.,, , vv ~,.. , ,v , 7" ?¢,_0# .I-~,.~ .~,,r¢ RlnT, 8-!/2" 500 s× TLW ~- 200 sx C!~ss G 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) 2-7/8" 7~!: ~ ' 7~;72 ' Perforated w/8 spf, 45~ phasing 7858 '-7878 'MD/6657 ' -6674 'TVD 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. '~ : ' ' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED Sc~ ~tt~ch~d Addend:m, d~tcd 8/15/88 . 27. PRODUCTION TEST , , , Date First Production I Method of Operation (Flowing, gas lift, etc.) N/A I Date of Test Hours Tested PRoDuCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ]GAS-OIL RATIO TEST PERIOD · , Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBI_ GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. COR E DATA , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None * NOTE: Drilled RR 5/14/88. Perforated well & ran tubing 6/25/88. Fractured well 8/1~,,~.7~8~( ~ . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LO Form 10-407 WC5/035 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 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 Kuparuk C 7684' 6513' N/A Base Kuparuk C 7714' 6538' Top Kuparuk A 7779' 6592' Base Kuparuk A 791.5' 6704' 31. LIST OF ATTACHMENTS Addendums (dated 8/10/88 & 8/15/88) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 8/14/88 30-14 Frac Kuparuk "A" sand perfs 7858'-7878' in 5 stages per procedure dated 8/9/88 as follows: Pmp pre-pad w/ 150 bbls gelled diesel @ 20 BPM, 7200 - 4980 psi. Pmp pad w/ 600 bbls gelled diesel @ 20 BPM, 5400-4360 psi. Stage 1: 50 bbls gelled diesel @ 2 ppg 16/20, 20 BPM, 4360-4100 psi Stage 2: 100 bbls gelled diesel @ 4 ppg 16/20, 20 BPM, 4100-4060 psi Stage 3: 110 bbls gelled diesel @ 6 ppg 16/20, 20 BPM, 4060-4150 psi Stage 4: 85 bbls gelled diesel @ 8 ppg 16/20, 20 BPM, 4150-4470 psi Stage 5: 90 bbls gelled diesel @ 10 ppg 16/20, 20 BPM, 4470-5060 psi Ail prop was 16/20 carbolite. Had a smooth ramp from 0-10 ppg concentration. ISIP was very low at end of job. Appears SSSV closed. Fluid to recover: 1235 bbls Sand in zone: 87,122# Sand in casing: 290# above top perf. Avg. pressure: 4400 psi Well turned over to production. ADDENDUM WELL: 7/24/88 30-14 Pmp 21 bbls hot diesel w/ 5% Musol and disp w/ 51 bbls cln diesel. Turn well over to Production. ~te SUB-SURFACE DIRECTIONAL SURVEY ~]UIDANCE [~]ONTINUOUS [~OOL Company ARCO ALASKA, INC. Well Name ..30-14 (1062'FNL, 2035'FWL~ SEC 22~ T13N~ R9E, ..llM) Field/Location KUPARUK, NORTH SLOPE~ ALASKA Job _Reference No. Date 72816 5-June-88 Logned By: Computed By: MCBRIDE STEVENS SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 30-1~ .... .~ KUPARUK NORTH SLOPE,ALASKA SURVEY OATE: 05-JUN-88 ENGINEER: MCBRIDE METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 40 DEG 14 MIN EAST ARCO ALASKA, INC. 30-14 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: It-JUN-88 PAGE DATE OF SURVEY: 05-JUN-Sb KELLY BUSHING ELEVATION: 58.00 FT ENGINEER: MCBRIDE' ' INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB- SE~ COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG M[N DEG HIN 0.00 0.00 -58.00 0 0 N 0 0 E 100o00 100.00 42.00 0 11 S 76 5 E 200.00 200.00 142.00 0 24 S 76 15 E 300.00 300.00 Z42.00 0 32 N 71 28 E 400.00 399.99 341.99 0 48 N 65 3 E 500.00 499.97 441.97 1 13 N 56 14 5 600.00 599.95 541.95 I 8 N 51 40 E 700.00 699.93 641.93 0 52 N 47 7 E 800.00 799.92 741.92 0 45 N 46 47 E 900.00 899.92 841.92 0 34 N 54 30 E 1000.00 999.91 941.91 0 38 llO0.OO 1099.88 1041.88 2 49 1200.00 1199.45 1141.45 7 24 1300.00 1298.04 1240.04 11 37 1400.00 1395.37 1337.37 14 52 1500.00 1490.90 1432.90 19 16 1600.00 1594.64 1526.64 21 43 1700.00 1676.73 1618.73 23 47 1800.00 1767.22 1709.22 27 1 1900.00 1854.32 1796.32 31 46 2000.00 1937.37 1879.37 35 35 2100.00 Z017.89 1959.89 36 25 2200.00 2098.35 2040.35 37 2 2300.00 2176.77 211 8.77 39 51 2400.00 2251.52 2193.52 43 4 2500.00 232:3.99 2265.99 43 53 2600.00 2395.84 2337.84 44 15 2700.00 2467.28 2409.28 44 29 2800.00 2538.84 24.80.84 44 3 2900.00 2610.99 2552.99 43 28 3000.00 2684.36 2626.36 42 8 3100.00 2759.34 2701.34 40 39 3200.00 2836.05 2778.05 39 12 3300.00 2914.06 2856.06 38 13 3400.00 2993.12 2935.12 37 16 3500.00 3073.60 3015.60 35 28 3600.00 31 55.54 3097.54 34 45 3700.00 3237.11 3179.11 35 59 3800.00 3317.98 3259.98 35 52 3900.00 3399-19 3341,19 35 33 · N 55 47 E S 66265 S 42 34 E S 33 24 E S 30255 S 28 8 E S 25 0 E S 22 0 E S ?.3 33 E VERTICAL OOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST OISTo AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 0.00 0.00 0.00 N 0.00 E 0.06 0.41 0.02 S 0.07 E 0.54 0.02 0.20 S 0.60 E 1.01 0.43 0.19 S 1.34 E 1.37 0.44 0.25 N 2.42 E 1.58 0.20 1.16 N 3.97 E 1.84 0.10 2.38 N 5.66 E 1.84 0.49 3.55 N 7.04 E 1.77 0.04 4.50 N 8.06 E 1.77 0.00 5.25 N 8.94 E 1.86 0.19 5.85 N 3.38 4.97 5.73 N 12.08 5.01 0.08 N 28.58 4.24 13.17 S 51.22 3.99 32.62 S 80.17 2.51 58.34 S 113.97 3.78 89.41 S 151.26, 1.65 125.21 S 19.1.51 4.92 238.28 4.68 S 26 54 E 292.01 S 32 1,4 E 350.26 S 36 42 E 409.32 S 38 2 5 471.30 S 34 29 E 537.51 S 33 54 E 606.02 S 33 23 E 675.11 S 33 41 5 744.59 S 35 41 E 814.11 S 36 36 E 883.18 S 37 24 E 951.02 S 37 30 E 1017.09 S 38 1 E 1081.18 S 38 34 E 1143.71 S 39 1 E 1204.93 S 39 36 E 1264.25 S 39 51 E 1321.57 S 39 45 E 1379.43 S 40 Z E 1438.24 S 40 55 E 1496.60 0.00 N 0 0 E 0.08 S 75 2 E 0.63 S 72 2 E 1.36 S 82 4 E 2.43 N 84 6 E 4.14 N 73 44 E 6.14 N 67 14 f 7.89 N 63 14 L 9.23 N 60 50 10.37 N 59 35 E 9.80 E 11.41 N 59 9 E 12.00 E 13.30 N 64 27 E 18.79 E 18.80 N 89 45 E 28.68 E 31.56 S 65 19 E 40.75 E 52.20 S 51 19 E 55.I7 E 80.29 S 43 24 E 70.78 E 114.03 S 38 Zl E 86.19 E 152.01 S 34 32 E 164.75 S 101.77 E 193.65 S 31 42 E 210.03 S 120.66 E 242.23 S 29 52 E 3.90 3.04 3.6.1 3.74 2.15 0.37 0.43 1.12 0.98 1.53 260.39 S 144.33 E 297.72 S 28 59 E 311.97 S 173.55 E 356.99 S 29 5 E 360.88 S 207.18 E 416.12 S 29 51 E 409.84 S 245.27 E 477.62 S 30 53 E 463.39 S 284.48 E 543.74 S 31 32 E 520.43 S 323.15 E 612.59 S 31 50 E 578.35 S 361.65 E 682.11 S 32 1 E ~ 636.74 S 400.21E 752.06 S 32 9 E / 694.15 S 439.98 E 821.84 S 32 22 E 750.07 S 480.81 E 890.95 S 32 39 E 1.31 1.45 0.92 0.87 1 1.75 0.40 1 0.68 0.83 804.30 S 521.76 E 958.71 S 32 58 E 856.79 S 562.01 E 1024.67 S 33 15 E 907.53 S 601.25 E 1088.63 S 33 31,E 956.63 S 640.04 E 1150.99 S 33 47 E 1004.35 S 678.41 E 1212.01 S 34 2 E 1050.25 S 716.01 E 1271.10 S 34 17 E 1094.30 S 752.69 E 1328.17 S 34 31 E 1138.76 S 789.72 E 1385.79 S 34 44 E 1183.90 S 827.40 E 1444.38 S 34 56 E 1228.31 S 865.28 E 1502.48 S 35 9 E ARCO ALASKAt INC. 30-14 KUPARUK NORTH SLOPEtALASKR COMPUTATION DATE: 21-JUN-Sa PAGE DATE OF SURVEY:: 05-JUN-~ KELLY BUSHING ELEVATION: 58.00 FT ENGINEER: MCBRIDE ' INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MERSURED 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 4000.00 3480.75 3422.7'5 35 7 4100.00 3562.60 3504.60 35 5 4200.00 3644.36 3586.36 35 16 4300.00 3725.71 3667.71 35 52 4400.00 3806.65 3748.65 35 58 4500.00 3887.73 3829.73 35 40 4600.00 3969.06 3911.06 35 28 4700.00 4050.71 3992.71 35 5 4800.00 4132.53 4074.53 35 3 4900.00 4214.52 4156.52 34 48 5000.00 4296.75 4238.75 34 31 5100.00 4379.27 4321.27 34 16 5200.00 4462.01 4404.01 34 5 5300.00 4544.87 4486.87 34 0 5600.00 46Z7.78 4569.78 33 58 5500.00 4710.77 4652.77 33 50 5600.00 4793.88 4735.88 33 42 5700.00 4877.13 4819.13 33 38 5800.00 4960.05 4902.05 34 16 5900.00 5062.72 4984.72 34 12 6000.00 5125.38 5067.38 34 18 6100.00 5207.94 5149.94 34 24 6200.00 5290.41 5232.41 34 26 6300.00 5372.87 5314.87 34 26 6400.00 5455.38 5397.38 34 17 6500.00 5538.05 5480.05 34 15 6600.00 5620.75 5562.75 34 7 6700.00 5703.1B 5645.18 34 59 6800.00 5784.94 5726.94 35 10 6900.00 5866.83 5808.83 34 55 7000.00 5948.88 5890.88 34 50 7100.00 6030.90 5972.90 34 56 7200.00 6112.94 6054.94 34 44 7300.00 6195.24 6137.24 34 28 7400.00 6277.77 6219.77 34 15 7500.00 6360.42 6302.42 34 15 7600.00 6443.11 6385.11 34 9 7700.00 6525.97 6467.97 33 57 7800.00 6608.92 6550.92 33 54 7900.00 6692.00 6,634.00 33 42 S 42 0 E 1554.43 S 42 17 E 1611.85 S 42 18 E 1669.40 S 39 51 E 1727.55 S 39 1! E 1786.25 S 39 38 E 1844.79 S 40 I E 1902.96 S 40 13 E 1960.70 S 40 26 E 2018.18 S 40 46 E 2075.45 S 41 11 E 2132.34 S 41 32 E 2188.81 S 41 52 E 2244.96 S 42 6 E 2300.91 S 42 19 E 2356.80 S 42 50 E 2412.53 S 43 31 E 2468.06 S 44 3 E 2523.36 S 44 36 E 2579.12 S 44 57 E 2635.20 S 45 15 E 2691.27 S 45 21 E 2747.48 S 45 18 E 2803.82 S 45 26 E 2860.16 S 45 42 E 2~)16.42 S 45 55 E 2972.40 S 45 46 E 3028.35 S 44 45 E 3086.73 S 44 33 E 3142.16 S 44 43 E 3199.38 S 44 54 E 3256.36 S 44 33 E 3313.39 S 44 ¢ E 3370.43 S 44 15 E 3427.10 S 44 28 E 3683.61 S 44 9 E 3539.57 S 43 42 E 3595.67 S 44 0 E 3651.56 S 44 11 E 3707.27 S 44 3 E 3762.82 0.58 0.20 0.81 1.46 0 0.31 0.39 0.20 0.32 0.30 0.42 0.40 0.17 0.10 0.23 0.36 0.36 0.53 0.40 0.23 0.16 0.19 0.07 0.24 0.54 0.14 0.35 0.87 0.49 0.20 0.45 0.69 0.26 0.33 0.15 0.42 0.15 0.27 0.20 0.57 1271.63 S 903.61 E 1559.99 S 35 23 E 1314.20 S 942.19 E 1617.05 S 35 38 E 1356.74 S 981.00 E 1674.25 S 35 52 E 1400.50 S 