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200-139
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, August 29, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2N-349A KUPARUK RIV U TARN 2N-349A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/29/2022 2N-349A 50-103-20345-01-00 200-139-0 W SPT 5078 2001390 1500 1740 1740 1740 1740 130 250 225 225 4YRTST P Adam Earl 8/1/2022 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 U TARN 2N-349A Inspection Date: Tubing OA Packer Depth 850 2510 2450 2450IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220803203307 BBL Pumped:0.7 BBL Returned:0.7 Monday, August 29, 2022 Page 1 of 1 9 9 9 9 9 9 99 9 James B. Regg Digitally signed by James B. Regg Date: 2022.08.29 15:36:45 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,April 01,2015 P.I.Supervisor 4'I7115 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2N-349A FROM: John Crisp KUPARUK RIV U TARN 2N-349A Petroleum Inspector Src: Inspector Reviewed By: P.I.SuprvC3—ge— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U TARN 2N- API Well Number 50-103-20345-01-00 Inspector Name: John Crisp 349A Permit Number: 200-139-0 Inspection Date: 3/22/2015 Insp Num: mitJCrl50325125130 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2N-349A rType Inj 1, G TVD f 5078 iTubing' 2800 - 1 moo - 2800 -r-2800 2800 -' PTD 2001390 - Type Test SPT Test psi' 1500 IA 780 11 2250 2220 - 2200 2200 ' Interval j4 TST — ' P/F P OA 200 250 • 250 ' ' 250 ' 250 H Notes: 1/2 bbl pumped for test CANNELI i ' :t Wednesday,April 01,2015 Page 1 of 1 • Page 1 of 1 Regg, James B (DOA) • From: Phillips, Jim (ASRC Energy Services) [Jim.Phillips@contractor.conocophillips.com] Sent: Wednesday, August 25, 2010 3:57 PM To: Regg, James B (DOA) ~~ ~ ~~ ~ ~/ t2 Subject: RE: State MITIA test results for 2N pad on 8/24/10 Follow Up Flag: Follow up P~ ~.,c3~ Flag Status: Red Attachments: MIT KRU 2N Pad DRAFT.xIs ~~~ ~~ ~ ~~ ~ Jim, I apologize for the mix up I am filling in for Brent this week and by mistake I did not double check the form before sending it off. Therefore I did not notice that it was showing 12 water injectors SI. I have attached the correct copy and again I am sorry about this mistake on my part. If you have any more questions please feel free to contact me. Jim Phillips Acting Problem Well Supervisor Email: N1617 @conocophillips.com Office: 659-7224 _._ _ __ _.. ~m From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, August 25, 2010 2:36 PM To: Phillips, Jim (ASRC Energy Services) Subject: RE: State MITIA test results for 2N pad on 8/24/10 Why were all the wells SI except the gas injector? Jim Regg AOGCC t . <; gg ,.(- } ~.. ,r~l~is zit ~i ~9~! "4 , 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Phillips, Jim (ASRC Energy Services) [mailto:Jim.Phillips@contractor.conocophillips.com] Sent: Wednesday, August 25, 2010 8:57 AM To: Regg, James B (DOA); Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Subject: State MITIA test results for 2N pad on 8/24/10 All, Attached is the MITIA tests for 2N pad that were waived by Chuck Shieve on 08/24/10. Jim Phillips Acting Problem Well Supervisor Email: N1617 @conocophillips.com Office: 659-7224 8/26/2010 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@arrlaska.gov OPERATOR: ConocoPhillipsAlaska Inc. ~~fiaq D~~¢'~~~ FIELD /UNIT /PAD: Kuparuk /KRU / 2N C [ DATE: 08/24/10 OPERATOR REP: Ives/MouserAES AOGCC REP: Packer De th Pretest Initial 15 Min. 30 Min. Well 2N-302 T e In'. W ND 5,185' Tubin 1,860 1,860 1,860 1,860 Interval 4 P.T.D. 2011150 T etest P Test si 1500 Casin 1,210 2,540 2,520 2,520 P/F P Notes: OA 235 265 260 260 Well 2N-306 T e In'. W ND 5,174' Tubin 2,150 2,150 2,150 2,150 Interval 4 P.T.D. 2040620 T etest P Test si 1500 Casin 1,245 2,820 2,760 2,760 P/F P Notes: OA 375 550 520 520 Well 2N-307 T e In'. W TVD 5,141' Tubin 1,500 1,500 1,500 1,500 Interval 4 P.T.D. 1990170 T etest P Test si 1500 Casin 810 2,180 2,150 2,150 P/F P Notes: OA 250 350 300 300 Well 2N-309 T e In'. W ND 5,042' Tubin 1,600 1,600 1,600 1,600 Interval 4 P.T.D. 1990210 T etest P Test si 1500 Casin 775 2,225 2,100 2,080 P/F P Notes: OA 300 365 340 340 Well 2N-310 T e In. W ND 5,004' Tubin 1,550 1,550 1,550 1,550 Interval 4 P.T.D. 2070900 T e test P Test si 1500 Casin 440 2,300 2,250 2,250 P/F P Notes: OA 270 390 350 350 Well 2N-314 T e In'. W ND 5,046' Tubin 1,600 1,600 1,600 1,600 Interval 4 P.T.D. 2001930 T e test P Test si 1500 Casin 600 2,300 2,270 2,270 P/F P Notes: OA 225 240 240 240 Well 2N-321A T e In'. W TVD 4,915' Tubin 1,500 1,500 1,500 1,500 Interval 4 P.T.D. 1981730 T e test P Test si 1500 Casin 575 2,280 2,250 2,250 P/F P Notes: OA 250 450 450 450 Well 2N-326 T e In'. W TVD 4,821' Tubin 1,860 1,860 1,860 1,860 Interval 4 P.T.D. 2001550 T etest P Test si 1500 Casin 1,150 2,760 2,720 2,710 P/F P Notes: OA 360 460 460 460 Well 2N-331 T e In'. W ND 4,770' Tubin 1,460 1,460 1,460 1,460 Interval 4 P.T.D. 1981170 T etest P Test si 1500 Casin 460 2,200 2,150 2,150 P/F P Notes: OA 300 480 480 480 Well 2N-335 T e In'. W ND 4,966' Tubin 1,950 1,950 1,950 1,950 Interval 4 P.T.D. 1982040 T e test P Test si 1500 Casin 560 2,800 2,600 2,590 P/F P Notes: OA 200 430 430 430 Well 2N-343 T e In'. G ND 4,937' Tubin 3,350 3,350 3,350 3,350 Interval 4 P.T.D. 1980920 T e test P Test si 1500 Casin 850 2,780 2,630 2,620 P/F P Notes: OA 400 420 420 420 Well 2N-348 T e In'. W ND 4,374' Tubin 1,500 1,500 1,500 1,500 Interval 4 P.T.D. 2011420 T e test P Test si 1500 Casin 630 2,280 2,240 2,240 P/F P Notes: OA 190 320 320 320 Welt 2N-349A T e In'. G ND 5,078' Tubin 1,625 1,625 1,625 1,625 Interval 4 P.T.D. 2001390 T e test P Test si 1500 Casin 280 ~ 2,320 ' 2,250 x2,250 P/F P ~ Notes: OA 150 250 250 250 Weil 2N-325 T e In'. W ND 5015' Tubin 1,975 1,975 1,975 1,975 Interval 4 P.T.D. 1981630 T e test P Test si 1500 Casin 750 2,675 2,630 2,630 P/F P Notes: OA 220 250 240 240 TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D =Drilling Waste M =Annulus Monitoring I =Initial Test G =Gas P =Standard Pressure Test 4 =Four Year Cycle I =Industrial Wastewater R =Internal Radioactive Tracer Survey V =Required by Variance N =Not Injecting A =Temperature Anomaly Survey T =Test during Workover W =Water D =Differential Temperature Test O =Other (descrtbe in notes) MIT Report Form BFL 11/27/07 MIT KRU 2N Pad 08-24-10 Revisedl.xls Page 1 of 1 • • Maunder, Thomas E (DOA) From: Osbom, Louise [Louise.Osborn(c~conocophillips.com] Sent: Friday, July 18, 2008 10:53 AM To: Peirce, John W; Maunder, Thomas E (DOA) Cc: Allsup-Drake, Sharon K Subject: RE: 2N-349A (200-139) Attachments: 2N-349A. pdf Here is the updated well status. Louise t~Cc.w~c'G~,a~+~~ 'p~r:~CJ From: Peirce, )ohn W ~y~ Tom, Sorry about the confusion. 2N-349A is currently on PWI at 2200 BWPD. Per my check of our databases, 2N- 349A has always been an WAG injector (service well). I noted the 2N-349A well schematic reports the well is a producer. This may have created the confusion. I'm guessing perhaps incorrect information was taken from the schematic then recorded to the 10-404. In any case, we will correct the schematic to avoid future confusion. We will check in the future to make sure that the well schematic well status agrees with the well status reported on the sundry. Sent: Friday, July 18, 2008 8:33 AM To: 'Maunder, Thomas E (DOA)'; Osborn, Louise Cc: Allsup-Drake, Sharon K Subject: RE: 2N-349A (200-139) Louise, Please correct to show 2N-349A is an injector. ~~~N~~ 1U~ ~ ~ ~~~$ Regards, John Peirce From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent; Friday, )uly 18, 2008 7:59 AM To: Peirce, John W Subject: 2N-349A (200-i39) John, I was reviewing the 404 recently submitted for adding perforations to this well. According to our information this well is a service well (WAG). You noted development and oil. Is there to be a change from service to development for this well? I look forward to your reply. Tom Maunder, PE AOGCC 7/18/2008 5~r • STATE OF ALASKA • .!i~i;~~ ~, F LQi1~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPER~~I~`~~'°' '`'~'~° ~~~''~~'~`~"~' n .. ~st~, ..,~-, 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate Q Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development Exploratory ^ 200-139 3. Address: Stratigraphic ^ Service ^/~ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 9. ~. GQ 50-103-20345-01 ' 7. KB Elevation (tt): 9. Well Name and Number: RKB 35' 2N-349A ' 8. Property Designation: 10. Field/Pool(s): ADL 380054, 375074 ~ Kuparuk River Field / Tarn Oil Pool 11. Present Well Condition Summary: Total Depth measured 6498' ~ feet true vertical 5757' feet Plugs (measured) Effective Depth measured 6250' feet Junk (measured) true vertical 5557' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 118' 16" 118' 118' SURFACE 2330' 7-5/8" 2330' 2310' PRODUCTION 567' 5-1/2" 5677' 5093' PRODUCTION 713' 3-1/2" 6498' 5751' ~i~N~~ JUL 2 5 2008 Perforation depth: Measured depth: 5940'-5962', 5990'-6010', 6020'-6030', 6080'-6120' true vertical depth: 5308'-5326', 5349'-5365', 5373'-5381', 5421'-5453' Tubing (size, grade, and measured depth) 3.5", L-80, 5674' MD. i~ Packers & SSSV (type & measured depth) no packer -+•~ C.Ca-S~~SS~G.\ rC'CC (~ G~`~ l'~ k~ f ` ~~ ~ ~ ~ Camco'DS' nipple ~ 503' 12. Stimulation or cement squeeze summary: d S~~~t ~~ ~ ~ ~~~ I l t t t d ~ n erva rea measure s e ( ) 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 1005 Subsequent to operation 854 -- 14. Attachments 15. Well Class after work: / $ Copies of Logs and Surveys run _ ~r , , LJ ^ Develo ment Service Exploratory p d'C4 1 Daily Report of Well Operations _X 16. W I Status er work: ~j~ ^ ~ /1 ~~ INJ^ WINJ ^ WDSPL {•s^ WAG[ Oil . ~ 17. I hereby certify that the foregoing is true and correct to the best of my kn ledge. Sundry Number or N/A if C.O. Exempt: none Contact John Peirce @ 265-6471 ~~ Printed Name J hn Peirce Title Wells Group Engineer ~2~W~Q D l ate © Signature /, ~ Phone: 265-6471 v -4612 ~~ ~ ~ P a h n Allsu Ora 263 ~ ~ ~ ~ ~~ ~ ~ S ~F~~ ~~i.. ~ ? 200 ~ ?•yOo Form 10-404 Revised 04/2006 7 ~ '~ i l _ _ Submit Original Only _ ~~r 2N-349A Well Events Summary DATE SUMMARY • • 5/30/08 PERFORATED INTERVAL 6080'-6120' WITH 2" HSD PJ OMEGA CHARGES, 6 SPF, 60 DEGREE PHASING. (API PEN: 21.8' ;API EH: 0.22") NO CHANGE IN WHP AFTER NEW PERFORATIONS WERE ADDED. KUP 2N-349A _ -- - ConocoPhillips wau nm;b~ Al~,k~. ii I~~ wefAae Avuuwi '.FIe1c Rome ~ _.._ -wNl srann wta:xm~m lnclmadon l'l Taal DwM ImcB) 501032034501 ~'~TARN PARTICIPATING AREA !INJ _ 36.88 6,498.0 _ CommwK `H2S (Ppm)'Data iAmotatlon -'~, ErM Date iK&Grd (R) -.. __~R g Release Data Wel : - /781200810:31:5] AM NIPPLE Camco D. '~. Last WO ~ 40 80 9/11/2000 c -~- I - - - Anrlofetion DepM (rtXBI ',~Eed Date ~'Mnotation ~ ~ ~- -- End Data Last Tag: 6,250.0 '~ 3/29/2008 Rev Reason: UPDATE WELL STATUS ! 7/18/2008 coNDUCTDR. 11e SURFACE. _ ............... ... _.. ... _..,..... _....,... ~....._~. _,..._......_.... 2.330 - __ _._.. _.. 5,650.0 NIPPLE CernoD 2.75 D Nlpple No-Go profile 5.658.0 CSR ~.~. 5 5 Baker Cag Seal Receptacle, Slze 8040 5,673.0 TTL Tubing Tail ~~ 5564 5,677.0 XO 5.5 BTCM Box x 3.5' Crossover GAS LIFT, S,fi06 PHASE NIPPLE, 5,650 CSR. 5.658 rn, s,6n PRODUCTION, 5,877 XO, 5,677 IPERF, 5,9405,962 IPERF, 5,9808,010 APERF, CPC, PRODUCTION. B,d98 TD (2N-349A)~ .. BA88 ~ ~ WELL LOG TRANSM/TTAL ~,: ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 [907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MT17 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fa~c (907) 245-8952 1 ] Caliper Report 13-Apr-08 2] Caliper Report 16-Apr-08 2N-349A 1 Report/ EDE 12-04 1 Report / EDe 50-103-20345-01 ~s~aa~- ri3a ~-~r3~~ r~9 -oG}c~ silo/35~` Signed Print Name: .e~~,L;~~~,cx>Z~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907}245-8951 FAX: (907)245-88952 E-MAIL : ~dsara~~sar~genn rres~ar~~lag.~arr~ WEESITE : imrnra.rsel~aar la .~aa~ ~~ APR ~ ~~ 200$ 50-029-20416-00 Date J C:1DociunenLs and Settings\Owner\Desktop\Transmi[_Conoco.doc • Memory Multi-Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 2N,349A Log Date: April 13, 2008 Field: Prudhoe Bay Log No.: 7227 State: Alaska Run No.: 1 API No.: 50-103-20345-01 Pipet Desc.: 3.5" 9.3 Ib. L-80 8RD EUE Top Log Intvl: Surface Pipet Use: Tubing & Casing Bot. log Intvl: 6,132 Ft. (MD) Inspection Type : Corrosive & Nlechanica/ Damage Inspection COMMENTS This caliper data is tied into the tubing tail ~ 5,673' (Driller's Depth). This log was run to assess the condition of the tubing and casing logged with respect to corrosive and mechanical damage. This is the first time a PDS caliper has been run in this well. The caliper recordings indicate the 3.5" tubing and casing logged are in good condition with respect to corrosive damage. No significant wall penetrations (> 19%), areas of cross-sectional wall toss (> 11 %) or minimum I.D. restrictions recorded throughout the tubing and casing logged. The caliper recordings indicate a bend in the casing (6,003' - 6,005') MAXIMUM RECORDED WALL PENETRATIONS No significant wall penetrations (> 19%) are recorded throughput the tubing and casing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas of cross-sectional wall loss (> 11%) are recorded throughout the tubing and casing logged. MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded throughout the tubing and casing logged. ~~~~ APR 3 200 Field Engineer: Wm. McCrossan Analyst: M. Lawrence Witness: J. Hansen P~oActive Diagnostic Services, Inc. J P.O. Box 1369, Stafford, TX ??497 Phone: {281) or {888) 565-9085 Fax: {Z81) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Fieid Office Phone: {907} fi59-2307 Fax: {907) 659-2314 us G fob- t v9 ~ ~~13~/ • • PDS Multifinger Caliper 3D Log Plot ~, S Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2N-349A Date : April 13, 2008 Description : Detail of Caliper Recordings Across Perforation Interval • • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (15.4' - 61 17.8') Well: 2 N-349A Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: April 13, 2008 iiff~ Approx. Tool Deviation ® Approx. Borehole Profile 27 779 1566 2354 3133 ~ Y .~ 3907 a v 4684 5468 GLM 1 194 6118 0 50 100 Damage Profile (% wall) /Tool Deviation (degrees) Bottom of Survey = 194 1 25 50 75 100 v I_ v Z = 125 'o 150 175 • PDS Report Overview ~, ~M Body Region Analysis Well: 2N-349A Survey Date: April 13, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: M. Lawrence Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L-80 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body metal loss body 150 100 50 0 0 to 1 to 10 to 20 to 40 ro over 1% 10% 20% 40% 85% 85% Number of ~oints anal sed total = 202 pene. 2 89 106 1 3 1 loss 66 135 1 0 0 0 Damage Configuration (body ) 30 20 10 0 isolated ganaral line ring hole/poss pitting corrosion corrosion corrosion ible hole Number of ~oints dama ed total = 49 29 20 0 0 0 Damage Profile (% wall) ~ penetration body .metal loss body 0 50 100 n GLM 1 Bottom of Survey = 194 Analysis Overview page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 2N-349A Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: April 13, 2008 Joint No. )t. Depth (Ft.) I't•n. t Ilnc~i +I!~~) Pen. Body (Ins.) Pc~n. `% :~c~t,il Loss °,<~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 15 t~ 0.00 I u 2.95 PUP .2 18 a 0.04 17 s 2.90 PUP Shallow ittin . 1 27 U 0.03 l a ~' 2.95 Shallow corrosion. 2 59 U 0.03 11 s 2.94 3 90 a 0.03 I1 .93 4 122 tl 0.03 1 1 1 2.93 5 153 U 0.03 II -1 2.92 6 84 0 0.03 i _> ? 