1019.31 E 1732.17 S 36 2 E 1445.90 S 1056.54 E 1790.78 S 36 9 E 1491.12 S 1093.71 E 1849.23 S 36 15 E 1535.79 S 1130.99 E 1907.30 S 36 22 1579.94 S 1168.19 E 1964.91 S 36 28 1623.76 S 1205.40 E 2022.28 S 36 35 E 1667.24 $ 1262.67 E 2079.40 S 36 41 E 1710.19 S 1279.98 E 2136.14 S 36 48 E 1752.59 S 1317.31 E 2192.46 S 36 55 E 1794.50 S 1354.69 E 2248.43 S 37 2 E 1836.11 S 1392.14 E 2304.20 S 37 10 E 1877.53 S 1429.72 E 2359.91 S 37 17 E 1918.61 S 1667.44 E 2415.46 S 37 24 E 1959.16 S 1505.49 E 2470.79 S 37 32 E 1999.15 S 1543.84 E 2525.8'7 S 37 40 E 2039.16 S 1582.90 E 2581.41 S 37 49 E 2079.06 S 1622.54 E 2637.26 S 37 58 E 2118.77 S 1662.43 E 2693.L1 S 38 7 E 2158.44 S 1702.55 E 2749.10* S 38 15 E 2198.20 S 1742.78 E 2805.24 S 38 24 E 2237.95 S 1783.03 E 2861.40 S 38 32 E 2277.50 S 1823.38 E 2917.49 S 38 40 E 2316.69 S 1863.74 E 2973.31 S 38 48 E 2355.84 S 1904.10 E 3029.12 S 38 56 E 2395.62 S 1944.36 E 3085.38 S 39 3 [ 2436.64 S 1984.79 E 3142.70 S 39 9 E 2477.47 S 2025.12 E 3199.83 S 39 15 E 2518.01 S 2065.43 E 3256.74 S 39 21 E 2558.61 S 2105.73 E 3313.70 S 39 27 E 2599.57 S 2145.63 E 3370.68 S 39 32,E 2660.31 S 2185.21 E 3427.30 S 39 36 E 2680.68 S 2224.68 E 3483.57 S 39 41 E 2720.91 S 2264.07 E 3539.69 S 39 65 E 2761.44 S 2303.04 E 3595.76 S 39 49 E 2801.85 S 2341.80 E 3651.63 S 39 53 E 2841.93 S 2380.68 E 3707.31 S 39 57 E 2881.87 S 2419.47 E 3762.84 S 40 0 E ARCO ALASKAt INC. 30-14 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 21-JUN-88 PAGE DATE OF SURVEY: 05-JUN-8~ KELLY BUSHING ELEVATION: 58.00 FT ENGINEER: MCBRIDE ' INTERPOLATED VALUES FOR EVEN ZO0 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/I00 FEET FEET FEET OEG MIN 8000.00 6775.55 67Z7.55 33 8 S 43 24 E 3817.65 0.00 2921.54 S 2457.46 E 3817.66 S 40 4 E 8100.00 6859.28 6801.28 33 8 S 43 24 E 3872.24 0.00 2961.26 S 2495.03 E 3872.24 S 40 6 E 8137.00 6890.26 6832.26 33 8 S 43 2¢ E 3892.¢3 0.00 2975.96 S 2508.9¢ E 3892.44 S 40 7 E ARCO ALASKAt INC. 30-14 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 21-JUN-88 PAGE' DATE OF SURVEY: 05-JUN-8,. KELLY BUSHING ELEVATION: 58.00 FT ENGINEER: MCBRIDE INTERPOLATED VALUES FOR EVEN 1000 FEET DF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -58.00 0 0 1000.00 999.91 941.91 0 38 2000.00 1937.37 1879.37 35 35 3000.00 2684.36 2626.36 42 8 4000.00 3480.75 3422.75 35 7 5000.00 4296.75 4238.75 34 31 6000.00 5125.38 5067.38 34 18 7000.00 5948.88 5890.88 34 50 8000.00 6775.55 6717.55 33 8 8137.00 6890.26 6832.26 33 8 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH - FEET DEG/IO0 FEET FEET FEET DEG MIN N 0 0 E 0.00 N 55 47 E 1.86 S 26 54 E 292.01 S 37 24 E 951.02 S 42 0 E 1554.43 S 41 11 E 2132.34 S 45 15 E 2691.27 S 44 54 E 3256.36 S 43 2~ E 3817.65 S 43 24 E 3892.43 0.00 0.19 3.90 1.31 0.58 0.42 0.16 0.45 0.00 0.00 0.00 N 0.00 E 0.00 N 0 0 E 5.85 N 9.80 E 11.41 N 59 9 E 260.39 S 144.33 E 297.72 S 28 59 E 804.30 S 521.76 E 958.71 S 32 58 E 1271.63 S 903.61 E 1559.99 S 35 23 E 1710.19 S 1279.98 E 2136'14 S 36 48 E 2118.77 S 1662.43 E 2693.11 S 38 7 2518.01 S 2065.43 E 3256.74 S 39 21 2921.54 S 2457.46 E 3817.6.6 S 40 4 E 2975.96 S 2508.94 E 3892.44 S 40 T E ARCO ALASKA, INC. 30-14 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 21-JUN-88 PAGE DATE OF SURVEY: OS-JUN-8,. KELLY BUSHING ELEVATION:; 58.00 FT ENGINEER: MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH OEG MIN DEG MIN 0.00 0.00 -58.00 0 0 N 0 0 E 58.00 58.00 0.,00 0 7 S 12 47 W 158.00 158.00 100.00 0 21 S 71 1Z E 258.00 258.00 ZO0.O0 0 25 N 88 51 E 358.01 358.00 300.00 0 39 N 68 28 E 458.02 458.00 400.00 I 4 N 58 48 E 558.04 558.00 500.00 1 11 N 53 57 E 658.06 658.00 600.00 I 2 N 49 4 E 758.07 758.00 700.00 0 47 N 47 16 E 858.08 858.00 800.00 0 37 N 50 12 E 958.08 958.00 900.00 0 36 1058.10 1058.00 1000.00 I 19 1158.28 1158.00 1100.00 5 28 1259.22 1258.00 1200.00 9 51 1361.45 1358.00 1300.00 13 33 1465.29 1458.00 1400.00 18 0 1571.42 1558.00 1500.00 20 47 1679.55 1658.00 1600.00 23 31 1789.63 1758.00 1700.00 26 30 1904.36 1858.00 1900.00 31 57 2025.46 1958.00 1900.00 36 16 2149.74 2058.00 2000.00 36 7 2275.72 2158.00 2100.00 39 2 2408.85 2258.00 2200.00 43 15 2547.26 2358.00 2300.00 44 2 2686.99 2458.00 2400.00 44 29 2826.65 2558.00 2500.00 43 56 2964.37 1658.00 2600.00 42 35 3098.23 2758.00 2700.00 40 40 3228.25 2858.00 2800.00 38 56 3355.73 2958.00 2900.00 37 43 3480.77 3058.00 3000.00 35 49 3603.00 3158.00 3100.00 34 47 3725.84 3258.00 3200.00 36 8 3849.33 3358.00 3300.00 35 41 3972.17 3458.00 3400.00 35 14 4094.38 3558.00 3500.00 35 4 4216.72 3658.00 3600.00 35 21 4339.88 3758.00 3700.00 35 57 4463.37 3858.00 3800.00 35 48 VERTICAL OOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN N 54 27 E N 86 15 E S 49 44 E S 35 53 E S 31 38 E S 29 4 E S 26 7 E S 22 30 E S 21 35 E S 23 39 E 0.00 0.00 0.00 N 0.00 E 0.00 0.16 0.00 S 0.00 E 0.31 0.33 O.1Z S 0.33 E 0.84 0.43 0.25 S 1.01 E 1.21 0.16 0.03 N 1.92 E 1.57 0.76 0.69 N 3.25 E 1.80 0.19 1.86 N ¢.98 E 1.86 0.29 3.08 N 6.51 E 1.80 0.00 4.11 N 7.65 E 1.75 0.42 4.98 N 8.59 E 1.82 0.10 5.59 N 2.23 3.14 6.09 N 7.45 4.95 3.33 N 20.95 4.35 6.84 S 41.89 2.98 24.52 S 69.32 4.85 48.62 S 103.96 3.37 80.07 S 143.45 1.41 117.61 S 187.00 4.62 240.53 4.64 S 28 $ E 306.56 S 34 31 E 379.45 S 38 19 E 455.90 S 34 16 E 543.51 S 33 36 E 638.63 S 33 31 E 735.53 S 36 0 E 832.57 S 37 15 E 927.08 S 37 30 E 1015.93 S 38 12 E 1098.95 S 38 49 E 1177.97 S 39 30 E 1253.01 S 39 51 E 1323.29 S 39 45 E 1394.63 S 40 26 E 1467.08 S 41 49 E 1538.42 S 42 17 E 1608.63 S 42 3 E 1679.07 S 39 18 E 1750.94 S 39 28 E 1823.39 0.00 N 0 0 E 0.00 S 45 0 E 0.35 S 69 52 E 1.04 S 76 I E 1.92 N 89 4 E 3.32 N 7T 56 E 5.32 N 69 29 7.21 N 6¢ 41 8.68 N 61 43 E 9.93 N 59 54 E 9.43 E 10.96 N 59 ZO E 10.64 E 12.26 N 60 13 E 15.47 E 15.83 N 77 51 E 24.35 E 25.29 S 74 18 E 35.88 E 43.46 S 55 39 E 49.87 E 69.64 S 45 43 E 66.31 E 103.96 S 39 37 E 83.09 E 144.00 S 35 14 E 160.35 S 100.00 E 188.97 S 31 56 E 212.17 S 121.62 E 244.55 S 29 49 E 3.84 3.15 3.24 1.26 0.69 0.74 0.32 1.38 1.46 1.04 273.62 S 151.22 E 312.63 S 28 55 E 336.56 S 189.68 E 386.33 S 29 24 E 397.71 S 235.75 E 462.34 S 30 39 E 468.35 S 287.91 E 549.77 S 31 34 E 547.71 .S 341.38 E 645.38 S 31 56 E 629.14 S 395.16 E 742.95 S 32 7 E 709.18 S 450.80 E 840.33 S 32 26 F 785.24 S 507.22 E 934.81 S 32 51 ~ 855.87 S 561.30 E 1023.51 S 33 15 E 921.51 S 612.23 E 1106.35 S 33 35 E 0.97 1.96 0.51 0.52 0.58 0.57 0.23 1.16 0 0.51 983.37 S 661.47 E 1185.14 S 33 55 E 1041.58 S 708.86 E 1259.90 S 34 14 E 1095.62 S 753.79 E 1329.88 S 34 31, E 1150.44 S 799.44 E 1400.94 S 34 47 E 1205.92 S 846.04 E 1473.10 S 35 3 E 1259.72 S 892.90 E 1544.07 S 35 19 E 1311.81 S 940.02 E 1613.84 S 35 37 E 1363.93 S 987.48 E 1683.87 S 35 54 E 1418.54 S 1034.20 E 1755.52 S 36 5 E 1474.62 S 1080.09 E 1827.87 S 36 13 E ARCO ALASKAt INC. 30-14 KUPARUK NORTH SLOPEtALASKA COMPUTATION DATE: 21-JUN-S8 PAGE DATE OF SURVEY:" 05-JUN-8~ KELLY 5USHING ELEVATION: 58.00 FT ENGINEER: MCBRIDE ° INTERPOLATED VALUES FOR EVEN 100 FEET DF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG 4586.42 3958.00 3900.00 35 32 4708.91 4058.00 4000.00 35 5 4831.10 4158.00 4100.00 34 59 4952.93 4258.00 4200.00 34 40 5074.25 4358.00 4300.00 34 19 5195.17 ¢458.00 4,400.00 34 6 5315.84 4558.00 4500.00 34 0 5436.44 4658.00 4600.00 33 54 5556.85 4758.00 4700.00 33 46 5677.02 4858.00 4800.00 33 37 5797.52 4958.00 4900.00 34 16 5918.47 5058.00 5000°00 34 13 6039.50 5158.00 5100.00 34 20 6160.69 5258.00 5200.00 34 27 6281.97 5358.00 5300.00 34 27 6403.17 5458.00 5400.00 34 17 6524.14 5558.00 5500,,00 34 16 6645.07 5658.00 5600.00 34 23 6767.04 5758.00 5700.00 35 13 6889.23 5858.00 5800.00 34 55 7011.12 5958.00 5900.00 34 51 7133.06 6058.00 6000.00 34 56 7254.79 6158.00 6100.00 34 36 7376.06 6258..00 6200.00 34 19 7497.08 6358.00 6300.00 34 15 7617.99 6458.00 6400..00 34 7 7738.61 6558.00 6500.00 33 56 7859.10 6658.00 6600.00 33 49 8137.00 6890.26 6832.26 33 8 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN S 40 0 E 1895.09 S 40 16 E 1965.82 S .40 32 E 2036.04 S ,60 59 E 2105.61 S 41 27 E 2174.30 S 41 52 E 2242.25 S 42 8 E 2309.76 S 42 27 E 2377.13 S 43 13 E 2444.13 S 63 56 E 2510.67 S 44 35 E 257'7.73 S 45' 2 E 2645.55 S 45 19 E 2713.46 S 45 19 E 2781.67 S 45 24 E 2850.00 S 45 43 E 2918.19 S 45 55 E 2985.92 S 45 25 E 3053.62 S 44 31 E 3123.21 S 64 42 E 3193.23 S 64 54 E 3262.70 S 44 18 E 3332.27 S 44 10 E 3401.53 S 44 25 E 3469.95 S 64 10 E 3537.93 S 43 42 E 3605.75 S 44 7 E 3673.08 S 44 10 E 3740.14 S 43 24 E 3992.43 0.17 0.18 0.41 0.39 0.29 0.17 0.05 0.37 0 0 0 0.22 0.09 0.13 0.21 0.50 0.12 1 0 0.20 0.47 0.64 0.29 0.24 0.41 0.29 0.06 0.05 0.00 1529.76 S 1125.92 E 1899.44 S 36 21 E 1583.85 S 1171.50 E 1970.02 S 36 29 1637.34 S 1216.99 E 2040.09 S 36 37 E 1690.05 S 1262.41 E 2109.49 S 36 45 1741.71 S 1307.69 E 2177.98 S 36 53 E 1792.49 S 1352.88 E 2245.73 iS 37 2 1842.68 S 1398.09 E 2313.03 S 37 I1 1892.55 S 1443.43 E 2380.18 S 37 19 L. 1941.74 S 1489.03 E 2446.95 S 3'7 28 E 1989.99 S 1535.01 E 2513.23 S 3'7 38 E 2038.14 S 1581.92 E 2580.02 S 37 69 E 2086.40 S 1629.89 E 2647.57 S 37 59 E 2134.44 S 1678.25 E 2715.21 S 38 10 E 2182.57 S 1726.97 E 2783.16 S 38 21 E 2230.79 S 1775.77 E 2851.28 S 38 31 E 2278.75 S 1824.66 E 2919.26 S 3~ 41 E 2326.14 S 1873.50 E 2986.79 S 38 50 E 2373.59 S 1922.23 E 3054.32 S 33 0 E 2423.09 S 1971.46 E 3123.79 S 39 7 E 2473.09 S 2020.78 E 3193.70 S 39 15 E 2522.51 S 2069.92 E 3263.0.6 S 39 22 E 2572.14 S 2118.98 E 3332.56' S 39 28 E 2621.94 S 2167.33 E 3401.75 S 39 34 E 2671.05 S 2215.23 E 3470.12 S 39 40 E 2719.74 S 2252.92 E 3538.05 S 39 45 2768.73 S 2310.01 E 3605.83 S 39 50 E 2817.34 S 2356.80 E 3673.13 S 39 54 F 2865.56 S 2403.64 E 3740.17 S 39 59 2975.96 S 2508.94 E 3892.44 S 4,9 7 E ARCO ALAS[A~ INC. 30-14 KUPARUK NORTH SLOPEpALASK~ MAI~KER TOP KUPARUK C BASE KUPARUK C TOP KURARUK A BASE KUPARUK A PBTD TD COMPUTATION DATE: 21-JUN-88 PAGE DATE OF SURVEY: 05-JUN-8~ KELLY BUSHING ELEVATION: 58.00 FT ENGINEER: MCBRIDE INTERPOLATED VALUES FOR CHOSEN HORIZONS MEASURED OEPTH BELOW KB 7684.00 7714.00 7779.00 7915.00 8025.00 8137.00 ORIGIN= 1062 FNL,2035 TVO FROM KB SUB-SEA 6512.70 6454.70 653'7.58 6479.58 6591.50 6533.50 6704.68 6646.48 6796.48 6738.48 6890.Z6 6832.26 SURFACE LOCATION AT FWL SEC 22,T13N RECTINGULAR COOR~tuMES NORTH/SOUTH EAST/WEST 2795.42 S 2807°47 S 2833°52 S 2887.83 S 2931.