2.94 7 216 U 0.02 '> 2.93 8 247 c l 0.03 I I 2.93 9 278 i~ 0.02 ~ 4 2.95 10 308 ~ t 0.02 ~) 4 2.95 11 339 ~ ~ 0.02 ti ~ 2.95 12 371 !I 0.03 11 I 2.92 13 403 c) 0.03 11 4 .93 14 434 ! J 0.03 1 I _' 2.94 15 465 U 0 (1 2.93 15.1 496 U 0 U t ~ 2.87 DS Ni le 16 498 a 0.03 11 ~~ 2.96 17 530 i) 0.02 ~) -t 2.95 18 562 U 0.02 ~) 2.93 19 92 (a 0.0 12 I 2.92 2 623 tl 0.03 Il -1 2.96 21 655 U 0.02 ~ 2.95 22 685 1 1 0.0 11 I 2.93 23 717 tt 0.03 It1 ~~ 2.95 24 748 t t 0.03 12 `; 2.94 25 779 a 0.03 12 t) .94 26 810 (~ 0.02 9 2.93 27 842 t) 0.03 11 _' 2.95 28 873 t) .0 9 u 2.93 29 904 (I 0.03 12 ~~ 2.93 30 936 U 0.02 ~) s 2.93 31 967 U 0.04 1 5 i 2.94 Shallow corrosion. 32 998 0 0.03 12 ~ ~ 2.95 33 1030 t~ 0.03 12 ~-t 2.96 34 1062 l l 0.03 1 ~ ~ 2.96 , 35 1093 ti 0.03 I2 _' 2.94 36 1125 a 0.05 I ~) -1 2.93 Shallow ittin . 37 1156 t1 0.03 1 3 I 2.93 Shallow ~~ittin . 38 1187 i I 0.02 ~) 2.95 39 1218 t) 0.02 ~) -1 2.96 40 1250 tl .02 `) 2.94 41 1281 a 0.04 1 ~ 2.96 Shallow ittin . 42 1313 t) 0.02 ti ~~ 2.95 43 1345 tt 0.02 ti ; 2.95 44 1376 +~ 0.03 l:i I 2.94 Shallow ittin . 45 1408 U 0.03 13 ~ 2.96 Shallow corrosion. 46 1439 U 0.01 ~ 2.96 47 1471 t~ 0.04 17 !~~ 2.92 Shallow corrosion. _ Penetration Body Metal Loss Body Page 1 II • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • -LATION SHEET 2 N-349A Kuparuk ConocoPhillips Alaska, Inc USA April 13, 2008 Joint No. Jt. Depth (Ft.) I'f•n. i 11>,c~t lln..) Pen. Body (Ins.) Pen. % Vl~~tal I os °~~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 48 1503 0 0.02 8 -~ 2.95 49 1534 U 0.02 7 3 2.96 50 1566 U 0.03 10 ~' 2.93 51 1597 t! 0.04 15 I 2.93 Shallow ittin . 52 162 9 t ! 0.02 9 J 2.96 53 1660 ct 0.03 1 > 5 2.94 Shallow corrosion. 54 1692 0 0.02 & 2.95 55 1723 U 0.02 ~) '~ 2.96 56 1755 0 0.02 i ~ 2.96 57 1786 t1 0.02 9 -) 2.95 58 1817 l! 0.02 ~) 1 2.94 59 1849 U 0.03 13 2.93 Shallow cor osion. 60 1880 t ! 0.0 ~? 2.95 61 1912 t ! 0.03 1 1 I 2.96 62 1944 0 0.02 8 0 2.93 63 1975 U 0.0 8 2.94 64 2007 U 0.04 17 a 2.94 Shallow c rrosion. 65 2039 0 0.03 10 t! 2.92 66 2070 t) 0.02 - ;! 2.95 67 2101 c ~ 0.03 1 1 > 2.96 68 2133 i 1 0.03 1 ~' 2.96 69 2165 U .04 15 2.94 Shallow corrosion. 70 2196 t 1 0.03 1 1 ~ i 2.94 71 2228 0 0.03 10 _' 2.91 72 2259 U 0.03 1~ 2.93 73 2291 U 0.03 11 ~ 2.95 74 2322 t! 0.03 12 1 2.93 75 2354 0 0.03 12 3 2.94 76 2385 (t 0.04 14 ~1 2.92 Shallow corro i n. 77 2416 t! 0.02 ~) a 2.94 78 448 U 0.02 ~) U 2.95 79 2478 t) 0.04 14 L 2.93 Shallow ittin . 80 2509 a 0.02 7 n 2.94 81 2540 U 0.03 1 3 ? 2.92 Shallow ittin . 82 2572 U 0.03 13 ~ 2.96 Shallow ittin . 83 2604 c! 0.02 ~ -1 2.97 84 2635 U 0.02 9 2.95 85 2667 t I 0.02 9 I 2.92 86 2 99 t) 0.04 14 ~ 2.94 Shallow itbn . 87 2 730 U 0.02 ~ r ! 2.94 8 2762 i! 0.03 13 2.96 Shallow ~ttin . 89 2792 t! 0.02 9 I 2.92 90 2823 t) 0.02 7 -l 2.96 91 2853 0 0.02 9 2.93 92 2 85 U 0.03 11 r ! 2.92 93 2915 c ~ 0.02 7 i 2.95 94 2945 i! 0.03 13 2.93 Shallow ittin . 95 2977 ~! 0.02 ~~ ~! 2.93 96 3008 0.02 _ 2.94 97 3030 0.02 I 2.92 Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINTTABI. Pipe: 3.5 in 9.3 ppf L-80 Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • - LATI O N SHEET 2 N-349A Kuparuk ConocoPhillips Alaska, Inc USA April 13, 2008 Joint No. Jt. Depth (Ft.) Pen. Upset Ilns.) Pen. Body (Ins.) I'en. "/<, Mc~t~il I ~~ss ~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 98 3071 U 0.02 7 I 2.94 9 3102 t) 0.02 ti 2.94 100 3133 l) 0.02 '~ _' 2.93 101 3164 t) 0.03 I I 2.93 102 3195 U 0.04 1 2.93 Shallow co rosion. 103 227 U 0.02 t1 ~~ 2.94 104 3258 U 0 03 1 1 4 2.94 105 3289 ~) 0.02 t3 U 2.93 106 332 t) 0.02 ~) 1 2.93 107 3352 t) 0.03 11 5 .94 108 3382 (~ 0.02 £3 1 .92 109 3413 a 0.03 I1 2 2.94 110 3442 n 0.03 I1 ? 2.95 111 3471 t) 0.02 ~) 5 2.94 112 3502 a 0.03 l i _' 2.94 Shallow corrosion. 113 3534 t) 0.02 ~) ~ 2.94 114 3565 n 0.02 9 u 2.92 115 3597 U 0.04 14 I 2.94 Shallow corrosion. 116 3628 a 0.03 12 2.94 117 3659 U 0.04 15 I 2.93 Shallow orrosion. 1 8 3690 t) 0.03 11 ? 2.91 119 3721 l) 0. 4 14 1 2.93 Shallow ittin . 120 3751 t) 0.02 ti I 2.93 121 3783 0 0.02 9 _' 2.93 12 3814 U 0.02 ~) t) .95 123 3845 t) 0.02 ~) ; 2.93 124 3877 I ~ 0.03 1 U 1 2.94 125 3907 (~ 0.04 I (~ I 2.93 Shallow ittin . 126 3939 t~ 0. 3 I 4 2.93 Shallow ittin . 127 3969 l~ 0.04 15 ~) 2.90 Shallow ittin . 128 4000 l) 0.03 13 ; 2.94 Shallow corrosion. 129 4031 t) 0.04 14 ? 2.93 Shallow corrosion. 130 406 l) 0.03 I~ ~ 2.94 131 4094 t l 0.03 1 1 t ~ 2.92 13 4125 U 0.03 11 I 2.93 133 4156 t) 0.03 I Z I 2.92 134 4187 t) 0. 3 1:3 _' 2.92 Shallow ittin . 135 4218 l1 0.02 ~) 1 2.92 136 424 0 0.03 12 3 2.91 137 4280 0 0.02 9 2 2.91 138 4310 tl 0.03 12 2.92 139 4342 ~) 0.03 12 ~' 2.94 140 4373 !~ 0.03 11 ~' 2.92 141 4403 t) 0.04 I ~~ <' 2.94 Shallow corrosion. 142 35 t) 0.02 ~~ i) 2.94 143 44b6 a 0.03 1 Z i 2.94 144 4497 l1 0.01 E~ 2.95 145 4528 U 0.04 14 4 2.95 Shallow ittin . 146 4560 !! 0. 4 14 .93 Shallow ittin . 147 4590 ' 0.03 I S -1 2.96 Shallow ittin . _ Penetration Body Metal Loss Body Page 3 PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf L-80 Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: iLATION SHEET 2 N-349A Kuparuk Conoco Phillips Alaska, Inc USA April 13, 2008 Joint No. Jt. Depth (Ft.) I'~~n. Ill»ct (Ins.) Pen. Body (Ins.) f'r~n. `%, ~h~t,~l loss ~> Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 148 4622 t) 0.03 L. I 2.93 Shallow i tin . 149 4653 tt 0.02 '~ t~ 2.92 150 4684 a 0.03 I _ I 2.94 151 4716 t) 0.03 1 ~ ~ ~ 2.92 15 4747 a 0.02 9 - 2.95 153 4779 U 0.02 '~ Z 94 154 4810 a 0.03 II 4 2.95 155 4842 t l 0.02 ') 1 2.91 156 4871 U 0.03 13 _' 2.93 Shallow ittin . 157 4903 tt 0.02 ~) ; 2.96 158 4934 t t 0.01 (~ 2.95 159 496 U 0.04 1 ~ I 2.92 Shallow ittin . 160 4997 a 0.03 l u _~ 2.92 161 502 9 t t 0.02 ~) ; 2.95 162 5060 tt 0.04 15 2.93 Shallow ittin . 163 5092 t ~ 0.03 1 t~ _a 2.95 164 5123 ~? 0.04 17 a 2.92 Shallow corrosion. 165 5155 ~ t 0.03 l I 2.93 Shallow corrosion. 166 5186 tt 0.04 14 I 2.93 Shallow ittin . 167 5217 t 1 0.02 ~> t t 2.91 168 5249 t t 0.02 ~) 2.94 169 5 8 it 0.04 14 I 2.93 Shallow ittin . 170 5312 t t 0.03 1 1 !) 2.91 171 5343 a 0.03 1 3 -t 2.94 Shallow ittin . 172 5375 O 0.03 I2 2.92 173 5405 tt 0.03 II I 2.95 174 543 7 U 0. 2 ~ t _' 2.92 175 5468 U 0.02 t3 2.94 176 5500 tt 0.02 ~> ; 2.95 177 5531 tt 0.03 1 ; I 2.93 Shallow ittin . 177.1 5562 (t 0 l) U 2.81 Slidin Sle ve 178 5565 tt 0.02 ~) > 2.95 178.1 5599 U 0.02 ti I 2.93 PUP 178.2 5603 t t 0 li a N A GLM 1 Not Available 178.3 5610 tt 0.03 11 ~ 2.90 PUP 179 5617 t t 0.02 ~t ~~ 2.95 179.1 5649 t t 0 U U 2.75 D Ni le 179.2 5651 (t 0.01 .3 tt 2.95 PUP 179.3 5656 u 0 t) it 2.95 Seal Assembl 179.4 5672 t t 0 U ~ ~ 2.95 Fnd of Tobin Tail 179.5 5674 t t 0 0 t t 3.50 Casin Seal Rece to le 179.6 5678 t? 0.03 1 I i t 2.93 PUP First oint of 3.5" Casin 179. 5688 a 0.03 I U 2.92 PUP 179.8 5696 t? 0.02 ~~ 1 2.92 PUP 180 5704 U 0.03 13 .~ 2.95 Shallow ittin . 181 5735 t t 0.02 ~) 3 2.95 182 5766 It 0.03 I1 2.93 183 5798 t t 0.02 ~? r t 2.89 184 5827 tt 0.02 - ! 2.94 Marker oint. 185 5837 t? 0.03 II 2.92 _ Penetration Body Metal Loss Body Page 4 PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • iLATION SHEET 2 N-349A Kuparuk ConocoPhillips Alaska, Inc USA April 13, 2008 Joint No. Jt. Depth (Ft.) I'c~n. IJI~u~~ (Inti.) Pen. Body (Ins.) Pen. %, 'vlci,il Icnti ~~ Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 186 5868 t ~ 0.03 1 u 2.92 187 5900 t t 0.03 11 _' 2.93 188 5931 t~ 0.10 41 ~> 2.90 Perforations. Lt. De osits. - 189 5963 t~. I ~ 0.13 52 I I 2.92 Pe orations. Lt D osits. 190 5994 t ~.t ~(~ 0.26 I t )i ~ 2.82 Perforations. Bend. 191 6024 t).lJti 0.21 t91 ~~ 2.93 Perforations. Lt De sits. 192 6055 U 0.06 14 I 2.93 Perforations. 193 6087 t~.US 0.04 1 ~ 2.93 Shallow corrosion. 194 61 18 t 1 0.03 13 t ~ 2.93 Shallow corrosion. _ Penetration Body Metal Loss Body Page 5 ConocoPhillips Alaska, Inc. • KRU 2N-349A 2N-349A API: 501032034501 Well T e: INJ An le TS: de SSSV T : NIPPLE Ori Com letion: 9/182000 An le TD: 36 d 6498 Annular Fluid: Last W/O: Rev Reason: TAG FILL NIP (503-504 Reference L Ref Lo Date: Last U ate: 5/19/2007 , OD:3.500) Last Ta : 6276' RKB TD: 6498 ftKB TUBING Last Ta Date: 5/182007 Max Hole An Is: 37 de 6143 (°x674, Casin Strln -ALL oD:3.500, ID 2 992 Descri lion Size To Boo TV D Wt Grade Thread . ) : CONDUCTOR 16.000 0 118 118 62.50 H-40 W ELDED SURF CASING 7.625 0 2330 2310 29.70 L-80 BTCM PROD CASING 5.500 0 5777 5175 15.50 L-80 BTC-MOD SLEEVE PROD CASING 3.500 5777 6490 575 0 9.30 L-80 8RD EUE (5564-5565, I ~ Tubin Strin -TUBING OD:3.5o0) Size To Bottom ND Wt Grade Thread PROD 3.500 0 5674 5091 9.30 L-80 8RD EUE CASING (0-5777, perforations Summa oD:5.5o0, Interval TVD Zone Status Ft SPF Date T e Comment Wt:15.50) 5940 - 5962 5308 - 5326 O 22 6 10/17/2000 IPERF 2.5" HSD' w/31J UJ 5990 - 6010 5349 - 5365 O 20 6 10/17/2000 IPERF 2.5" HSD' w/31J UJ 6020 - 6030 5373 - 5381 O 10 6 10/172000 IPERF 2.5" HSD' w/31J UJ Gas urt Gas Lift Mandreis/Valve s irWreUDUmmy St MD ND Man Mfr Man Type V Mfr V Type V OD Latc h Port TRO Date Run Vlv valve 1 Cmnt (5606-5607, OD:4 725 1 5606 5035 CAM CO KBG 2-9 DMY 1.0 DCK 0.000 0 9/172000 . ) Other lu s e ui .etc . -JEWELRY De th ND T e Descri lion ID 503 503 NIP Camco'DS' Ni le w/No-Go rofile 2.875 5564 5001 SLEEVE Baker CMU Slidin Sleeve w/2.812 Camco rofile 2.812 5650 5071 NIP Camco 2.75'D' Ni le No- Go rofile 2.750 NIP 5658 5078 CSR Baker Cs Seal Rece tacle Size 800 3.500 (5650-5651, 3 50 5673 5090 TTL Tubin Tail 2.992 . OD: 0) 5677 5093 XO 5.5 BTCM Box x 3.5" Crossover 3.500 6365 5649 CPC Wethertord CementPlu Catcher 0.000 CSR (5658-5659, OD:5.500) TTL (56735674, OD:3.5D0) XO (5677-5678, OD:5.500) Perf (5940.5962) Pert (5990.6010) CPC (6365-6366, OD:3.500) PROD CASING (5777-6490, OD:3.500, Wt:9.30) . . ~ ConocoPhillips Alaska RECEIVED SEP 1 2 2007 Atlaka O¡I & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 09,2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 f'I\MNED SEP 12 2007 Anchorage, AK 9950 I 5.",ul JDO-13Q aN~ "34-q Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped on September 8, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call M.J. Loveland at 907-659-7043, if you have any questions. :2¥-~' ConocoPhillips Well Integrity Field Supervisor . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 9/9/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitorl Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft aal 2N-327 207-069 12" n/a 12" n/a 3.5 9/8/2007 2N-329 198-067 24" n/a 24" n/a 6 9/8/2007 2N-331 198-117 26" n/a 26" n/a 2 9/8/2007 2N-332 200-079 8" n/a 8" n/a 2 9/8/2007 2N-333 206-025 29" n/a 29" n/a 8.5 9/8/2007 2N-349 200-139 3" n/a 3" n/a 1 9/8/2007 2N-350 201-175 11" n/a 11" n/a 4.5 9/8/2007 2P-438 201-082 4' 10" n/a 4' 10" n/a 2 9/8/2007 06/08/07 Schlumberger NO. 4286 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ], 120m 8, (i~" Gnl'l!t c{1mm¡s~i~NE.D JUN 1 4 2001 ~v Field: Kuparuk Ù Ie... {;JOÖ - l3D¡ Well Job # Color CD Log Description . i.._ Date._, ,. "....... "..~...,~.~...t:::~."..,<;;......~- BL 2L-321 11629010 MULTI-FINGER CASING INSPECTION 05/12/07 1 2C-16 11629008 PPROF/LDL 05/10/07 1 2G-11 11638863 PRODUCTION PROFILE 05/05/07 1 1C-125 N/A MEM INJECTION PROFILE 05/05/07 1 2D-13 11638861 PRODUCTION PROFILE 05/03/07 1 2D-08 11638862 PRODUCTION PROFILE 05/04/07 1 2G-09 11638864 PRODUCTION PROFILE 05/06/07 1 2N-349A 11629004 RST/ WFL 05/04/07 1 3H-19 11638867 PRODUCTION PROFILE 05/09/07 1 1Q-10 11628771 MEM PRODUCTION PROFILE 05/03/07 1 1 E-11 11629012 INJECTION PROFILE 05/14/07 1 2L-321 11665439 USIT OS/25/07 1 2V -08A 11629013 PM IT 05/15/07 1 1 J-160 11632704 PRODUCTION PROFILE 03/19/07 1 1 H-07 11665436 SBHP SURVEY OS/20/07 1 2F -11 11665434 PRODUCTION PROFILE 05/19/07 1 2X-07 11665433 INJECTION PROFILE 05/18/07 1 1 B-01 11665432 PRODUCTION PROFILE 05/17/07 1 2X-01 11637338 INJECTION PROFILE 05/15/07 1 2Z-29 11665438 PRODUCTION PROFILE OS/22/07 1 1 H-22 11637339 INJECTION PROFILE 05/16/07 1 1 Y -11 11632708 INJECTION PROFILE OS/23/07 1 1G-03 11637336 INJECTION PROFILE 05/14/07 1 1A-23 11665443 MEM PRODUCTION PROFILE OS/29/07 1 1 F-08 11665435 SBHP SURVEY OS/20/07 1 1J-170 11632709 INJECTION PROFILE OS/24/07 1 1D-109 N/A INJECTION PROFILE 05/13/07 1 2M-24 11665440 SBHP SURVEY OS/28/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~ , , ~7 ' 0,,1 ( y¡,¡ [y,-; ,/ I{!I!' V "' ~ !~-r DATE: Wednesday, August 09,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2N-349A KUPARUK RIV U TARN 2N-349A ~b 0 - ~ :3 OJ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv "w;, ¡¿--, ~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U TARN 2N-349 API Well Number 50- I 03-20345-0 I -00 Inspector Name: Chuck Scheve ^ Insp Num: mitCS060808 I 92654 Permit Number: 200- 139-0 Inspection Date: 8/8/2006 ReI Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ! 2N-349A ¡Type Inj. : 'Vi ! TVD I -- 5078 ! IA I 1000 ! 2650 ! 2610 2600 ! I ' I I ! I I P.T. I 2001390 :TypeTest I SPT i Test psi 1500 I OA I 250 ! 300 I 300 300 I I i i ,----+- ./ Tubing I 1800 I 1800 I 1800 1800 I Interval 4YRTST P/F P I I ..-- I ,- Notes Pretest pressures were observed and found stable, Well demonstrated good mechanical integrity, SCANNED AUG 2 4 2006 Wednesday, August 09, 2006 Page I of I MEMORANDUM ) State of Alaska ) Alaska Oil and Gas Conservation Commission FROM: Chuck Scheve Petroleum Inspector DA TE: Wednesday, November 09,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHJLLIPS ALASKA INC 2N-349A KUPARUK RIV U TARN 2N-349A C' n'" \3 ~Ùv TO: Jim Regg ï7 ¡¡(c:( . ,/ hé~.:C1l' I 't U '" P.I. Supervisor (. Src: Inspector Reviewed By: P.I. Suprv jBß- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U TARN 2N-349 API Well Number 50-103-20345-01-00 ^ Insp Num: mitCS051108062418 Permit Number: 200-139-0 Rei Insp Num Inspector Name: Chuck Scheve Inspection Date: 1116/2005 Packer Depth Pretest Initial 15 Min. 30 Min. f ;~!t :::~~~~~::;:~:T:~~ps~T--,:::85 -T~: _II,___~~__L - ·___~O~-+_-2~¡--+--2::: Interval 4YRTST PIF P Tubing 1700 1700 1 1700 I 1700 __..._____.__._____._..... ___.__m________.__.._.L.______ _____.______.__._._._...___ _...__._.._...___..........____ 45 Min. 60 Min. -.--"----- . ---.--- I -.,....-,-.- _.'_.~-_. Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. ~CANNED NOV 1 7 20G5 Wednesday, November 09,2005 Page I 0 f 1 F:\LaserFiche\CvrPgs _I nserts\M icrafil m _ Marker.doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ) ) "--" ~ , ( I! , ;>00- \ '~'\ , , MECHANICAL INTEGRITY REPORT' ""- , CasiTIg: -<~\>.x.\ :.---..~e.:... : OPER & FIELD -c..V ~ \t-ù ~\ -:, ~ ~\'" "W""ELL NUKB toR ð ~ - ~\.-.\ '; ~ d).:J .- Sl.-\ ~ ;)--00'- \ \ \ Tn: lO~~B.11D" 5"'S~ TVD; ?ETD: b~Ç ~ S~Lt'LTVD S \ ~' Shoe: 5~'ì.LHD TVD i DV: \-J~' l1D .Tvl) '/.... '"2.y ~ '::> Sho e : <0 ~<;. \ MD , t.~Q . :\Joi:::g: J "/...., Packe:!:" S~S)(21D ~ole Size ~ ~/~ anå '; ¡, U D 7"', ':':-; . q ,/ \ "" -',-........ U~ - - 1.J .-. _:.- .' \ '-..J :~1:G REL~;_S::::. c;lv'ö --00 : ""FLL D ^ T ,. ,~~ r-.. _:'. TVD j :OP: Sc'ì\J-m --~ .-;¡ ;. ,¡ l.J TVD i Set: ê. t ¡Perfs -~~Q to Co 0 -)Û." i g t:EC?_Alnc:..L INTEGRITY - PART fl t ~~ Annulus Press Test: ~p 14.' if f Co=e~ts: Jo"'-c--..~\c".~ 2,;,/7.;-0 \ i~f Ivþ ~,r-., L. Cu A N-, C A- ¡ n ""I to l1..t". ~..J... INTEGRITY - PART /2 iLú¡{.-- -- 11-]-- " Cement Volumes:' þ...mt. Liner ~ ., I~~ ?) J?J I~J 1 ~ tJ-r.eJ i..9 ~(j1 " \Ohb-OÙ if ~Lð ~ Cement Bond Log (Yes or No) .~ ~... ; In AOGCC File ,\,~:> , ,,;) ~ -9 eEL ::valuation, zone above perfs ~~\ 0-.-( ì.", ':) \/~'-( :ß' \J ~ \"\ ",.) ,. '.--~] ~ '"" W-~~ ~ 'tJO\.'7~c)' ~ 9 21 Proàuc.tion Log: Type 1]1¿t . 1 P "1CONCLUSIONS : ' r"' ~ ~~?art n: "^,,-s:-üc..,,,>Cà...~~\IT~J Ii> ~I-? a r '.: : 2 : K.I' \"è:> '! ~ t (;: ( J..