½7 S 2975°96 S 2335.59 E 2347. Z3 E 237:2.51E Z425o26 E 2466.85 E 2508.94 E ARCO ALASKA, INC. 30-14 KUPARUK NORTH SLOPEtALASKA COMPUTATION DATE: 21-JUN-B8 KELLY DATE BUSHING · ~*~~~ STRATIGRAPHIC SUMMARY MARKER MEASURED DEPTH BELOW KB ORIGIN: 1062 TVD FROM KB SUB-SEA TOP KUPARUK C BASE KUPARUK C TaP KURARUK A BASE KUPARUK A PBTD TO 7684.00 7714.00 7779.00 '7915.00 8025.00 8137.00 6512.70 6454.70 6537.58 6479.58 6591.50 6533.50 6704.68 6646.48 6796.48 6738.4B 6890.26 6832.26 FINAL WELL LOCATION AT TO: TRUE MEASURED VERTICAL DEPTH DEPTH SUB-SEA VERTICAL DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 8137.00 6890.26 6832.26 3892.64 S 40 7 E FNL,2035 FW REC NO OF SURVEY:' ELEVATION: ENGINEER: PAGE 05-JUN-88 58.00 FT MCBRIDE SURF L,SE TANG RTH/ 795. 807. 833. 887. 931. 975. ACE LOCATION AT C 22,Tt3N,RgE,UM ULAR COORDINATES SOUTH EAST/WEST 42 S 2335.59 E 47 S 2347.23 E 52 S 2372.5! E 83 S 2625.26 E 47 S 2466.85 E 96 S 25'08.94 E SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA, INC. 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L.L.L..i~i~ .... i....i..~i.L i ..ii i ~ i . i i i ii'"'i t i i i L ~l~O0g~ ~ ~ ~i ~ ~ ~ i i i ! i i~[i i i i!~,ii ~ t i NORTH ,.. PROJECTION ON VERTICAL PLANE NORTH - SOUTH SCALED IN VERTICAL DEPTHS HORIZ SCALE = I/1000 IN/FT HORIZONTAL PROJECTION (1062'FNL, 2035'FWL, SEC 22, T13E, R9E, UM) NO~?H 1000 REF 728 ] 6 SCALE: = i/S00 IN/FT ~00 - l DO0 - I SOO -~000 -~00 80UTH -~3000 -~00 WEST SO0 ! 000 ! SO0 2000 2S00 ~000 ~SO0 EAST STATE OF ALASKA ALA,~-,A OIL AND GAS CONSERVATION COMM~o,.~ION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown __ Stimulate __ Plugging Perforate _ Pull tubing Alter casing Repair well Pull tubing Other X 2. Name of Operator 5. Type of Well:(:::::~ 6. Datum elevation (DF or KB) Development ARCO Alaska, Inc. Exploratory _ RKB ~)' feet 3. Address Stratigraphic ,~ 7. Unit or Property name P. O. BOX 100360, Anchorage, AK 99510 Service~ Kuparuk River Unit 4. Location of well at surface 8. Well number 1062' FNL, 2035' FWL, Sec.22, T13N, R9E, UM 30-14 At top of productive interval 9. Permit number/Approval number 1423' FSL, 909' FEL, Sec. 22, T13N, R9E, UM 88-39/90-01 1 At effective depth 10. APl number 1287' FSL, 778' FEL, Sec.22, T13N, R9E, UM 50-029-21~02 At total depth 11. Field/Pool Kuparuk River Field 1242' FSL, 736' FEL, Sec. 22, T13N, R9E, UM Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 8137' feet Plugs (measured) true vertical 6 8 9 0' feet None Effective depth: measured 8025' feet Junk (measured) true vertical 6 7 9 6' feet None Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 1 6" 175 SX AS I 11 0'MD 110'TVD Surface 2331' 9 5/8" 900 sx AS III & 2364'MD 2225'TVD 300 sx Class G Top job w/100 sx AS I Production 8047' 7" 550 SX TLW & 8107'MD 6864'TVD Liner 200 SX Class G Perforation depth: measured 7858'-7878', 781 4-7834', 7792-7806' true vertical RECEIVED Tubing (size, grade, and measured depth 2 7/8" J-55 tbg w/tail @ 7646' Packers and SSSV (type and measured depth) HB pkr @ 7572' & 'FVLD' SSSV @ 1788' ~,Dj~ 13. Stimulation or cement squeeze summary 4taska Oil &~,,,,._. Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (producing) 896 823 0 1 207 1 47 Subsequent to operation (injecting) - 670 0 6 5 0 2500 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Water Injector ~ Daily Report of Well Operations X Oil m Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'"~1~)'~'' ~ Title ~)~~ O~~ ~/~l~ate Form 10-404 Rev 05/17/89 SUBMIT IN DUPLICATE ALASKA OIL AND GAS CONSERVATION COHHISSION MECHANICAL INTEGRITY TEST PR~:TEST START 15 MIN 30 MIN .... *P *1 TYPE OF PKR CASING TBG REO TBG TIME TIME TIME WELL *S - ANNULUS TVD S I ZE/WT/GRADE S I ZE TEST CSG TBG TBG TBG START T IHE & COHMENTS NAHE '14 *N FLU I D MD PRESS PRESS CSG CSG CSG PRESS PRESS PRESS ......... . ,i , ............. . ,, , Ill ............ I ...... I ..l I ....... ..... ........ Il .... ,, : . ...... I ..... ~ I.I .... I ' *TUBING INJECTION FLUID: P = PRODUCE WATER INJ S = SALT MATER INJ N = HISCIBLE INJECTION I = INJECTING N = NOT INJECTING D.EWS.06 rev 0311. J ANNULAR FLUID: DIESEL GLYCOL SALT WATER DRILLING MUD OTHER OTHER GRAD I ENT; AOGCC Wl /' ' 'N _ - ~" . COMPANY REP SIGNATURE ~ ~ ~(0~'~-~'--''~ .~/'5-"/~'¥/' 20 AAC 25.O30(a) ' AAC 25.~12(c) AAC 25.252(d) STATE OF ALASKA ALASKA OILAND GAS CONSERVATION COMMI, dlON n APPLICATION FOR SUNDRY APPROVALS" 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program_ Operation Shutdown _ Re-enter suspended well_ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other X 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1062' FNL, 2035' FWL, Sec.22, T13N, R9E, UM At top of productive interval 6. Datum elevation (DF or KB) RKB 58' 7. Unit or Property name Kuparuk River Unit 8. Well number 30-14 9. Permit number feet 1423' FSL, 909' FEL, Sec. 22, T13N, R9E, UM At effective depth 1287' FSL, 778' FEL, Sec.22, T13N, R9E, UM At total depth 1242' FSL, 736' FEL, Sec. 22, T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 8137' feet Plugs (measured) 6890' feet None lO. APl number 5o-029-21 802 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth' measured true vertical 8025' feet Junk (measured) 6 7 9 6' feet None Casing Length Size Cemented Measured depth True vertical depth Conductor Surface 80' 2331' 8O47' Production Liner Perforation depth: measured 7858'-7878', true vertical 6657'-6674', Tubing (size, grade, and measured depth 2 7/8" J-55 tbg w/tail @ 7646' Packers and SSSV (type and measured depth) 16" 9 5/8" 7" 175 sx AS I 110'MD 900 sx AS III & 2364'MD 300 sx AS II Top job w/100 sx AS I 550 sx TWL & 8107'MD 200 sx Class G 7814'-7834', 6620'-6637', HB pkr @ 7572' & FVLD' SSSV @ 1788' 110'TVD 2225'TVD 6864'TVD 6603'-6614' 13. Attachments Description summary of proposal _ Convert well from oil producer to water iniector. Detailed operation program_ BOP sketch 14. Estimated date for commencing operation December 20, 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas __ Suspended Service Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,,~.¢~ ~,~~z..~C".,_~,.f./-~?P F~RCOMMi~SiO~ U~SEON'LY'' -'~2 Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP. Test_ Mechanical Integrity Test~ Approved by the order of the Commission Form 10-403 Rev 5/03/89 Location clearance Subsequent form require ORIGINAL SIGNED BY LONN1E C. SMITH SUBMIT IN TRIPLICATE Attachment to Application for Sundry Approval Kuparuk River Unit Wells 30-6,14,16a Conversion to Water Injection Service Wells 30-6, 14, and 16a are currently oil producers, as listed on the Application for Sundry Approval. This Application for Sundry Approval is to convert these three wells to water injection service. A Wireline BOPE will be used during the portions of the conversion procedure which require wireline work. Expected static bottom-hole pressures for each well are listed below. No workover fluid will be used during the conversion procedure. MIT's, as required by the State, will be performed on these wells prior to conversion, and the MIT form will be forwarded to the State upon completion. WELL Expected SBHP 30-14 2000 psi 30-16a 2000 psi 30-6 2000 psi 2 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANOE 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) 5. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF W ] REL ! NE BOP EQU ! PMENT ARCO Alaska, Inc. Date: April 24, 1989 Transmittal #: 7462 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 O- 1 8 Sub-Surface Pressure Survey 2 - 1 1 - 8 9 # 6 4 61 3 3 O- 08 Bottom Hole Pressure Surveyq 2 - 2 6 - 8 9 # 9 6 2 6 3 6 30-05 Sub-Surface Pressure Survey 2-1 6-89 #29855 3 O- 14 Sub-Surfece Pressure Survey 1 - 2 3 - 8 9 # 7 2 6 5 5 3 O- 1 8 Kuparuk Well Pressure Report 2 - 1 I - 8 9 Sand 'A' 3 O- 14 Kuparuk Well Pressure Report 1 - 2 3 - 8 9 Sand 'A' 30-08 Kuparuk Well Pressure Report 2-23-89 Sand'A' 30-1 7 Kuparuk Well Pressure Report 3 - 0 4 - 8 9 Sand °A' Receipt Acknowledged: DISTRIBUTION; D&M State of Alaska SAPC Mobil Chevron Unocal ARCO Alaska, Inc. Date: February 17, 1989 Transmittal #: 7429 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3F-11 3H-12 30-07 3F-10 3F-06 3F-02 3F-16 3F-16 3F-11 3Fo04 3F-05 3F-13 3N-10 3N-10 3N-04 3N-09 30-14 30-14 3M-18 3F-16 3F-13 3F-13 3F-13 3F-13 3F-08 3F-16 3F-16 3F-13 3F-16 3F-16 3F-16 3F-14 Sub-Surface Pressure Survey Kuparuk Well Pressure Report Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuapruk Ku )aruk Ku~aruk Ku3aruk Ku~aruk Ku3aruk Ku~aruk Ku~aruk Ku~aruk Ku ~aruk Ku~aruk Ku ~aruk Ku~aruk Ku~aruk Ku ~aruk Kul~aruk Kuparuk 10-06-88 8-29-88 Well Pressure Report I 2- 20 - 88 Well Pressure Report 8 - 29 - 87 Well Pressure Report 8 - 29 o 87 Well Pressure Report 8 - 29 - 89 Well Pressure Report 8 - 1 7- 87 Well Pressure Report 8 - 1 7- 87 Well Pressure Report 8 - 29 - 87 Well Pressure Report 6 - 26 o 87 Well Pressure Report 1 2- 1 2- 88 Well Pressure Report . I 2- 31 - 88 Well Pressure Report 6- 1 I - 87 Well PresSure Report 6 - 11 - 87 Well Pressure Report 9 - 01 - 87 Fluid Level Report 5 - 04 - 87 Fluid Level Report 2 - 13 - 89 Fluid Level Report 2- 1 0 - 89 Fluid Level Report 2 - 1 0 - 89 Fluid Level Report 6 - 05 - 87 Fluid Level Report 6 - 09 - 87 Fluid Level Report 6 - 1 8 - 87 Fluid Level Report 6 - 1 6 - 87 Fluid Level Report 6 - 21 o 87 Fluid Level Report 5 - 08 - 87 Fluid Level Report 8 - 1 8 - 87 Fluid Level Report 8 - 24 - 87 Fluid Level Report 6 - 05 - 87 Fluid Level Report 6 - 2 / 3 - 87 Fluid Level Report 8 - 5 - 8 7 Fluid Level Report 6 - 5 o 8 7 Fluid Level Report 9 - 8 - 8 7 #7-889 Amerada Sand 'A' Amerada Amerada Amerada Sand 'A' Sand 'A' Amerada Sand 'A' Both Sands Both Sands Sand 'A' Casing Casing Casing Casing Tubing Casing Casing Commissio,.] Casing Anchorage Tubing Casing Casing 3F-14 3F-06 3F-14 3F-08 3F-14 3F-09 3F-05 3F-09 3F-06 3F-05 3N-10 3N-10 3N-11 3N-10 3N-05 3N-04 3N-13 3N-11 3N-18 3N-17 3N-07 3N-15 3N-05 3N-09 3N-04 3N-14 3N-08 3N-06 3N-02 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-07 3N-01 3N-04 3N-04 3N-09 3N-10 Receipt Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Acknowledged: Level Report Level Report Level Report Level Report Level Report Level Report Level Report Leyel Report Level Re ~ort Level Re ~ort Level Re ~ort Level Re ~ort Level Re ~ort Level Re ~ort Level Re ~ort Level Re ~ort Level Re ~ort Level Re ~ort Level Re ~ort Level Re ~ort Level Re.~ort Level Re ~ort Level Re ~ort Level Re ~ort Level Re ~ort Level Re ~ort Level Re ~ort Level Re ~ort Level Re ~ort Level Re ~ort Level Re ~ort Level Re aort Level Report Level Re ~ort Level Re ~ort Level Re ~ort Level Re ~ort Level Re ~ort Level Re aort Level Re 3ort Level Re ~ort Level Reaort 9-11-87 12-06-86 9-11-87 10-11-87 9-16-87 4-11-88 4-08-88 4-01 -88 3-26-88 1 -30-88 10-12-87 10-15-87 10-28-87 10-28-87 10-28-87 10-28-87 3-19-87 9-12-87 9-10-98 9-10-87 9-10-87 9-12-87 9-08-87 9-01 -87 9-01 -87 9-06-87 9-06-87 9-06-87 9-06-87 6-01 -87 5-31 -87 6-03-87 6-06-87 .6-08-87 6-09-87 6-25-87 4-17-87 4-18-87 6-17-87 6-20-87 5-07-87 8-24-87 ........................... Date: Casing Tubing Casing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing ~, ~ Alaska Oil & G~s Con,:. ....... ~rr~C~orage DISTRIBUTION: D&M State of Alaska ~ Mobil Chevron Unocal SAPC ARCO Alaska, Inc. Date: February 9, 1989 Transmittal Ct: 7422 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 B - 1 3 Kuparuk Fluid Level Report 2 - 0 6 - 8 9 Casing 2 W - 0 1 Kuparuk Fluid Level Report 2 - 0 2 - 8 9 Casing 2 X - 1 4 Kuparuk Fluid Level Report 2 - 0 2 - 8 9 Casing 3 F- 1 5 Kuparuk Fluid Level Report 2 - 0 2 - 8 9 Tubing 3 A-0 1 Kuparuk Fluid Level Report 2 - 0 2 - 8 9 Tubing 2 G- 0 6 Kuparuk Fluid Level Report I - 3 1 - 8 9 Tubing 3 O- 1 4 Kuparuk Well Pressure Report I 0- 2 5 - 8 9 Amerada Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION: D&M state of Alaska Chevron Mobil Unocal SAPC STATE OF ALASKA ~ ALAS,,,~ OIL AND GAS CONSERVATION COM;...3SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing Alter Casing [] Other [~ COMPLETE 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 58' Feet 3. Address 6. Unit or Property name P.0o Box 100360, Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 1062' FNL, 2035' FWL, 5ec.22, T13N, RgE, UN At top of productive interval 1423' FSL, 909' FEL, Sec.22, T13N, R9E, UN At effective depth 1287' FSL, 778' FEL, Sec.22, T13N, RgE, UN At total depth 1242' FSL, 736' FEL, 5ec.22, T13N, R9E, UN 7. Well number 30-14 8. Approval number 8-485 9. APl number 50--029-21802 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 2331' Producti on 8047 ' Perforation depth: measured 8137 ' MD 6890 ' TVD 8025'MD 6796'TVD Size 1 6" 9-5/8" 7" 7858'-7878'MD feet feet feet feet Plugs (measured) None Junk (measured) None Cemented Measured depth 175 sx AS I 900 sx AS III & 300 sx AS II Top job w/lO0 sx AS I 550 sx TLW & 200 sx Class G llO'MD 2364'MD 8107'MD ~ue Vertical depth 110'TVD 2225'TVD 6864'TVD true vertical 6657'-6674'TVD 12. Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail ~ 7646' Packers and SSSV (type and measured depth) HB pkr ~ 7572' & FVLD SSSV ~ 1788' Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Compl. Well H~.~story w/Addendum, dated 6/15/88 Daily Report of Well Operations ~ Copies of Logs)and Surveys Run [~ Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~,j~/,..~ Form 10-404 Rev. 12-1- Title Associate Engineer Date (Dani) 5W03/016 Submit in Duplicate ,, ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ARCO ALASKA INC. Field KUPARUK RIVER FIELD Auth. or W.O. no. AK3064 Operator ARCO ICounty or Parish NORTH SLOPE Lease or Unit Title ADL: 25513 COMPLETE AND PERFORATE IAccounting cost center code St at~%K 30-14 Jwe, no. Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. 06/25/88 ( TD: 8137 PB: 8025 SUPV:DL/KR 06/26/88 ( 1 TD: 8137 PB: 8025 SUPV:DL/KR API: 50-029-21802 IA.R.Co. W.i., ,~°tal number of wells (active or inactive) on this] Jcost center prior to plugging and 56 0000 Jabandonment of this well Hour Prior status if a W.O. 06/24/88 ! 1645 HRS Complete record for each day reported NORDIC 1 SHEARED PBR 7"@ 8107' MW:10.0 NACL/NABR MOVED RIG FROM 30-15 TO 30-14. ACCEPTED RIG @ 1645 HRS, 6/24/88. ND TREE. NU BOPE & TESTED TO 3000 PSI. PERFORATED 'A' SAND F/7858'-7878' WITH 8 SPF, 45 DEGREE PHASING. RIH WITH 2-7/8" COMPLETION ASSY. DAILY:S47,275 CUM:$896,788 ETD:S896,788 EFC:$1,295,000 RELEASED RIG 7"@ 8107' MW: 6.9 DIESEL SHEARED PBR. TESTED ANNULUS TO 2500 PSI. TESTED SSSV TO 1500 PSI. ND BOPE. NU TREE AND TESTED TO 5000 PSI. DISPLACED WELL WITH DIESEL. SET BPV. SECURED WELL AND RELEASE RIG @ 1030 HRS, 6/25/88. (TAIL @ 7646', 'FVLD' SSSV @ 1788', 'HB' PKR @ 7572') DAILY:S100,039 CUM:$996,827 ETD:S996,827 EFC:$1,295,000 Released rig Date ind of rig Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) I Producing method ~Official reservoir name(s) I Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and (iltribution, see Procedures Manual, S~)f:tion 10, Drilling, Pages 86 and 87. JDate JTitle '1-1o- ASSOCIATE ENGINEER ADDENDUM WELL: 6/06/88 30-14 RU SOS. Rn CET f/8000'-2300'. Rn 6-1/8" GR. Rn GCT f/7970'-50'. RD Schl. Dril~g Supe~or STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM,OSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown ~ Re-enter suspended well [] Alter casing [] Time extension [] Change approved program ~ Plugging [] Stimulate_~ Pull tubing [] Amend order r~_ Perforate ~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360. Anchoraoe. AK 99510-036~ _ 4. Location of well at surface 1062' FNL, 2036' FWL, Sec. 22, T13N, RgE, UN 5. Datum elevation (DF or KB) RKB 59 ' 6. Unit or Property name K,,.nar,Jk River Ilnit 7. VVell number 30-14 feet At top of productive interval 1320' FSL, 792' FEL, Sec. 22, T13N, R9E, UM (approx) At effective depth 1320' FSL, 747' FEL, Sec. 22, T13N, RgE, UM (approx) At total depth 1276' FSL, 705' FEL, Sec. 22, T13N, RgE, UM (approx) 8. Permit number 88-39 9. APl number 50-- 029-21802 10. Pool Kuparuk River 0ii Pool 11. Present well condition summary Total depth' measured true vertical Effective depth: measured true vertical Casing Length 8137 'MD feet 6898 ' TVD feet 8025'MD 6805'TVD Size feet feet Plugs (measured) None Junk (measured) None Cemented Measured depth True Vertical depth Conductor 80 ' Surface 2331 ' 16" 175 sx AS I 1lO'MD 110'TVD 9-5/8" 900 sx AS III & 2364'MD 2229'TVD 300 sx AS II Top job w/lO0 sx AS I 7" 550 sx TLW & 8107'MD 6873'TVD 200 sx Class G Production 8047' Perforation depth: measured NONE true vertical NONE Tubing (size, grade and measured depth) NONE Packers and SSSV (type and measured depth) NONE RECEIVED JUN 2 2 1988 Alaska 0il & Gas Cons. Commission Anchorage 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch Well Hi story 13. Estimated date for commencing operation June, 1988 14. If proposal was verbally approved ~u])~equ~.m[,~,,~ ~:/~ '~ ~..-3~ .'~V°~-~]~e~°r[er']' o,'1 ,..~/ Name of approver ~'orm No.~.-L~D~edJ_//':__4/~z9 Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ ~ Title Associate Engineer ~ Commission Use Only (Dani SA3/106) Date Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Approved Copy Returned Commissioner Approval No. by order of - the commission Form 10-403 Rev 12-1-85 Submit in triplicate ARCO ,.,Il and Gas Company Well History - Initial Report - Daily In-tructiona: Prepare and submit the "initial Report" On Ihs first Wednesday after a well is spudded or workover operations are atarled. Daily work prior to Spudding should be summarized on the form giving inclusive dates only. District ]County. parishorbgh .... ]State ARCO Alaska, Inc. J NORTH SLOPE Field ILeass or Unit KUPARUK RIVER FIELD J ADL: 25513 30-14 Auth. or W.O, no. ~Title AK3064 ~ DRILL API: 50-029-21802 no. Operator IARCO W I ARCO I 56.0000 Spudded or W.O. begUnsPUD ]Date 05/07/88 IH°ur 1830 HRS JPrlorstatusifsW,O. Date and depth as ol 8:00 a.m. o5/o8/88 ( TD: 1350'( SUPV:RB/SB 05/09/88 ( TD: 2385'( 1 SUPV:RB/SB 05/10/88 ( TD: 3493'( SUPV:RB/SB 05/11/88 ( 4 TD: 6293'( 2~ SUPV:RB/SB 05/12/88 ( TD: 7450'( 1 SUPV:JS 05/13/88 ( TD: 8066'( SUPV:JS 05/14/88 ( TD: 8137'( SUPV:JS Complete record for each day reposed DOYON 14 5O) DRILLING 16"@ 110' MW: 9.1 VIS: 73 MIRU. ACCEPT RIG @ 1330 HRS 5/07/88. SPUDDED @ 1830 HRS 5/07/88. NAVIDRILL 12-1/4" HOLE TO 1350'. DAILY:S55,350 CUM:$55,350 ETD:S55,350 EFC:$1,295,000 ) FINISHING TOP JOB 9-5/8"@ 2364' MW: 9.0 VIS: 63 35) NAVIDRILL 12 1/4" HOLE TO 2385'. RUN 59 JTS OF 36# J55 BTC 9 5/8" CASING. FC @ 2283', FS @ 2364'. CEMENTED CASING WITH 900 SX ASIII 12.1 PPG LEAD, FOLLOWED BY 300 SX ASII 15.2 PPG TAIL. CIP @ 0330 HRS 5/09/88. PERFORM TOP JOB WITH 100 SX AS I 15.7 PPG SLURRY. FULL CEMENT RETURNS. DAILY:S178,187 CUM:$233,537 ETD:S233,537 EFC:$1,295,000 ) DRILLING 9-5/8"@ 2364' MW: 8.7 VIS: 31 08) NU BOPE AND TEST SAME. RIH. TAG FC @ 2280'. TEST CASING TO 2000 PSI. DRILL TO 2395'. PERFORM LOT. TURBODRILL 8-1/2" HOLE TO 3493'. DAILY:S60,190 CUM:$293,727 ETD:S293,727 EFC:$1,295,000 ) DRILLING 9-5/8"@ 2364' MW: 9.5 VIS: 38 00) TURBODRILL 8-1/2" HOLE TO 6293'. DAILY:S42,381 CUM:$336,108 ETD:S336,108 EFC:$1,295,000 ) DRILLING 9-5/8"@ 2364' MW: 9.9 VIS: 39 57) TURBODRILL 8-1/2" HOLE TO 7148'. TRIP FOR BIT. TURBODRILL 8-1/2" HOLE TO 7450' . DAILY:S60,476 CUM:$396,584 ETD:S396,584 EFC:$1,295,000 POOH LD BHA 9-5/8"@ 2364' MW:10.0 VIS: 44 .6) TURBODRILL 8-1/2" HOLE TO 8066'. CBU. DROP SURVEY. PUMP PILL. POOH 10 STDS. PUMP DRY JOB. POOH LD BHA. DAILY:S49,723 CUM:$446,307 ETD:S446,307 EFC:$1,295,000 ) RUNNING 7" CASING 9-5/8"@ 2364' MW:10.0 VIS: 42 71) RU SCHLUMBERGER TO LOG 8-1/2" OPEN HOLE. RAN OPEN HOLE LOGS. RD SCHLUMBERGER AND CLEARED FLOOR. MU BHA #5 W/NEW BIT. RIH TO SHOE ON 5" DP. CUT DRLG LINE. RIH TO 8066', FILL PIPE @ 6100' DRILLED F/8066'-8137'. CIRCULATE HOLE CLEAN. MIXED AND SPOTTED MUD/DIESEL PILL. POOH 10 STDS. PUMPED PILL. POOH LDDP. LD BHA #5. PULLED WEAR RING. RU FLOOR. BEGIN RUNNING 7" CASING. DAILY:S167,852 CUM:$614,159 ETD:S614,159 EFC:$1,295,000 The above is correct Signature For form prepar, l~on and ~istribution, see Procedures~¥anual, Section 10, Drilling, Pages ~6 and 87. J Date~_~ I Title - 7-E~ ASSOCIATE ENGINEER RECEIVED AR3B-459-1-D JUN 2 2 ]988 Alaska 0ii & Gas Cons. Commission Anchorage JNumber all daily well history forms consecutively as they are prepared for each well. Page no. ARC~. ,.)il and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovera when an official test Is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District I County or Parish I State ARCO Alaska, Inc. I NORTH ST,OPE J AK Field ILease or Unil KUPARUK RIVER FIELD ~ ADL: 25513 Auth. or W.O. no. ITitle AK3064 I DRILL Accounting cost center code API: 50-029-21802 30-14 JweH no. Operator ARCO Spudded or W.O. begun SPUD A.R.Co, W.I. 56.0000 Date Iotal number of wells (active or inactive) on this DSt center prior to plugging and bandonment of this well our IPrior status if a W.O. 1830 HRS I 05/07/88 Date and depth as of 8:00 a.m. o5/15/88 ( TD: 8137'( SUPV:JS Complete record for each day reported DOYON 14 RELEASED RIG 7"@ 8107' MW: 9.9 VIS: 40 CONTINUED RUNNING 7" CASING. CIRCULATE AND CONDITION HOLE. CEMENTED CASING WITH 550 SX TLW & 200 SX CLASS G. CIP @ 1625 HRS, 5/14/88. BUMPED PLUG. (7" SHOE @ 8107'). SET SLIPS. CUT 7", SET STACK BACK. INSTALLED PACKOFF. NU TUBING HEAD & TESTED TO 3000 PSI - OK. INJECTED 6 BBLS OF DIESEL DOWN THE ANNULUS. SECURED WELL AND RELEASED RIG @ 2300 HRS, 5/14/88. DAILY:S235,354 CUM:$849,513 ETD:S849,513 EFC:$1,295,000 Old TD Released rig JNew TD PB Deplh Date IK nd of rig Classifications (oil. gas, etc.) Producing method Potential test data JType completion (single, dual, etc.) Official reservoir name(s) Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected For form preparation ~ distribution, see Procedures Manu~ll/Section 10, Drilling, Pages 86 and-'87. ASSOCIATE ENGINEER RECEIVED Number all dally well history forms consecutively as they are prepared for each well. iPage no. AR3B-459-3-C JUN 2 2 ]988 DlvlalonofAtlantlcRk:hfleldCompany Alaska 0ii & Gas Cons. Commission Anchorage ' '.~' :' ".: "'." '-~' .'.~ ..... ;* ' f;':;' ~. "" :."!"',"- '~,":'~' : ""'--'.~ '; ~' .';'. '.: .....:...~1..:..~ ~..: ..,....?-,:. ,:..~.. :,~:....;...~,~. ,:. ";r"" ':." ~ "?:'".~'; ' :"'"' :"f'-' ,' '"" ' ~ ';":' ~ ' ' :" "~'" ".J '-'~:.:~-:._~":.:~.',., J__ i;, ~,1 ,.; :~_".i.:( ;~.: ~" ARCO Alaska, Inc. Date: June 17, 1988 Transmittal #: 7193 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. Please acknowledge receipt and return 3 O- 13 Cement bond Log (CBT) 6 - 6 - 8 8 6490 - 7818 3 O- 15 Cement Evaluation Log (CET) 6 - 5 - 8 8 2695 - 9324 ,-~30-14 Cement Evaluation Log (CET) 6 - 5 - 8 8 2295 - 8006 If you have any questions, concerning this or any other transmittals please call me at 265-6835. Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION: NSK Drilling il. '"',,'i. State of Alaska(+sepia) 3 ARCO Alaska, Inc. Date: May 26, 1988 TranSmittal #: 7165 RETURN TO: ARCO Alaska, Inc. Attn: Sabrina A. McKnuckles Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. "-"'30-16A 5" Dual Induction 4-27-88 4600-8337 a~,3 O- 16A Cyberlook 4 - 27 - 88 7500 - 8200 "~O-16A 2" Dual Induction 4-27-88 4600-8337 ~'30-16A 2" & 5" Porsity FDC 4-27-88 7450-8311  O-16A 2" & 5" Raw FDC 4-27-88 7450-8311 O- 15 5" Dual Induction 5 - 05 - 8 8 2773 - 9291 ~ O- 15 2" Dual Induction 5 - 05 - 88 2773 - 9291 ,~'"'"-,30-15 2" & 5" Porosity FDC 5-05-88 2773-9265' ~"'~30-15 2" & 5" Raw FDC 5-05-88 2773-9265 ~30-15~ Cyberlook 5-05-88 8700-9291 "'~"~ 30-. 14,~ Cyberlook 5-13-88 7490-8000 · ,m~30 1 - 4~ 2" &5" Raw FDC 5-13-88 7490-8021 '~0-14' 2"&5" Porosity FDC 5-13-88 7490-8021 O- 14i' 2" Dual Induction 5 - 1 3 - 88 2364 - 8046 ~ 3 O- 144 5" Dual Induction 5 - 1 3 - 88 2364 - 8046 ~"'~30-13 2" Dual Induction 5-21 -88 4340-7945 ~30-13 5" Dual Induction 5-21-88 4340-7945 ~30-13 Cyberlook 5-21 -88 7300-7900 .., 30-13 2" & 5" Porosily FDC 5-21 -88 71 96-791 9 30 13 2" & 5" Raw FDC 5-21-88 7196-7919 If you have any questions, concerning this or any other transmittals please ca me a~_. j~. 0 265-6835. Alaska Oil & Gas Cons. Commis~ioll An0herage ARCO Alaska, Inc. Date: May 26, 1988 Transmittal Cf: 7162 RETURN TO: ARCO Alaska, Inc. Attn: Sabrina A. McKnuckles Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 30-1 6A Open Hole Tape and Listing 5 - 0 5 - 8 8 Cf 7 2 71 6 3 O- 1 5 Open Hole Tape and Listing 5 - 1 5 - 8 8 Cf 7 2 7 4 6 3 O, 1 4 Open Hole Tape and Listing 5 - 1 8 - 8 8 Cf 7 2 7 6 0 '~ 3 O- 1 3 Open Hole Tape and Listing 5 - 2 5 - 8 8 Cf 7 2 7 6 5 If you have any questions, concerning this or any other transmittals please call me at 265-6835. Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION: Lynn Goettinger Stale of Alaska 011 & Gas Cons. Commissi0D Anohorage April 2.6, 1988 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re. Kuparuk River Unit 30-14 ARCO Alaska, Inc. Permit No. 88-39 Sur. Loc. 106-2'FNL, 2036'FWL, Sec. 22, T13N, R9E, Btmhole Loc. l195'FSL, 686'FEL, Sec. 22, T13N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling fie!d work, please notify this office 24 hours prior to .commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may ~witness testing before drilling below the shoe of the conductor pipe. V~ truly ~y~urs, C ~. Ch~rton" Chairman of Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COPRMISSION dlf .Enclosure cc: Department of Fish & Game, Habitant Section w/o encl. · Department of Environmental Conservation w/o encl. ~"- STATE OF ALASKA '-' , - ALASKA OIL AND GAS CONSERVATION L _.MMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~ Redrill IqI lb. Type of well. Exploratory [] Stratigraphic Test Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc RKB 59' PAD 24' feet Kuparuk River Field · , Kuparuk River Oil Poe 3. Address 6. Property Designation P.O. Box 100360, Anchorage, AK 99510-0360 ADL 25513 ALK 2554 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1062'FNL, 2036'FWL, 5ec.22, T13N, RgE, UM Kuparuk River Unit Statewide At top of productive interval (~ target) 8. Well nu.mber Number 1320'FSL, 792'FEL, 5ec.22, T13N, RgE, UN 30-14 #8088-26-27 At total depth 9. Approximate spud date Amount 1195'FSL, 686'FEL, 5ec.22, T13N, R9E, UM 05/02/88 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 1581P:[<~BoNsDed depth(MD and TVD) property line 30-15 686'~ TD feet 25' L~ surface feet 2560 (6830'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 1 052 feet Maximum hole angle 380 Maximum surface ].]