~~~ ;; I ç 0'-\ ~CÁ~NE[) FEB 0 9 2004 ¡ 15 min 3 0 min ,..- í ~ ~~~~~,~~ ~Ö"T . ; Csg ,\ ~ L ; DV ~ ~ . , ' CÜjt ~o 1 to cove:!:" Der£ s ' ç¡ "s C)(A:"-) '1' ~ 'c) \ (., '5)"'f..,. 0'\ \Q,\ ~ S> ~~'\ <::\1"<6'-. -\ ..\0 ~,\.~. ~... I ':\' \ -\~\. . . . Theore tical TOC 'Th,\ Cx~R~ ~_..i.~c..~\ð~R::~È\ (.g~~')<¡_O Evaluation Permit to Drill 2001390 MD 6498 TVD ,.~-- DATA SUBMITTAL COMPLIANCE REPORT 1116~2003 Well Name/No. KUPARUK RIV U TARN 2N-349A Operator CONOCOPHILLIPS ALASKA INC 5757 - Completion Dat 10/17/2000 ~- Completion Statu WAGIN Current Status WAGIN ! APl No. 50-103-20345-01-00 UIC Y REQUIRED INFORMATION Mud Log N__Qo Sample N.._Qo Directional Survey ~ _~_~--.~,-. _ - DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Log Log Run Name Scale Media No Interval Start Stop (data taken Eom Logs Portion of Master Well Data Maint OH I Dataset CH Received Number Comments Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y Chips Received? Analysis R~.~.iv~.d? Daily History Received? Formation Tops Comments: Compliance Reviewed By: Date: Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2840 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia CD Color IR-14 ITS-- i 5 i LEAK DETECTION LOG 01109103 1 2G-15 i ~q- I:~ J LEAK DETECTION LOG 01108/03 1 1G-11 1~-I~ | LEAK DETECTION LOG 01110103 1 1A-08 ! -/~--(~ LEAK DETECTION LOG 01107/03 1 2U-02 i]<~-OOC~ LEAK DETECTION LOG 01111103 1 2N-349A ~=~0 D-I~)C~ INJECTION PROFILE 12/20102 1 3S-09 ,~D~-c~O ~ JEWELRY LOG/PSP 12124102 1 lC-22 c::~C~-<~c2~c~ PERF RECORD & POST PERF SaHP 01117103 3S-10 ~ O~=~-~)~ PERFIJEWELRY/PSP 01115103 1 1Y-21 jc~.~. J(::)c~ STATIC PRESS/TEMP LOG 01/14103 1 1Y-34 jc~ ~.O¢~ I STATIC PRESS/TEMP LOG 01/t4103 I , F_.CEI 01/31/03 DATE: Please sign and return one copy of this transmittal to Beth at the ~bove address or fax to (907) 561-8317. Thank you. FEB 0 7 2003 Ala~ 0~ & Gas Cons. PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Naska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 January 16, 2002 Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West 7m Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kuparuk Area Annular Disposal, Fom~ Quarter, 2001 Dear Commissioner: Please find attached the report with the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2001, as well as total volumes disposed into annuli for which' disposal authorization expired during the fourth quarter of 2001. Please call me at 265-6830 should you have any questions. Sincerely, R. Thomas Greater Kupamk Team Leader RT/skad CC: Marty Lemon Mike Mooney Paul Mazzolini Chip Alvord Kuparuk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Well Files Annular Dis ~osal durin the fourth quarter of 2001: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-42 2193 100 0 2293 385 31314 33992 June October CD2-15, CD2-24, CD2-33 2001 2001 2P-417 5331 100 0 5431 0 627 6058 Sept 2001 December 2P-420, 2P-448 2001 CD2-24 2981 100 0 3081 375 30543 33999 July 2001 October CD2-15, CD2-33, CD2-39, 2001 CD2-14 1C-16 12338 100 0 12438 0 19679 32117 Sept 2001 October 1C-131, 1C-125, 1C-102 ~ 2001 CD2-39 27400 100 0 27500 379 0 27879 October November CD2-15, CD2-47 2001 2001 CD2-14 14359 100 0 14459 376 0 14835 November December CD2-45, CD2-47 2001 2001 1C-14 22389 100 0 22489 0 0 22489 Oct 2001 Nov 2001 1C-109' 2P-438 30331 100 0 30431 212 0 30643 Oct2001 Dec 2001 2P-420, 2P-415, 2P-429 ... CD2-15 0 0 0 0 371 0 ' 371 NA* NA* *Freeze protect CD2-15 only CD2-47 10315 100 0 10415 375 0 10790 Dec 2001 Dec 2001 CD2-34 Total Volume into Annuli ~or · ~,,~,, ~ o~u,,~=o u~u t~u~u~jut wnu,-n ~tzFuzut numort~uuon ~ptrea aurtng tnefourtn ~,~ner z~l: Fr~ Pro.ct To~i Volume S~ End Source We~ Total h(1) Total h(2) Total h(3) ~ui~ l~ec~. Da~ Da~ Well Name Volume Volume Volume Volume S~ of Annul~ 2L-313 26290 1~ 0 0 263~ O~n, F~'~o~c~ M~h 1999 ~ 2~ 2~317, 2~307 ~' 1D-36 301~ 1~ 0 0 302~ O~n, Fr~ ~omc~ ~t 2~ Nov 2~ ID~2, 1D-34 CD1-31 6698 1~ 0 392 7190 ~n, F~ ~o~cmd Feb 2~1 M~h CDI-14 2~1 · 2N-~5 0 0 0 380 380 O~n, F~ ~o~ NA** NA** ** ~ pro~t .. volumes only ... 1D-M 31915 1~ 0 218 '32233 Open, Fr~ ~omc~ Nov 2~ D~ 2~ ID-32, I~0A 2N-349A 0 0 0 0 0 ~en, F~ ~o~ ....... lDO2 32~0 1~ 0 265 32405 O~n, Free~ ~o~t~ D~ 2~ J~ 2~1 ID-37, 1D-39 Scblumlmrger NO. 1641 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Bird, Suite 300 Anchorage, AK-99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job if Log Description Date BL Sepia CD Color 2K-27 ... I~~~ STATIC BOTTOMHOLE PRESSURE 11/07101 I 1 2L-317A <~131~-,-~ It~ WATERFLOW LOG/RST-C W/PSP 11108101 1 1 2N-304 ~:~01- I~0- SBHP & JEWELRY LOG " 11117J01 I 1 2N-307 [c)~-Oi -J INJECTION PROFILE 11/09/01 I 1 2N-325 /c)~.../~) INJECTION PROFILE 11111101 I 1 2N-331 / 0) ~'-- I I"1 INJECTION PROFILE 11111/01 1 1 2N-343 / q~'-~)cT ~ INJECTION PROFILE 11/13/01 I 1 2N-349A --~)~)-~ INJECTION PROFILE 11113/01 1 I 11/26/01 DATE: RECEIVED 2. 2:001 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thanl~ Oil & GElS COilS. Commission Anch~age .. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Pedorate _ Pull tubing _ Alter casing _ Repair well _ Other_X 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 158' FNL, 1172' FEL, Sec. 3, T9N, R7E, UM At top of productive interval 166' FSL, 1928' FWL, Sec. 34, T10N, R7E, UM At effective depth At total depth 5042' FNL, 3666' FEL, Sec. 34, T10N, R7E, UM 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service__X (asp's 460421, 5911852) (asp's 458242, 5912188) (asp's 457925, 5912259) 6. Datum elevation (DF or KB feet) RKB 153 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2N-349A 9. Permit number / approval number 200-139 / 10. APl number 50-103-20345-01 11. Field / Pool Kuparuk River Field / Tarn Pool 12. Present well condition summary Total depth: measured true vertical 6498 5757 feet Plugs (measured) feet Effective depth: measured true vertical Casing Length Size CONDUCTOR 118' 16" SURF CASING 2177' 7-5/8" PROD CASING 5624' 5-1/2" PROD CASING 713' 3-1/2" PROD CASING 6365 5649 feet Junk (measured) feet Cemented 9 cu yds High Early 430 sx AS III Lite, 240 sx Class G 113 sx Class G, 350 sx Class G (included above) Measured Depth TrueverticalDepth 118' 118' 2330' 2310' 5777' 5094' 6490' 5750' Perforation depth: measured 6020' - 6030', 5990' - 6010', 5942' - 5962', 5940' - 5942' true vertical 5373' - 5381', 5349' - 5365', 5310' - 5326', 5308' - 5310' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg O 5674' MD. Packers & SSSV (type & measured depth) casing Seal Receptacle O 5658' MD. CAMCO 'DS' NIPPLE W/NO-GO PROFILE @ 503' MD. RF_CE VED NOV 1 2001 Alaska 0il & Gas Cons. Commissio~ Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily AveraRe Production or Injection Data Gas-Md Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X Oil ._ Gas __ Suspended Service _Water ,njector___~ {~llk~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Peter Nezaticky ~'~ / Title Wells Supervisor Form 10-404 Rev 06/15/88 · ORIGINAL Questions? Call Peter Nezaticky 659-7224 Date 11/12/01 Prepared by Sharon AIIsup-Drake 263-4612 SUBMIT IN DUPLICATE PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2N(W4-6)) WELL JOB SCOPE JOB NUMBEd ' " 2N ANN-COM M 1107011721.4 DATE DAILY WORK UNIT NUMBER 11/08/01 OOA CEMENT TOP JOB 2N-303, 317, 343, 349 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR I YESI YES APC-AREND NEZATICKY FIELD AFC# CC# DAILY COST ACCUM COST Signed ESTIMATE K85329 35TN2N1 NG Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 0 PSI 0 PSI 0 PSII 0 PSII 0 PSI DAILY SUMMARY CEMENT TOP JOBS ON THE SURF X COND (OOA). 2N-303, 317, 343, 349.[WH Maintenance] TIME LOG ENTRY 11:00 ON LOC. MIRU 12:00 PRE-JOB SAFETY MEETING. START MIXING CEMENT. 12:30 12:45 CEMENT MIXED, 6 BBL OF 15.7 PPG ARTIC SET. START PUMPING CEMENT DOWN 2N-303 SURF X CONDUCTOR ANNULUS (OOA) THROUGH 1" HOSE TAKING RETURNS TO VAC TRUCK, PUMPED 5 BBL. START MIXING 4 BBL OF CEMENT. 13:00 CEMENT MIXED MOVED TO 2N-343.' PUMPED 2 BBL INTO A 6 FT VOID. 13:25 MOVED TO WELL 2N-349. PUMPED 1 BBL INTO A 7.5 FT VOID. 14:00 DUMPED 5 GAL OF CEMENT INTO 2N-317. SMALL 8 INCH VOID, BUT PREVIOUSLY REPORTED SOFT MATERIAL WHEN TAGGED. 14:30 RDMO NOV Alaska 0il & Gas Cons. Commissiop Anchorage SUNDRY NOTICE 10-404 Phillips Kuparuk Well 2N-349 Annular Cement "Top-Job" November 08, 2001 Phillips Alaska, Inc., Kuparuk well 2N-349 surface casing has "grown" several inches to the point where the casing hanger was no longer contacting the conductor pipe. The cement top between the surface casing and conductor pipe (7 5/8" x 16") was measured at 7.5 feet below grade. Arctic Set I cement (15.7 ppg) was pumped into the annular void (1 bbls) via a hose, filling from the bottom-up. The cement top was brought to the surface of the conductor pipe. 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. RECEIVED NOV i 5 ?~S!i! Alaska Oil & Gas Cons. Commis$ior~ Anchorage August 17, 2001 Chuck Mallary Drilling Engineering Supervisor Phillips Alaska, Inc P.O. Box 100360 Anchorage, Alaska 99510-0360 Request for Annular Disposal Authorization---Sundry Approval 301-219 Kuparuk River Unit (Tam) 2N-332 Phillips Alaska, Inc Permit No: 200-079 Dear Mr. Mallary: Enclosed is the approved sundry application for annular disposal operations in KRU (Tarn) 2N- 332. In addition to complying with the requirements and limitations of 20 AAC 25.080 (volume not greater than 35,000 barrels or disposal period greater than one year), the Commission is requiring that pressures be monitored on the surface casing annuli of wells 2N-331 and 2N-329 while waste is being disposed of into 2N-332. At a minimum, pressure readings should be taken before pumping begins, during disposal pumping and at the conclusion of a given batch. Please inform Tom Maunder at 793-1250 should the pressure monitoring indicate any communication between the wells. The pressure monitoring records should be submitted to the Commission with the normal quarterly report or sooner if the currently planned wells are finished. Sincerely, Julie M. Heusser Commissioner BY ORDER OF THE COMMISSION Dated this of August, 2001 jjc/Enclosures 3-Aug-01 AOGCC 333W 7th Ave Suite 100 Anchorage, AK, 99501 To whom it may concern, Included in this package are disks for the following final surveys as requested. · 2N-303, IFR and MWD 7.oO-t1¢,'~ · 2N-305, IFR and MWD · 2N-349, IFR and MWD ~.~o It t · 2N-349A, IFR and MWD ;Zec~t~ If you have any questions or concerns please do not hesitate to call. Regards, -Vic Eppler SSDS IFR/SMS (907) 273-3564 RECEIVED AUG 0 ? a)01 Annular disposal permits on 2N pad (Tarn) Snbject: Annular disposal permits on 2N pad (Tarn) Date: Fri, 6 Jul 2001 09:56:35 -0800 From: "Brian D Noel" <bnoel~ppco.com> To: tom_maunder~admin, state.ak.us Tom - As we discussed today, Nabors 16E is drilling 2N-302 (first of 4 wells planned for 2N pad). We were using 2N-318 annulus for disposal, but on 7/1/01 during routine pumping the annulus abruptly plugged. Since then have been pumping in diesel as pressure allows to freeze protect. We will be drilling out of 2N-302 surface casing this afternoon and have 7500' of hole to reach TD. On 2N pad there are 5 more wells permitted for annular disposal that have not exceeded the one year/35,000 bbls stipulation: 2N-305 %300-277 11/30/00 380 bbls 2N-316 %300-240 09/18/00 340 bbls 2N-332 %300-187 07/17/00 0 bbls (this should be +/-350 bbls for initial test & freeze protect, will check our records) 2N-347 %300-186 07/17/00 31,640 bbls 2N-349A %300-278 11/30/00 335 bbls Prior to initiation of disposal operations into any of the unused permitted annuli, the commission has requested additional information for review. To expedite this review, have selected 2N-316 as our next choice. The majority of wells within 1/4 mile radius of 2N-316 are the same as those included in the 2N-318 additional data package reviewed in January 2001. I am gathering data on four other wells (three of which were permitted for annular disposal in the past). Attached are the LOT's, casing record and morning report summary for 2N-316. Please note that on 2N-316 mud broached'around the conductor as surface hole reached TD'd. Surface casing was run and cemented to surface and LOT's indicate shoe integrity. The production hole was then drilled to TD. I will send over paper copies of data for all the wells within 1/4 mile of 2N-316 surface shoe today. (See attached file: 1ST LOT CIT 2N 316 7 13 00.xls)(See attached file: ANNULAR LOT 8 6 00 2N-316 rev by TJB 9 8 00.xls)(See attached file: 2N-316 7_625 Csg Tally & Detail.xls)(See attached file: 2n-316 morning reports.xls) Thanks - Brian 265-6979 ~-~IST LOT CIT 2N 316 7 13 00.xls Name: 1ST LOT CIT 2N 316 7 13 00.xls Type: EXCEL File (applieation/msexcel) Encoding: base64 I'~-~ANNULAR LOT 8 6 00 2N-316 i Name: ANNULAR LOT 8 6 00 2N-316 rev by TJB 9 8 00.xls rev by TJB 9 8 O0.xlsIType: EXCEL File I (application/msexcel) IEncoding: base64 1 of 2 7/12/2002 2:02 PM Annular disposal permits on 2N pad (Tarn) [~-~2N-316 7_625 Csg Tally & Detail.xls Name: 2N-316 7_625 Csg Tally &Detail. xls Type: EXCEL File (applieation/msexcel) Encoding: base64 ~2n-316 morning reports.xls Name: 2n-316 morning reports.xls I Type: EXCEL File (application/msexcel) I Encoding: base64 2 of 2 7/12/2002 2:02 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Change approved program _ Pull tubing _ Variance _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: 6. Datum elevation (DF Development _ RKB 153 Exploratory _ 7. Unit or Stratigraphic _ Service__X Kuparuk Ri' Unit Location of well at surface 158' FNL, 1172' FEL, Sec. 3, T9N, R7E, UM At top of productive interval 166' FSL, 1928' FWL, Sec. 34, T10N, R7E, UM At effective depth (asp's 460421, 5911852) (asp's 458241.5, 5912187.5) At total depth 5042' FNL, 3666' FEL, Sec. 34, T10N, R7E, UM (asp's 457925, 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 118' SURF CASING 2177' PROD CASING 5624' PROD CASING 713' PROD CASING Size 16" 7-5/8' 5-1/2" 3-1/2" 6498 feet 5757 feet 6365 feet 5649 feet Plugs Jun 9 cu Early III Lite, 240 sx Class G : Class G, 350 sx Class G uded above) Other_X Annular Disposal 8. Well 2N. )er / approval number I-103-20345-01 Pool Field / Tarn Pool Measured Dep~ 118' 2330' 5677' 6490' True vertical Depth 118' 2310' 5094' 5750' Perforation depth: measured 5942'-5962', 5940'-5942' RECEIVED true vertical 5373' 5349'-5365', 5310'-5326', 5308'-5310 Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 13. Attachments Description 14. Estimated date for September 14, 16. If 17. I hereby certify Signed Chuck 3-' 9.3#, L-80 Tbg O 5674' MD. CSR CAMCO 'DS' NIPPLE W/NO-GO PROFILE O 503' MD. SEP 1 1 2001 Alaska Oil & Gas Cons. Commission Anchorage operation proposal _~( Detailed operations program __ BOP sketch __ ............................ 