./4-0 psig At total depth (TVD) 3].60 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5¢ H-40 Weld 80' 35' 35' 115' 115' +200 cf 12-1/4 9-5/8 ' 36.0~ J-55 BTC 2273' 35' 35' 2308' 2219' 900 sx AS II I & HF-EtW 300 sx AS I I 8-1/2" 7" 26.0~ J-55 BTC 8102' 34' 34' 8136' 6832' ~.,00 sx TLW lead & HF-E~W /200 sx Class G tail 19. To be completed for Redrill, Re-entry, and Deepen Operations. // TUC 500' above UGNU Present well condition summary ¢f~./',,~(~.,¢W,/ 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 Structural Conductor ~;., i ~'~' v Surface Intermediate : '; .... Production Perforation depth: measured true vertical 20. Attachments Filing fee [~, Property plat [] BOP Sketch [] Diverter Sketch 1~ Drilling program Drilling fluid program t~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby c/e/~,, that,/~.d¢~¢the for.e.~ y/~ true .and correct to the best of my knowledge Signed ~/x;~,/~f~¢f~" Title Regional Drilling Engineer Bat · - // ~ "' / Commission Use Only,~...~ ,T~,, / Permit Nut'bar J APl number I Approval date ...... I ~;(~e- 66v-er letter f¢8- 3~ 50-o~¢- z~.e¢~ 04/26/88 for other requirements Conditions of approval Samples required [] Yes ~ No Mud log required ~ Yes [] No Hydrogen sulfide measures [] Yes 1~ No Directional survey required ~ Yes [] No Required work~~~[] 5M; [] 10M; E~ 15M ~,~ Other: by order of Approved by ~,..// , Commissioner the commission Date Form 10-401 Rev. 12-1-85 triplicate ; . ..... :__' .~_.~ TVD ~2219 :THO 2308 DEP 398 · ......... . ~ ~ N~T/-uO"u'sN~s TVD.2?09 THD-292r DEp-rr? : ~ : · <m ...... aooo._ ~ ........... ~ SAK SNDS :TVD-3479 THD-3899 DEP-13Z1 ~7 DEG 40 MI N~ ......... ............. -5 TVD-5839 TMD-6881 DEP-3193 ......... 600~ ~ X T/ ZO"~ D fVD"64~4 THD"?6~ DEP"~65~ : ~ ; ~ T/ ZONE C TVD'~521 THD'~T43 DEP'~720 .......................... ~ ..................... '. -- T~ ZONE A TVD 6565 TMD 7798 DEP 3754 · ; ', ~ ', TARGET CHTR TVD-6620 THD-7868 DEP-37~ ~ ~ B/ KUP SNDS TVD-6674 THD-7936 DEP-~8 ........... ~OOQ-.. 0 ~ooo 2000 ..... i .............. i ............ ! VERTICAL SECT!ON 3000 4000 TD (LOG PT) ._. TVD-6832 THD-8 36 DEP-3960 '' i -- lid-30, ~e!l Nol 14 PropoIidl ...... Kuperuk Pleld, North Slope, Alaeke .................................. 30O& ................ gEST~EAST .- 0 1 000 . 2000 3000 I I ,, I I :TARGETDEp.~Ti, iD.?~TVi).GG20C~4TER ~~ G~UTH ~ EAST 245;1 TARGET LOOATIOM*- 13~0' FI~. ?g~* FEI. TD LGCAT[ON' SEC. 22. T13N. S 40 DEl; 14 M IN E 3796' (!TO TARGET) i _. 950 _ 100( _ 105( ! I I i I ', : 1 8.501 ~1 900. 1 950 2000 2050 21 O0 2150 KUPARUK RIVER UNIT 20' D IVERTER SCHEHATIC I I I 4 DESCRIPTION 1. 16' C~TOR 2. FI'lC SLIP-ON WELD STARTII~ HEAD 3. Fl'lC OlVERTER A$S~"IBLY WITH ~ 2-I/16' 20OO PSI BALL VALVES 4. 20' 2000 PSi DR&LINe SPOa. WI10' QrrLETS 5. I0' HCR BALL VALVES W/lO' DIVERTER LINF.~. A SINeLE VALVE OPEN~ AUTOHATICALLY CLOSU~ OF ANNiJ. AR PgLeVEN1~. VALVES CAN ReqOTELY CONTROLLED DIVER$1~. 6. 20' 2000 PSI ~ ~ , - ARCO ALASKA. I1~.. REOUESTS APPROVAL OF THIS OlVERTER SYSTEM AS A VARIANCE FROH 20AAC2$.03$(b) r'IAINTENANCE & OPERATION 2 UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER ANO BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOU~. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE OOWNWIN0 DIVERSION. DO NOT ,SHUT IN WELL UNDER ANY CIRCUHST/~.NCE5 , 1 7 i, 6 ! > > DIAGRAM #1 1~-5/8" 5000 PSI RSRRA BOP STACK ~. II" - ~0 PSI X 13-5/8' - ,5000 PSI SPACER SPO0. 4. 1~-5/8' - ~ ~I PI~ ~ ~ 1~5/8" - ~ ~Z ~ZLLI~ ~ ~~E ~ K~LL L]~S ~ 1~5/8" - ~ ~1 ~E ~ ~[~ ~ ~ T~, 7. 1~5/8~ - ~ ~I ~~ i 8. 9. I0. II. ACCtJvUkATOR CAPACITY, TEST I. Q-ECK /~D FILL ACO.M.I.ATOR RESERVOIR TO PROI:~R LEVEL WITH HYDP. ALLIC FLUID. 2. ~ THAT ACCUM, JLAT~ PRESSLRE IS 3000 PSI WITH 1500 PSI DON~TEEAM CF THE REGLLATCR. 3. CDSERVE TIIvE.,. T~EN CLOSE ALL UNITS SIMJLTAI~CXJ~Y AN) RECORD ll-E TIME AJ~ ~ REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PLM3 OFF. 4. RECO~ ON NADC REPORT, THE ACCE. PT~ LOIAER LIMIT IS 45 SE~ CLOSING TII~ AI~ 1200 PSI EIEivlAI~ 1,3--5/8" ~ STA,CK TEST FILL BOP STACK AN) CI-12KE IvlN~FCL.D WITH ARCTIC DIESEL. C~CK THAT ~L L~ ~LY ~T~CTED. ~AT TEST ~ IN ~L~ ~TH ~I~ JT ~ ~ LI~ V~ ~~ TO ~ ST~. ~L O~R V~S ~ ~~ ~ TO ~ ~~ TO ~ED ~~ TO 0 ~I. ~N ~~ LZ~ V~ ~ T~ PI~ R~ ~ ~ VAL~ ~ KI~ ~ ~ LI~S. ~T TO ~I ~ ~ ~I ~ IN ~P 4. ~IE ~I~ ~L V~ LI~S, ~ ~S ~ A ~ ~I L~~~~I HI~, ~ST ~ IN ~P 4. ~ ~T ~ A F~L ~I~ ~ITI~ ~N T~ PI~ ~T ~T~ PI~ R~ TO ~ ~I ~ ~ PSI. ~N ~TT~ PI~ ~L ~ ~ ~E. ~ ~I~ ~I. ~N ~I~ ~ FLUIE ~T ~L V~ IN ~ILLI~ ~ITI~ 12. ~ST ~~I~ V~ ~Y, ~LLY C~ ~ILL PI~ ~ETY ~ ~I.  ~EST I~~TI~ ~ ~~ ~~ER ~ST .~ . . 510084001 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1 ) MIRU. 2) Install FMC diverter system. 3) Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. 4) Run and cement 9-5/8" casing. 5) Install and test BOPE. Test casing to 2000 psig. 6) Drill out cement and 10' new hole. Perform leak off test. 7) Drill 8-1/2" hole. to logging-point according to directional plan. 8) Run open hole logs. 9) Continue drilling 8-1/2" hole to provide 100' between PBTD and bottom of Kuparuk sands. 10) Run and cement 7" casing. Pressure test to 3500 psig. 11) Downsqueeze Arctic pack and cement in 7" x 9-5/8" annulus. 12) ND BOPE and install temporary Xmas tree. 13) Secure well and release rig. 14) Run cased hole logs. 15) Move in workover rig. NU BOPE. 16) PU 7" casing scraper and tubing, TIH to PBTD. Circulate hole with clean brine and TOH standing tubing back. 17) Perforate and run completion assembly, set and test pa.cker. 18) ND BOPE and install Xmas tree. 19) Change over to diesel. 20) Flow well to tanks. Shut in. 21) Secure well and release rig. 22) Fracture stimulate. SHALE SHAKERS MUD CLEANER CENTRIFUGE .TYPICAL MUD SYSTEM SCHEMATIC Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing tO. Weight Up 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators · Notes: 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 12.0 ppg EMW and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur 'before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. L~KS/ih l D: !<RU.,.'C I ./NU,,'DR ! LL I t'.lG .I ~**$ N.L WELLS lOCATED IN SEC. 22 T. l$ N., R. 9 F_, UMIAT MERIDIAN. TEL N0:907-265-6£18 ,.. VICINITY MAP SC,dd~ i · Z"IdIL, Y.S t, AIL ¢OOROINATES ARE A.$.P., ZONE 4. ~ ALL DISTANCES ~HOWN ARE TRUF.. $. ELEVATIONS ARE B.P.M.~.L. 4. REFER. FIELD BOOK I..-B8-~ 5. Ct[ ELEVATIONS FROM ~ED-RIXX-$365,~ 6, HORIZONTAl.. POSITION BASED ON ~ CON~L MONUMENTS ~ I-OUNSIllURY & We_!l_ Y ASP$ X LATITUDE. ~,~ LONGITUDE, F, NL .EWE Elev. El~v_ ~ 6,0Z Z,~5.27 5ZS,47O. Z7 ~Z8~']?,338" 1490 47'~0.897" ~4' 184~' IT, 6' 23.9' 6,022,073. ~ 525 ~490.94 70e~' 17.128" 149047'~0.5~'' 745' 1~55' 17. I[~l 149 47,29.8~. Y6~: 1879; 18.~ 6,ozz'o~o,~ 525,5t5.5e ~2s: ' " 5 6~022,~8. ~ 525,528.58 7~Z8, " 149o 47, 29.4~, 81 I, 1892, 18. 2~6, 1~2~, .149o47, ~,071, 832, 19~ 19. I, ? 6,021 ~965.~ 5~5,553.~ 8' !~9 14~47 28,6~. 09~; 1917, 10.2. 2~l 9 6~021 ,g2~. t2 5~ ,578.27 i5.632 149 47 27.974 897 1941 18.4 23.2 I0 6~021 t84~ 525 ~623.61 ~28' 14.~" 149~47'26..6~'' 975' 1986' 18.7' 11 6,021 ~822.~ 525,6~5.7l ~' 14.651" 149e 47'Z6;~95" ~7' 1998' 18.0' 23.5' ~ 6,ozi,e~.e7 525,648.~ 7~2e', /4. 437" .'149o47',~.9~ IOt~' 201l' te.8' t3 6,021 )779. 16 525,661 ,~ ~e~, 14.'Z23"' 149°47,25.~, 1041', ZOZ4', 18.9', 23.0, 14 6,0ZI ~7.~ 525,6~.~ ~o~, 14.010'~ *149047,~5,~,, t0~ ZOO, 19.0, ~.8, 15 6,021,735.76 $ZS~6.1Z ~o~ 13.~5 149°47 24.8~ 1084 2046, 19.0, 22.~; 16 6,0~ 1~?14. 15 525,6~. 17 ~e28' I~.~" 149047'~4.4~ I1~ 20~, 19. t 17 6,0~1,69~ 5Z5,7t0.85 ~' 13.36~" 149°47'Z4.0~ I 12~ 2073 19.0' t8 6,02 I ,670.97 525 ~TZ~.~ ~29' 13. 157" 149047'~3,733 1149' 2085' 19.0' 23.3' ..... ~ , ,,~,--- ,. .-- t HEaEiY CE~Tllrt THAT I Aid PROP[lILY REGISTERED AND L~ENSED TO TICE LAND SURVEYING tN THE STATE OIr ALASKA AND THAT TNI3 PI. AT REPRESENTS A .LOCATION SURVEY MADE BY ME OR UNDER. MY :~JPERVIStON, AND THAT ALI. DIMENSION3 ~ OTI. t[R OET,IdI.~ ARE CORRECT A8 ARCO Alaska lnc v D.S. 3.0 WELL coNDUCTOR -BUILT ............... ::" - ~A~ ~- ..... kOU 8 URY soci fes l~eSOR~$[ ................ CHECK LIST FOR NEW WELL PERMITS Company /~/~C<D Lease & Well No. ITEM APPROVE DATE YES NO (1) Fee ~ ~'/zl/J88 1. Is the permit fee attached .......................................... /'~ (2 thru 8) (8) (3) Admin ~ z~fpM]~) 9. (9 thru 13) - 10. ~. 