15. Status of well classification as: best of my Conditiol of approval: Notify Commission so I Plug Integrity _ BOP Test _ Mechanical Integrity Test _ '"' Approved by order of the Commission ,, , Oil __ Service Drilling Engineering Supervisor FOR COMMISSION USE ONLY may witness Location clearance_ Subsequent form required 10- Gas _ Suspended _ Questions? Call Brian Noel 265-6979 Pre, aredb~/sDhaartoenAlls~:e~2638~d r') i ~, i O,,, INAL Commissioner Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLI CATE Annulus Disposal Transmittal Form Designation of the well or wells to receive drilling wastes: The depth to the base of freshwater aquifers and if present: ~, stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission finding that the waste will be confined and will not come to the surface or contaminate freshwater. A list of all publicly recorded wells within one-quarter mile and all publicly recorded water wells within one mile of the well to receive drilling waste: Identify the types and maximum volume of waste to be disposed of and the estimated density of the waste slurry: An estimate of maximum anticipated pressure at the outer casing shoe during annular disposal operations and calculations showing how this value was determined: Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to provide zone isolation: Details that show the inner and outer casing strings have sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: Any additional data required by the Commission to confirm containment of drilling wastes: 2N-349A No Aquifers / Base Permafrost = +/-1,200 TVD RKB 7-5/8" surface casing set in the Cretaceous shales of the Colville Group below the West Sak sands. From the 7-5/8" shoe to the top of cement on production casing shale and minor non-hydrocarbon bearing sands are exposed. Ten wells on 2N pad - See attached map. There are no potable water wells within one mile of 2N-349A. Types of waste can be drilling mud, drilling cuttings, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well and any added water needed to facilitate pumping of drilling mud or drilling cuttings. Maximum volume to be pumped is 35,000 bbls. Maximum anticipated pressure at casing shoe during disposal operations is 1,944 psi. See attached calculation page. See attached: cementing reports, LOT / FIT reports and casing reports for 2N-349A and the ten wells within 1/4 imile radius. See attached: casing summary sheet and calculation pages. Sperry-Sun Drilling Services Horizontal Distance Proximity Scan on Current Survey Data (North Reference) Reference Survey: Kuparuk 2N- 2N-349A (and Parent Profiles) Single Point Scan at 23fg.00ft. Measured Depth. Scan Radius is 1320.00ft. Kuparuk River Unit Comparison Well Name - Profile Name Reference Well C o m p a r i s o n W e I I Measured Vertical Measured Vertical Depth Depth Depth Depth Northings (ft) (ft) (ft) (ft) (ft) Kuparuk 2N 2N-309 - 2N-309 2319.00 2299.93 2580.94 2299.93 903.50 N 2N-317 - 2N-317 2319.00 2299.93 2660.44 2299.93 830.69 N 2N-318 - 2N-318 2319.00 2299.93 2586.86 2299.93 660.07 N 2N-319 - 2N-319 2319.00 2299.93 2422.43 2299.93 403.03 N 2N-320 - 2N-320 2319.00 2299.93 3234.03 2299.93 732.74 N Eastings (ft) North Slope, Alaska Kuparuk 2N Proximity Relative Relative Distance North (ft) Direction 360.17 E 1046.46 32.36 221.40 W 811.44 358.48 338.08 W 655.27 347.83 25.81 E 445.00 30.48 1188.67 W 1219.14 305.80 2N-325 - 2N-325 2319.00 2299.93 2623.84 2299.93 468.29 N 469.59 W 523.55 329.00 2N-335 - 2N-335 2319.00 2299.93 2379.26 2299.93 202.44 S 47.23 W 269.41 145.48 2N-337 - 2N-337 2319.00 2299.93 2815.08 2299.93 774.14 S 731.98 W 955.52 213.84 2N-339 - 2N-339 GYRO 2319.00 2299.93 2945.29 2299.93 717.50 S 1143.24 W 1197.11 232.00 2N-345 - 2N-345 2319.00 2299.93 2769.10 2299.93 243.85 S 1085.42 W 923.85 253.44 2N-349 - 2N-349 2319.00 2299.93 2319.00 2299.93 19.53 N 199.92 W 0.00 98.57 All station coordinates were calculated using the Minimum Curvature method. All data is in feet (us) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Coordinate System is NAD27 Alaska State Planes, Zone 4, US Foot. Grid Convergence at Surface is -0.300°. Profile Sections Survey: 2N-349 from 0.00 to 2477.79ft. Survey: 2N-349A from 2477.79 to 6498.00ft. 3 July, 2001 - 15:51 Page 2 of 2 DrillQuest 2.00.09.001 WELLS W/SURFACE CASING SHOE (+/- 2300' TVD) WITHIN 1/4 MILE 2N-349A Wells I Permit # I Permit DateI Cement ReportI Casing Tally I No. of LOTI Source well I Ann. Vol. I Start DateI End DateI · x x I 0 398-251 09/25/98 x x I 2N-317(see note B) 106 Audi-98 300-239 09/13/00 x x 2 2N-314, 2N-302 17578 12/01/00 Jul-01 x x 2 0 x x 2 0 398-304 11/25/98 x x 2 !2N-325 (see note C) 150 Sep-98 398-310 11/25/98 x x 2 see note A 25495 Jul-00 Sep-00 398-182 07/17/98 x x 2 2N-331, 2N-325, 2N-321 30639 Aug-98 Sep-98 x x I 0 398-217 08/28/98 x x 2 0 2N-309 2N-317 2N-318 2N-319 2N-320 2N-325 2N-335 2N-337A 2N-339 2N-345 A) source wells were 2N-349 (4598), 2N-316 (5771), 2N-318 (15126) B) freeze protect and LOT volumes only C) freeze protect volumes only d c CtI .:ar:: ~ ~ =ij'~ 0 fA « ~.~ . m <liZ ¡~ <ë g.~/~ ~ W ~.. .:i:..' --~= € <~ =- ~f' ,20°å:. Z .' ---- ~ c: ('(1 t1 (5 I '" íIJ Well 2N-349A Date 7/24/01 TVD 2310 ft. ,,,,, Surface Intermediate Surface Casing Size 7.625 In. Wt. 29.70 lbs. Grade L 80 Pburst @ 100% 6890 psi Pburst @ 85% 5857 psi Fluid Weigth on Backside 8.3 ppg Max Disposal Pressure 1500 psi Maximum Mud Weight = 44.6 ppg (to burst casing) Surface Casing Burst MMW = Pb@85%+(Fluid Weight on Backside)(.052)(TVD)-Max Disposal Press (.052)(TVD) Maximum Pressure at Surface Shoe Max Disposal MW Max Pressure at Surface Shoe = 12.0 ppg 1944 psi Max Pressure at Surface Shoe Max Press=Max Disposal Press+(Max Disposal MW)(.052)(TVD)-(Fluid Wt. On Backside)(.052)(TVD) Intermediate Casin.q Size 5.500 In. Wt. 15.50 lbs. Grade L 80 Pcollapse @ 100% 4990 psi Pcollapse @ 85% 4242 psi Gas Depth (TVD) 2311 ft. Gas Gradient 0.11 ppg Max Disposal Pressure 1500 psi Maximum Mud Weight = (to collapse casing) 24.9 ppg Intermediate Casing Collapse MMW = Pc@85%+(Gas Gradient)(Gas TVD)-Max Disposal Press (TVD)(.O52) 13-Jun-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Surveys Re: Distribution of Survey Data for Well 2N-349A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 2,477.79' MD 2,520.00' MD 6,498.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED JUN 1 4 ~.001 ~ou'! 07 DEFINITIVE Kuparuk River Unit North Slope, Alaska Kuparuk 2N, Slot 2N-349 2N-349A Job No. AKZZfOf69, Surveyed: f$ April, 2000 SURVEY REPORT 13 June, 2001 Your Reft AP150fO3203450f Surface Coordinates: 59ff852. f2 N, 460420.86 E (70° fO' 12.4084" N, Kelly Bushing: f 53. fOft above Mean Sea Level 150°fg'O6.7f85"tllO ORILLIN(~i S:E RV I EE.~ Survey Ref: svy9563 A Halliburton Company Sperry-Sun Drilling Services Survey Report for 2N-349A Your Ref: AP1 501032034501 Job No. AKZZlOf69, Surveyed: f5 April, 2000 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2477.79 20.880 272.232 2295.41 2448.51 2520.00 21.170 272.830 2334.81 2487.91 2574.30 22.810 277.380 2385.16 2538.26 2637.40 24.900 278.900 2442.87 2595.97 2732.90 28.750 280.260 2528.08 2681.18 2826.48 31.670 277.880 2608.94 2762.04 2921.46 32.470 277.080 2689.43 2842.53 3016.96 34.490 279.690 2769.08 2922.18 3111.85 34.920 279.340 2847.09 3000.19 3204.84 35.080 279.840 2923.26 3076.36 3300.61. 35.000 279.770 3001.67 3154.77 3394.91 35.160 281.060 3078.85 3231.95 3489.86 35.120 280.160 3156.49 3309.59 3585.56 34.890 279.250 3234.88 3387.98 3680.29 34.830 280.490 3312.61 3465.71 3774.95 34.820 278.580 3390.32 3543.42 3868.97 35.820 280.110 3467.04 3620.14 3964.09 35.950 279.300 3544.10 3697.20 4060.56 36.140 280.050 3622.10 3775.20 4153.60 36.020 279.750 3697.30 3850.40 4248.23 35.710 280.240 3773.99 3927.09 4342.94 35.480 278.790 3851.00 4004.10 4437.95 35.550 279.980 3928.34 4081.44 4531.75 35.690 279.190 4004.59 4157.69 4626.66 35.850 279.890 4081.59 4234.69 4721.14 36.030 280.070 4158.09 4311.19 4815.49 35.920 279.700 4234.44 4387.54 4910.05 36.200 279.860 4310.89 4463.99 5005.27 36.440 281.290 4387.61 4540.71 5100.18 36.190 279.500 4464.09 4617.19 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 23.83 N 255.75W 5911877.28 N 460165.24 E 24.49 N 270.88W 5911878.03 N 460150.11 E 26.33 N 291.11W 5911879.97 N 460129.89 E 29.96 N 316.37W 5911883.73 N 460104.65 E 37.16 N 358.85W 5911891.16 N 460062.21E 44.54 N 405.34W 5911898.78 N 460015.76 E 51.10 N 455.34W 5911905.60 N 459965.79 E 58.81 N 507.44W 5911913.59 N 459913.73 E 67.74 N 560.72W 5911922.79 N 459860.50 E 76.63 N 613.31W 5911931.96 N 459807.95 E 85.99 N 667.50W 5911941.60 N 459753.82 E 95.79 N 720.80W 5911951.68 N 459700.57 E 105.85 N 774.51W 5911962.02 N 459646.91 E 115.11N 828.62W 5911971.56 N 459592.85 E 124.39 N 881.97W 5911981.12 N 459539.56 E 133.34 N 935.27W 5911990.35 N 459486.30 E 142.18 N 988.90W 5911999.47 N 459432.72 E 151.58 N 1043.86W 5912009.15 N 459377.81E 161.12 N 1099.81W 5912018.99 N 459321.90 E 170.54 N 1153.79W 5912028.69 N 459267.98 E 180.16 N 1208.39W 5912038.60 N 459213.43 E 189.27 N 1262.75W 5912047.99 N 459159.11 E 198.27 N 1317.21W 5912057.28 N 459104.71E 207.37 N 1371.07W 5912066.66 N 459050.89 E 216.56 N 1425.78W 5912076.14 N 458996.23 E 226.17 N 1480.40W 5912086.03 N 458941.67 E 235.69 N 1535.00W 5912095.83 N 458887.12 E 245.14 N 1589.85W 5912105.58 N 458832.31 E 255.50 N 1645.29W 5912116.22 N 458776.93 E 265.64 N 1700.57W 5912126.65 N 458721.71 E Dogleg Rate (°/'lOOft) 0.854 4.353 3.452 4.082 3.372 0.954 2.597 0.499 0.353 0.093 0.804 0.547 0.596 0.751 1.152 1.420 0.518 0.498 0.230 0.446 0.924 0.731 0.513 0.463 0.221 0.258 0.312 0.925 1.148 North Slope, Alaska Kuparuk 2N Vertical Section Comment 251.20 Tie on Point 265.84 Window Point 285.70 310.89 353.58 400.15 449.83 501.86 555.38 608.22 662.73 716.52 770.79 825.20 878.88 932.43 986.25 1041.51 1097.76 1152.09 1207.07 1261.67 1316.33 1370.45 1425.41 1480.41 1535.36 1590.53 1646.53 1702.32 f3 June, 2001 - ~5:29 Page 2 of 4 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 2N-349A Your Ref: AP1501032034501 Job No. AKZZfOf69, Surveyed: f5 April, 2000 Kuparuk River Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 5193.12 34.500 278.800 4539.89 4692.99 274.20 N 1753.64 W 5912135.48 N 458668.67 E 5289.37 33.940 278.980 4619.48 4772.58 282.56 N 1807.12 W 5912144.13 N 458615.24 E 5384.05 33.710 277.760 4698.14 4851.24 290.23 N 1859.26 W 5912152.07 N 458563.14 E 5478.31 33.760 278.240 4776.52 4929.62 297.52 N 1911.10 W 5912159.63 N 458511.34 E 5572.96 34.220 280.980 4855.01 5008.11 306.36 N 1963.26 W 5912168.74 N 458459.23 E 5667.49 35.440 283.740 4932.60 5085.70 317.93 N 2015.98 W 5912180.59 N 458406.57 E 5763.17 35.130 283.790 5010.71 5163.81 331.08 N 2069.66 W 5912194.02 N 458352.96 E 5857.86 35.140 280.840 5088.15 5241.25 342.70 N 2122.89 W 5912205.92 N 458299.79 E 5952.50 35.800 284.040 5165.23 5318.33 354.54 N 2176.50 W 5912218.04 N 458246.25 E 6047.46 36.480 284.060 5241.92 5395.02 368.14 N 2230.82 W 5912231.92 N 458191.99 E 6142.81. 36.880 282.860 5318.39 5471.49 381.39 N 2286.21W 5912245.46 N 458136.67 E 6237.43 36.860 283.000 5394.09' 5547.19 394.09 N 2341.55W 5912258.45 N 458081.41 E 6331.78 36.860 283.310 5469.58 5622.68 406.97 N 2396.66W 5912271.62 N 458026.36 E 6427.29 35.940 283.070 5546.45 5699.55 , 419.91N 2451.84W 5912284.84 N 457971.25 E 6498.00 35.940 283.070 5603.70 5756.80 429.29 N 2492.27W 5912294.44 N 457930.87 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 25.904° (01-Sep-00) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 287.370° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 6498.00ff., The Bottom Hole Displacement is 2528.97ft., in the Direction of 279.773° (True). Dogleg Rate (o/t00ft) 1.870 0.591 0.757 0.288 1.690 2.108 0.325 1.793 2.082 0.716 0.861 0.091 0.197 0.975 0.000 North Slope, Alaska Kuparuk 2N Vertical Section Comment 1755.53 1809.07 1861.12 1912.77 1965.19 2018.96 2074.12 2128.39 2183.09 2239.00 2295.82 2352.42 2408.86 2465.39 2506.77 Projected Survey June, 200~ - ~5:29 Page 3 of 4 D~'illQuest 2.00.08o005 Sperry-Sun Drilling Services Survey Report for 2N-349A Your Reft AP150f032034501 Job No. AKZZlO169, Surveyed: ~5 April, 2000 Kuparuk River Unit North Slope, Alaska Kuparuk 2N Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 2477.79 2448.51 23.83 N 255.75W 2520.00 2487.91 24.49 N 270.88W 6498.00 5756.80 429.29 N 2492.27W Comment Tie on Point Window Point Projected Survey Survey tool program for 2N-349A From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) 0.00 0.00 6498.00 Vertical Depth (ft) 5756.80 Survey Tool Description AK-6 B'P_IFR-AK (2N-349) t, . June, 2001 - 15:29 Page 4 of 4 DrillQuest 2,00,08.005 Kuparuk River Unit North Slope, Alaska Kuparuk 2N, Slot 2N-349 2N-349A MWD Job No. AKMMOOf 69, SURVEY REPORT 13 June, 200~ ! Your Ref: API-50103203450~i Surface Coordinates: 5911852.12 N, 460420.86 E (70° lO' ~2.4084" N, 150° 19' 06.7185" W) Kelly Bushing: ~i$$. lOft above Mean Sea Level nRILLII~iB SERVICES .. Survey Ref: svy9311 A Halliburton Company Kuparuk River Unit MeaSured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth eft) 2477.79 20.880 272.610 2295.40 2448.50 2520.00 21.170 272.830 2334.80 2487.90 2574.30 22.810 276.580 2385.15 2538.25 2637.40 24.900 278.230 2442.86 2595.96 2732.90 28.750 279.710 2528.07 2681.17 2826.48 31.670 277.100 2608.93 2762.03 2921.46 32.470 276.500 2689.42 2842.52 3016.96 34.490 279.200 2769.07 2922.17 3111.85 34.920 278.890 2847.08 3000.18 3204.84 35.080 279.360 2923.25 3076.35 3300.61. 35.000 279.320 3001.66 3154.76 3394.91 35,160 280.550 3078.84 3231.94 3489.86 35.120 279.610 3156.48 3309.58 3585.56 34.890 278.660 3234.87 3387.97 3680.29 34,830 279.700 3312.60 3465.70 3774.95 34.820 277.840 3390.31 3543.41 3868.97 35.820 279.490 3467.03 3620.13 3964.09 35.950 278.730 3544.09 3697.19 4060.56 36.140 279.400 3622.09 3775.19 4153.60 36.020 279.150 3697.29 3850.39 4248.23 35.710 279.810 3773.98 3927.08 4342.94 35,480 278,390 3850.99 4004.09 4437.95 35.550 279,920 3928.33 4081.43 4531.75 35.690 279.190 4004.58 4157.68 4626.66 35.850 279,730 4081.58 4234.68 4721.14 36.030 279.530 4158.08 4311.18 4815.49 35,920 279,190 4234.43 4387.53 4910.05 36.200 279,300 4310.88 4463.98 5005.27 36,440 280,270 4387.60 4540.70 5100.18 36,190 278.440 4464.08 4617.18 Sperry-Sun Drilling Services Survey Report for 2N-349A MWD Your Ref: API-50f03203450 Job No. AKMMOOf 69, Local Coordinates Northings Eastings (ft) (ft) 10.88 N 257.13 11.60 N 272.26 13.29 N 292.51 16.59 N 317.81 23.34 N 360.36 Global Coordinates Northings Eastings (ft) (ft) 30.18 N 406.93 .36.15 N 457.01 43.37 N 509.18 51.86 N 562.53 60.32 N 615.19 W 5911864.34 N 460163.79 E W 5911865.14 N 460148.67 E W 5911866.94 N 460128.43 E W 5911870.37 N 460103.14 E W 5911877.35 N 460060.63 E 69.25 N 669.45 78.60 N -722.83 88.16 N 776.64 96.88 N 830.84 105.52 N 884.29 W 5911884.42 N 460014.09 E W 5911890.65 N 459964.05 E W 5911898.15 N 459911.92 E W 5911906.93 N 459858.61E W 5911915.66 N 459805.99 E 113.76 N 937.71 121.96 N 991.44 130.78 N 1046.49 139.73 N 1102.54 148.56 N 1156.62 W 5911924.87 N 459751.78 E W 5911934.50 N 459698.45 E W 5911944.34 N 459644.70 E W 5911953.34 N 459590.54 E W 5911962.26 N 459537.14 E 157.69 N 1211.30 166.41N 1265.73 175.19 N 1320.22 184.26 N 1374.09 193.38 N 1428.81 W 5911970.78 N 459483.76 E W 5911979.26 N 459430.08 E W 5911988.37 N 459375.07 E W 5911997.61N 459319.06 E W 5912006.73 N 459265.03 E 202.65 N 1483.48 211.67 N 1538.17 220.61N 1593.11 230.20 N 1648.68 239.33 N 1704.14 W 5912016.14 N 459210.40 E W 5912025.15 N 459156.02 E W 5912034.21 N 459101.58 E W 5912043.56 N 459047.75 E W 5912052.97 N 458993.08 E W 5912062.53 N 458938.46 E W 5912071.83 N 458883.82 E W 5912081.06 N 458828.93 E W 5912090.94 N 458773.40 E W 5912100.36 N 458718.00 E Dogleg Rate (°/lOOft) 0.712 3.975 3.477 4.091 3.421 0.907 2.628 0.490 0.337 0.087 0.769 0.571 0.618 0.631 1.122 1.470 0.488 0.454 0.204 0.524 0.906 0.938 0.477 0.373 0.227 0.242 0.304 0.654 1.172 Vertical Section 248.65 263.3O 283.13 308.27 350.89 397.38 446.96 498.9O 552.36 605.15 659.59 713.33 767.54 821.87 875.46 928.91 982.63 1037.81 1093.98 1148.22 1203.14 1257.69 1312.31 1366.43 1421.38 1476.33 1531.22 1586.32 1642.22 1697.88 North Slope, Alaska Kuparuk 2N Comment Tie-on Survey Window Point June, 200~ - ~4:58 Page 2 of 4 DriilQuest 2.00.08.005 ~0~ ~~0 00000 00000 ZZZZZ ZZZZZ ZZZZZ ~~ ~~0 ~00~ ~0~ ~0~ ~0~ ZZZZZ ZZZZZ ZZZZZ mmmmm mmmmm mmmmm Z 0 0 Z 0 Z t,.,O .,-~ ,-.,~ 4~ .