4z-~;z-$~ 11. (10 and 13) 12. 13. (4) Casg (14 thru 22) (23 thru 28) (6) OTHER (29 thru 31) 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 and is wellbore plat included ................ ~ 7. Is operator the only affected party ................................. ~ 8. Can permit be approved before fifteen-day wait ...................... ~ 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ......................... ~ Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will'all casing give adequate safety in collapse, tension and burst.. Is this 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 the drilling fluid program schematic and list of equipment adequate zB¢ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~OOO psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. For exploratory and. Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones ............ 31. If an offshore loc., are survey results of seabed conditions presented/ ./ 32. Additional requirements ............................................ 0 Geo lo§7: En~ineerin~: rev: 02/17/88 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE z+ ~ o I oo ~ ~'~' -1 o / ~ 890 /( I6o o ,r,,./ Additional Remarks: 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. lo LIS TAPE VERIFICATION ~ISTING LVP OlO.H02 VERIFICATION LISTING PAGE ;EDIT ! 8 72760 b/' COMMENTS {EDIT biS,ARCO KUPARUK 30-14,API # 50-029-21802 HEADER ** :,EDIT 8 _CONTINUATION # ~01 P:REV'IOU8 TAPE i · O~.MENTS .EDIT LI~ARC(] KUPARUK ~ O-14~API ~ 50-029-2~802 ** FILE H~ADER ** S ,001 ~AX ENGTH : 1024 FI.L ~ P E I0 ~ R V US FIbE INFORMATION RECORDS MNE~ CONTENTS UNIT TYPE CATE SIZE CODE CN : ARCO A~/A/SKA, INC, 000 000 018 065 WN : 30-14 000 000 006 065 FN : KUPARUK 000 000 008 065 RANG{ 9E 000 000 002 065 TOWN: 13N 000 000 004 065 SECT{ 22 000 000 002 065 COUN{ NORTH SLOPE 000 000 0~2 065 STAT{ AbASKA 000 000 0 6 065 CTRY{ USA 000 000 004 065 MNEM CONTENTS iIII IIIIIIii PR~S: g UNIT TYPE CATE SIZE CODE IIII ~IIi IIiI IIII 000 000 001 065 bYP '010,H02 VgR1FICATION ~I$?ING PA:G~ 2 · ARCO ALASKA 3 0'14 21802 ANY ~ 72760 13-MAY-B8 ~l. JI D ~ATRIX SANDSTONE RMC RH AT BHT m I t5 ~ 148 DF , COMPENSA?t~D N~UI'RON (CNL), AND GAMMA RAY I'H~O C'k$lN~ ~ I~N$IT¥ LVP OlO,H02 VERIFICATION LISTING PAGE 8A'MPbED~ 2,)FILE EDIT~O02 CONTAINS HI RES FORMATION DENSITY (FDH). COMPENSATED ME-UTRON (CHH)SAi~P:LEiD MI,~" THIS DATA HAS NOT BEEN SCHLUMBERGER LOGS INCLUDED WITH THIS MAGNETIC DUAL ; SPHERICAbb~ FOCUSED bOG.(DIb} :bABLE'i a:046;~: :TO 2364:~ :UTRON bOG (CNb), · :b~BbE, (CS~t64' TO 986' GAMMA RAY THR~ DATA AVAi ~0 MAT]ON DENSITY DATA AVAiL, ABbEI ' H 1,2" CFDH) bVP 010, 02. VERIFICATION LISTING PAGE 4 ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE SI.ZE R~PR CODE EN:?R:Y 66 ~ 6 ~ FDC FDC DPMI FDC NFDC FDC FFDC FDC TNRA tnb RTNR CNL NpHi CNL RCNT CNL CFTC CNL CNTC CNL IENS CNL R CNL GR TENS CSG API Pi API APl FIbE SIZE SPb REPR bOG TgPCbA, SS MOD NO, CODE FT O0 000 g 0 OHM~ O0 220 ~0 0 0 44 I OHMM O0 ) 0 OHM~ O0~ ~0 ~V 00 010 AP! O0 3t0  B 00 AP1 O0 kB O0 N O0 G/C3 O0 oo PU 00 890 CPS O0 35,4 oo O0 000 PU O0 890 CPS O0 000 CPS O0 000 PS O0 000 PS O0 000 LB O0 6 GAPI O0 API O0 3 4 0 0 4 4 0 0 4 OI 0 0 4 4 O! 0 0 0 0 4 01 0 0 4 0 0 o o 1 02 0 0 4 Ol 0 0 4 O0 0 0 4 Ol 0 0 4 02 0 0 4 Ol 0 0 4 O0 0 0 4 O0 0 0 4 O0 0 0 4 O0 0 0 4 O0 0 0 4 O0 0 0 4 21 0 0 4 01 0 0 4 01 0 0 4 21 0 0 4 1 8 00000000000000 00000:000000000 I 68 00000000000000 68 00000000000000 ~ 68 I 6~ $8 1 68 00000000000000 I 68 00000000000000 I 68 00000000000000 1 68 00000000000000 I 68 00000000000000 1 68 00000000000000 I 68 00000000000000 ! 68 00000000000000 1 68 00000000000000 I 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 ** DATA ** DEPT SP DTENS RTNR 806 3844 20 3 0000 SFLU 2656 GR 0000 CALl 6883 NFDC 4526 NPHI TENS 8 858 ~39 RHOB FFDC 38 86~7 RCNT 4,2406 384 , 0000 GR 9772,3088 DRHO ,0000 TNRA 2068,8657 RCFT 4,4169 108,8125 0,1662 3. 248 590, 010 LVP OIO,H02 VERIFICATION I~ISTIN6 PAGE i5 658,5852 CNT~ -999,2500 TENS 8000 0000 SFLU 759 -999 DEPT 7900 0000 SFLU 2088,0B20 TENS '999~250i0 3 I55 IbD 10~ DEPT T,C D~PT .FTC DEPT PHI .TNR CFTC DEPT DpH! RTNR CF?C GR DEPT TENS 0000 SFLU NFDC NPH! CNTC TENS 7700 0000 SFbU 0000 !ioooo 9984 NFDC - TENS 7600 0000 SFbU -167 ~500 GR 5408 000 CALl 9 8717 NFDC 3 2279 NPH! 748 1947 CNTC -999 2500 TENS ZSO0,O000 162,7500 5520.0000 5721 NPHI 9637 , CNTC -~i,2SO0 TENS 7400 0000 SFLU :134' 999,3750 GR .2500 CALl { '999 , ~ : 7o 6~ 6509 . : TENS 3 6209 lbD 114 8750 TEN 1719 RHO~ · 999 2500 3 58O 32 2183 "999 592 lLP 500 TENS 203 RHOB 5000 FFDC 76 RCNT 1,7300 IbD 116, TENS 628,0000 FFDC 50.4393 RCNT !687,7087 TENS 999;2500 2.1368 IbD ,I11,5625 TENS 999,2500 RHOB 3844,0000 GR 108,8125 57:1. 0000 GR 101 7500 5 4:0-7~1:Ib~: 5,5.:648 O0 0 G 87, ~ oo ~N ; 548' 0000 GR 87, 5 29 5254 IbM 556~ 5560 0000 GR 26 ~:.8727 O0 63 5000 11A ~0 111 8750 54 3,2960 . 3 DRHO 44 7500 TNRA 5408,0000 GR 2670 '26 2500 } ,3992 IbM 0 DRHO 67!i 0 TNRA 552 0000 GR 307 4375 oo , 40g,84 1,9483 IbH 5460,0000 GR "999.2500 DRHO  ,9870 -999, O0 LVP 010,H.02 YER'IFICATION LISTING PAGE DE'PT '999. "9:9'9. :999. 999., 7:300 "999 ":999 DEPT 7200 0000 SFbU ~PHI NFDC :~NR NPH! - CNTC - DEPT 7100 0000 $'FbU DEPT DpH! RTNR CFTC GR ' DEPT SP TENS PHI TNR CFTC GR DEPT SP TENS RTNR CFTC DEPT NFDC NPH! CNTC TENS 7000,0000 $[LU -44,Q000 '999;2500 ~Ab! '999.2500 NFDC '999.2500 NPH! :999,2500 CNTC 999,2500 TENS 6900 0000 8FbU 250 CAb! '99~ 2500 NFDC -99 2500 NPH! -999 2500 CN?C -999 2500 TENS 6800 0000 SFLU -3! 9219 GR -999 2500 CAbI ~999 2500 NFDC '999 2500 NPH! '999 2500 CNTC -999 2500 TENS 6700,0000 srbu '9'9,96 ' O0 RCNT 999 3 2:4 O0 TENS TENS 2 -99 "99~ '99~ 3174 ILD 375O [~N$ 2500 HOB 2500 TENS 2500 2 I00 -999 -999 -999 -999 -999 0825 ILD 3125 TENS 2500 RHOB 500 FFDC 500 RCNT 500 TENS 5O0 3 -999 -999 -999 -999 0047 8750 TEN& 2500 RHOB 2500 FFDC 500 RCNT 500 2500 2.5044 ILD '999,2500 GR -999, :500 GR -999 2500 GR -999 2500 GR -999 -999 -999 0000 2500 DRHO 500 TNRA 500 RCFT 2500 GE -999 -999 -999 -999 9529 IbM 0000 GR 2500 DRHO  500 TNRA 500 RCFT 2500 GR , 0 GR ,ooo..o '999' RCFT -999,250~ OR 2.4310 IbM -999',500 27 -999 I ,725.3 -999 ':99g -999 500 -9 -9 O0 -999 2500 .999 2500 ,9807 999. 500 999, 500 999,22500 -999, 500 -999 O0 '999 2500 -999 2500 -999 2500 -999 2500 2,4530 LVP OIO,H02 V~R:IFICA?ION blSTI~G p · ...... AGE: 7 DEPT DEPT ST P EN8 DE:PT DEPT SP TENS DPH! CFTC DEPT SP TENS DP~I RT R FTC DEPT Sp TENS DPH! RT~R CFTC 660.0 0000 6500 0000 SFLU -999 "999 NTC 6400 0000 SFLU t500 NFDC ~500 NPH! !SO0 !500 TENS 6300 0000 SFbU -23 9844 GR -999 2500 CAb! '999 2500 NFDC -999 2500 NPHI '999 2500 CNTC -999 2500 TENS 620O -999 -999 -999 99 0000 8FLU 5 2 GR 5~0 CkbI ~00 NFDC O0 NPH! O0 CNTC )~00 TENS -~99 -99 RCNT :'* ~'~, !!: '999 ,2500 GR -999 2500 2 8 715 IbO -0325 :.~bM 3'0676 ,0000 GR ''999,205 0 ,2500 TNRA ''999, ~25:0:0i !REFT -999'2500 OR -999;2500 2 8067 I lad -999 -999 -999 -999 500 500 TENS 500 2 ,3994 IbD -999 -999 t500 FFDC 500 RCNT '999 ~500 TENS '999 500 2 6760 1ED 98 5 TENS -999 ~i~O RHOB -999 500 RCNT 9~ 2500 TENS 29 2500 -999.~)00 NFDC -999;2500 FrDC ...z -999; 500 CNTC -'999,2500 TENS -999,~500 TENS -999;2500 -999,2500 GR 5807 IbM -999 2,4721 'IbM 4600,000 '999,2500 TNRA :999,2500 R:CFT 999,2500 GR "999 "999 '999 8068 ILH 0000 GR 2500 DRHO 2500 TNRA 2500 RCFT 2500 OR 2 5539 IbM 4~33 0000 GR 2,00 !500 TNRA '500 GR -999 2500 2 -~99 -!99 -999 -999 -9992500 2 4810 2500 999 2500 -999 -999 2500 2 7639 '999 -999 2500 -999 2500 -999 2500 2 5554 -999 2500 -999 2500 '999 2500 '999 2500 -999 2500 D:~:PT: 6000 0000 SF{~U ~P 2500 CNTC 2500 TENS D:EPT 590:0 5800 0'0:00 SFbO NPHI DEPT DEPT SP TENS DPH! CFTC GR 5700 0000 SFSU GR 500 NFDC 500 ~PH! -999 ~500 CNTC -.999 ~500 TENS 5600,0000 SFLU '999, '999,1~00 NFDC '999, O0 NPH! -999,25 N DEPT 5500.0000 SFLU DEPT SP TENS PHI TIvR 5400,0000 SFbU -28,1406 GR '999,2500 CALl '999,2500 NFDC -999,2500 NPHI ~2249 999, FFDC '99:9; RCNT -999, RHOB -999, -999.{500500 -999.2500 TENS -999;2500 2 98 -999 -999 -999 -999 -999 9491 lED 5000 TENS 2500 RHOB RCNT 2500 TENS 2500 2,3358 lbD 71, 000 TENS -999, 500 RHOB '999 O0 RCNT -999:{~00 TENS '999 O0 2,6736 ISD 98, ~50 TENS '999, O0 RHOB -999,2500 FFDC -999,2500 RCNT 3 04:9:5 -999 2500 GR '999 2500 GR -999 ,$9.47 I'h~ ,0000 GR ;2500' DRHO ,~.~:9,2500 TNRA ;2500 CFT -999.2500 OR 3 4140 '999 -999 "999 -999 0259 ILM 000 GR 500 DRHO RCFT 2500 GR 2 3993 ILM ~044 0000 GR 999 2500 DRHO -999 2500 TNRA -999 2500 RCFT -999 2500 OR 2,7608 ISM ~930,0000 GR 999.2500 DRHO -999.2500 TNRA -999,2500 RCFT 3 015:! -999 0 :999 999 '999 2500 '999 50O 2 9799 -999 .,,,°o '999, O0 -999 2500 2, 198 -999, 500 =999, 500 -999, 500 '999' 500 '999,2500 2,6867 -999,2500 -999,2500 -999,2500 -999,2500 LVP :010, 02 VERIFICATION LISTING DEPT -999,2500 CNTC -999,2:900 TE~$ 5300 0000 SrLU -30 '999 DEPT D:EP:T DEPT DPHI C GlTC DEPT DPHI 'RTNR CFTC GR DEPT SP TENS DpHI RTNR DEPT 0000 SFLU 3906 OR 2500 ~Abl CNTC 5iiO0,O000 '27.5938 i~LU 2500 ' 0 . 