-.~ 0 -.-~. 0 ¢:~0 ZZZ Z TRANSMITTAL ProActive Diagnostic Services, Inc. State of Alaska AOGCC 333 W. 7th Street Suite 700 Anchorage, Alaska 99501 RE' Distribution - Final Print[s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Joey Burton / Jerry Morgan ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 , LOG' DIGITAL MYLAR / BLUE LINE REPORT WELL '~ DATE TYPE OR SEPIA PRINT(S) OR' / CD-ROM F~LM BLUE L~NE ~ Open Hole ! I 1 Res. Eval. CH I I 1 Mech. CH '1 Caliper Survey t Rpt or 2 Color Print Name: L.~. ~J'~~,~) I Date ' ~~~E~ED HAY 0 7 2001 ProActive Diagnostic Services, Phone:(907) 245-8951 Fax:(907) 245-8952 Inc., Aladm Oil & Gas Cons. Commimion Anchorage 310 K Street Suite 200, Anchorage, AK 99501 E-mail: pdsanchorage~mcmorylog, com Wcbsite: ,-L LOG TRANSMITTAL ProActive Diagnostic Services, Inc. State of Alaska AQSC~ 333 W. 7th Street Suite~l' ! CIO Anchorage, Alaska 99501 RE: Distribution - Final Print{s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Joey Burton / Jerry Morgan ProActive Diagnostic Services, Inc. 310 KStreet Suite 200 Anchorage, AK 99501 LOG DIGITAL MYLAR / BLUE LINE REPOm WELL DATE TYPE OR SEPIA PRINT[SI OR CD-RI::)M FILM BLUE LINE ~n .~, J, ~ I I 1 /'~.-/0 / Res. Eval. CH 1 I .C_~!!~cr Cur~y I Rpt or 2 Color Signed: Print Name: Date: I ' ProActive Diagnostic Services, Inc., 310 K Street Suite 200, Anchorage, AK 99501 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pdsanchorage~memorylog.com Website: www.memory_ log. corn To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 November 21, 1999 MWD Formation Evaluation Logs 2N-349A, AK-MM-00169 ~O0-!~g ~/ 1 LDWG formatted Disc with verification listing. API#: 50-103-20345-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 Date: 0 o o o o O0 o 0 WELL LOG TRANSMITTAL To'- State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 November 30, 2000 RE: MWD Formation Evaluation Logs 2N-349A, AK-MM-00169 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 ~cD¥$q2N-349A: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20345-01 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20345-01 2" x 5" MD Neutron & Density Logs: 50-103-20345-01 2" x 5" TVD Neutron,& Density Logs: 50-103-20345-01 1 Blueline ~' 1 Folded Sepia 1 Blueline ~ 1 Folded Sepia 1 Blueline , 1 Folded Sepia 1 Blueline '~ 1 Folded Sepia :SENT BY' Phone: 269-461 11-28- 0 ; 3:§SPM ' PHILLIPS AK INC--,. 907 276 7§42:# 1/ 2 Fax To.' Mr. Wondzell Front: Brian Noel Fem. 9-907-276-7,F,42 Bates November 28, 2000 Phane: Pages: 1 R~ Pad Diagram cc: I'1 Urgent [] For Review [] Please Comment I-I Please Reply [] Plense Mr. Wondzell, Hem is the pad diagram for 2N as requested.. 265-69'/9. If you have any questions, please feel free to e~1ll me at Thanks, Brian SENT BY: 11-28- 0 ' 8'§SPM ; ~78AC$ PHILLIPS AK INC--,- 907 276 7542:# 2/ 2 LEOEND · EXISTING CONDUCTOR LOCATION FUTUR[ CONDUCTOR LOCATION AS-BUILT CONDUCTOR LOCATION Conductors ore Locoted 'Sec. $, T. 9 N., R. 7£. ....... ' ......... ' ' ~- ~. .-w~...~. .~. ~ ~ - . . ~'~' ~ ~ ~ ~ ~ ta' ~ %.~;~,.,~, ..~=¢' u~;~. ,,, ,. .... , ,~. ~,0 V a 8 2.000 ,, T , ~ 'V-'$' N PAGE 2 OF 2 FOR NO7ES ~ ]'AREA:~ PHILLIPS Inc. I ·, MOOU,LE:XXXX ' UNIT: 02.: "DS2N Y~LL CONDUCTOR 3~ AS-BUILT ' ........... ' 2N-305 and 2N-349A sundry approval for annular ini,~ "%n . Subject: 2N-305 and 2N-349A sundry approval for annular injection Date: Tue, 28 Nov 2000 17:08:44-1000 From: "Brian D Noel" <BNOEL~ppco.com> To: blair_wondzell~admin.state.ak.us CC: "Randy L. Thomas" <RLTHOMAS~ppco.com>, "Paul Mazzolini" <PMAZZOL~ppco.com>, "Tom J Brassfield" <TBRASS~ppco.com> Blair - Re: Your inquiry on broaches after surface casing was cemented on 2N pad >From the collective memory of everyone involved with the three phases of Tarn drilling on 2N pad - after the surface casing was cemented there have been no instances of broaching while drilling the wells to total depth. Pressure tests of the surface casing prior to drill out and the initial FIT or LOT have shown integrity of the casing and the cement at the shoe. Please let me know if you require additional information. Thanks - Brian 265-6979 1 ofl 11/29/00 7:19 AM A~$ STATE OF AI.ASKA '~, ' AL ~ OIL AND GAS CONSERVATION COM ,,,~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG .1. Status of well Classification of Service Well Oil I~1 Gas D Suspended r"l Abandoned D Service I~1 -'~-"'" MI Injector 2. Name of Operator "~'~'~"~' 7. Permit Number Phillips Alaska, Inc. _~/~_~ 200-139 3. Address :'~'~-- · t 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 [~'~..'?~,-,~,t 50-103-20345-01 4. Location of well at surface -.~'-' ................... 9. Unit or Lease Name ..... , ~.,,, , , 158' FNL, 1172' FEL, Sec. 3, T9N, R7E, UM (ASP: 460421, 5911852) ' ' ~ Kuparuk River Unit At Top Producing Interval ! _ ~';'! ~.'~ ? 10. Well Number 166' FSL, 1928' FWL, Sec. 34, T10N, R7E, UM (ASP: 458241.5, 5912187.5) ' '...;:..~., ,:..... 2N-349A At Total Depth : .... ~ ....... i 11. Field and Pool 236' FSL, 1612' FWL, Sec. 34, T10N, R7E, UM (ASP: 457925, 5912259) Kuparuk River Field 5. Elevation In feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Tarn Pool RKB 35 feet I ADL 380054 & 375074 ALK 4602 12. Date Spudded 13. Date T.D. Reached 14. Date Como. SusD. Or Aband. 115. Water Depth, If offshore 16. No. of Completions September 12, 2000 September 15, 2000 ~, 2000 I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Sun/ey 120. Depth where SSSV set 21. Thickness of Permafrost 6498' MD / 5757' TVD 6365' MD / 5649' TVD YES r~l No DI N/A feet MD 1205' approx. 22. Type Electric or Other Logs Run 9-7/8' hole - Dipole Shear Sonic, Induction/GR, Density-Neutron and 6-3/4' hole - GR/Res, Density-Neutron 23. CASING, LINER AND CEMENTING RECORD SE3-rlNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I-rOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 118' 24' 9 cu yds High Early 7.625" 29.7# L-80 Surface 2331' 9.875" 430 sx AS III Ute, 240 sx Class G 5.5" x 15.5# L-80 Surface 5677' 6.75" 113 sx Class G Lead, 350 sx Class G Tall 3.5" 9.3# L-80 5677' 6491' 6.75" Included above 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD intewal, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 5674' 5658' (CSR) 5990'-8010' MD 6349'-5355' TVD 6. spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5942'-5962' MD 5310'-5328' TVD 8 spf ' ' 000 N/A 5940'-5942' MD 6308'-5310' TVD 6 spf 27. 331~ODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) N/A Injecting Date of Test Hours Tested Production for OIL-BBL GAS-MOF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MOF WATER-BBL OIL GRAVITY - APl (con') pst 24-Hour Rate > 28. CORE DATA Brief description of lithology, pomstty, fmcturss, apparent dips and pmssence of oil, gas or water. Submit core chips. N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit In duplicate 29. GEOLOGIC MARKEI~ 30. (" FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T-3 5870' 5251' T-2 6035' 5385' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hel~)by certify that the following is true and correct to the best of my knowledge. Questions? Call Brian Noel 265-6979 _ Signed-.~t_l~f~~ ( ~.~'~(. Title DrillinaEnqlneerinflSupervisor Date Lq~i~J. ~ James Trantham Prepared by Sharon AIIsup-Drake 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 the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Date: 10/12/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2N-349 STATE:ALASKA COUNTY: NORTH sLOPE WEST FIELD: TARN PARTICIPATING AREA SPUD:09/03/00 START COMP: RIG:NABORS 19E BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20345-00 09/02/00 (D1) TD/TVD: 115/115 SUPV:R.W. SPRINGER MW: 9.8 VISC: 80 PV/YP: 28/40 (115) REPLACING DIVERTER KNIFE VALVE APIWL: 9.0 Rig down and move ball mill & pits. Move sub over well. Accept rig @ 1700 hrs. 9/2/00. Nipple up diveter system and function test and test all gas alarms. 09/03/00 (D2) TD/TVD: 343/343 SUPV:R.W. SPRINGER MW: 9.7 VISC: 76 PV/YP: 19/38 (228) DRILLING SURFACE (HI-LINE POWER 8 HR) APIWL: 10.0 Drill out cement. Tagged cement @ 61'. Fluid test diverter. Fish junk out of conductor (wrench). Diverter knife valve leaking, attempt to repair. Nipple up new diverter valve. Drill out cement from 61'-73'. PJSM. Drilled from 73-170'. Change over to spud mud. Drilled from 170'-343' 09/04/00 (D3) MW: 10.2 VISC: 67 PV/YP: 19/30 TD/TVD: 17.00/1696 (1357) DRILLING @ 1885' SUPV:R.W. SPRINGER Drilled from 343'- 1700'. APIWL: 8.6 09/05/00 (D4) MW: 10.2 VISC: 52 PV/YP: 18/22 APIWL: 8.0 TD/TVD: 2338/2316 (638) RIGGING UP TO RUN CASING (24 HR HI-LINE POWER) SUPV:R.W. SPRINGER Drilling from 1700'-1809' Pump lo-hi vis sweep. Short trip to 1042', trip back in hole, circ bttms up. Drilled from 1809' to 2338'. Pump hi-vis sweep & circ hole clean. POH short trip to 1740', RIH. Pump hi vis sweep & circ hole clean. POH. PJSM. Run Platform express. 09/06/00 (D5) MW: 9.6 VISC: 48 PV/YP: 15/15 APIWL: 6.5 TD/TVD: 2338/2316 ( 0) TESTING CASING SUPV:R.W. SPRINGER Continue logging w/platform express. PJSM. Rig up to run 7-5/8" casing, PJSM. Run 7-5/8" casing. PJSM. Pump cement. Bumped plugs, floats held. Nipple down diverter. Nipple up BOP's and test. · -: '"'" Date: 10/12/00 ARCO ALASKA INC. 2 : WELL SUMMARY REPORT .... 09/0?/00 (D6) ~,~: 9.5 ~ISC: 48 PV/¥P: 13/15 AP'ri~,_,: 6.0 TD/TVD: 2625/2316 ( 287) DRILL'rNG ~ 3120' 9~.4 ~R ~'r-LI~E POWER) SUPV:R.W. SPRINGER Finish testing BOPE. PJSM. Tag cement @ 2232'. Circ hole clean. Drilled cement from 2232' to float collar @ 2245', hard cement, shoe and 20' new formation to 2358'. Perform leakoff. PJSM. RIH. Circ bottoms up. Perform 2nd leak off test to 12.7 ppg EMW. Drill from 2358' to 2625' 09/08/00 (D7) TD/TVD: 2625/2316 ( SUPV:R.W. SPRINGER MW: 9.6 VISC: 46 PV/YP: 15/14 0) DRILLING @ 4415' (24 HR HI-LINE POWER) APIWL: 4.4 Drilled from 2628'-3500'. Circ hole clean f/wiper trip. Short trip from 3500'-2324'. Drilled from 3500'-4068'. 09/09/00 (D8) MW: 9.7 VISC: 46 PV/YP: 14/11 APIWL: 3.6 TD/TVD: 5649/5400 (3024) @ T.D., CIRCULATING PRIOR TO CSG WIPER TRIP (24 HR HI- SUPV:R.W. SPRINGER Drilled from 4068'-5649'. 09/10/00 (D9) MW: 9.6 VISC: 43 PV/YP: 12/10 APIWL: 3.8 TD/TVD: 6043/5776 (394) CONDITIONING &CIRCULATING ON BTM FOR CEMENT PLUGS. (24 SUPV:R.W. SPRINGER Drilled from 5649'-6043'. Circ and condition w/sweep. Monitor well, pump pill, POH to shoe, no tight spots. RIH to bottom. Circ & condition, check for flow & pump dry job. POH check for flow @ shoe. Rig up to run 2-7/8" tubing cementing stinger. 09/11/00 (D10) TD/TVD: 6043/5776 ( SUPV:R.W. SPRINGER MW: 9.6 VISC: 41 PV/YP: 12/ 8 0) FINISHING TESTING BOPE. APIWL: 3.8 R/U to run tubing cementing stinger. RIH w/tubing. Circ & condition for cement plug. Lay balanced cement plug in three stages from 6043'-4700'. POH to 4324'. Circ hole clean. PJSM. Circ & condition mud @ 3000'. Pump hi-vis gel mud pill & POH, laying pill from 3000' to 2700'. Lay densified balanced cement kickoff plug from 2700' to 2400' POH slowly to 2400', circ clean. POH. Rig up to test BOPE. 09/12/00 (Dll) MW: 9.6 VISC: 45 PV/YP: 14/12 APIWL: 4.0 TD/TVD: 3145/3028 ( 0) DRLG 6 3/4" HOLE @ 3560' ( RIG ON HI LINE POWER LAST 2 SUPV:DEARL W. GLADDEN Set test plug, test BOPs to 300/3500 psi. TIH, tag cmt @ 2513'. Circ & cond. Sidetrack time drill 2513' to 2530'. Dir drilling 2530' to 3145'. 09/13/00 (D12) MW: 9.6 VISC: 47 PV/YP: 15/13 APIWL: 3.6 TD/TVD: 4513/4142 (1368) DIR DRLG 6 3/4" HOLE @ 4859' (RIG ON HI LINE POWER LAS SUPV:DEARL W. GLADDEN Dir drilling from 3145' to 3660'. CBU. Wiper trip to shoe. Dir drilling from 3660' to 4513'. Circ hole clean. Date: 10/12/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 09/14/00 (D13) MW: 9.6 VISC: 46 PV/YP: 13/15 APIWL: 3.4 TD/TVD: 5338/4812 ( 825) DIR DRLG 6 3/4" HOLE @ 6080' (RIG ON HI LINE POWER THE SUPV:DEARL W. GLADDEN Dir drilling from 4513' to 5338' 09/15/00 (D14) MW: 9.6 VISC: 42 PV/YP: 10/10 APIWL: 3.6 TD/TVD: 6498/5756 (1160') TOH -L/D BHA SUPV:DEARL W. GLADDEN Dir drilling from 5833' to 6498'. Circ hole clean, rotate & recip pipe, monitor well, pump dry job. Wiper trip to surface shoe @ 2330', no excess drag, no swab. C/O 20" air boot on BOP riser. TIH, no tight hole. Circ and condition mud to run casing. 09/16/00 (D15) MW: 9.6 VISC: 42 PV/YP: 10/10 APIWL: 3.6 TD/TVD: 6498/5756 ( 0) CMT 5.5" X 3.5" CSG. SUPV:DEARL W. GLADDEN Circ and condition hole to run casing. Monitor well. TOH. R/U to run 3.5" tubing on mono bore completion. PJSM. Run 3.5" tubing. Run 5.5" casing. Circ & cond, CBU. Cont to run casing. CBU ~ 2300'. Continue to run casing. 09/17/00 (D16) MW: 8.5 VISC: 0 PV/YP: 1/ 0 APIWL: 0.0 TD/TVD: 6498/5756 ( 0) L/D DP OUT OF DERRICK(RIG ON HI LINE POWER LAST 24 HRS SUPV:DEARL W. GLADDEN Continue running 5.5" x 3.5" mono bore casing. Circ and condition to cement casing. PJSM. Cement casing. Bumped plug. Floats held. Set packoff and test to 5000 psi, OK. Run 3.5" tubing. 09/18/00 (D17) MW: 8.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 6498/5756 ( 0) WELL 2N-305 - NIPPLE UP & READY PITS FOR SPUD MUD ( RI SUPV:DEARL W. GLADDEN Circ sea water until well clean. Pump freeze protect down annulus. Pressure test tubing to 3500 psi, OK. Pressure test 5.5"x 3/5" annulus to 3500 psi. N/D BOPs, NU tree and test to 5000 psi. Release rig @ 8:30 pm 9/18/00. PJSM. Move rig module. PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2N-349AON4-6)) WELL 2N-349A DATE 10/17/00 DAY 2 JOB SCOPE JOB NUMBER P E R FO RATIO NS- E-LI N E(260) 1006000742.1 DAILY WORK UNIT NUMBER SCMT RERUN CONFIRMED YESTERDAYS - PERF W/2.5" HSD @ 6 SPF 2145 31J UJ /STATIC LOG OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR YES I YES SWS-SPENCER ODELL Initial Tbg Press Final Tbg Press Initial Inner Ann 0 PSI 35 PS1 0 PSI Final Inner Ann I I 0 PSI Initial Outer Ann I I 0 PSI Final Outer Ann 0 PSI DAILY SUMMARY SCMT RERUN - CONFIRMED YESTERDAYS LOG / PERF W/2.5" HSD @ 6 SPF (31J UJ CHARGES) - INTERVALS: 6020-6030 / 5990 - 6010 / 5942-5962 / 5940-5942 FT MD / RAN STATIC PRESSURE/TEMP LOG, SBHP = 2265 PSI. [Perf, Pressure Data] TIME LOG ENTRY 08:00 MIRU - SAFETY MEETING 08:45 CALIBRATE RELATIVE BEARING OF SCMT WITH MAP I AT TDC 09:00 PT LUBRICATOR TO 300 PSI 09:05 PT LUB TO 3000 PSI 09:10 RIH WITH: HEAD/AH-38/SWIVEL/CENTRALIZER/PSP/CENTRALIZER/SC MT/CENTRALIZER/BOI-I'OM NOSE = 34 FEET X 1.6875 INCH 10:15 AFTER PERFORMING MANY FREE PIPE CALIBRATIONS ON RIH, THIS (SCMT #5) IS RESPONDING TO THE WELL THE SAME AS YESTERDAY'S TOOL (SCMT #3) AT TD, BLED OFF 1200 PSI TO 20 PSI WHP, BEGIN LOGGING MAIN PASS 10:20 11:10 TODAY'S LOG CONFIRMED YESTERDAY'S LOG. PHONED CLIENT WITH RESULTS - POOH. WILL PROCESS YESTERDAY'S LOG 12:00 AT SURFACE - REMOVE SCMT 12:15 PRE-ARM SAFETY MEETING - ARM GUN #1 12:30 GUN #1 RIH = HEAD/AH-38/SWIVEL/CCL-L/WEIGHT/SAFE FIRE HEAD/SAFE HEAD ADAPTER/10 GUN/BOTTOM NOSE = 24.4 FEET X 2.5" MAX OD 13:00 LOG A TIE IN PASS FROM 6230 TO 5630 FT 13:20 LOG UP INTO POSITION TO SHOOT GUN #1. CCL DEPTH AT 6010.3 FT / CCL TO TOP SHOT = 9.7 FEET ! INTERVAL = 6020-6030 FT MD 13:30 GOOD INDICATIONS AT SURFACE OF DETONATION - POOH 14:00 AT SURFACE - CONFIRMED ALL SHOTS FIRED - ARMED GUN #2 14:30 RIH GUN #2 = HEAD/AH-38/SWIVEL/SAFE FIRE HEAD/SAFE HEAD ADAPTER/20 FOOT GUN/BOTTOM NOSE 14:45 AT FLAG AT 5900 FT MD - DEPTH RIGHT ON 14:46 LOG DOWN COUNTING COLLARS 15:00 LOG CCL INTO POSITION AT 5986.3 FT MD / 3.7 FT CCL TO TOP SHOT / INTERVAL = 5990-6010 FT MD 15:05 GOOD INDICATION OF DETONATION - POOH 15:40 AT SURFACE - CONFIRMED ALL SHOTS FIRED TIME lOG ENTRY 15:50 GUN #3 ARMED - RIH. TOOL = SAME AS #2 GUN ABOVE 16:15 LOG UP INTO POSITION TO SHOOT GUN #3 - CCL DEPTH AT 5938.3 FT MD / CCL TO TOP SHOT = 3.7 FT/ INTERVAL = 5942 - 5962 FT MD 16:20 GOOD INDICATION OF DETONATION - POOH 16:50 AT SURFACE - CONFIRMED ALL SHOTS FIRED - ARM GUN #4 17:00 17:40 RIH GUN #4 = HEAD/AH-38/SWIVEL/WEIGHT/SAFE FIRE HEAD/SAFE HEAD ADAPTER/5 FT GUN (2 FT LOADED)/BOTTOM NOSE LOG INTO POSITION TO SHOOT GUN #4 - CCL DEPTH = 5927.3 FT MD / CCL TO TOP SHOT = 12.7 FT MD / INTERVAL = 5940 - 5942 FT MD 17:45 GOOD INDICATION OF DETONATION - POOH 18:30 AT SURFACE - CONFIRMED ALL SHOOTS FIRED - RIG DOWN GUN - RIG UP PRESSURE/TEMP TOOL 19:00 SBHP TOOL IN LUBRICATOR FOR 1ST STOP- TOOL = HEAD/AH-38/SWlVEL/WEIGHT/PBMS-A/BOTTOM NOSE = 17.6' X 1.6875". PRESSURE = 27 PSI. 19:15 RIH 19:45 20:00 20:19 20:40 20:55 AT TD (6538 FT MD) - LOG A TIE IN PASS LOGGED AT STATION AT TD ( 6538 FT MD). PRESSURE = 2397 PSI. LOGGED STATION AT 5985 FT MD ( MID PERF ). PRESSURE = 2265 PSI, LOGGED STATION AT 5862 FT MD ( 100 FT TVD ABOVE STATION AT 5985 FT). PRESSURE = 2227 PSI. POOH 21:20 IN LUBRICATOR - LOG A STATION. PRESSURE = 38 PSI, 21:40 BEGIN RIG DOWN 22:40 RIG DOWN COMPLETE - PROCESSING DATA 23:00 CALLED DSO - LEFT PAD i · Iq~ ~. -o "- o < , ! I I a "' ~ ~ 5 " ..,..r- - I I ,!.. .. ,...~ z - i I · u ~' ~. o n. w :~'"' i ._ ,.r--.--- '7 .~ 14 oi I o~ § ~'o=,o ~ = I '80 ~ o ,~ ,~ .uS · " · · ,':. ,':. . '" · · ~ o c~ cl ci c~ m c~ m. c~ oi c~ ' ci ~ ' N ' ' ci d .a '.- ~ .a ~ a ...... .,- ;. ° -~ 8 8 ~ 8 ~ ~ ~ .~ ~ m r,. ,,,. . . ~ $ ','~, ~.. 0 ................ ~. ~ . , ,q o _, aaY. j z ,. _ -.- ....... ~. ~. ~. r-, It{t ,~' ~ ~ ~ UJ · ~ ~'~ . .~ ..... < ' lO ~ .~ ""' ' ''~'~'' '~ .... I z =. P ~4 d ........ '- ..... I d,~ g g-~ o ~ Zicq, °.°~ . . . < n- n- ~ ..... c~ - ~ ~ ~, ~ w w w w w w w w w w w w w w w w w w w ii ! ! i i Cl~ ILl .. Z : g ~ ~ ~ ..... '..1~ ..... ':"" '~: ~ z u ... · Z n" i ' : 0 ' : :~. ..... ~-~""" ..~ .~ o ~ § ' ~. :- ,-... . v~z~, !:~-, ~"'o d ~ c~ o . . . ~ ~. R ,,1- ....... ....... ~ ......... ~ - 71' E ~. ..... ,_ .. ~. ,,. ~. ~ ~ ~o ,, ._ ..._ ,,, . . - ~ " ~ '~' ,- o o ~o i~ ~: o ~ :. o [:~ ~ ~ ..... i. 0 _ ... ~'~..... N --~ -~° I I I t I I I I I i I / i!. ]I STATE OF ALASKA ' ALASK~ OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Other_X Change approved program _ Pull tubing _ Variance _ Perforate _ Annular Injection 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development_X RKB 35 feet 3. Address Exploratory _ 7. Unit or Property name P. O. Box 100360 Stratlgraphic_ Anchorage, AK 99510-0360 sew~ce_ Kuparuk River Unit 4. Location of well at surface 8. Well number 158' FNL, 1172' FEL, Sec. 3, TgN, R7E, UM (ASP: 460421, 5911852) 2N-349A At top of productive interval 9. Permit number / approval number 158' FSL, 1955' FWL, Sec. 34, T10N, R7E, UM (per APD) 200-139 At effective depth 10. APl number 50-103-20345-01 At total depth 11. Field / Pool 236' FSL, 1610' FWL, Sec. 34, T10N, R7E, UM Kuparuk River Field/Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 6498 feet Plugs (measured) true vertical 5757 feet Effective depth: measured 6365 feet Junk (measured) true vertical 5649 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 83' 16" 9 cu. Yds High Early 118' 118' Surface 2296' 7.625' 430 sx AS III Lite, 240 sx Class G 2331' 2311' Intermediate 5642' 5.5" x 113 sx Class G Lead, 350 sx 5677' 5094' Class G Tail & Production 814' 3.5" included above 6491' 5751' Perforation depth: measured 6020'-6030', 5990'-6010', 5940'-5962' t~ 1¢' ~ ~," ~ ";'~ L.' ...... "'""' ~' ' .......... true verlical 5373'-5381': 5349'-5365', 5308'-5326' /~O~' S~<~"u~ ,~'(" Tubing (size, grade, and measured depth 3.5", 9.3#, Srd EUE @ 5674' C 0 ~'~' ,aS, '~ '"~ Uk~... f~tj.,.5~¢~'a";' .-.]' .. "' Packers & SSSV (type & measured depth) Casing Seal Receptacle @ 5658' UD, NoSSSV "~. ~-~ Ca~ ~ 13. Attachments Description summary of proposal __ Detailed operations program __ BOP sketch __ LOT test, surface cement details and casing detail sheets _...X 14. Estimated date for commencing operation 15. Status of well classification as: November 6, 2000 16. If proposal was verbally approved Oil __X Gas ~ Suspended _ Name of approver Date approved Service _ 17. I hereby certify that the foregoing Is true and correct to the best of my knowledge. Questions? Call Brian Noel 265-6979 Signed ~~"T/~,~''~'~ Title: Drilling Engineering Supervisor Date ~:~.~ ~ J~ ~ Trantham Prepared b~ Sharon Al/su~-Drake FOR COMMISSION USE ONLY · Conditions of approval: Notify Commission so representative may witness I Appro~~..~ Plug Integrity __ BOP Test m Location clearance __[ ,,,,~ ~~ Mechanical Integrtty Test __ Subsequent form required 10- ~ '~ ~ Approved by order of the Commission O~[~N~tIL. ... SIGNED. ....... E~¥ commissioner Date // Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE i, --,... __ __ __ , ~, ~, ~,',l--, ~', C:), ~, l ! ~qt~ i -~ i iin~ I ~ I --~ I -~ I ~ I ~--1 ,,,., k-Il I-, ,,-., ,..,, .,., ..,, ,w, ~,., --'1 I I ,.......,.....--..--...--.,--......,.....................',....,...',........,... 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I ................................................. .0 C~ ._. ~ II II o t:: o o i,m · ,- U o = o + ~ :RlflSS:l~d Phillips Alaska Drilling Cementing Details Well Name: 2N 349 Report Date: 09/06/2000 Report Number: 5 Rig Name: Nebors 19E AFC No.: AK 0059 Field: TARN Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: LC Depth: % washout: 7-5/8 9-7/8 21 2330 2245 $0+ Centralizers State type used. intervals covered and spacing Comments: 28 BOW SPRING JTS 1-12 EVERY 3 JTS TO SURFACE Mud Weight: PV(prior cond): PV(alter cond): YP(prior cond): YP(after cond): Comments: 10.2 19 18 32 30 SPUD Gels before: Gels after: Total Volume Circulated: 24/39 24/39 2+ .., Wash 0 Type: Volume: Weight: Comments: ARCO Wash 20 BBL 8.5 Spacer 0 Type: Volume: Weight: Comments: ARCO B45 40 BBL 10.2 Lead Cement 0 : Type: I Mix wtr temp: No. of Sacks: Weight: Yield: Comments: AS III UteI 75 430 10.7 4.44 ". : '. Additives: .. .. G W1.5% D124, 9.0%D44, .4%D46, 30.0%D53,1.5%S1,1.5% D79, ' '.. ' '....." ..i: . .: "!Additives: · G WI1.0% 81, .2% D46, .3% D6S DlSP!aCen!e,t.; '0 .:...: .'...'! i" Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: ':., :. ". 5 5 70 . .. '" i ':"' =:'', := .'i :'i .i' ..':.ii' ":' = Reciprocation length: Reciprocation speed: Str. Wt. Down: .:.: .: , :.. ,. .'..",,..: .i. 17' I SPM 40 ,, "" ' ' :' .." . .:; ::! .'~ ".:'. ~. : :; Theoretical Displacement: Actual Displacement: Str. Wt. in mud: "" .i';'".:..:'": .... ::,,'::.i ,!,"': .... 103 BBL 103 BBL Calculated top of cement: CP: Bumped plug: Floats held: CEMENT TO SURFACE Date:9/6/00 YES YES Time:1340 Remarks:PUMPED - 140 BBL EXCESS LEAD, CMT TO SURFACE, swn'CHED TO TAIL. USED VACUMN TRUCKS ON CONDUCTOR TO ASSIST DURING DISPLACEMENT. FULL RETURNS THROUGHOUT. RECIPROCATED UNTILL LAST TWENTY BBLS OF DISPLACEMENT. Cement Company: Dowell IRig Contractor: NABORS Approved By: R.W. SPRINGER Casing Detail 7-5/8" surface casing # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Nabors 19E RT to GL = 34.50' TOPS Above RKB 4.54 7 5/8" Landing Joint (38.97 total) 34.50 4.54 7 5/8" FMC GEN IV FLUTED MANDREL HANGER 2.71 39.04 jts.32-54 7 5/8", 29.7#, L-80 BTC-MOD 977.10 41.75 Tam Port Collar 2.44 1018.85 jts 3-31 7 5/8", 29.7#, L-80 BTC-MOD 1224.08 1021.29 Gemeco Float Collar 1.32 2245.37 jts 1-2 7 5/8", 29.7#, L-80 BTC-MOD 82.64 2246.69 Gemeco Float Shoe 1.50 2329.33 BTM OF SHOE @ ..... >>>>> 2330.83 TD of 9 7/8" hole = 2338'MD 28 TOTAL, Gemeco Bow Spring Centralizers 3, Centralizers in center of jts. 2, $1 and 32 over stop collars 25 ,Centralizers over collars of jts. 1,3-12, 15, 18, 21,24, 27, $0, 3~ 36, 39, 42, 45, 48, 51, 5~1 Remarks: String Weights with Blocks: 70 k Up, 50 k Dn, 15k Blocks. Ran 54 joints of casing. Drifted casing with 6. 750"plastic rabbit. Used Best-o-Ufe 2000 thread compound on all connections. Eight joints surplus. Nabors 19E Drilling Supervisor; R. W. Springer WELL: 2N-349 PHILLIPS Alaska, Inc. DATE: 09/05/00 1 OF 1 PAGES PHILLIPS ALASKA INC CASING TALLY PAGE: 1 of 2 WELL: 2N-349 Kuparuk Unit RIG: Nabors 19E TUBING DESCRIPTION: 7 5/8", 29.7#, L-80, BTC-M DATE: ####### Column 1 Column 2 Column 3 I Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet NoI Feet J No Feet No Feet No Feet No Feet No Feet I I 1 39.52 26 40,19 511 43.18I 76 101 126 151 176 2 43,12 27 43.24 521 43,10 177 102 127 152 177 I I 3 41,26 28 43.68 531 43.32 178 103 128 153 178 I I 4 43.03 29 43.43 54140,53I 79 104 129 154 179 5 43,00 30 43,76 55~~ ........... 80 105 130 155 180 6 42.31 31 42,92 56~ 81 106 131 156 181 7 42,66 32 43,05 57~ 82 107 13~ 157 182 8 42.51 33 43.73 58~ 83 108 133 158 183 9 41.20 34 42.36 59~ 84 109 134 159 184 10 43.71 35 43.70 6o 85 110 135 160 185 11 43,13 36 43.22 61 86 111 136 161 186 12 43.02 37 42.62 62 87 112 137 162 187 13 41.92 38 40.64 63 88 113 138 163 188 14 42.74 39 42,69 64 8g 114 139 164 189 15 42.25 40 40.36 65 9O 115 140 165 190 16 41.60 41 39,95 66 91 116 141 166 191 17 42.25 42 42.48 67 92 117 142 167 192 18 41,33 43 43.18 68 93 118 143 168 193 19 43.77 44 43,13 69 94 119 144 169 194 20 41,57 45 42,77 70 95 120 145 170 195 21 42.18 46 42.48 71 96 121 146 171 196 22 40.88 47 43,61 72 97 122 147 172 197 23 40.45 48 42,66 73 98 123 148 173 198 24 38,82 49 43.10 74 99 124 149 174 199 25 41,27 50 41.24 75 100 125 150 175 200 Tot 1049.50 Tot 1064.19 Tot 377.32 Tot Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = 2491.01 TOTAL JOINTS THIS PAGE = 59 DIRECTIONS: Float Shoe = 1.50 Float Collar = 1.32 Stage Collar = 2.50 Fluted Hanger = 1.32 PHILLIPS AlaSka, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY :. 2N-349A NIP t OD:3.500) TUBING (0-5674, OD:3.500, ID:2.992) SLEEVE (5564-5565, OD:3.500) Gas Lift landrel/Dummy Valve 1 (5606-5607, OD:4.725) NIP (5650-5651, OD:3.500) CSR (5656-5659, OD:5,500) : = : TTL (5673-5674, OD:3,500) Ped (5940-5~2) (5990-6o10) cPc (6366-6366, OD:3.500) PROD CASING (5777-6490, OD:3,500, Wt:9.30) KRU 2N-349A APl:, 501032034501 SSSV Type:,. NIPPLE __ Annular Fluid:' Well Type: ii_NJ .....................- ..... A.~ngle__@_TS: '..d_e_gj~ .......... O_ri_g__Completion: 19118100 ' Angle ~,_T_D_: .. 36_~d_~_g_~ 6498 Last W/O:' Rev Reason:: Ta.g. fill · .. R_.e.f_e_re__nce_Lp_g:. - ......... La.s_t. Ta~ 6002 , Last Tag Date: i 4/30/01 :.Casing String_-__ALL ~._D. escr_!ption CONDUCTOR SURF CASING PROD CASING ........ Ref_L__og Date:: Last Update:, 5/1/01 ............................. T D;;.._6,~. _9_8_ ff K___B_ ................. . ..................... Max Hole Angle:. 37 deg (~ 6143 16.000 ._.I ....__0_. 118 ~, 118 : 62.50 ' H-40 'WELDED 7.625 ; 0 2330 ' 2310 ' 29.7_0_._: _ ._L.-8__O__L BTCM 5.500 ~ ....... ~ ......i .... _5_7_7_7_ ...... L. 5175 , 15.50 . L-80 I BTC-MOD PROD CASING I 3.500 I 5777 I 6490 ~ 5750 I 9.30 ; L-80 ' 8RD EUE I Tubing__S_t.r!ng - TUBING Size i Top_ ;Bottom, TVD :,~--"'-~/~- ..... ,,:--~-d-e-"T ............... -T-~'~'~ ........... Perforations Summary ..... -i'~;~erv~i ...... [ ..... ~'VD [ Zone !Status! Ft ISPF '-'-~--'~.~Y..--~__~i'] ................ ~-~-~-n-t ................ --'~94~-5~--[--~b-~=~-3-~--[ ----' ]' ...... ~ ....F-2-~'F--~- i-'i-o/~d-i'i~RF ~TE"-~§'b}'-w-7~-u~- ............. ,~-i~_~~.~.'F-'~-~-~---~.-y.~ ............ [ ...... ~ ..... ['-~b'- --~--"i'-i-0-~'~b--[ IP---~'-F-L~'.'~"' HSE}[ W-~-~'O~' ............ Gas Lift Mandrels/Valves "§Y[-~ CFF~V-15-]--M a--~' T-* 'M--a-~--T' "V' ~-~;:-~-~I-*~-~i-~-~:i-~;;t-c-~*I~l~-~-~--~k-(~:~-~---~F~-~/i~¢~* ...]- -] -I Mfr --l-.. Ty~e [ l ] .1...... [ Run Lc_mnt Other{pl.u_gs, e~u_ip_,:etc;). JEWELRY . ' .... ' · · . .... ~(~' - ilJ'i.~ -~'l~-~ -'ii .... ~] p ...... ~_~-~"~ ~'~r~j!-~ .p.'j~ -~)~' '~'~fJl-~ ..................................................................... ]L~6-~- ' -75_-5_-~' "l-~¥f-1'-'-'~ E~-~ ~ ~--' K~ ~KC~0-S~i a F_n~_~ F~-~' ~?~ ~ ~-~ ~'~-c-~ '~p_- 'r~_~. ........................................................ F-_ _2~- '- ................................................ '.:L~_~;~_3:_~-o~'~-':l ........ ~%-R-'"'_-_l_~.~'~a'~__'~-..."i~a~'7 ~ i~F~o:~'o' ............................................................... I--'~:~'o-F "56~-~ ''lilI~__~.9.111~]~ .... ~r'T-'-ml~b-]'~-Tjii .................................................................................................... ~LY r""",'-- ,----t-~- ................... --r- .......................... U J- · I ' I I I I I I I I I , I I I I I I I I l I I ,I ' I I I I I ' I I I I I I I I I I I I .... ,.-I--, .......... I ...................... ~l I--I a~l 141 L~,' {01 ~1 ~I ~l ~Jl {Of 141 ~I IOl ~I ~I I I I I I l f,~l l_~l~,l~,l~,l~,ll~ll~.l~ll~l~.l~,l~,l~,'~ I I { I I I ' ' I~,' I I ' I ' '0' ' ' I I ' m~ : :o.w,olo,~:o: Io:o:o,o,o:olol i i : i i l ======================================= ~ .... ~, ....... {__.~.~lll~ .... ~l~ll~lll~illl~l. l.__ I C~ { I ' Ill { , I { { I , { ' ' I l ~j{ I I I I ;l lol lOl ;l a~l ~ ~{ ~ I0 lO' iw,.,, wi z' 'z ,, i , , , ,~ I~,~,~,~~! , , , :.,al.,., ....... :.-!.- .i ....: I W WI W WI Wi } { I } } } , I I , { "": :o:.l,l.. c~l I I I I I [ II II I I I I I { l I I I I ' ' I ' I ' I I ' I I I ' I I I ill! I I I I i I I i ! I i : i I i I : : ll~ , ~ : : , : ~ , : ~ , : : ~ : i : i i i i ' I ' i I I I ' I I I I I ' I ' ' ' I : I : , I , I l ,l,'~l ' t I , i I , , , : , : 01 ' I I ~ i t : I , I :' ' "' ' : 0 .~. II l___ { , : : : ': I i I I { I i'LJ. illllllll!ll Ul :::' ir"'] T'-] 'i' i iT! T-{ i ! ! ! i , . , l 'l~{Lr~llOlOlO ol~l~im}~Im 0)I ~l~l j I I J J I J ~l : i.! .i.! i ! ...... .! i i j i i i I I I I , I I j I I I I I I I : I I ' I I I i ! !'l I ! .... .... .......... , II :qnss:31id >- iii LU uJ m LIJ ARCO Inc. Cementing Details Well Name: 2N-309 \ Report Date: 03/13/99 Report Numhen 4 Rig Name: Pool 6 .,' AFC No.: AK9733 Field: ',,, Casing Size Hole Diameter. Angle thru KRU: Shoo Depth: LC Depth: % washout: 7.025' 9.~'/'5' 2583 2496 CentrellzMa State lype used, intervals covered and spa'ctng Comments: Ran 1 bowspring per Joint on its 1-12 & 1 eyre7 third Joint to eurfaca. Bowopring~ In the oonter of Joint. 1, 2 & ~8, 39 with atop rings. 29 total Mud Weight: PV(prior cond): PV(after cond): YP(pdor cond): YP(after oond): Comments: 10.2 42 24 62 21 Gels before: Gals after. Total Volume Circulated: 22/42 Wll 850 bbla i · Weeh 0 Type: Volume: :Weight: Comments: ARCO 20 8.35 Spacer 0 Type: Volume: Weight: Comments: ARCO Spegar 30 10.5 Le.d Cement 0 Type: I Mix~rtemp: No. of Seeks:I Weight: Yield: ~mts:" ' .. AS III Ute 70 370 10.7 4.43 ,. , Claes G wi 60% 1:)-124, 9.01, D44, 0.4% D45, 50% D5% 1.5% D79 Comments: . Cleee G I AS I 70 258 15.8 1,17 .... · ' ~.. Additives: ' . . ' . Clale G w/1% S1, 0.2% D46, 0.3% D65 Dloplaooment .0 Rate(before tall at ,hoe): Rate(tall around ehoe): · Str, Wt, Up: Comments: . 6 6 115k Reciprocation length: Reciprocation ,pood: Str, Wt, Down: 20 15 fpm 110k Theoretical Displacement: Actual Displacement:. Str. Wt. In mud: 94.66 95.0 Calculated top of. cement: CP: Bumped plug:. Rgats held: Surface Date:;I/1~/99 yes. no Time:22:4S Remarks:Cement Job Went good with full retume thru entire Job. Reciprocated casing unt!1250 bbll Lead gament away. Bumped'plug wi 1125 atrokel (1119 strokes calculated). Fagots did not hold. Pressured up to 1500 pal & shut in cement head WOC 4 hre. Bled off pregaure, Flonti/ooment holding. Celloflalm. game back tste ~ 202 bbls lead cement away (pumped extra Mad cement). 