9;250 NFDC 2500 5000 -.999 999 -.999 '999 0000 SFLU !906 ~500 O0 NFDC !~00 NPHI 2500 CNTC 2500 TENS 49OO '3 -99~ -999 -999 -999 -999 0000 SFLU 094 GR 500 CAbI 500 NFDC 500 NPHZ 2500 CNTC 2500 TENS 4800 °33 -999 -999 '999 -999 -999 0000 SFLU 343 250~ GR CAb! 2500 NFDC 250O NPH! 2500 CNTC 2500 TENS 4700,0000 SFLU '33,4063 GR '999,2500 CALl '999, '999 ,: 2: '999,2500 7:27:6 ;: lb~  500 TENS 500 1,7860 lbo 8 ,7500 -9~'~; ,oooo OR 2500 RH,.O~ . ;2:500 -~,2500 FFDC 999,2500 -222,2500 TENS '999.2900 OR -~,2500 2 1603 ILD 680 -999 -999 TENS -999 2500 GR 2 10 -999 -999 -999 -999 2 86 -999 -999 -999 3 -999 -999 -999 -999 oooo 2500 RHOB TNRR 2500 -999 RC.F~ 2500~00 TENS -999 2500 GR 7587 ILD RHOB o rroc O0 TENS TENS 2500 RHOB 2500 FFDC 2500 RCNT 2500 TENS 2500 2,8576 ILD 9~,5000 TENS '99 ,2500 RHOB 9460 oooo 2500 2500 2500 IbM GR DRHO TNRA RCFT GR ~56:4208 Ib~ ~99 ,0000 GR 2500 DRHO 999,2500 TNRA -999~2500 RCFT '999,2500 GR 0676 ILN '999, O0 DRHO -999,2500 -999 25O0 -999 2500 -999 2500 6¸4 )0 )0 -999 2500 2 8140 '999 2500 '999 2500 '999 2500 '999 2500 ~999 2500 93'!729 , :II o 9 2500 2,9104 '999:1500 '999 500 bVP 010,H02 VERIFICATION blS?ING PAGE 1,0 DEPT DEPT P -D~PT DE'PT C G[TC DEPT $ DpHI RTNR CFTC GR DEPT TE~S DpHI RTNR CFTC DEPT 46,00 -999 -999 ,2500 · 2500 0000 SrbU 4500 0000 8FbU ,,,999 - 9:9:9 4400,0000 '9 '999, 4300 0000 ~062 tSO0 ! ,500 ~500 -999 ,2500 -999 ~2500 4200 0000 -40 1562 -999 2500 -999 250O -999 2500 -999 250O -999 2500 4100 0000 -43 8437 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 4000,0000 TC ENS 8FLU ,I ! CTNTC 8FLU NFDC NPHI SFbU GR CAbI NFDC NPHI CNTC TENS SFbU GR CAbI NFDC NPHI CNTC TENS SFLU '999, '999, '999, 0704 TENS 3 7570 '9999 "99 '999~ 'y~,2500 -999;2500 2,947:6 95 !500 -999! 500 0 4 95 75 50 -999 O0 -999 2500 -999 2500 -999 2500 -999 2500 4 5587 96 1250 -999 2500 -999 2500 -999 2500 -999 2500 -999 250O 3,9090 TENS XLD TE~$ RH ,B FFDC RCNT TENS ILD TENS RHOB FFDC RCNT TENS XLD TENS RHOB FFDC RCNT TENS ILD -999 500 TNRA *999 500:i:RCFT :~"99'9 500 GR -999 !500 GR -999 ~500 GR -999 1500 GR 0 GR HO " 2500 TN ,soo -999 2500 GR 3 ~,2.812 IbM ~ .0000 GR 9,2500 DRHO '999,2500 TNRA '999,2500 RCFT '999,2500 GR 4.9461 ~90 0000 99 2500 999 -999 2500 GR DRHO RCFT GR 305~,6438 IbM ,0000 GR '999,2500 DRHO '999,2~00 TNRA '999,2 O0 RCFT '999,2500 GR 4,1007 -999 2500 4 0 -999 O. '999 ~0 -999 1500 O0 "999 '999 500 "999 500 -999 500 5,3526 -999.2500 -999,2500 -999, 0 999,2500 :133 -99 500 '999~ 500 '999,:500 ~999e ~00 '999, O0 3,7816 TC DEPT 3900 9062 GR 2-500 CAbI 90 -999 -999 -999 -999 -999 I b D DE:PT 3800 '0000 SFLU' NFDC NPHI 99 EN8 D:EPT 3700 a'FbU NNFDC PHi CNTC D~PT 3600,0000 srbu ,6875 R?NR -999~2500 NPHI CFTC 999.2500 CNTC GR ~999,2500 TENS DEPT TEHS DPHI RTNR FTC DEPT Sp TENS DpHI CFTC GR 3500 0000 8FLU 25 CAbI -999 2500 NFDC -999 2500 NPHI -999 2500 CNTC -999 2500 TE~$ 3400 0000 SFhU -62 6250 GR -999 2500 CAbI -999 2500 NFDC -999 2500 NPHI -999 2500 CNTC -999 2500 TENS TEN~ 3 l:bD TENS X LD O0 O0 50O 5OO -999 -999 -999 "999 -999 -999 -999 -999 -999 4664 lbo 4688 2500 1ENS HOB RCNT 0 TENS 303 0082 -9;~ 5625 TENS 2500 RHOB =999 2500 FFDC 0999 2500 RCNT -999 2500 TENS -999 2500 9 6909 IbD 79 5 -,,,I ~999 !500 FFDC 999 500 RCNT -999 500 TENg -999 2500 PAGE: -999 !500 GR '999 ~:999 '999 2:500 -99 2500 TNR '.99~ A ,,999 2500 RCF T: ~999 ,',,999 2500 OR ,.999 7338 Ib:~! 6 I NRA 2.500 GR -999 O5 1500 7 4229 IbM . .! -99! 2500 GR -999 ~00 20.2070 ! .oooo ,2500 DRHO 999,2500 TNRA -999~2500 RCFT '999,2500 GR -999 ,,,999 -999 8465 2500 195,8249 IbM ,.2500 DRHO ~999,2500 TNRA 999,2500 RCFT '999,2500 OR 165 8374 -99 O0 '999. ~00 '9990 O0 -999,2500 i, 0779 IbM 26 , 0000 GR '9 ,2500 DRHO ,,,99 , 2500 TNRA ,2500 RCFT '999.2500 GR 9 -999 -999 -999 -999 -999 9481 250O 2500 2500 250O 25OO LVP'OtO,H02 VE'RIFICATION LISTING PAGE 12 DEP? 0000 SFbU 1' NNFDC DEPT DEPT DEPT OEP? DpHI RTNR  FTC R 3200 -0000 8FLU 31 -999 -999 0000 U bi NFD ~CNTC EN,S 3:000 0000 SFbU NPHI 2500 CNTC 2500 TENS 2900 0000 SFbU -88 0625 GR 2500 NPHI :99 500 NS DEPT 2800,0000 8FLU SP ' -84~5&25 GR TENS -999;2500 CAbI DPH! -999,2500 NFDC RTNR -999~2500 NPH! CFTC -999,2500 CNTC GR -999.2500 TENS DEPT SP TENS DPH! RTNR 2700,00.00 SFbU -64,3125 GR -999,2500 CAbI '999'2500 NFDC '999,2500 NPHI 97.3~ $ Ib:D 0 ' TEN~ ,999~ 0 RH08 '999, "999, '999,;2500 TENS '999;2500 -999 -999 1159 IbD 7 ,4880 I LD . 5 99~ TENS EH.OB -999 2500 FrDC ,,,999 2500 ECN'I' '999 0 9 7874 IbD 0 RHOB FFOC RCNT -999 ~500 TENS -999 500 17 9520 LD 54 50 {ENS -999 ~00 RHOB -999 2500 FFDC -999 2500 RCNT '999 2500 TENS '999 2500 6 ,70 -999 -999 -999 5556 IbD 9375 TENS 2500 RHOB 2500 FFDC 2500 RCNT -999 2500 GR 9 63,75 ,0 GR 8 4634 TNRA Ecr? -999 ~soo GR 9 1679 XGM oooo 99 2500 DRHO - 2500 RCFT -999 2500 GE 18 2354 '999 -999 -999 -999 7375 IbM 0000 GR 2500 DRHO 2500 TNRA !500 RCFT 500 GR 9,6679 Ib~ 2194,0000 GR -999,2500 DRHO -999,2500 TNRA -999,2500 RCFT -999 2500 8 -999 2500 6¸4 ~00 B -999 !500 8 4505 '999 O0 oo 999 O0 -999 2500 17,3712 -999,2500 "999, 0 oo -9,,. -999,~ 00 -999 ~ 0 -999 2500 -999 2500 -999 2500 bVP 010,.H02 VERIFICATION LISTING PAGE DEPT 999,250:0: T~N S -999, 2600 0000 SFLU -60 ':99'9 -999 '999 '999,2500 GR -999,2500 -999 3242 :'I~ ooo 50:0 : DRHO :: 2500 GR -999 PT DEPT DPHI FTC DEPT SP ~ENS DpH! RTNR CFTC DEPT ENS DPHI RTNR CFTC GR DEPT TENs 2500 0000 -999 -999 -999 ,,999 TENS '999 '999 '999,2500 TNRA -999 2500 RCF? -:999 '999,2500 GR -999 4067 ~500 2400 00:00 SF~U NFDC NPHI CNTC TENS .! '999 1:880 i~ 0540 ILS ~99 RCNT TENS -999 GR -999 2500 2300 0000 srbo -999 25O -999 ~50~ NFDC 281~ CNTC TENS -999 2500 IbD RHOB -999 2500 FFDC '999 2500 RCNT -999 2500 TENS i880 0000 -999 2500 Ib~ - DRHO - RCFT -999 2500 GR -999 999 :' O0 -999 2500 2200,0i~0 SFLU ClhI '999, 500 NFDC '999, 500 NPHI '999, NTC -999 2500 ILD 'I 500 FFDC - ~ 500 RCNT ! 0000 -999 250.0 DRHO '999 RCFT -999 2500 GR -999 -999 -999 -999 -999 -999 2500 2500 2500 2500 2100 0000 SFbU 500 GR -999 2500 NFDC -999 2500 NPH! -997 2500 CNTC 3 1875 TENS -999 2500 IbD -99 ~500 TENS -99~ 500 RHOB -999 FFDC -999 500 TENS 1775 0000 -999 2500 -999 2500 GR -999 2500 DRHO -999 2500 TNRA -999 2500 RCFT -999 2500 GR -999 -999 -999 -999 -999 -999 500 5OO 50O 0 2500 2000,0000 SFLU '9~.2500 GR -9 ,2500 CALl -999 2500 XLD -999~2500 TENS '999,2500 RHOB -999.2500 IbM -999,2500 GR '999.2500 DRHO '999,2500 '999,2500 '999,2500 LVP 010,H02 VERIFICATION LISTING PAGE14 "999, "' 999 ~ DEPT 0000 SFLU 0000 ,U DEPT DEPT ~NS DPH CFTC OR DEPT CFTC DEPT ~P DPHI CFTC OR DEPT 0000 1600 0000 -999 '5 999 250~ -999 25 0 ' 0 47 9062 1500 0000 -999 2500 -999 2500 -999 2500 -999 2500 9062 400,0000 999,2500 999'2500 999, .999,~ 500 5OO -999, 500 39'~750 1300.0000 SFL, U CNTC TENS NFDC CNTC TENS SFbU NFDC NPHi CNTC TENS SFLU GR CALI NFDC NPH! CNTC TENS SFLU '999. 500 FF ', :9, 0 TN -99 ~500 ' 500 -999~ TENS -999,2500 OR -~99 2500 t 745 ' -99:9 2:50:0 l~ -999 TENS -999 0:0 lb:M, ,,,999 2500 -999 ~999 2500 OR -999 -999 -999 HO : '9 :'!, } TENS -9 2500 GR =999 2500 '999 -999 1600 ILD - TENS -999 ~500 GR -999 2500 -999 '999.2500 '999'2500 '999,2500' '999. 50 0000 TENS RHOB FFDC RCN? TENS -999,2500 ibm -999,2500 GR -999'2500 DRHO -999,2500 TNRA -999;2500 RCF? -999,2500 GR O0 O0 500 -999 -999 -999 :999 999 -999 1495 2500 1ED 500 TENS 500 RHOB 2500 FFDC 2500 RCNT 2500 TENS 0000 -999,2500 IbM -999,2500 GR "999.2500 DRHO 0 TNRA -999~2500 GR -999 -999 -999 '999 -999 -999 500 50O 2500 500 500 250O '999,2500 1ED '999. O0 RHOB '999'2500 FFDC -999;2500 RCNT -999.2500 T~NS 1450.0000 -999 -999 -999 -999 '999 '999 2500 2500 GR 2500 DRHO 2500 ?NRA 2500 RCFT 2500 OR -999 -999 -999 -999 -999 -999 2500 2500 2500 2500 2500 2500 '999,2500 IbD "999,2500 IbM -999.2500 LYP 010.H 2 VERIFICATION LISTING PAG.E.i 1:5 ~ =999 999 500 GR 500 :CALl 5.00 NFDC 500 NPH,! 1200 0000 SFLU 2500 G R 2500 CAbI :9~,2500 TEN~: -999 999.2500 R~O "999 "999~2500 FrDC ~999 -999;25,oo R,¢N,T : -999;2500 TENS 999 1380~0000 '99:9 999 999 ..999 2500 GR '999 250:0: ZbN : ~999 2500 2500 GR -999 1500 "9:99 500 -999 2500 DEP:T C GRFTC DEPT 1100 0000 SFbU -999 1000 NFDC NPHI: CNTC TENS SFbU NFDC NPHX -999 CN~C 6t TENS DEPT 985,0000 SFLU 20 ~NS 999, CALl  PHI -999 0 C~TC -999, O0 CaNPH! -999 2500 -99 .9999 TENS -~999 999 -999 -999 -999 t180 TENS 500 FFD~ 500 RCNT 500 TENS 000 i500 IGD RHOB 500 FFDC 500 RCNT 0 TENS -999:2500 ZG:M t5 00 GR °999 500 DRHO -999 2500 TNRA -999 2500 Reft -999 -999 2500 Ge -999 2500 -999 2500 -999 2500 GR 2500 O0 '999 -999 2500 -999 ?99 999 -999 25,00 IbM -999,2500 2500 TNRA '999.2500 2500 RCFT -999;2500 2500 GR -999.2500 ** FILE TRAILER FILE NA~E :EDIT ,001 SERVICE NAME : VERSION # ~ATE ~ AXIMU~ LENGTH { 1024 FiLE TYPE NEXT FILE NAME EOF ********** ** FILE HEADER ** FILE NAME ~EDIT ,002 ~¥~ 010,H02 VERIFICATION blSTING PkGf!6 ~ N # :  H ~ 1024 PREVIOUS FIbE ~ DATA FORMAT RECORD ENT.RY B,[~OCKS T'¥PE DA?Ur~ SPECIFICATION RbOCK8 MNEM SERVICE SERVICE UNIT APl ID O.OER# bOG ~H ~H ~DH ~DH FFDC FDH T~A CNH ~T.~R CNH NPH! 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