77 bi)la 10.8+ cement returna to aurfece. ICement Company: DS IRig Contractor: POOL ' IAppmved By: Fred Herbert / Rick Overstmet ARCO Alaska, Inc. Casing Detail 7.625" Surface Casing WELL: TARN 2N-309 DATE: 3113199 Subsidiary of Atlantic Richfield Company i OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Pool 6 RT to LR = 34.60' TOP~ Above RKB · 7 5/8" Landing Joint 34.60 · FMC GEN V- Prudhoe 7 5/8" Csg Hgr 2.85 34.60 . Jts 39-62 7 5/8", 29.7#, L-80 BTC-mod (24 jts) 971.40 37.45 TAM 7 5/8" Port Collar 2.48 1008.85 Jts. 3-38 7 5/8", 29.7#, L-80 BTC-mod (~36'~ts~) 1484.70 1011.33 Gemeco Float Collar 1.40 2496.03 jts 1-2 7 5/8", 29.7#, L-80 BTC-mod (2 jts) 84.45 2497.43 . Gemeco Float Shoe 1.50 2581.88 . Casing Shoe @ 2583.38 T.D. @ 2595' leaving 11.62' of rathole , 29 Gemeco Bow Spring CENTRALIZERS . Run centralizers in center of Jts. 1, 2, 38, 39, over stop collars . and over casing collars on 'Jts. 3-12 and over collars of its. 15, 18, 21, 24, 27, 30, 33. 36. 42~ 45, 48, 51, 54, 57.'60. .. , , Joints 63- 73 (11 joints) will remain in the pipe shed;" , ! , , . . · , , , Remarks: String Weights with Blocks: 115K Up, 110K Dn, 70k Blocks. Ran 62 oints of casing. Drifted casing with 6.750" plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Casing is non-coated. Pool 6 Drilling Supervisor: Fred Herbert / Rick Overstreet . 05-Oct-00 AOGCC Lori Taylor 3001 Pomupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2N-349A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 2,477.79' MD 2,520.00' MD 6,498.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) ALASI~A OIL AND GAS CONSERVATION COPlPliSSION James Trantham Drilling Engineering Supervisor Phillips Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re: Kuparuk River Unit 2N-349A Phillips Alaska, Inc. Permit No: 200-139 Sur Loc: 158'FNL, 1172'FEL, Sec. 3, T9N, R7E, UM Btmhole Loc. 207'FSL, 1662'FWL, Sec. 34, T10N, R7E, UM Dear Mr. Trantham: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Please note that any disposal of fluids generated from'this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site 2N must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. .incerely, ~jr. Commissioner BY ORDER OF TItE~, O~V~MISSION DATED this / ¢~ day of September, 2000 t dlf/Enclosures CC: Department of Fish & Gmne, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Phillips Alaska, Inc. [ Post Office Box 100360 Anchorage, Alaska 99510-0360 September 12. 2000 Daniel T. Seamount, Jr., Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 2N-349 A Sidetrack Surface Location: 158' FNL 1172' FEL Sec 3 T9N R7E, UM or ASP4, NAD 27 co,~dinates of X=460,421 & Y=5,911,852 Target Location: 158' FSL, 1955' BEt..~c. 34, T10N, R7E, UM Bottom Hole Location: 207' FSL, 1662' FWL Sec. 34, T10N, R7E, UM Dear Commissioner Seamount, Phillips Alaska, Inc. hereby files this Application for Permit to Drill (Sidetrack) the Tarn development well KRU 2N-349, located approximately seven miles southwest of the Kuparuk River Unit's 2M Drillsite. The original wellbore was drilled to a TD of 6043' MD on 9/12/00 and was determined to not meet our minimum net pay cut-off's for completing the well. A sidetrack location has been chosen which should increase net pay and is located approximately 834' from the current bottom hole location. The sidetrack plan has been discussed with Blair Wondzell. The well is accessed via a new gravel road originating at 2M Pad. Nabors Rig 19e will drill the well. If commercial, the well will also be completed with Nabors 19e. Attached is the information required by 20 AAC 25.005(c). There will be no reserve pit for this well. Waste drilling mud will be disposed of down the annulus of an existing well on Drillsite 2N (subject to AOGCC approval), or hauled to a KRU Class II disposal well. All cuttings generated will be preferentially ground at the on-site ball mill and injected down an approved, existing well annulus on 2N pad or stored temporarily onsite or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be in the Tarn formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, Phillips has not included an H2S contingency plan with this Application, and requests an exemption from the H2S requirements. However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H2S. The following are Phillips' designated contacts for reporting responsibilities to the Commission: 1) Completion Report Sharon AIIsup-Drake, Drilling Technologist 263-4612 (20 AAC 25.070) 2) Geologic Data and Logs Bill Morris, Geologist 263-4588 (20 AAC 25.071) If you have questions or require additional information, please contact Tom Brassfield at 265-6377 or me at 265-6434 in our Anchorage office. ncerely, ~ James Trantham Drilling Engineering Supervisor Phillips Alaska, Inc. is a Subsidiary of Phillips 66 RECEIVED SEP 12 ; 000 Co s. Cemm Daniel T. Seam'b.~nt, Jr. Application for Permit to Drill Page 2 KRU 2N-349 A Sidetrack Attachments cc: KRU 2N-349 A Sidetrack Well File RECEIVED SEP 1 2. ?.000 Alaska 0~t & (~as Cons. Commiss'~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work: Drill r~ Redrill D I lb. Type of well. Exploratory D Stratigraphic Test D Development Oil r~ Re-entry D Deepen r~I Service D Development Gas [-'] Single Zone [~] Multiple Zone r'~ 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. RKB 35 feet i 3. Address 6. Property Designation 3~5"~,75/ ~ Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 380054 ALK 4602 ~ Tarn Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 158' FNL, 1172' FEL, Sec. 3, T9N, R7E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 158' FSL, 1955' FWL, Sec. 34, T10N, R7E, UM 2N 349A #U-630610 At total depth 9. Approximate spud date Amount 207' FSL, 1662' FWL, Sec. 34, T10N, R7E, UM September 12, 2000 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 207 @ TD feetI 2N-335 276' @ 2500' feet 2560 6416' MD / 5696' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 2500 MD Maximum hole angle 35.31 Maximum surface 1872 psig At total depth (TVD) 2400 psig 18. Casing program Settin~l Depth size Specifications Top Bottom Quantity of Cement Hole Casin~l Wei~lht Grade Couplin~l Len~h MD TVD MD TVD linclude sta~le data) 24" 16" 62.5# H-40 Weld 83' 35' 35' 118' 118' 9 cy High Early 9.875" 7.625" 29.7# L-80 BTCM 2295' 35' 35' 2330' 2317' 430 sx AS III L & 240 sx Class 6.75" 5.5" x 15.5# L-80 LTC Mod 5602' 35' 35' 5637' 5060' 600 sx Class G 6.75" 3.5" 9.3# L-80 8rd EUE 779' 5637' 5060' 6416' 5696' see above 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet ORIGINAL Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Intermediate ProductionRECEIVED Perforation depth: measuredSEP 12 : 000 Aia6ka OH & Gas Cons. Commission true verticalAnchorage 20. Attachments Filing fee ~] Property Plat [~ BOP Sketch r~ Diverter Sketch D Drilling program [~] Drilling fl{lid program [~] Time vs depth plot DRefraction analysis F'] Seabed report r~ 20 AAC 25.050 requirements r~ 21. i hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Torn Brassfield265-657, Signed ~j~"Tv,,~,~,~{~~,~/ Title: OrillingEnginee#ngSupe~visor Date ~12.- ~-~' James Trantharn Pr~ared bv Tom Brassfielc Commission Use Onl} Permit Number ~__/,..~4:~ I APInumber 50-/(.~..~'" ~("~.~'- ~ II Appr°valdat~;~'/o/'~--'~,~ ISeec°verletter Ifor other requirements Conditions of approval Samples required D Yes [~ No Mud log required D Yes r~ No Hydrogen sulfide measures [~ Yes ~1~ No Directional survey required ~[~ Yes r-~ No Required working pressure for BOPE D2M; D 3M; D 5M; F'~ lOM;D Other: ORIGINAL SIGNED BY D Taylor Seamount by order of ~, .... Approved by Commissioner the commission Date~'~ ~" jc~ J Form 10-401 Rev. 12/1/85 · Submit in triplicate ,, , ( Phillips Alaska, Inc. . GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD- PRODUCER/Injector KRU 2N-349 A Sidetarck Current wellbore status: Surface casing was set at 2330' MD with full returns to surface. Production hole was drilled to 6043' MD and it was determined that the Bermuda interval did not meet the Phillips minimum net pay cut-off criteria. The Geologists picked the Bermuda interval from 5500' to 5550' MD and noted a 4' sand stringer at 4990' MD. An open hole cement plug was spotted from TD to 4700' MD, and a 300' cement kick-off plug was set from 2795' to 2495' MD. The intent is to sidetrack the wellbore to a new bottom hole location approximately 834' west of the current BHL as follows: . . Drill 6-3/4" or 6-1/2"x7-1/2" hole to TD according to directional plan. Run LWD logging equipment with density and porosity tools. Note: If significant hydrocarbon zones are present above the Tarn, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). Run and cement 5-1/2" L-80 LTC Csg X 3-1/2" L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 3. Pressure test casing to 3,500 psi. . Run 3-1/2" L-80 8rd EUE-Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. 5. Set TWC, ND BOPE and install production tree. 6. Secure well. Rig down and move out. 7. Handover well to Operations Personnel, RECEIVED SEP 12 2000 ;~asKa ~,; ~ ~as Co~s. Commi~s~ Anchorage Phillips Alaska, Inc. { DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2N-349 A Sidetrack Drillinq Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casing point 9.5-10.2 ppg 16-26 25-35 50-120' 10-20 15-40 7-15 9.5-10 _+10% Drill out to TD 9.0 - 11.0 ppg 6-20 5-20 35-50 2-6 4-8 <6 through Tarn 9.0-10 <11% Drillinq Fluid System: Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Degasser IPit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum. anticipated surface pressure (MASP) while drilling the production hole is calculated using a reservoir pressure of 2400 psi at a target mid-point of 5276' TVD. Gas gradient is anticipated to be 0.1 psi/ft. Using this data, the MASP is calculated to be: MASP=((2400/5276)-0.1 )*5276 MASP=1872 psi Therefore PAl will test the BOP equipment to 3500 psi after setting surface casing. Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2N pad are expected to be -2,400 psi (0.49 psi/fi). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.25 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 5276'. Target (Midpoint T2 T3) (2400+150)/(0.052'5276)=9.29. Phillips Alaska, Inc. ( Well Proximity Risks: The nearest well to 2N-349 A Sidetrack is 2N-335. The wells are 275.9' from each other at a depth of 2500' MD. This well does meet with the Phillips ellipse separation criteria. Drillinq Area Risks: Recent information has indicated the possibility of gas migration from the reservoir to a shallower sand interval. However, NO overpressured zones were encountered while drilling 2N-347, 2N-332, 2N-316, 2N-318, or 2N-349 wellbores. Log, tracer, pump-in test, and offest BHPBU evaluations indicate migration has not occurred outside of the wellbore interval and is most likely isolated below the TOC and/or below the Iceberg interval. In the event gas migration has occurred into the Iceberg interval at 4303' TVD, the highest required MW would be 10.7 ppg. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (>4 hr) in pumping operations. The 2N-349 A Sidetarck surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. Following drilling operations, Phillips Alaska, Inc. will submit application for approval of 2N-349 A Sidetarck for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,300') + 1,500 psi Max Pressure = 2,935 psi This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping (.' Phillips Alaska, Inc. ( operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt ,Connection 85% of 85% of OD (ppf) Grade Range iType Collapse Collapse Burst Burst 7-5/8" 29.7 L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 5Y2" 15.5 L-80 3 LTC-Mod 4,990 psi 4,242 psi 7,000 psi 5,950 psi 31/2'' 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi 8,636 psi Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). 2000- 22OO 24-OO 2600 2800 3O00 3200 ~-~ 3~00 ~ 3600 ~D ~800 13 4000 ~ 4200 I~- 4400 I 4600 4800 5000 52O0 54O0 5600 58OO 6OO0 7 5/8 ~ .. Phillips Alaska, Inc. Structure: Tam Or;Il Site 2H Well: 349 Reid: Tam Developmen~ field Location: North Slope, Alaska <- West (feet) 2600 2400 2200 2000 1600 1600 1 400 1200 1000 800 600 400 200 I I I I I I I I I I I I I I I I I I ! I I I I I I Tie Pt - KOP 23.93 26.86 DIS: 5.00 deg per 100 ft 29.79 52.74 EOC 400 I 200 ~ 200 207' FSI_, 1662' FWL 158' FSL, 1955' FWL 147' FNL, 1437' FEL SEC. 54, TION, R7E SEC. ,:34. TION, R7E SEC. 3, T9N, R7E TANGENT ANGLE 35.3 !DEG 278.37 AZIMUTH 177' (TO TARGET) ***Plane of Proposaiee* TRUE T5 Target- Mid Bermuda T2 C35 TD - Casing Pt i i i i i i i i I i i i i i Ii i ii i ii I i i i i i i 0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 VerticalSection (feet)-> Azimuth 278.57 with referenoe 0.00 N, 0.00 E from slot #549 . 0 0 0 0 0 0 0 CD 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 I Structure: Tarn Drill Site 2N Well : 549 IField: Tarn Development Field Location: North Slope, AlaskaI 320 330 340 TRUE NORTH 350 0 10 20 30 4O 310 50 300 60 290 7O 28O 8O 270 90 260 100 25O 110 240 120 230 130 220 210 2OO 190 Normol Plone Trovelling Cylinder - Feet 140 150 180 170 160 All depths shown ore Meosured depths on Reference Well <- North (feet~'" I I I I I I I I I i I I I I ! I , I ~ o ~o <- (.j. eJa~) L,I.I.JON 0 o 8 8/ / / / / o / / / / I I ! / ! ! <- Norfh (feel) (' ol I I I I I I I I % % %. %. % % % % RECEIVED SEP 12. 2000 Alaska Oi{ & Gas Co~s. Commission Anchorage oo <- (1.eej.) ql..~ON Phillips Alaska, Inc. Tarn Drill Site 2N 349 slot #349 Tarn Development Field North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref: 349 Version#1 Our ref: prop404B License : Date printed: 12-Sep-2000 Date created : 11-Sep-2000 Last revised : 11-Sep-2000 Field is centred on n70 12 49.742,w150 18 33.414 Structure is centred on n70 10 13.955,w150 18 32.772 Slot location is n70 10 12.408,w150 19 6.719 Slot Grid coordinates are N 5911852.085, E 460420.841 Slot local coordinates are 157.20 S 1171.81 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <O-12735'>,,347,Tarn Drill Site 2N PMSS <10920 - 11225'>,,331,Tarn Drill Site 2N PMSS <O-8683'>,,332PB1,Tarn Drill Site 2N PMSS <6209 - 12026'>,,332,Tarn Drill Site 2N PMSS <7387 - 8182'>,,325,Tarn Drill Site 2N PMSS <O-8500'>,,317,Tarn Drill Site 2N PMSS <O-12077'>,,335,Tarn Drill Site 2N PMSS <O-9553'>,,323,Tarn Drill Site 2N PMSS <O-7039'>,,319,Tarn Drill Site 2N PMSS <266'-11061'>,,320,Tarn Drill Site 2N PMSS <5303 - 11526'>,,321,Tarn Drill Site 2N PMSS <9235 - lO028'>,,321A,Tarn Drill Site 2N PMSS <8085-8239'>,,339,Tarn Drill Site 2N PMSS <O-10520'>,,308,Tarn Drill Site 2N PMSS <O-8960'>,,307,Tarn Drill Site 2N PMSS <288-8750'>,,309,Tarn Drill Site 2N PMSS <0-12339'>,,341,Tarn Drill Site 2N PMSS <9483 - 9631'>,,343,Tarn Drill Site 2N PMSS <O-7431'>,,345,Tarn Drill Site 2N PMSS <O-9134'>,,313,Tarn Drill Site 2N PMSS <O-9690'>,,329,Tarn Drill Site 2N PMSS <O-10655'>,,337PB1,Tarn Drill Site 2N PMSS <7090-10245'>,,337,Tarn Drill Site 2N PMSS <O-11197'>,,315,Tarn Drill Site 2N PMSS <O-11456'>,,318,Tarn Drill Site 2N PMSS <O-13692'>,,316,Tarn Drill Site 2N PMSS <O-6043'>,,349PB1,Tarn Drill Site 2N Closest approach with .3-D Minimum Distance method Last revised Distance 7-Jun-2000 1025.7 lO-May-2000 933.5 6-Jul-2000 878.1 18-Jul-2000 878.1 21-Dec-lgg8 483.7 14-Aug-1998 774.2 27-0ct-1998 275.9 15-Aug-2000 1026.g g-Oct-lgg8 499.9 9-Feb-lgg9 727.2 2g-Feb-2000 1099.5 21-Dec-1998 1099.5 9-0ct-1998 844.3 24-Feb-1999 1305.1 8-Mar-1999 1226.4 30-Mar-1999 1076.0 30-Sep-1998 979.4 28-Feb-2000 909.6 21-Ju1-1998 634.7 4-Aug-1998 1274.3 lO-May-2000 813.1 27-Jun-2000 678.2 27-Jun-2000 678.2 1B-Jul-2000 1194m7 1-Sep-2000 647.g lO-Aug-2000 968.7 11-Sep-2000 0.0 M,D, 2500 0 2500 0 2500 0 2500 0 2500 0 2500 0 2500 0 2500 0 2500 0 2500 0 2500 0 2500 0 2500 0 2500 0 2500 0 2500.0 25O0 0 2500 0 2500 0 2500 0 25O0 0 2500 0 2500 0 2500 0 2500 0 2500 0 2500.0 Diverging from M.D. 2500.0 2500.0 2500.0 2500.0 2500.0 2500.0 2500.0 2500.0 2500.0 2500,0 2500,0 2500.0 2500.0 2500,0 2500.0 2500.0 2500.0 2500.0 6415.9 2500.0 2500.0 2500.0 2500.0 2500.0 2500.0 2500.0 2500.0 Phillips Alaska. Inc, Tarn Drill Site 2N 349 slot #349 Tarn Development Field North Slope. A1 aska 3-D MINIMUM DISTANCE CLEARANCE REPORT INCLUDING POSITION UNCERTAINTIES Baker Hughes INTEQ Your ref: 349 Version#1 Our ref : prop4048 License : Date printed : 12-Sep-2000 Date created: 11-Sep-2000 Last revised: 11-Sep-2000 Field is centred on n70 12 49.742,w150 18 33.414 Structure is centred on n70 10 13.955,w150 18 32,772 Slot location is n70 10 12.408,w150 19 6.719 Slot Grid coordinates are N 5911852.085, E 460420.841 Slot local coordinates are 157.20 S 1171.81W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 200 feet Proximities will incorporate' ellipses - when survey tools are defined for both wells. Ellipse separation in reverse brackets, e.g. )10.2(, where available. DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath 326 Version~f2,,326,Tarn Drill Site 2N 322 Version#35,,322,Tarn Drill Site 2N 303 Version~5,,303,Tarn Drill Site 2N PMSS <O-12735'>,,347,Tarn Drill Site 2N PMSS <10920 - 11225'>,,331,Tarn Drill Site 2N PMSS <O-8683'>,,332PB1,Tarn Drill Site 2N PMSS <6209 - 12026'>,,332.,Tarn Drill Site 2N PMSS <7387 - 8182'>,,325,Tarn Drill Site 2N PMSS <0-8500'>,,317,Tarn Drill Site 2N PMSS <O-12077'>,,335,Tarn Drill Site 2N PMSS <O-9553'>,,323,Tarn Drill Site 2N PMSS <O-7039'>,,319,Tarn Drill Site 2N PMSS <266'-11061'>,,320,Tarn Drill Site 2N PMSS <5303 - 11526'>,,321,Tarn Drill Site 2N PMSS <9235 - lO028'>,,321A,Tarn Drill Site 2N PMSS <8085-8239'>,,339,Tarn Drill Site 2N PMSS <O-10520'>,,308,Tarn Drill Site 2N PMSS <0-8960'>,,307,Tarn Drill Site 2N PMSS <288-8750'>,,309,Tarn Drill Site 2N Closest approach with 3-D Minimum Distance method Last revised Distance 30-Aug-2000 )971.4( 22-Aug-2000 31-Aug-2000 7-Jun-2000 lO-May-200O 6-Jul-2000 18-Jul-2000 21-Dec-1998 14-Aug-1998 27-0ct-1998 15-Aug-2000 9-0ct-1998 g-Feb-1999 29-Feb-2000 21-Dec-1998 9-0ct-1998 24-Feb-1999 8-Mar-1999 30-Mar-1999 )1247.0( )1511.2( )1011 g( )919 7( )860 5( )860 5( )458 9( )731 9( )23~.1( )g93.1( )457.1( )687.2( )1078 3( )1078 3( )825 5( )1275 8( )1202 4( )1045 9( M.D. Diverging from M.D. 2500.0 2500.0 2500.0 2500.0 2500.0 2500.0 2500.0 2500.0 2500.0 2500.0 2500.0 2500.0 2500.0 2500.0 2500.0, 2500.0 2500.0 2500.0 2500.0 2500.0 2500.0 5965.2 2500.0 2500.0 2500.0 2500.0 2500.0 2500.0 2500,0 2500.0 2500.0 2500.0 2500.0 2500.0 2500.0 2500.0 2500.0 2500.0 PMSS <0-12339'>,,341,Tarn D~'1~ Site 2N PMSS <9483 - 9631'>,.343.Tarn Drill Site 2N PMSS <O-7431'>,,345,Tarn Drill Site 2N PMSS <O-g134'>..313.Tarn Drill Site 2N PMSS <O-96go'>,.329,Tarn Drill Site 2N PMSS <O-10655'>..337PB1,Tarn Drill Site 2N PMSS <7090-10245'>..337,Tarn Drill Site 2N PMSS <O-11197'>,,315,Tarn Drill Site 2N PHSS <O-11456'>,.318.Tarn Drill Site 2N PHSS <O-13692'>.,316.Tarn Drill Site 2N 305 Version#6,.305,Tarn Drill Site 2N PMSS <O-6043'>..34gPB1,Tarn Drill Site 2N 30-Sep-1998 )959.7( 28-Feb-2000 )894.71 21-Ju1-1998 )615.91 4-Aug-1998 )1241.5~ lO-May-2000 )787.9~ 27-Jun-2000 )648.2~ 27-Jun-2000 )648.2~ 18-Jul-2000 )1165.1~ 1-Sep-2000 )617.8 lO-Aug-2000 )931.6 1-Sep-2000 )1448.6( 11-Sep-2000 )O.Ot 2500.~" 2500.0 2500.0 2500.0 2500.0 2500.0 2500.0 2500.0 2500.0 2500.0 2500.0 2755.6 2500.0 2500.0 6415.9 2500.0 2500.0 2500.0 2500.0 6240.0 2500.0 5820.0 2500.0 2755.6 RECEIVED SEP 1 2 2000 Naska ~ & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Tarn Drill Site 2N,349 Tarn Development Field,North Slope, Alaska CLEARANCE LISTING Page 2 Your ref : 349 Version#1 Last revised : 11-Sep-2000 Reference wel 1 path Object wellpath: PMSS <O-6043'>,,349PB1,Tarn Drill Site 2N M.D. T.V.D. Horiz Min'm Ellipse Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 2500.0 2550.0 2600.0 2650.0 2700.0 2469.2 2515.7 2561.6 2607.1 2652.0 11.2N 265.1W 2500.0 2469.2 11.2N 265.1W 90.0 0.0 )0.0( 12.3N 283.6W 2550.0 2515.9 12.1N 283.1W 109.7 0.5 )0.0( 13.8N 303.2W 2600.0 2562.4 13.1N 301.4W 110.9 2.1 )0.0( 15.6N 324.0W 2649.9 2608.8 13.8N 319.7W 113.6 5.0 )0.0( 17.9N 345.9W 2699.7 2655.1 14.2N 337.9W 115.0 9.4 )0.0( 2750.0 2800.0 2850.0 2900.0 2950.0 2696.3 2740.0 2783.0 2825.5 2867.2 20.6N 368.9W 2749.4 2701.4 14.7N 356.2W 115.1 14.9 )0.0( 23.7N 393.0W 2798.9 2747.4 15.1N 374.4W 115.0 21.8 )4.5( 27.2N 418.1W 2848.1 2793.2 15.2N 392.5W 115.2 30.0 )11.8( 31.1N 444.3W 2897.6 2839.1 15.3N 410.8W 115.2 39.5 )20.5( 35.4N 471.6W 2946.9 2884.8 16.1N 429.3W 114.5 49.7 )30.0( 3000.0 3050.0 3100.0 3150.0 3200.0 2908.2 2949.0 2989.8 3030.6 3071.4 40.ON 499.8W 2996.0 2930.2 17.3N 448.0W 113.7 60.7 )40.5( 44.8N 528.3W 3044.7 2975.2 18.6N 466.6W 113.0 72.0 )51.1( 49.6N 556.8W 3093.0 3019.8 19.8N 485.0W 112.5 83.3 )61.9( 54.4N 585.3W 3140.8 3064.1 20.6N 503.0W 112.3 95.1 )72.9( 59.1N 613.8W 3189.0 3108.8 21.0N 521.1W 112.4 107.0 )84.1( 3250.0 3300.0 3350.0 3400.0 3450.0 3112.2 3153.0 3193.8 3234.6 3275.4 63.9N 642.3W 3237.4 3153.7 21.0N 539.2W 112.6 119.2 )95.5( 68.7N 670.8W 3286.2 3199.0 20.9N 557.4W 112.9 131.3 )106.9( 73.5N 699.3W 3335.0 3244.2 20.9N 575.8W 113.0 143.4 )118.1( 78.2N 727.8W 3383.7 3289.3 21.0N 594.1W 113.2 155.3 )129.3( 83.0N 756.3W 3432.4 3334.3 21.0N 612.6W 113.3 167.2 )140.4( 3500.0 3550.0 3600.0 3650.0 3700.0 3316.2 3357.0 3397.8 3438.6 3479.4 87.8N 784.8W 3481.1 3379.3 20.9N 631.1W 113.5 179.1 )151.5( 92.5N 813.3W 3529.2 3423.9 20.8N 649.4W 113.7 191.0 )162.5( 97.3N 841.8W 3576.8 3467.9 20.7N 667.3W 113.7 203.1 )173.8( 102.1N 870.3W 3623.6 3511.5 20.9N 684.5W 113.6 215.5 )185.5( 106.9N 898.8W 3672.0 3556.6 21.1N 702.1W 113.6 228.1 )197.4( All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot#349 and TVD from RKB (Nabors 19E) (153.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 278.37 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Nabors 19e 11" 5,000 PSI BOP COMPONENTS 3" 5,000 psi WP OCT L_ J I I L_ 11" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 11" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom 3" 5,000 psi wP Shaffer GATE VALVE MANUAL GATE V KILL LINE ~r~ 3" 5,000 psi wP Shaffer GATE VALVE ] w/hydraulic actuator I~ / J / DSA 13-5/8" 5,000 psi WP '"~L x 11" 3,000 psi WP ~ r_j [~~~~raulic actuator 11" 5,000 psi WP L--~ ~........ DRILLING SPOOL w/two 3" 5M psi WP outlets J SINGLE 11" 5,000 psi WP, I HYDRIL MPL BOP w/pipe rams WELL PERMIT CHECKLIST COMPANY ~" WELL NAME_~/V~'-~4/~PROGRAM: exp FIELD & POOL 4/~(")/~,.)__~'" INIT CLASS~V "~(.~ Ii/ //'~//' _ GEOL AREA ADMINISTRATION ENGINEERING APPR DATE GEOLOGY DATE Permit fee attached ....................... Lease number appropriate.~..,~.z.-..~.~.,;~o;~. '"~7 '/'~ :' ~/' . 2. 3. Unique well name and,number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... dev v/ redrll serv wellbore seg ann. disposal para req ON/OFF SHORE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~,,~(~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. ~,C~)./__'"',) UNIT# ~)//'/'~::, ~ · N 30. 31. 32. 33. 34. ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... APPR DATE (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N ~N N ~N Is presence of H2S gas probable ................. Y Permit can be issued wlo hydrogen sulfide measures ..... (~,,N- - ' · · · Data presented on potential overpressure zones ....... ~ N Seismic analysis of shallow gas zones ........... ~' I'J~" Y N 'J~ A..~/'[~.~ ~ ~/~--"J~/,'~:~:--- ~'/ /~.. ~_~~ .~~ Seabed condition survey (if off-shore) ........ .~,,~'./Y~ ' Y N /x.,-~.~,.~..,z.~:.~.,/.~.~ ~ ~ ~ ,' .~'./t,,~/ Z,,u -3~ -,~-.-//'~;,~7.~... Contact name/phone for weekly progress repo~s~ploratory only] Y N V N /~'~tS~T t'~P~P~'~-°~' ~)~-~'''~'-~''l~J~¢'"'~ I/~'-/~'z',~-'P--~ "T'HI,.5 t._t3~..z.-I"4JTO Y N ~o~-t~._/~p~p.~¢E4) ~u~-~5o~ (Z/~ ~/~) · Y N Y N Y N GEOLOGY: ENGINEERING: UlClAnnular COMMISSION: Commentsllnstrucfions: Z c:\msoffice\wordian\diana\checklist (rev. 02117/00) ) ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Fri Nov 17 22:27:12 2000 Reel Header Service name ............. LISTPE Date ..................... 00/11/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 00/11/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit (Tarn Pool) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 2 AK-MM-00169 B. HENNINGSE R. SPRINGER 2N-3494 501032034501 Phillips Alaska, Inc. Sperry Sun 17-NOV-00 MWD RUN 3 AK-MM-00169 B. HENNINGSE D. GLADDEN 3 09N 07E 158 1172 153.10 DERRICK FLOOR: 151.77 GROUND LEVEL: 119.30 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 16.000 117.0 6.750 7.625 2330.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL oNLY AND NOT PRESENTED. 3. MWD RUN 2 AND 3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTRO- MAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABLILIZED LITHO- DENSITY (SLD). 4. MWD DATA IS CONSIDERED PDC PER THE E-MAIL FROM D. SCHWARTZ OF PHILLIPS ALASKA, INC., ON 11/13/00. THIS WELL KICKS OFF FROM 2N-349 AT 2520'MD, 2487'TVD, AND IS TIED TO THE PARENT WELLBORE. 5. MWD RUNS 1-3 REPRESENT WELL 2N-349 WITH API#: 50-103-20345-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6498'MD, 5756'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVIT (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: 6.75" MUD WEIGHT: 9.5 - 9.7 PPG MUD SALINITY: 700 PPM CHLORIDES FORMATION WATER SALINITY: 19149 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2297.5 6443.5 RHOB 2320.0 6422.0 NPHI 2320.0 6406.0 NCNT 2320.0 6406.0 DRHO 2320.0 6422.0 PEF 2320.0 6422.0 FCNT 2320.0 6406.5 RPX 2320.5 6450.5 RPS 2320.5 6450.5 RPM 2320.5 6450.5 RPD 2320.5 6450.5 FET 2320.5 6450.5 ROP 2353.5 6498.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 2297.5 2520.0 3 2520.0 6498.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD PU-S 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 RHOB MWD G/CM 4 1 68 DRHO MWD G/CM 4 1 68 PEF MWD BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit Min Max DEPT FT 2297.5 6498 ROP MWD FT/H 1.4 766.88 GR MWD API 48.38 256 RPX MWD OHMM 0.55 386.35 RPS MWD OHMM 0.54 1413.99 RPM MWD OHMM 0.69 2000 RPD MWD OHMM 0.56 1939.78 FET MWD HOUR 0.33 112.81 NPHI MWD PU-S 10.53 67.51 FCNT MWD CNTS 97 907.3 NCNT MWD CNTS 12414.6 36198.3 RHOB MWD G/CM 1.813 3.315 Mean 4397.75 117.343 143.465 3.82732 3.96967 5.41383 4.80926 1.16939 34.5769 264.08 19521.1 2.34485 Nsam 8402 8290 8293 8261 8261 8261 8261 8261 8173 8174 8173 8205 First Reading 2297.5 2353.5 2297.5 2320.5 2320.5 2320.5 2320.5 2320.5 2320 2320 2320 2320 Last Reading 6498 6498 6443.5 6450.5 6450.5 6450.5 6450.5 6450.5 6406 6406.5 6406 6422 DRHO MWD G/CM -0.165 0.855 PEF MWD BARN 0.76 14.65 0.0666661 8205 2.83172 8205 2320 2320 6422 6422 First Reading For Entire File .......... 2297.5 Last Reading For Entire File ........... 6498 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER:. 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 2297.5 PEF 2320.0 DRHO 2320.0 RHOB 2320.0 NCNT 2320.0 FCNT 2320.0 NPHI 2320.0 RPD 2320.5 FET 2320.5 RPM 2320.5 RPS 2320.5 RPX 2320.5 ROP 2353.5 $ LOG HEADER DATA DATE LOGGED: STOP DEPTH 2520.0 2520.0 2520 0 2520 0 2520 0 2520 0 2520 0 2520 0 2520.0 2520.0 2520.0 2520.0 2520.0 10=SEP-00 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE DGR EWR4 CTN SLD $ TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMP THERMAL NEUTRON STABILIZED LITHO DEN BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (,IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Insite 0.41 Memory 2520.0 18.7 22.6 TOOL NUMBER PB01630GR4 PB01630GR4 PB01630GR4 PB01630GR4 6.750 2330.0 LSND 9.70 45.0 9.9 500 3.6 2.000 1.110 1.900 2.200 78.0 146.0 78.0 78.0 Depth Units ....................... Datum Specification Block sub-type.. Name DEPT ROP GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF Service Order Units Size Nsam Rep FT 4 1 68 MWD020 FT/H 4 1 68 MWD020 API 4 1 68 MWD020 OHMM 4 1 68 MWD020 OHMM 4 1 68 MWD020 OHMM 4 1 68 MWD020 OHMM 4 1 68 MWD020 HOUR 4 1 68 MWD020 PU-S 4 1 68 MWD020 CNTS 4 1 68 MWD020 CNTS 4 1 68 MWD020 G/CM 4 1 68 MWD020 G/CM 4 1 68 MWD020 BARN 4 1 68 .0 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit DEPT FT ROP MWD020 FT/H GR MWD020 API RPX MWD020 OHMM RPS MWD020 OHMM RPM MWD020 OHMM RPD MWD020 OHMM FET MWD020 HOUR .NPHI MWD020 PU-S FCNT MWD020 CNTS NCNT MWD020 CNTS RHOB MWD02,0 G/CM DRHO MWD020 G/CM PEF MWD020 BARN Min 2297.5 1 66 48 38 0 55 0 54 0 69 0 56 0 33 31.78 97 12414.6 1.985 -0.049 3.17 Max 2520 576.55 172.84 386.35 1413.99 2000 1939.78 54.03 59.32 280.9 20566 3.027 0.747 14.65 Mean 2408.75 142.777 116.176 5.9167 9.29702 39.4262 24.7973 6.04397 41.9224 170.627 16245.9 2.20522 0.109185 5.00835 Nsam 446 334 446 400 400 400 400 400 401 401 401 401 401 401 First Reading 2297.5 2353.5 2297.5 2320.5 2320.5 2320.5 2320.5 2320.5 2320 2320 2320 2320 2320 2320 Last Reading 2520 2520 2520 2520 2520 2520 2520 2520 2520 2520 2520 2520 2520 2520 First Reading For Entire File .......... 2297.5 Last Reading For Entire File ........... 2520 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. 3 .5000 BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE RPM PEF ROP GR RPS RPD FET NPHI FCNT NCNT RHOB DRHO RPX $ LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH STOP DEPTH 2520.5 6450.5 2520.5 6422.0 2520.5 6498.0 2520.5 6443.5 2520.5 6450.5 2520.5 6450.5 2520.5 6450.5 2520.5 6406.0 2520.5 6406.5 2520.5 6406.0 2520.5 6422.0 2520.5 6422.0 2520.5 6450.5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : MOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE DGR EWR4 CTN SLD $ TOOL TYPE DUAL GAMMA Pd%Y ELECTROMAG. RESIS. 4 COMP THERMAL NEUTRON STABILIZED LITHO DEN BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 15-SEP-00 Insite 0.41 Memory 6498.0 22.8 36.9 TOOL NUMBER PB01630GR4 PB01630GR4 PB01630GR4 PB01630GR4 6.750 DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ' Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 2330.0 LSND 9.60 42.0 10.9 500 9.0 2.050 1.111 1.850 2.100 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT, ROP MWD030 GR MWD030 RPX MWD030 RPS MWD030 RPM MWD030 RPD MWD030 FET MWD030 NPHI MWD030 FCNT MWD030 NCNT MWD030 RHOB MWD030 DRHO MWD030 PEF MWD030 FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 OHMM 4 1 68 20 6 OHMM 4 1 68 24 7 HOUR 4 1 68 28 8 PU-S 4 1 68 32 9 CNTS 4 1 68 36 10 CNTS 4 1 68 40 11 G/CM 4 1 68 44 12 G/CM 4 1 68 48 13 BARi~ 4 1 68 52 14 72.0 138.6 72.0 72.0 First Last Name Service Unit Min Max DEPT FT 2520.5 6498 ROP MWD030 FT/H 1.4 766.88 GR MWD030 API 68.57 256 RPX MWD030 OHMM 0.96 20.07 RPS MWD030 OHMM 0.97 19.64 RPM MWD030 OHMM 1 18.59 RPD MWD030 OHMM 1.05 15.32 FET MWD030 HOUR 0.4 112.81 NPHI MWD030 PU-S 10.53 67.51 FCNT MWD030 CNTS 120.9 907.3 NCNT MWD030 CNTS 14139 36198.3 RHOB MWD030 G/CM 1.813 3.315 DRHO MWD030 G/CM -0.165 0.855 PEF MWD030 BARN 0.76 4.45 Mean Nsam Reading Reading 4509.25 7956 2520.5 6498 116.275 7956 2520.5 6498 145.016 7847 2520.5 6443.5 3.721 7861 2520.5 6450.5 3.69859 7861 2520.5 6450.5 3.68314 7861 2520.5 6450.5 3.79218 7861 2520.5 6450.5 0.921356 7861 2520.5 6450.5 34.1979 7772 2520.5 6406 268.901 7773 2520.5 6406.5 19690.1 7772 2520.5 6406 2.35202 7804 2520.5 6422 0.0644813 7804 2520.5 6422 2.71988 7804 2520.5 6422 First Reading For Entire File .......... 2520.5 Last Reading For Entire File ........... 6498 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/11/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN. Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/11/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File
